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 November, 2024

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 nine months ended September 30, 2024, 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. 333-226663), Form S-8 (File No. 333-236213), Form F-3 (File No. 333-249039), Form F-3 (File No. 333-279253), Form F-10 (File No. 333-268493), Form S-8 (File No. 333-264838), Form S-8 (File No. 333-276111) and Form S-8 (File No. 333-276112), and Form S-8 (File No. 333-281205).











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: November 5, 2024/s/ Jocelyn H. Perry
By: Jocelyn H. Perry
Title:Executive Vice President, Chief Financial Officer





Exhibit 99.1
fortislogo.jpg

St. John's, NL - November 5, 2024

FORTIS INC. RELEASES THIRD QUARTER 2024 RESULTS

This news release constitutes a "Designated News Release" incorporated by reference in the prospectus supplement
dated September 19, 2023 to Fortis' short form base shelf prospectus dated November 21, 2022.

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 third quarter results.1

Highlights
•Third quarter net earnings of $420 million or $0.85 per common share, up from $394 million or $0.81 per common share in 2023
•Adjusted net earnings per common share2 of $0.85, up from $0.84 in the third quarter of 2023
•Capital expenditures2 of $3.6 billion through September; capital expenditures of $5.2 billion expected for 2024
•Released 2025-2029 capital plan of $26 billion, representing 6.5% average annual rate base growth
•MISO's long-range transmission plan continues to advance; ITC expects at least US$3.0 billion of investments for tranche 2.1
•Declared 4.2% increase in fourth quarter common share dividend

"Our strong third quarter results reflect the growth of our utilities as they continue to execute their capital programs," said David Hutchens, President and Chief Executive Officer, Fortis. "In September, our Board of Directors declared a 4.2% increase in the fourth quarter dividend that will mark 51 years of consecutive increases in dividends paid. We remain committed to our regulated growth strategy, focused on annual dividend growth of 4-6% through 2029 for shareholders, while delivering affordable and reliable energy to our customers."

Net Earnings
The Corporation reported net earnings attributable to common equity shareholders ("Net Earnings") of $420 million for the third quarter of 2024, or $0.85 per common share, an increase of $26 million, or $0.04 per common share compared to the third quarter of 2023. The increase was driven by rate base growth across our utilities, and strong earnings in Arizona largely reflecting new customer rates at Tucson Electric Power ("TEP") effective September 1, 2023. Unrealized gains on derivative contracts recognized in the third quarter of 2024, as well an unfavourable deferred income tax adjustment recognized by ITC in the third quarter of 2023, also contributed to earnings growth. The increase was partially offset by the timing of recognition of new cost of capital parameters approved for FortisBC in 2023 as well as higher holding company finance costs.

On a year-to-date basis, Net Earnings were $1.2 billion, or $2.45 per common share, an increase of $85 million, or $0.13 per common share compared to the same period in 2023. The increase was due to rate base growth, higher earnings in Arizona, unrealized gains on derivative contracts, and the unfavourable deferred income tax adjustment recognized by ITC in 2023, as discussed above. Growth was partially offset by higher operating costs at Central Hudson, higher holding company finance costs, and the November 1, 2023 disposition of Aitken Creek. Although the disposition of Aitken Creek was unfavourable in comparison to the same period in 2023, the impact will be neutral for the annual period.

The change in earnings per share for both the third quarter and year-to-date periods also reflected an increase in the weighted average number of common shares outstanding, largely associated with the Corporation's dividend reinvestment plan.

Adjusted Net Earnings2
There were no adjustments to Net Earnings for the three and nine months ended September 30, 2024. For the three and nine months ended September 30, 2023, favourable adjustments totaling $17 million and $27 million, respectively, were recognized to Net Earnings related to the mark-to-market accounting of natural gas derivatives at Aitken Creek and the revaluation of deferred income tax assets at ITC.


____________________
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 ("U.S. GAAP") 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



Capital Expenditures2
Capital expenditures for 2024 are expected to be approximately $5.2 billion, up from $4.8 billion previously anticipated for the year. The increase is driven by the timing of expenditures associated with the Eagle Mountain Pipeline project at FortisBC Energy and a higher forecast U.S.-to-Canadian dollar exchange rate. The annual capital program is on track with $3.6 billion invested through September.

In August 2024, TEP announced the development of the Roadrunner Reserve 2 battery energy storage system facility. The 200 megawatt ("MW") system will store 800 MW hours of energy, enough to serve approximately 42,000 homes for four hours when deployed at full capacity. TEP will own and operate the system, which is included in the Corporation's five-year capital plan, has a total project cost of more than $400 million and is scheduled for completion in 2026.

The Corporation's new 2025-2029 capital plan totals $26 billion, $1.0 billion higher than the previous five-year plan. The increase is driven by projects associated with the Midcontinent Independent System Operator ("MISO") long-range transmission plan ("LRTP") and resiliency investments at ITC, as well as distribution investments largely due to customer growth at FortisAlberta. The plan is low-risk and highly executable, with nearly all investments being regulated and only 23% relating to major capital projects.

The five-year capital plan is expected to be funded primarily by cash from operations and regulated debt. Common equity proceeds are expected to be provided by the Corporation's dividend reinvestment plan, assuming current participation levels. The Corporation's $500 million at-the-market common equity program remains available and provides funding flexibility as required.

Significant opportunities remain beyond the five-year plan, including incremental investments associated with the MISO LRTP. Based on the final portfolio provided by MISO in September 2024, and subject to MISO Board approval anticipated in December 2024, ITC estimates at least US$3 billion in capital expenditures for the MISO LRTP tranche 2.1 projects located in Michigan and Minnesota where rights of first refusal are in effect. The majority of this investment is expected beyond 2029.

Regulatory Updates
In August 2024, Central Hudson filed a general rate application with the New York State Public Service Commission ("PSC") requesting new customer rates effective July 1, 2025. The timing and outcome of this proceeding is unknown.

In August 2024, MISO concluded its variance analysis associated with LRTP tranche 1 projects in Iowa, reaffirming the original allocation of projects, including the allocation to ITC. As a result, work on all ITC tranche 1 projects in Iowa has resumed. The variance analysis was conducted by MISO as a result of the inability to construct LRTP tranche 1 projects in Iowa due to ongoing legal proceedings. Total tranche 1 investments of US$1.2 billion are included in the 2025-2029 capital plan, with approximately US$800 million located in Iowa.

In October 2024, the Federal Energy Regulatory Commission ("FERC") issued an order in response to the 2022 D.C. Circuit Court decision vacating certain FERC orders that had established the methodology for setting the base return on equity ("ROE") for transmission owners operating in the MISO region, including ITC. The order revised the base ROE of ITC's MISO utilities from 10.02% to 9.98% and also directed the payment of certain refunds, with interest, by December 1, 2025. The application of the order will result in a regulatory liability of approximately $35 million (US$26 million) to be recognized by ITC in the fourth quarter of 2024. Fortis' 80.1% share of the related after-tax earnings impact will be approximately $22 million, of which the vast majority relates to periods prior to January 1, 2024.

In October 2024, the PSC issued a Show Cause Order which directed Central Hudson to explain why the PSC should not initiate a proceeding in connection with a gas-related explosion that occurred in November 2023. Central Hudson will file a response to the order within 30 days.

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. The Corporation's $26 billion five-year capital plan is expected to increase midyear rate base from $38.8 billion in 2024 to $53.0 billion by 2029, translating into a five-year compound annual growth rate of 6.5%.3

Beyond the five-year capital plan, 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, transmission investments associated with the MISO LRTP tranches 1, 2.1 and 2.2 as well as regional transmission in New York; climate adaptation and grid resiliency investments; renewable gas solutions and liquefied natural gas infrastructure in British Columbia; and the acceleration of cleaner energy infrastructure and load growth investments across our jurisdictions.

____________________
3    Calculated using a constant United States dollar-to-Canadian dollar exchange rate.
ii



Fortis expects its long-term growth in rate base will drive earnings that support dividend growth guidance of 4-6% annually through 2029, and is premised on the assumptions and material factors listed under "Forward-Looking Information".

Fortis is on track to achieve its corporate-wide targets to reduce direct greenhouse gas ("GHG") emissions by 50% by 2030 and 75% by 2035 from a 2019 base year. The Corporation's additional 2050 net-zero direct GHG emissions target reinforces Fortis' commitment to further decarbonize over the long-term, while continuing our focus on reliability and affordability.


Non-U.S. GAAP Reconciliation
Periods ended September 30QuarterYear-to-Date
($ millions, except earnings per share)2024 2023 Variance2024 2023 Variance
Adjusted Net Earnings
Net Earnings420 394 26 1,210 1,125 85 
Adjusting items:
Unrealized loss on mark-to-market of derivatives at Aitken Creek4
— 8 (8)— 18 (18)
Revaluation of deferred income tax assets5
— 9 (9)— 9 (9)
Adjusted Net Earnings420 411 9 1,210 1,152 58 
Adjusted net earnings per share ($)
0.85 0.84 0.01 2.45 2.37 0.08 
Capital Expenditures
Additions to property, plant and equipment1,248 952 296 3,383 2,797 586 
Additions to intangible assets52 31 21 142 122 20 
Adjusting item:
Wataynikaneyap Transmission Power Project6
— 25 (25)29 109 (80)
Capital Expenditures1,300 1,008 292 3,554 3,028 526 

About Fortis
Fortis is a well-diversified leader in the North American regulated electric and gas utility industry with 2023 revenue of $12 billion and total assets of $70 billion as at September 30, 2024. The Corporation's 9,600 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 news 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 2024 and 2025 through 2029; forecast rate base and rate base growth through 2029; targeted annual dividend growth through 2029; the expected impact of the disposition of Aitken Creek on earnings for the annual period; the nature, timing, benefits and expected costs of certain capital projects, including FortisBC Energy's Eagle Mountain Pipeline project, ITC's transmission projects associated with the MISO LRTP, TEP's Roadrunner Reserve 2 battery energy storage system facility and additional opportunities beyond the capital plan, including further expansion of the electric transmission grid in the U.S. to facilitate the interconnection of cleaner energy, transmission investments associated with the MISO LRTP tranches 1, 2.1 and 2.2 as well as regional transmission in New York, climate adaptation and grid resiliency investments, renewable gas solutions and liquefied natural gas infrastructure in British Columbia, and the acceleration of cleaner energy infrastructure and load growth investments across our jurisdictions; the expected timing, outcome and impact of legal and regulatory proceedings and decisions; the expected sources of funding for the capital plan, including the expected source of common equity proceeds; the expectation that long-term growth in rate base will drive earnings that support dividend growth guidance of 4-6% annually through 2029; the 2030 and 2035 GHG emissions reduction targets; and the 2050 net-zero direct GHG emissions target.

____________________
4    Represents the mark-to-market accounting of natural gas derivatives at Aitken Creek, net of income tax recovery of $3 million and $7 million for the three and nine months ended September 30, 2023, respectively. The sale of Aitken Creek closed on November 1, 2023.
5    Represents the revaluation of deferred income tax assets resulting from the reduction in the corporate income tax rate in the state of Iowa.
6    Represents Fortis' 39% share of capital spending during the construction of the Wataynikaneyap Transmission Power Project. Construction was completed in the second quarter of 2024.
iii



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: reasonable outcomes for legal and 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; the continuation of current participation levels in the Corporation's dividend reinvestment plan; 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 news 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 Third Quarter 2024 Results
A teleconference and webcast will be held on November 5, 2024 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 third 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, https://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 1.800.717.1738 while those outside of North America can participate by calling 1.289.514.5100. 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 two hours after the conclusion of the call until December 5, 2024. Please call 1.888.660.6264 or 1.289.819.1325 and enter passcode 33826#.

Additional Information
This news release should be read in conjunction with the Corporation's September 30, 2024 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 EnquiriesMedia Enquiries
Ms. Stephanie AmaimoMs. Karen McCarthy
Vice President, Investor RelationsVice President, Communications & Government Relations
Fortis Inc.Fortis Inc.
248.946.3572709.737.5323
investorrelations@fortisinc.commedia@fortisinc.com
iv

Exhibit 99.2
Interim Financial Statements











FORTIS INC.

Condensed Consolidated Interim Financial Statements
For the three and nine months ended September 30, 2024 and 2023
(Unaudited)
1
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Interim Financial Statements
CONDENSED CONSOLIDATED INTERIM BALANCE SHEETS (Unaudited)
FORTIS INC.
September 30,December 31,
As at (in millions of Canadian dollars)20242023
ASSETS
Current assets
Cash and cash equivalents$896 $625 
Accounts receivable and other current assets (Note 5)1,690 1,818 
Prepaid expenses233 150 
Inventories 607 566 
Regulatory assets (Note 6)787 866 
Total current assets4,213 4,025 
Other assets 1,361 1,298 
Regulatory assets (Note 6)3,767 3,518 
Property, plant and equipment, net46,330 43,385 
Intangible assets, net 1,555 1,510 
Goodwill 12,416 12,184 
Total assets$69,642 $65,920 
LIABILITIES AND EQUITY
Current liabilities
Short-term borrowings (Note 7)$97 $119 
Accounts payable and other current liabilities 3,098 2,972 
Regulatory liabilities (Note 6)666 577 
Current installments of long-term debt (Note 7)1,866 2,296 
Total current liabilities5,727 5,964 
Regulatory liabilities (Note 6)3,444 3,381 
Deferred income taxes 4,744 4,399 
Long-term debt (Note 7)29,708 27,235 
Finance leases347 339 
Other liabilities 1,279 1,270 
Total liabilities45,249 42,588 
Commitments and contingencies (Note 15)
Equity
Common shares (1)
15,466 15,108 
Preference shares1,623 1,623 
Additional paid-in capital8 9 
Accumulated other comprehensive income969 653 
Retained earnings4,433 4,112 
Shareholders' equity22,499 21,505 
Non-controlling interests 1,894 1,827 
Total equity24,393 23,332 
Total liabilities and equity$69,642 $65,920 
(1)    No par value. Unlimited authorized shares. 497.3 million and 490.6 million issued and outstanding as at September 30, 2024 and December 31, 2023, respectively.
See accompanying Notes to Condensed Consolidated Interim Financial Statements
2
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Interim Financial Statements
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF EARNINGS (Unaudited)
FORTIS INC.
QuarterYear-to-Date
For the periods ended September 30 (in millions of Canadian dollars, except per share amounts)
2024 2023 2024 2023 
Revenue $2,771 $2,719 $8,559 $8,632 
Expenses
Energy supply costs737 773 2,459 2,872 
Operating expenses740 682 2,245 2,136 
Depreciation and amortization480 443 1,427 1,319 
Total expenses1,957 1,898 6,131 6,327 
Operating income814 821 2,428 2,305 
Other income, net (Note 11)102 47 240 180 
Finance charges 355 331 1,038 969 
Earnings before income tax expense561 537 1,630 1,516 
Income tax expense83 92 253 241 
Net earnings$478 $445 $1,377 $1,275 
Net earnings attributable to:
Non-controlling interests$39 $34 $112 $100 
Preference equity shareholders (Note 8)19 17 55 50 
Common equity shareholders420 394 1,210 1,125 
$478 $445 $1,377 $1,275 
Earnings per common share (Note 12)
Basic$0.85 $0.81 $2.45 $2.32 
Diluted$0.85 $0.81 $2.45 $2.32 
See accompanying Notes to Condensed Consolidated Interim Financial Statements

CONDENSED CONSOLIDATED INTERIM STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)
QuarterYear-to-Date
For the periods ended September 30 (in millions of Canadian dollars)
2024 2023 2024 2023 
Net earnings$478 $445 $1,377 $1,275 
Other comprehensive income (loss)
Unrealized foreign currency translation gains (losses) (1)
(211)421 358 38 
Other (2)
(2)1 (4)4 
(213)422 354 42 
Comprehensive income$265 $867 $1,731 $1,317 
Comprehensive income attributable to:
Non-controlling interests$18 $79 $150 $104 
Preference equity shareholders19 17 55 50 
Common equity shareholders228 771 1,526 1,163 
$265 $867 $1,731 $1,317 
(1)Net of hedging activities and income tax expense of $2 million and recovery of $5 million for the three and nine months ended September 30, 2024, respectively (three and nine months ended September 30, 2023 - income tax recovery of $7 million and $1 million, respectively)
(2)Net of income tax recovery of Snil and $1 million for the three and nine months ended September 30, 2024 (three and nine months ended September 30, 2023 - income tax expense of $2 million and $4 million, respectively)
See accompanying Notes to Condensed Consolidated Interim Financial Statements
3
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Interim Financial Statements
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CASH FLOWS (Unaudited)
FORTIS INC.
QuarterYear-to-Date
For the periods ended September 30 (in millions of Canadian dollars)
2024 2023 2024 2023 
Operating activities
Net earnings$478 $445 $1,377 $1,275 
Adjustments to reconcile net earnings to net cash provided by operating activities:
Depreciation - property, plant and equipment424 386 1,254 1,145 
Amortization - intangible assets37 37 114 113 
Amortization - other19 20 59 61 
Deferred income tax expense61 64 112 119 
Equity component, allowance for funds used during construction (Note 11)
(37)(25)(99)(71)
Other17 48 39 97 
Change in long-term regulatory assets and liabilities88 (2)(12)(84)
Change in working capital (Note 13)251 (33)76 144 
Cash from operating activities1,338 940 2,920 2,799 
Investing activities
Additions to property, plant and equipment(1,248)(952)(3,383)(2,797)
Additions to intangible assets(52)(31)(142)(122)
Contributions in aid of construction30 17 81 88 
Contributions to equity-accounted investees— (24)— (24)
Other(43)(50)(155)(139)
Cash used in investing activities(1,313)(1,040)(3,599)(2,994)
Financing activities
Proceeds from long-term debt, net of issuance costs (Note 7)1,190 229 2,608 2,110 
Repayments of long-term debt and finance leases(413)(97)(1,109)(794)
Borrowings under committed credit facilities2,368 1,290 6,096 5,165 
Repayments under committed credit facilities (2,642)(1,071)(5,972)(5,009)
Net change in short-term borrowings30 (5)(22)(170)
Issue of common shares, net of costs and dividends reinvested13 6 34 34 
Dividends

Common shares, net of dividends reinvested(186)(175)(549)(517)

Preference shares(19)(17)(55)(50)

Subsidiary dividends paid to non-controlling interests(32)(24)(86)(64)
Other7 14 (6)42 
Cash from financing activities316 150 939 747 
Effect of exchange rate changes on cash and cash equivalents(6)15 11 13 
Change in cash and cash equivalents335 65 271 565 
Change in cash associated with assets held for sale— 10 — (9)
Cash and cash equivalents, beginning of period561 690 625 209 
Cash and cash equivalents, end of period$896 $765 $896 $765 
Supplementary Cash Flow Information (Note 13)
See accompanying Notes to Condensed Consolidated Interim Financial Statements

4
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Interim Financial Statements
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CHANGES IN EQUITY (Unaudited)
FORTIS INC.
For the three months ended September 30
(in millions of Canadian dollars, except share numbers)
Common Shares
(# millions)
Common SharesPreference Shares Additional Paid-In CapitalAccumulated Other Comprehensive Income (Loss)Retained EarningsNon-Controlling InterestsTotal Equity
As at June 30, 2024495.2 $15,346 $1,623 $8 $1,161 $4,611 $1,908 $24,657 
Net earnings— — — — — 439 39 478 
Other comprehensive loss— — — — (192)— (21)(213)
Common shares issued2.1 120 — — — — — 120 
Subsidiary dividends paid to non-controlling interests— — — — — — (32)(32)
Dividends declared on common shares ($1.205 per share)
— — — — — (598)— (598)
Dividends on preference shares— — — — — (19)— (19)
As at September 30, 2024497.3 $15,466 $1,623 $8 $969 $4,433 $1,894 $24,393 
As at June 30, 2023486.4 $14,889 $1,623 $8 $669 $4,190 $1,798 $23,177 
Net earnings— — — — — 411 34 445 
Other comprehensive income— — — — 377 — 45 422 
Common shares issued2.1 105 — — — — — 105 
Subsidiary dividends paid to non-controlling interests— — — — — — (24)(24)
Dividends declared on common shares ($1.155 per share)
— — — — — (564)— (564)
Dividends on preference shares— — — — — (17)— (17)
Other— — — 1 — — 1 2 
As at September 30, 2023488.5 $14,994 $1,623 $9 $1,046 $4,020 $1,854 $23,546 
See accompanying Notes to Condensed Consolidated Interim Financial Statements
5
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Interim Financial Statements
CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CHANGES IN EQUITY (Unaudited)
FORTIS INC.
For the nine months ended September 30
(in millions of Canadian dollars, except share numbers)
Common Shares
(# millions)
Common SharesPreference SharesAdditional Paid-In CapitalAccumulated Other Comprehensive IncomeRetained EarningsNon-Controlling InterestsTotal Equity
As at December 31, 2023
490.6 $15,108 $1,623 $9 $653 $4,112 $1,827 $23,332 
Net earnings— — — — — 1,265 112 1,377 
Other comprehensive income— — — — 316 — 38 354 
Common shares issued6.7 358 — — — — — 358 
Subsidiary dividends paid to non-controlling interests— — — — — — (86)(86)
Dividends declared on common shares ($1.795 per share)
— — — — — (889)— (889)
Dividends on preference shares— — — — — (55)— (55)
Other— — — (1)— — 3 2 
As at September 30, 2024497.3 $15,466 $1,623 $8 $969 $4,433 $1,894 $24,393 
As at December 31, 2022
482.2 $14,656 $1,623 $10 $1,008 $3,733 $1,812 $22,842 
Net earnings— — — — — 1,175 100 1,275 
Other comprehensive income— — — — 38 — 4 42 
Common shares issued6.3 338 — (1)— — — 337 
Subsidiary dividends paid to non-controlling interests— — — — — — (64)(64)
Dividends declared on common shares ($1.72 per share)
— — — — — (838)— (838)
Dividends on preference shares— — — — — (50)— (50)
Other— — — — — — 2 2 
As at September 30, 2023488.5 $14,994 $1,623 $9 $1,046 $4,020 $1,854 $23,546 
See accompanying Notes to Condensed Consolidated Interim Financial Statements
6
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
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; (ii) the impact of market conditions, particularly with respect to long-term wholesale sales at UNS Energy; (iii) changes in the U.S.-to-Canadian dollar exchange rate; 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 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
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. Consists of non-regulated holding company expenses, as well as non-regulated long-term contracted generation assets in Belize. Also includes results for the Aitken Creek natural gas storage facility ("Aitken Creek") until the November 1, 2023 date of disposition.


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 ("2023 Annual Financial Statements"). A summary of significant outstanding regulatory matters follows.

ITC
MISO Base ROE: In 2022, the U.S. Court of Appeals for the District of Columbia Circuit issued a decision vacating certain Federal Energy Regulatory Commission ("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, and remanded the matter to FERC for further process. This matter dates back to complaints filed at FERC in 2013 and 2015 challenging the MISO base ROE then in effect.

In October 2024, FERC issued an order that removed the use of the risk premium model from the calculation of the base ROE, while maintaining other modifications to the methodology. The updated methodology revised the base ROE from 10.02% to 9.98%, with a maximum ROE inclusive of incentives not to exceed 12.58%. The order also directed the payment of certain refunds, with interest, by December 2025, for the 15-month period from November 2013 through February 2015, and prospectively from September 2016. The application of the order will result in a regulatory liability of approximately $35 million (US$26 million) to be recognized by ITC in the fourth quarter of 2024.

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 remain unknown.

Transmission Right of First Refusal ("ROFR"): In December 2023, the Iowa District Court ruled that the manner in which Iowa's ROFR statute was passed is unconstitutional. The statute granted incumbent electric transmission owners, including ITC, a ROFR to construct, own and maintain certain electric transmission assets in the state. The District Court did not make any determination on the merits of the ROFR itself, but did issue a permanent injunction preventing ITC and others from taking further action to construct the MISO long-range transmission plan ("LRTP") tranche 1 Iowa projects in reliance on the ROFR.

7
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
2. REGULATORY MATTERS (cont'd)

In May 2024, MISO commenced a variance analysis process as a result of the inability to construct a portion of the tranche 1 LRTP projects in Iowa due to the injunction imposed by the District Court. In August 2024, MISO concluded the variance analysis, which reaffirmed the original allocation of projects to ITC and other incumbent transmission owners. While the results of MISO's variance analysis process allow ITC to move forward with the development of its portion of tranche 1 LRTP projects in Iowa, various legal proceedings with respect to this matter are ongoing for which the timing and outcome are unknown.

Central Hudson
2024 General Rate Application: In July 2024, the New York State Public Service Commission ("PSC") approved a one-year rate plan for Central Hudson with retroactive application to July 1, 2024, including an allowed ROE of 9.5%, an increase from the previous allowed ROE of 9.0%. The decision also maintained the 48% common equity component of capital structure.

Customer Information System ("CIS") Implementation: In June 2024, the PSC issued an order that concluded the investigation concerning Central Hudson's billing system implementation. The PSC also released the final report issued by an independent third-party which determined that the CIS is stable and the critical issues have been resolved. As part of the order, total costs of US$63 million were agreed to not be recovered from customers, of which the majority were recognized prior to 2024. The remaining costs associated with the order, including Central Hudson's US$4 million contribution to a customer benefit fund recognized in the second quarter of 2024, are not expected to be material.

2025 General Rate Application: In August 2024, Central Hudson filed a general rate application with the PSC requesting an increase in electric and gas delivery rates effective July 1, 2025. The application includes a request to set Central Hudson's allowed ROE at 10% and a 48% common equity component of capital structure. The timing and outcome of this proceeding are unknown.

Show Cause Order: In October 2024, the PSC issued a Show Cause Order which directed Central Hudson to explain why the PSC should not initiate an enforcement proceeding in connection with a gas-related explosion that occurred in November 2023. Central Hudson will file a response to the order within 30 days. The timing and outcome of this proceeding are unknown.

FortisBC Energy and FortisBC Electric
2025-2027 Rate Framework: In April 2024, FortisBC filed an application with the British Columbia Utilities Commission requesting approval of a rate framework for the period 2025 through 2027. The rate framework builds upon the current multi-year rate plan and includes, amongst other items, a revised level of operation and maintenance expense per customer indexed for inflation less a fixed productivity adjustment factor, a similar approach to growth capital, a forecast approach to sustaining and other capital, continued collection of an innovation fund recognizing the need to accelerate investment in clean energy innovation, and the continued sharing with customers of variances from the allowed ROE. The rate framework also proposes the continuation of deferral mechanisms currently in place. The regulatory process will continue throughout 2024, with a decision expected in mid-2025.

FortisAlberta
Generic Cost of Capital ("GCOC") Decision: In October 2023, the Alberta Utilities Commission ("AUC") issued a decision on the 2024 GCOC proceeding. In November 2023, FortisAlberta sought permission to appeal the GCOC decision to the Court of Appeal of Alberta ("Court of Appeal") on the basis that the AUC erred in its decision to not adjust FortisAlberta's ROE and common equity component of capital structure to address incremental business risk associated with competition from Rural Electrification Associations ("REAs") located in FortisAlberta's service area, as well as heightened regulatory risk due to the non-recovery of costs attributable to REAs. In April 2024, the Court of Appeal granted FortisAlberta permission to appeal, which is expected to be completed in the first quarter of 2025.

Third PBR Term Decision: In October 2023, the AUC issued a decision establishing the parameters for the third performance-based rate ("PBR") setting term for the period of 2024 through 2028. In November 2023, FortisAlberta sought permission to appeal the decision to the Court of Appeal on the basis that the AUC erred in its decision to determine capital funding using 2018-2022 historical capital investments without consideration for funding of new capital programs included in the company's 2023 cost of service revenue requirement as approved by the AUC. FortisAlberta's application for permission to appeal the decision will be heard by the Court of Appeal in the fourth quarter of 2024.


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 ("U.S. GAAP") 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 2023 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.
8
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
3. ACCOUNTING POLICIES (cont'd)

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 2023 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.

Segment Reporting: ASU No. 2023-07, Improvements to Reportable Segment Disclosures, is effective for Fortis' December 31, 2024 annual financial statements and for interim periods beginning in 2025, on a retrospective basis. The ASU requires disclosure of incremental segment information, including significant segment expenses and other items that are included in segment profit or loss. Fortis does not expect the ASU to materially impact its disclosures.

Income Taxes: ASU No. 2023-09, Improvements to Income Tax Disclosures, is effective for Fortis on January 1, 2025 on a prospective basis, with retrospective application and early adoption permitted. The ASU requires additional disclosure of income tax information by jurisdiction to reflect an entity's exposure to potential changes in tax legislation, and associated risks and opportunities. Fortis does not expect the ASU to materially impact its disclosures.


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 nine months ended September 30, 2024 and 2023.

As of September 30, 2024, accounts receivable included $17 million due from Belize Electricity (December 31, 2023 - $8 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 September 30, 2024 and December 31, 2023, there were no material inter-segment loans outstanding. Interest charged on inter-segment loans was not material for the three and nine months ended September 30, 2024 and 2023.


9
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
4. SEGMENTED INFORMATION (cont'd)

RegulatedNon-Regulated
Inter-
UNSCentralFortisBCFortisFortisBCOtherSubCorporatesegment
($ millions)ITCEnergyHudsonEnergyAlbertaElectricElectricTotaland OthereliminationsTotal
Quarter ended September 30, 2024
Revenue556 883 338 246 209 130 399 2,761 10 —2,771 
Energy supply costs— 330 106 45 — 39 217 737 — —737 
Operating expenses128 193 165 101 45 33 60 725 15 —740 
Depreciation and amortization110 100 35 85 73 21 54 478 2 —480 
Operating income318 260 32 15 91 37 68 821 (7)—814 
Other income, net23 16 14 12 4 2 6 77 25 —102 
Finance charges121 40 20 40 34 21 22 298 57 —355 
Income tax expense51 32 6 (9)7 4 5 96 (13)—83 
Net earnings169 204 20 (4)54 14 47 504 (26)—478 
Non-controlling interests31 — — — — — 8 39 — —39 
Preference share dividends— — — — — — — — 19 —19 
Net earnings attributable to common equity shareholders138 204 20 (4)54 14 39 465 (45)—420 
Additions to property, plant and equipment and intangible assets355 303 107 237 147 29 121 1,299 1 —1,300 
As at September 30, 2024
Goodwill8,301 1,869 610 913 231 235 257 12,416 — —12,416 
Total assets25,349 14,035 5,651 9,885 6,161 2,786 5,431 69,298 355 (11)69,642 
Quarter ended September 30, 2023
Revenue520 899 290 294 190 128 377 2,698 21 —2,719 
Energy supply costs— 381 88 64 — 38 202 773 — —773 
Operating expenses120 185 146 94 44 29 54 672 10 —682 
Depreciation and amortization104 90 28 77 67 24 51 441 2 —443 
Operating income 296 243 28 59 79 37 70 812 9 —821 
Other income, net21 7 13 9 1 2 5 58 (11)—47 
Finance charges112 36 16 38 32 20 23 277 54 —331 
Income tax expense 60 36 5 7 3 2 6 119 (27)—92 
Net earnings 145 178 20 23 45 17 46 474 (29)—445 
Non-controlling interests26 — — 1 — — 7 34 — —34 
Preference share dividends— — — — — — — — 17 —17 
Net earnings attributable to common equity shareholders119 178 20 22 45 17 39 440 (46)—394 
Additions to property, plant and equipment and intangible assets237 187 92 155 150 30 127 978 5 —983 
As at September 30, 2023
Goodwill8,332 1,876 613 913 228 235 258 12,455 — —12,455 
Total assets24,657 13,071 5,323 8,712 5,806 2,660 5,131 65,360 970 (45)66,285 

10
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
4. SEGMENTED INFORMATION (cont'd)

RegulatedNon-Regulated
Inter-
UNSCentralFortisBCFortisFortisBCOtherSubCorporatesegment
($ millions)ITCEnergyHudsonEnergyAlbertaElectricElectricTotaland OthereliminationsTotal
Year-to-date September 30, 2024
Revenue1,662 2,348 1,016 1,143 610 396 1,359 8,534 25 —8,559 
Energy supply costs— 928 324 284 — 109 814 2,459 — —2,459 
Operating expenses393 588 503 297 142 100 185 2,208 37 —2,245 
Depreciation and amortization330 299 96 253 217 65 162 1,422 5 —1,427 
Operating income939 533 93 309 251 122 198 2,445 (17)—2,428 
Other income, net77 37 44 31 9 5 16 219 21 —240 
Finance charges354 112 56 118 101 61 69 871 167 —1,038 
Income tax expense153 62 19 48 20 12 17 331 (78)—253 
Net earnings509 396 62 174 139 54 128 1,462 (85)—1,377 
Non-controlling interests94 — — 1 — — 17 112 — —112 
Preference share dividends— — — — — — — — 55 —55 
Net earnings attributable to common equity shareholders415 396 62 173 139 54 111 1,350 (140)—1,210 
Additions to property, plant and equipment and intangible assets1,021 726 294 660 410 89 322 3,522 3 —3,525 
As at September 30, 2024
Goodwill8,301 1,869 610 913 231 235 257 12,416 — —12,416 
Total assets25,349 14,035 5,651 9,885 6,161 2,786 5,431 69,298 355 (11)69,642 
Year-to-date September 30, 2023
Revenue1,558 2,300 1,049 1,411 550 383 1,304 8,555 77 —8,632 
Energy supply costs— 980 416 582 — 107 787 2,872 — —2,872 
Operating expenses380 579 452 283 130 90 170 2,084 52 —2,136 
Depreciation and amortization308 265 84 232 198 72 152 1,311 8 —1,319 
Operating income 870 476 97 314 222 114 195 2,288 17 —2,305 
Other income, net57 33 40 25 4 4 17 180 — —180 
Finance charges316 109 49 122 92 59 65 812 157 —969 
Income tax expense 156 62 19 47 8 6 20 318 (77)—241 
Net earnings 455 338 69 170 126 53 127 1,338 (63)—1,275 
Non-controlling interests83 — — 1 — — 16 100 — —100 
Preference share dividends— — — — — — — — 50 —50 
Net earnings attributable to common equity shareholders372 338 69 169 126 53 111 1,238 (113)—1,125 
Additions to property, plant and equipment and intangible assets837 555 248 389 451 92 335 2,907 12 —2,919 
As at September 30, 2023
Goodwill8,332 1,876 613 913 228 235 258 12,455 — —12,455 
Total assets24,657 13,071 5,323 8,712 5,806 2,660 5,131 65,360 970 (45)66,285 

11
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
5. ALLOWANCE FOR CREDIT LOSSES

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

QuarterYear-to-Date
($ millions)2024 2023 2024 2023 
Periods ended September 30
Balance, beginning of period(69)(60)(68)(58)
Credit loss expense(7)(10)(23)(24)
Credit loss deferral(6)(5)(26)(9)
Write-offs, net of recoveries9 10 45 26 
Foreign exchange— — (1)— 
Balance, end of period(73)(65)(73)(65)

See Note 14 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 2023 Annual Financial Statements. A summary follows.
As at
September 30,December 31,
($ millions)
2024 2023 
Regulatory assets
Deferred income taxes 2,166 2,058 
Deferred energy management costs 532 521 
Rate stabilization and related accounts 465 521 
Employee future benefits 254 254 
Derivatives166 197 
Deferred lease costs 149 137 
Deferred restoration costs130 115 
Manufactured gas plant site remediation deferral 78 81 
Generation early retirement costs68 64 
Renewable natural gas account 54 47 
Other regulatory assets 492 389 
Total regulatory assets4,554 4,384 
Less: Current portion(787)(866)
Long-term regulatory assets3,767 3,518 
Regulatory liabilities
Future cost of removal1,669 1,547 
Deferred income taxes1,252 1,280 
Rate stabilization and related accounts404 292 
Employee future benefits250 294 
Renewable energy surcharge140 129 
Alberta Electric System Operator charges deferral91 121 
Energy efficiency liability87 78 
Electric and gas moderator account64 50 
Other regulatory liabilities153 167 
Total regulatory liabilities4,110 3,958 
Less: Current portion(666)(577)
Long-term regulatory liabilities3,444 3,381 

12
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
7. LONG-TERM DEBT
As at
September 30,December 31,
($ millions)2024 2023 
Long-term debt30,038 28,131 
Credit facility borrowings 1,720 1,572 
Total long-term debt31,758 29,703 
Less: Deferred financing costs and debt discounts(184)(172)
Less: Current installments of long-term debt(1,866)(2,296)
29,708 27,235 

Significant Long-Term Debt IssuancesInterest
Year-to-date September 30, 2024MonthRateUse of
($ millions, except as noted)
Issued

(%)
MaturityAmountProceeds
ITC
Secured senior notesJanuary5.98 2034US85 
(1) (2) (3)
First mortgage bondsJanuary5.11 2029US75 
(1) (2) (3)
First mortgage bondsJanuary5.38 2034US75 
(1) (2) (3)
Unsecured senior notesMay5.65 2034US400 
(3) (4)
UNS Energy
Unsecured senior notesJune5.60 2036US30 
(1) (3)
Unsecured senior notesAugust5.20 2034US400 
(3) (4)
Central Hudson
Senior notesApril5.59 2031US25 
(1) (3)
Senior notesApril5.69 2034US35 
(1) (3)
FortisBC Electric
Unsecured debenturesAugust4.92 2054100 
(1)
FortisAlberta
Unsecured debenturesMay4.90 2054300 
(1) (2) (3) (4)
Caribbean Utilities
Unsecured senior notesMay6.17 2039US40 
(1) (2) (3) (5)
Unsecured senior notesMay6.37 2049US40 
(1) (2) (3) (5)
FortisOntario
Unsecured senior notesAugust5.05 205455 
(1)
Fortis
Unsecured senior notesSeptember4.17 2031500 
(1) (3) (4)
(1)    Repay short-term and/or credit facility borrowings
(2)    Fund capital expenditures
(3)    General corporate purposes
(4)     Repay maturing long-term debt
(5)     Total of US$50 million expected to be used to fund or refinance a portfolio of new and/or existing qualifying green initiatives

UNS Energy issued US$400 million of unsecured senior notes in August 2024, as noted above. The unused net proceeds from this issuance have been invested in interest-bearing accounts as at September 30, 2024. The balance will be used to repay maturing long-term debt within the next 12-month period.

In September 2024, ITC priced US$250 million of first mortgage bonds with funding expected in December 2024. The related issuances will consist of US$125 million of 11-year, 4.88% bonds and US$125 million of 19-year, 5.25% bonds. Proceeds are expected to be used to repay maturing long-term debt, repay credit facility borrowings, fund capital expenditures and for general corporate purposes.

In October 2024, Central Hudson issued US$25 million of 5-year, 4.88% senior notes, US$44 million of 10-year, 5.30% senior notes and US$35 million 12-year, 5.40% senior notes. Proceeds will be used to refinance long-term debt and for general corporate purposes.

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. In September 2023, Fortis established an at-the-market equity program ("ATM Program") pursuant to the short-form base shelf prospectus, that allows the Corporation to issue up to $500 million of common shares from treasury to the public from time to time, at the Corporation's discretion, effective until December 22, 2024. As at September 30, 2024, $500 million remained available under the ATM Program and $1.5 billion remained available under the short-form base shelf prospectus.
13
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
7. LONG-TERM DEBT (cont'd)
As at
Credit facilitiesRegulatedCorporateSeptember 30,December 31,
($ millions)Utilitiesand Other2024 2023 
Total credit facilities4,211 1,912 6,123 6,176 
Credit facilities utilized:
Short-term borrowings (1)
(97)— (97)(119)
Long-term debt (including current portion) (2)
(1,025)(695)(1,720)(1,572)
Letters of credit outstanding(55)(21)(76)(101)
Credit facilities unutilized3,034 1,196 4,230 4,384 
(1)    The weighted average interest rate was 6.9% (December 31, 2023 - 6.9%).
(2)    The weighted average interest rate was 5.5% (December 31, 2023 - 6.2%). The current portion was $1,263 million (December 31, 2023 - $1,160 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 $5.6 billion of the total credit facilities are committed with maturities ranging from 2024 through 2029.

See Note 14 in the 2023 Annual Financial Statements for a description of the credit facilities as at December 31, 2023.

In April 2024, FortisBC Energy increased its operating credit facility from $700 million to $900 million and extended the maturity to July 2028. In May 2024, FortisBC Electric increased its operating credit facility from $150 million to $200 million and extended the maturity to April 2028.

In May 2024, the Corporation extended the maturity on its unsecured US$500 million non-revolving term credit facility to May 2025. Half of the term credit facility was repaid in the third quarter of 2024 and the remaining US$250 million has been fully utilized as at September 30, 2024. The facility is repayable at any time without penalty. In June 2024, the Corporation amended its $1.3 billion revolving term committed credit facility to extend the maturity to July 2029.

In August 2024, Newfoundland Power increased its operating credit facility from $100 million to $130 million and extended the maturity to August 2029.


8. PREFERENCE SHARES

On March 1, 2024, the annual fixed dividend per share for the First Preference Shares, Series K was reset from $0.9823 to $1.3673 for the five-year period up to but excluding March 1, 2029.

On December 1, 2024, the annual fixed dividend per share for the First Preference Shares, Series M will reset from $0.9783 to $1.3733 for the five-year period up to but excluding December 1, 2029.

14
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
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)2024 2023 2024 2023 
Quarter ended September 30
Service costs18 16 6 6 
Interest costs40 39 7 8 
Expected return on plan assets(54)(50)(7)(6)
Amortization of actuarial gains(1)(2)(4)(5)
Amortization of past service credits/plan amendments1 — — — 
Regulatory adjustments(1)2 — 1 
Net benefit cost3 5 2 4 
Year-to-date September 30
Service costs55 47 18 17 
Interest costs120 119 22 23 
Expected return on plan assets(164)(150)(20)(17)
Amortization of actuarial gains(1)(7)(13)(14)
Amortization of past service credits/plan amendments— (1)— (1)
Regulatory adjustments(1)8 1 4 
Net benefit cost9 16 8 12 

Defined contribution pension plan expense for the three and nine months ended September 30, 2024 was $14 million and $45 million, respectively (three and nine months ended September 30, 2023 - $13 million and $42 million, respectively).


10. DISPOSITION

In November 2023, Fortis sold its Aitken Creek business to a subsidiary of Enbridge Inc. for approximately $470 million including working capital and closing adjustments.

For the three and nine months ended September 30, 2023, Aitken Creek had net earnings of $5 million and $23 million, respectively.


11. OTHER INCOME, NET

QuarterYear-to-Date
($ millions)2024 2023 2024 2023 
Periods ended September 30
Equity component, allowance for funds used during construction37 25 99 71 
Gain (loss) on derivatives, net23 (15)17 (3)
Non-service component of net periodic benefit cost19 15 55 47 
Interest income (1)
17 20 49 54 
Gain (loss) on retirement investments, net5 (3)5 1 
Equity income1 3 5 10 
Other— 2 10 — 
102 47 240 180 
(1)    Includes interest on short-term deposits, as well as interest on regulatory deferrals, including the PPFAC at TEP and UNSE

15
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
12. EARNINGS PER COMMON SHARE

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

20242023
Net EarningsWeightedNet EarningsWeighted
to CommonAverageto CommonAverage
ShareholdersSharesEPSShareholdersSharesEPS
($ millions)(# millions)($)($ millions)(# millions)($)
Quarter ended September 30
Basic EPS420 496.2 0.85 394 487.4 0.81 
Potential dilutive effect of stock options— 0.2 — 0.3 
Diluted EPS420 496.4 0.85 394 487.7 0.81 
Year-to-date September 30
Basic EPS1,210 493.9 2.45 1,125 485.3 2.32 
Potential dilutive effect of stock options— 0.2 — 0.3 
Diluted EPS1,210 494.1 2.45 1,125 485.6 2.32 


13. SUPPLEMENTARY CASH FLOW INFORMATION

QuarterYear-to-Date
($ millions)2024 2023 2024 2023 
Periods ended September 30
Change in working capital
Accounts receivable and other current assets20 (68)83 421 
Prepaid expenses(47)(42)(76)(61)
Inventories(17)(69)(31)(7)
Regulatory assets - current portion(27)(25)107 135 
Accounts payable and other current liabilities271 151 (76)(386)
Regulatory liabilities - current portion51 20 69 42 
251 (33)76 144 
Non-cash financing activity
Common share dividends reinvested106 99 324 304 
($ millions)2024 2023 
As at September 30
Non-cash investing activities
Accrued capital expenditures638 376 
Contributions in aid of construction10 14 


14. 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.

16
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
14. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT (cont'd)

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 price 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 September 30, 2024, unrealized losses of $166 million (December 31, 2023 - $197 million) were recognized as regulatory assets and unrealized gains of $25 million (December 31, 2023 - $37 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, which was sold on November 1, 2023, held 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 were measured using forward pricing from published market sources.

Gains or losses associated with changes in the fair value of these energy contracts are recognized in revenue. During the three and nine months ended September 30, 2024, gains of $5 million and $44 million were recognized in revenue, respectively (three and nine months ended September 30, 2023 - losses of $7 million and gains of $6 million, respectively).

Total Return Swaps
The Corporation holds total return swaps to manage the cash flow risk associated with forecast future cash and/or share settlements of certain stock-based compensation obligations. The swaps have a combined notional amount of $134 million and terms up to three years expiring at varying dates through January 2027. 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 nine months ended September 30, 2024, unrealized gains of $20 million and $16 million, respectively were recognized in other income, net (three and nine months ended September 30, 2023 - unrealized losses of $12 million and $7 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 September 2026 and have a combined notional amount of $461 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 nine months ended September 30, 2024, unrealized gains of $2 million and unrealized losses of $3 million, respectively, were recognized in other income, net (three and nine months ended September 30, 2023 - unrealized losses of $3 million and unrealized gains of $4 million, respectively).

Interest Rate Contracts
During the second quarter of 2024, ITC entered into and settled interest rate locks with a combined notional value of US$300 million. These contracts were used to manage interest rate risk associated with the issuance of US$400 million unsecured senior notes in May 2024. Realized losses of US$3 million were recognized in other comprehensive income, which will be reclassified to earnings as a component of interest expense over 5 years.

During the third quarter of 2024, ITC entered into interest rate swaps with a combined notional value of US$105 million which will be used to manage interest rate risk associated with forecasted debt issuances. The swaps have 5-year terms, include mandatory early termination provisions, and will be terminated no later than the effective dates in the second quarter of 2026. Fair value was measured using a discounted cash flow method based on secured overnight financing rates ("SOFR"). Unrealized gains and losses associated with the 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 less than $1 million were recorded for the three and nine months ended September 30, 2024.

During the third quarter of 2024, Fortis entered into and settled interest rate locks with a combined notional value of $250 million. These contracts were used to manage interest rate risk associated with the issuance of $500 million unsecured senior notes in September 2024. Realized losses of $2 million were recognized in other comprehensive income, which will be reclassified to earnings as a component of interest expense over 7 years.


17
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
14. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT (cont'd)

Cross-Currency Interest Rate Swaps
The Corporation holds cross-currency interest rate swaps, maturing in 2029, to effectively convert its $500 million, 4.43% unsecured senior notes to US$391 million, 4.34% debt. The Corporation has 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 foreign 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 SOFR. During the three and nine months ended September 30, 2024, unrealized gains of $6 million and unrealized losses of $9 million, respectively, were recorded in other comprehensive income (three and nine months ended September 30, 2023 - unrealized losses of $16 million and $6 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 September 30, 2024
Assets
Energy contracts subject to regulatory deferral (2) (3)
— 46 — 46 
Energy contracts not subject to regulatory deferral (2)
— 11 — 11 
Total return swaps and foreign exchange contracts (2)
— 16 — 16 
Other investments (4)
204 — — 204 
204 73 — 277 
Liabilities
Energy contracts subject to regulatory deferral (3) (5)
— (187)— (187)
Energy contracts not subject to regulatory deferral (5)
— (2)— (2)
Cross-currency interest rate swaps (5)
— (11)— (11)
— (200)— (200)
As at December 31, 2023
Assets
Energy contracts subject to regulatory deferral (2) (3)
— 49 — 49 
Energy contracts not subject to regulatory deferral (2)
— 6 — 6 
Foreign exchange contracts (2)
— 5 — 5 
Other investments (4)
145 — — 145 
145 60 — 205 
Liabilities
Energy contracts subject to regulatory deferral (3) (5)
— (209)— (209)
Energy contracts not subject to regulatory deferral (5)
— (3)— (3)
Total return and cross-currency interest rate swaps (5)
— (6)— (6)
— (218)— (218)
(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)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. The fair value of these investments is included in cash and cash equivalents and other assets, with gains and losses recognized in other income, net
(5)Included in accounts payable and other current liabilities or other liabilities


18
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
14. 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 AmountCounterparty
Recognized inNetting ofCash Collateral
($ millions)Balance SheetEnergy ContractsPosted/(Received)Net Amount
As at September 30, 2024
Derivative assets57 (25)15 47 
Derivative liabilities(189)25 — (164)
As at December 31, 2023
Derivative assets55 (24)28 59 
Derivative liabilities(212)24 (1)(189)

Volume of Derivative Activity
As at September 30, 2024, 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
September 30,December 31,
2024 2023 
Energy contracts subject to regulatory deferral (1)
Electricity swap contracts (GWh)
758 628 
Electricity power purchase contracts (GWh)
221 588 
Gas swap contracts (PJ)
241 228 
Gas supply contracts (PJ)
156 134 
Energy contracts not subject to regulatory deferral (1)
Wholesale trading contracts (GWh)
2,824 1,310 
Gas swap contracts (PJ)
4 3 
(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 since the suspension of collection efforts initially required in response to the COVID-19 pandemic. Central Hudson continues to contact customers regarding past-due balances and collection efforts continue to expand. Under its regulatory framework, Central Hudson can defer uncollectible write-offs that exceed the amounts collected in customer rates for future recovery.

UNS Energy, Central Hudson, FortisBC Energy, 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 $94 million as at September 30, 2024 (December 31, 2023 - $117 million).
19
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
Notes to Condensed Consolidated Interim Financial Statements (Unaudited)
For the three and nine months ended September 30, 2024 and 2023
14. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT (cont'd)

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 September 30, 2024, US$2.2 billion (December 31, 2023 - US$2.6 billion) of corporately issued U.S. dollar-denominated long-term debt has been designated as an effective hedge of net investments, leaving approximately US$12.4 billion (December 31, 2023 - US$11.5 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 September 30, 2024, the carrying value of long-term debt, including current portion, was $31.8 billion (December 31, 2023 - $29.7 billion) compared to an estimated fair value of $30.6 billion (December 31, 2023 - $27.9 billion).


15. COMMITMENTS AND CONTINGENCIES

Commitments
There were no material changes in commitments from that disclosed in the Corporation's 2023 Annual Financial Statements, except that in August 2024, TEP entered into a US$268 million Engineering, Procurement, and Construction Agreement for the development of the Roadrunner Reserve 2 battery energy storage system facility. The facility is expected to be placed in service in 2026.

Contingency
In April 2013, FortisBC Holdings Inc. 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 across reserve lands. 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 as the outcome cannot yet be reasonably determined.
20
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT

Exhibit 99.3
Interim Management Discussion and Analysis

Contents
About Fortis1Cash Flow Requirements12
Performance at a Glance2Cash Flow Summary14
Business Unit Performance5Contractual Obligations15
ITC5Capital Structure and Credit Ratings15
UNS Energy5Capital Plan16
Central Hudson6Business Risks18
FortisBC Energy7Accounting Matters19
FortisAlberta7Financial Instruments19
FortisBC Electric8Long-Term Debt and Other19
Other Electric8Derivatives19
Corporate and Other9Summary of Quarterly Results20
Non-U.S. GAAP Financial Measures9Related-Party and Inter-Company Transactions20
Focus on Sustainability10Outlook21
Regulatory Matters11Forward-Looking Information21
Financial Position12Glossary22
Liquidity and Capital Resources12Condensed Consolidated Interim Financial Statements (Unaudited)F-1

Dated November 4, 2024

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 2023 Annual Financial Statements and the 2023 Annual MD&A and is subject to the cautionary statement and disclaimer provided under "Forward-Looking Information" on page 21. 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 1.36 and 1.34 for the quarters ended September 30, 2024 and 2023, respectively; (ii) average of 1.36 and 1.35 year-to-date September 30, 2024 and 2023, respectively; (iii) 1.35 and 1.36 as at September 30, 2024 and 2023, respectively; (iv) 1.32 as at December 31, 2023; (v) 1.36 for the 2024 annual forecast; and (vi) 1.30 for all other forecast periods. Certain terms used in this Interim MD&A are defined in the "Glossary" on page 22.


ABOUT FORTIS

Fortis (TSX/NYSE: FTS) is a well-diversified leader in the North American regulated electric and gas utility industry, with 2023 revenue of $12 billion and total assets of $70 billion as at September 30, 2024. The Corporation's 9,600 employees serve 3.5 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 2023 Annual MD&A and Note 1 to the Interim Financial Statements.

1
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
PERFORMANCE AT A GLANCE
Key Financial Metrics
Periods ended September 30QuarterYear-to-Date
($ millions, except as indicated)
2024 2023 Variance2024 2023 Variance
Revenue2,771 2,719 52 8,559 8,632 (73)
Common Equity Earnings
Actual420 394 26 1,210 1,125 85 
Adjusted (1)
420 411 9 1,210 1,152 58 
Basic EPS ($)
Actual0.85 0.81 0.04 2.45 2.32 0.13 
Adjusted (1)
0.85 0.84 0.01 2.45 2.37 0.08 
Dividends paid per common share ($)
0.59 0.565 0.025 1.77 1.695 0.075 
Weighted average number of common shares outstanding (# millions)
496.2 487.4 8.8 493.9 485.3 8.6 
Operating Cash Flow1,338 940 398 2,920 2,799 121 
Capital Expenditures (1)
1,300 1,008 292 3,554 3,028 526 
(1)See "Non-U.S. GAAP Financial Measures" on page 9

Revenue
The increase in revenue for the quarter was due to: (i) new customer rates at TEP effective September 1, 2023; (ii) Rate Base growth; and (iii) a higher U.S.-to-Canadian dollar exchange rate. The increase was partially offset by the timing of recognition of new cost of capital parameters approved for FortisBC in September 2023 retroactive to January 1, 2023, and lower wholesale electricity sales at UNS Energy.

The decrease in revenue for the year-to-date period was due to lower flow-through costs in customer rates, driven by lower commodity prices at FortisBC Energy and Central Hudson, as well as lower short-term wholesale sales revenue at UNS Energy due to unfavourable pricing. The decrease was partially offset by: (i) new customer rates at TEP effective September 1, 2023; (ii) Rate Base growth; and (iii) a higher U.S.-to-Canadian dollar exchange rate.

Earnings and EPS
Common Equity Earnings increased by $26 million in comparison to the third quarter of 2023 driven by: (i) Rate Base growth; and (ii) strong earnings in Arizona, reflecting new customer rates at TEP effective September 1, 2023, an increase in the market value of investments that support retirement benefits and higher production tax credits. Unrealized gains on derivative contracts recognized in the third quarter of 2024, and an unfavourable deferred income tax adjustment recognized by ITC in the third quarter of 2023, also contributed to the growth in earnings. The increase was partially offset by the timing of recognition of new cost of capital parameters approved for FortisBC in 2023, which included $26 million associated with the retroactive impact to January 1, 2023, as well as higher holding company finance costs.

Common Equity Earnings for the year-to-date period increased by $85 million in comparison to the same period in 2023. The increase was due to Rate Base growth, higher earnings in Arizona, unrealized gains on derivative contracts, and the deferred income tax adjustment recognized by ITC in 2023, as discussed above. Growth was partially offset by: (i) higher operating costs at Central Hudson; (ii) higher holding company finance costs; and (iii) the November 1, 2023 disposition of Aitken Creek. Although the disposition of Aitken Creek was unfavourable in comparison to the same period in 2023, the impact will be neutral for the annual period.

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.

There were no adjustments to Common Equity Earnings for the three and nine months ended September 30, 2024. For the three and nine months ended September 30, 2023, favourable adjustments were recognized to Common Equity Earnings associated with the mark-to-market accounting of natural gas derivatives at Aitken Creek and the revaluation of deferred income tax assets at ITC. Refer to "Non-U.S. GAAP Financial Measures" on page 9. The changes in Adjusted Basic EPS for the quarter and year-to-date periods are illustrated in the following charts.



2
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
chart-c8bad1e13c9b459eb52a.jpg
(1)    Includes UNS Energy and Central Hudson. Reflects higher earnings at UNS Energy largely due to new customer rates at TEP effective September 1, 2023, an increase in the market value of investments that support retirement benefits, and higher production tax credits, partially offset by higher operating expenses. Results at Central Hudson were consistent with the third quarter of 2023 as higher earnings associated with Rate Base growth and a higher allowed ROE effective July 1, 2024 was offset by the timing of operating expenses in comparison to the related recovery in customer rates
(2)    Reflects Rate Base growth and an increase in the market value of investments that support retirement benefits, partially offset by higher holding company finance costs
(3)    Average foreign exchange rate of 1.36 in 2024 compared to 1.34 in 2023
(4)    Includes FortisBC Energy, FortisAlberta and FortisBC Electric. Reflects lower earnings at FortisBC due to the timing of recognition of new cost of capital parameters approved in September 2023, which included $0.05 associated with the retroactive impact to January 1, 2023, as well as the timing of operating costs. Also reflects higher earnings at FortisAlberta due to Rate Base and customer growth, as well as an increase in the allowed ROE effective January 1, 2024
(5)    Includes a $0.02 unfavourable impact associated with the disposition of Aitken Creek in November 2023, as well as higher holding company finance costs and a lower income tax recovery, partially offset by unrealized gains on derivative contracts
(6)    Weighted average shares of 496.2 million in 2024 compared to 487.4 million in 2023

chart-e8c4901b2ade4e20b90a.jpg
(1)    Includes UNS Energy and Central Hudson. Reflects higher earnings at UNS Energy largely due to new customer rates at TEP effective September 1, 2023, favourable margins on wholesale sales, an increase in the market value of investments that support retirement benefits, and higher production tax credits, partially offset by higher operating costs. Also reflects lower earnings at Central Hudson due higher operating expenses in the first half of 2024, the timing of recovery of operating expenses in the third quarter of 2024, and favourable regulatory adjustments recognized in 2023, partially offset by Rate Base growth and a higher allowed ROE effective July 1, 2024
(2)    Reflects Rate Base growth and an increase in the market value of investments that support retirement benefits, partially offset by higher holding company finance costs
(3)    Includes FortisBC Energy, FortisAlberta and FortisBC Electric. Primarily reflects Rate Base growth, as well as higher earnings at FortisAlberta due to an increase in the allowed ROE, higher demand charges and customer growth
(4)    Average foreign exchange rate of 1.36 in 2024 compared to 1.35 in 2023
(5)    Includes a $0.05 unfavourable impact associated with the disposition of Aitken Creek in November 2023, as well as higher holding company finance costs and a lower income tax recovery, partially offset by unrealized gains on derivative contracts
(6)    Weighted average shares of 493.9 million in 2024 compared to 485.3 million in 2023

3
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
Dividends and TSR
Fortis paid a dividend of $0.59 per common share in the third quarter of 2024, up from $0.565 paid in the third quarter of 2023.

In September 2024, the Board declared a fourth quarter common share dividend of $0.615, up 4.2% from its third quarter common share dividend. Fortis has increased its common share dividends for 51 consecutive years and is targeting annual dividend growth of approximately 4-6% through 2029. See "Outlook" on page 21.

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

TSR (1) (%)
1-Year5-Year10-Year20-Year
Fortis24.1 5.8 10.0 11.2 
(1)Annualized TSR per Bloomberg as at September 30, 2024

Operating Cash Flow
The $398 million increase in Operating Cash Flow for the quarter was primarily driven by FortisBC Energy due to: (i) deposits received related to the construction of the Eagle Mountain Pipeline project; (ii) the receipt of an income tax refund, as expected; and (iii) the timing of flow-through costs in customer rates. The increase was also due to higher cash earnings, reflecting Rate Base growth and new customer rates at TEP, as well as the timing of flow-through costs at Central Hudson and FortisAlberta, partially offset by higher interest payments.

The $121 million increase in Operating Cash Flow for the year-to-date period was due to: (i) higher cash earnings, reflecting Rate Base growth, as well as new customer rates and higher sales at TEP; (ii) the higher collection of flow-through costs at UNS Energy and Central Hudson; and (iii) the collection of deposits and an income tax refund at FortisBC Energy, as discussed above. The increase was partially offset by: (i) the timing of flow-through costs in customer rates as well as other changes in working capital balances at FortisBC Energy; (ii) the timing of flow-through transmission costs at FortisAlberta; (iii) higher interest payments; and (iv) the disposition of Aitken Creek in November 2023, which contributed approximately $115 million of cash flow year-to-date September 30, 2023 primarily associated with changes in working capital balances.

Capital Expenditures
Capital Expenditures for 2024 are expected to be approximately $5.2 billion, up from $4.8 billion disclosed in the 2023 Annual MD&A. The increase is largely due to the timing of expenditures associated with the Eagle Mountain Pipeline project at FortisBC Energy and a higher forecast U.S.-to-Canadian dollar exchange rate. The Corporation is now using a 2024 annual forecast foreign exchange rate of 1.36 as compared to 1.30 used previously.

Year-to-date Capital Expenditures of $3.6 billion represent 69% of the forecast for the year, and are $0.5 billion higher than the same period in 2023 largely related to the construction of the Eagle Mountain Pipeline project at FortisBC Energy and battery energy storage investments at UNS Energy (see "Capital Plan" on page 16). Capital Expenditures is a Non-U.S. GAAP Financial Measure. Refer to "Non-U.S. GAAP Financial Measures" on page 9 and in the "Glossary" on page 22.

New Five-Year Capital Plan
The Corporation's new 2025-2029 capital plan totals $26.0 billion and is $1.0 billion higher than the previous five-year plan. The increase is driven by projects associated with the MISO LRTP and resiliency investments at ITC, as well as distribution investments largely due to customer growth at FortisAlberta. See "Capital Plan" on page 16 for further information.
4
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
BUSINESS UNIT PERFORMANCE
Common Equity EarningsQuarterYear-to-Date
Periods ended September 30VarianceVariance
($ millions)2024 2023 
FX (1)
Other2024 2023 
FX (1)
Other
Regulated Utilities
ITC138 119 2 17 415 372 4 39 
UNS Energy204 178 3 23 396 338 5 53 
Central Hudson20 20 — — 62 69 — (7)
FortisBC Energy(4)22 — (26)173 169 — 4 
FortisAlberta54 45 — 9 139 126 — 13 
FortisBC Electric14 17 — (3)54 53 — 1 
Other Electric (2)
39 39 — — 111 111 — — 
465 440 5 20 1,350 1,238 9 103 
Non-Regulated
Corporate and Other (3)
(45)(46)— 1 (140)(113)(2)(25)
Common Equity Earnings420 394 5 21 1,210 1,125 7 78 
(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. Certain corporate and non-regulated holding company transactions, included in the Corporate and Other segment, are 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 non-regulated holding company expenses, as well as long-term contracted generation assets in Belize. Also includes Aitken Creek up to the November 1, 2023 date of disposition

ITCQuarterYear-to-Date
Periods ended September 30VarianceVariance
($ millions)2024 2023 FXOther2024 2023 FXOther
Revenue (1)
556 520 9 27 1,662 1,558 18 86 
Earnings (1)
138 119 2 17 415 372 4 39 
(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, an unfavourable deferred income tax adjustment recognized in the third quarter of 2023 as discussed below, and an increase in the market value of certain investments that support retirement benefits. The increase was partially offset by higher holding company finance costs.

In September 2023, the state of Iowa reduced its corporate income tax rate from 8.4% to 7.1%, effective January 1, 2024. As a result, ITC revalued the related deferred income tax assets, resulting in a $9 million unfavourable impact to earnings for the three and nine months ended September 30, 2023.

UNS EnergyQuarterYear-to-Date
Periods ended September 30VarianceVariance
($ millions, except as indicated)2024 2023 FXOther2024 2023 FXOther
Retail electricity sales (GWh)
3,631 3,668 — (37)8,522 8,484 — 38 
Wholesale electricity sales (GWh) (1)
1,325 1,407 — (82)4,515 4,038 — 477 
Gas sales (PJ)
2 1 — 1 12 12 — — 
Revenue883 899 16 (32)2,348 2,300 27 21 
Earnings204 178 3 23 396 338 5 53 
(1)    Primarily short-term wholesale sales
5
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
Sales
The decrease in retail electricity sales for the quarter was due primarily to lower air conditioning load associated with milder temperatures in the third quarter of 2024. The increase in retail electricity sales for the year-to-date period was due to higher air conditioning load associated with warmer temperatures in the second quarter of 2024, partially offset by milder temperatures experienced in the first and third quarters of the year.

The decrease in wholesale electricity sales for the quarter was driven by lower short-term wholesale sales due to less favourable market conditions, and lower long-term wholesale sales due to the expiration of certain contracts. The increase in wholesale electricity sales for the year-to-date period was driven by higher short-term wholesale sales, due to market conditions, partially offset by lower long-term wholesale sales as discussed for the quarter. 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.

Gas sales for the quarter and year-to date periods were comparable with the same periods in 2023.

Revenue
The decrease in revenue, net of foreign exchange, for the quarter was due primarily to: (i) lower wholesale sales revenue, due to lower volumes as discussed above as well as unfavourable pricing on short-term wholesale sales; and (ii) the recovery of overall lower fuel and non-fuel costs through the normal operation of regulatory mechanisms. The decrease was partially offset by new customer rates at TEP effective September 1, 2023.

The increase in revenue, net of foreign exchange, for the year-to-date period was due primarily to new customer rates at TEP effective September 1, 2023 and the recovery of overall higher fuel and non-fuel costs through the normal operation of regulatory mechanisms. The increase was partially offset by lower wholesale sales revenue, largely driven by unfavourable pricing on short-term wholesale sales.

Earnings
The increase in earnings, net of foreign exchange, for the quarter and year-to-date periods was due to: (i) new customer rates at TEP effective September 1, 2023, following the conclusion of the general rate application; (ii) an increase in the market value of certain investments that support retirement benefits; (iii) higher production tax credits related to the Oso Grande generating facility; and (iv) higher AFUDC. The increase was partially offset by: (i) higher depreciation expense, due to new depreciation rates also approved as part of the rate application; and (ii) higher operating costs, primarily reflecting labor costs. Higher margins on wholesale sales, partially offset by lower transmission revenue, also contributed to the year-to-date increase in earnings.

Central HudsonQuarterYear-to-Date
Periods ended September 30VarianceVariance
($ millions, except as indicated)2024 2023 FXOther2024 2023 FXOther
Electricity sales (GWh)
1,402 1,315 — 87 3,873 3,725 — 148 
Gas sales (PJ)
6 5 — 1 19 18 — 1 
Revenue338 290 6 42 1,016 1,049 11 (44)
Earnings20 20 — — 62 69 — (7)

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 due to warmer weather.

Gas sales for the quarter and year-to-date periods were relatively consistent with the comparable periods in 2023.

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 was due primarily to the conclusion of Central Hudson's 2024 general rate application and related rebasing of customer rates with retroactive application to July 1, 2024 (see "Regulatory Matters" on page 11), and the flow through of higher energy supply costs driven by commodity prices.

The decrease in revenue, net of foreign exchange, for the year-to-date period was due primarily to the flow through of lower energy supply costs driven by commodity prices, partially offset by the rebasing of customer rates effective July 1, 2024, discussed above. Favourable regulatory adjustments recognized in 2023 that did not reoccur in 2024 also contributed to the year-to-date decrease in revenue.

6
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
Earnings
Earnings for the quarter were comparable with the same period in 2023. Results for the quarter were favourably impacted by Rate Base growth and the conclusion of Central Hudson's 2024 general rate application, including a higher allowed ROE effective July 1, 2024. This increase was offset by the timing of operating expenses in comparison to the related recovery in customer rates, discussed below.

The decrease in earnings for the year-to-date period was due to operating expenses in excess of that recovered in customer rates for the first half of 2024, as well as the timing of operating expenses in the third quarter of 2024 as compared to the related recovery in customer rates, discussed below. Favourable regulatory adjustments recognized in 2023 also contributed to the year-to-date decrease, partially offset by Rate Base growth and the higher allowed ROE effective July 1, 2024.

The conclusion of Central Hudson's 2024 general rate application is expected to provide cost recovery that is better aligned with ongoing operating expenses. The favourable impact associated with the rebasing of customer rates, however, will vary over quarterly reporting periods, with the increase in revenue expected to be higher in the fourth quarter of 2024 than that reflected in the third quarter.

FortisBC Energy
Periods ended September 30QuarterYear-to-Date
($ millions, except as indicated)2024 2023 Variance2024 2023 Variance
Gas sales (PJ)
32 27 5 153 147 6 
Revenue246 294 (48)1,143 1,411 (268)
Earnings(4)22 (26)173 169 4 

Sales
The increase in gas sales for the quarter was primarily due to higher average consumption by industrial and transportation customers. The increase in gas sales for the year-to-date period was due to higher average consumption by industrial, residential and commercial customers.

Revenue
The decrease in revenue for the quarter was due to the timing of recognition of new cost of capital parameters approved by the BCUC in September 2023 retroactive to January 1, 2023, as well as the recovery of lower flow-through commodity costs.

The decrease in revenue for the year-to-date period was due primarily to the recovery of lower flow-through commodity costs and the normal operation of regulatory mechanisms.

Earnings
The decrease in earnings for the quarter was due to the timing of recognition of new cost of capital parameters approved by the BCUC in September 2023, which resulted in $23 million of earnings recognized in the third quarter of 2023 associated with the first half of 2023. The timing of operating costs also contributed to the decrease in earnings.

The increase in earnings for the year-to-date period was due primarily to higher net investments in regulated assets.

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.

FortisAlberta
Periods ended September 30QuarterYear-to-Date
($ millions, except as indicated)2024 2023 Variance2024 2023 Variance
Electricity deliveries (GWh)
4,388 4,294 94 12,896 12,703 193 
Revenue209 190 19 610 550 60 
Earnings54 45 9 139 126 13 

Deliveries
The increase in electricity deliveries for the quarter and year-to-date periods was due primarily to customer additions and higher average consumption by industrial customers, partially offset by lower average consumption by residential customers. The reduction in average residential usage was associated with agriculture customers and reflected reduced irrigation needs due to higher rainfall.

7
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
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
The increase in revenue for the quarter and year-to-date periods was due to: (i) an increase in the allowed ROE from 8.50% to 9.28%, as approved by the AUC, effective January 1, 2024; (ii) Rate Base growth, including changes associated with the third PBR term beginning January 1, 2024; and (iii) customer additions. Higher industrial and commercial demand charges also contributed to the year-to-date increase in revenue.

Earnings
The increase in earnings for the quarter and year-to-date periods was due to the higher allowed ROE, Rate Base growth and customer additions, partially offset by higher operating expenses due to inflationary increases as well as higher income tax expense. Higher demand charges, discussed above, also contributed to the year-to-date increase in earnings.

FortisBC Electric
Periods ended September 30QuarterYear-to-Date
($ millions, except as indicated)2024 2023 Variance2024 2023 Variance
Electricity sales (GWh)
864 822 42 2,597 2,577 20 
Revenue130 128 2 396 383 13 
Earnings14 17 (3)54 53 1 

Sales
The increase in electricity sales for the quarter and year-to-date periods was due to higher average consumption by residential customers due to warmer weather. The increase was also due to higher average consumption by industrial customers, partially offset by lower average consumption by commercial customers.

Revenue
The increase in revenue for the quarter and year-to-date periods was due primarily to higher electricity sales and Rate Base growth, partially offset by the normal operation of regulatory mechanisms. The increase in revenue for the quarter was partially offset by the timing of recognition of new cost of capital parameters approved by the BCUC in September 2023, retroactive to January 1, 2023.

Earnings
The decrease in earnings for the quarter was due to the timing of recognition of new cost of capital parameters approved by the BCUC in September 2023, which resulted in $3 million of earnings recognized in the third quarter of 2023 largely associated with the first half of 2023.

The increase in earnings for the year-to-date period was due primarily to Rate Base growth, partially offset by higher operating costs.

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

Other ElectricQuarterYear-to-Date
Periods ended September 30VarianceVariance
($ millions, except as indicated)2024 2023 FXOther2024 2023 FXOther
Electricity sales (GWh)
1,924 1,897 — 27 7,346 7,228 — 118 
Revenue399 377 2 20 1,359 1,304 4 51 
Earnings39 39 — — 111 111 — — 

Sales
The increase in electricity sales for the quarter and year-to-date periods was due to higher average consumption by residential and commercial customers, as well as customer additions. Higher average consumption was largely due to the conversion of home heating systems from oil to electric in Eastern Canada, increased tourism-related activities in the Caribbean, and for the third quarter, overall warmer weather.

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


8
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
Earnings
Earnings for the quarter and year-to-date periods were consistent with the comparable periods in 2023. An increase in earnings associated with higher electricity sales and Rate Base growth was largely offset by higher operating, depreciation and finance costs, particularly at Newfoundland Power. A regulatory order approving cost recovery for Newfoundland Power was received in October 2024 and will be recognized in the fourth quarter of 2024.

Corporate and OtherQuarterYear-to-Date
Periods ended September 30VarianceVariance
($ millions, except as indicated)2024 2023 FXOther2024 2023 FXOther
Electricity sales (GWh) (1)
59 46 — 13 135 106 — 29 
Revenue (2)
10 21 — (11)25 77 — (52)
Net loss (3)
(45)(46)— 1 (140)(113)(2)(25)
(1)    Reflects electricity sales at Fortis Belize
(2)    Includes revenue for Fortis Belize as well as revenue for Aitken Creek up to the November 1, 2023 date of disposition
(3)    Includes non-regulated holding company expenses, earnings for Fortis Belize, as well as earnings for Aitken Creek up to the November 1, 2023 date of disposition

Sales
The increase in electricity sales for the quarter and year-to-date periods reflected higher hydroelectric production in Belize associated with rainfall levels.

Revenue
The decrease in revenue for the quarter and year-to-date periods reflected the disposition of Aitken Creek in November 2023, partially offset by higher hydroelectric production in Belize.

Net Loss
The decrease in net loss for the quarter was due to unrealized gains on derivative contracts, largely reflecting mark-to-market gains on total return swaps, as well as higher hydroelectric production in Belize, partially offset by higher holding company finance costs and a lower income tax recovery.

The disposition of Aitken Creek in November 2023 had a $8 million unfavourable impact on the net loss in the Corporate and Other segment for the year-to-date period. Although the disposition was unfavourable in comparison to the same period in 2023, the impact will be neutral for the annual period. Absent the disposition of Aitken Creek, the net loss for the year-to-date period, excluding foreign exchange, increased by approximately $17 million due to higher holding company finance costs and a lower income tax recovery, partially offset by unrealized gains on derivative contracts and higher hydroelectric production in Belize.


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 the project.

9
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
Non-U.S. GAAP Reconciliation
Periods ended September 30QuarterYear-to-Date
($ millions, except as indicated)2024 2023 Variance2024 2023 Variance
Adjusted Common Equity Earnings and Adjusted Basic EPS
Common Equity Earnings420 394 26 1,210 1,125 85 
Adjusting items:
Unrealized loss on mark-to-market of derivatives at Aitken Creek (1)
— 8 (8)— 18 (18)
Revaluation of deferred income tax assets (2)
— 9 (9)— 9 (9)
Adjusted Common Equity Earnings420 411 9 1,210 1,152 58 
Adjusted Basic EPS ($)
0.85 0.84 0.01 2.45 2.37 0.08 
Capital Expenditures
Additions to property, plant and equipment1,248 952 296 3,383 2,797 586 
Additions to intangible assets52 31 21 142 122 20 
Adjusting item:
Wataynikaneyap Transmission Power Project (3)
— 25 (25)29 109 (80)
Capital Expenditures1,300 1,008 292 3,554 3,028 526 
(1)    Represents the mark-to-market accounting of natural gas derivatives at Aitken Creek, net of income tax recovery of $3 million and $7 million for the three and nine months ended September 30, 2023, respectively, included in the Corporate and Other segment. The sale of Aitken Creek closed on November 1, 2023
(2)    Represents the revaluation of deferred income tax assets resulting from the reduction in the corporate income tax rate in the state of Iowa, included in the ITC segment
(3)    Represents Fortis' 39% share of capital spending during the construction of the Wataynikaneyap Transmission Power Project, included in the Other Electric segment. Construction was completed in the second quarter of 2024


FOCUS ON SUSTAINABILITY

Fortis' focus on sustainability is outlined in its 2023 Annual MD&A and the Corporation continues to advance work on a range of sustainability initiatives. In July 2024, Fortis released its 2024 Sustainability Report which summarizes progress and includes key performance indicators for 2023. The Corporation has reduced direct GHG emissions by 33% through 2023 compared to 2019 levels, marking significant progress towards its interim targets to reduce GHG emissions 50% by 2030 and 75% by 2035, as well as its 2050 net-zero direct GHG emissions target. Also in 2023, GHG intensity factors related to energy delivered to customers and electricity generated reached the lowest levels in the last five years.

The Corporation released its 2024 Climate Report in March 2024, building on the 2022 TCFD and Climate Assessment and further detailing our understanding of climate-related impacts across the Fortis group of companies. The report provides climate scenario analysis using low and high emissions scenarios over three time horizons, outlines physical risks and opportunities for priority assets using nine climate hazards, and assesses transition risks and opportunities using a framework based on enterprise risk management principles. The report further details mitigation and resiliency activities across Fortis utilities, and provides enhanced disclosures on climate governance.

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.

Sustainability and Climate-Related Disclosures
In March 2024, the CSSB issued the exposure drafts, CSDS S1, General Requirements for Disclosure of Sustainability-Related Financial Information, and CSDS S2, Climate-Related Disclosures, which outline proposed disclosure requirements requiring an entity to disclose information about its sustainability-related and climate-related risks and opportunities, including the disclosure of material Scope 1, 2 and 3 GHG emissions. The CSSB continues to deliberate the proposals and expects to issue final standards in December 2024. The CSSB standards must be adopted by the CSA to become mandatory for Canadian reporting issuers. The content and timing of the CSA's mandatory disclosure requirements are unknown.

In March 2024, the SEC released Rule No. 33-11275, The Enhancement and Standardization of Climate-Related Disclosures for Investors, which outlines climate-related disclosure requirements. The rule requires disclosure of the financial effects of severe weather events and other natural conditions, as well as other climate-related financial information, in the notes to the financial statements. In addition, the rule requires disclosure of risk management, governance and oversight activities, the impact of material climate-related risks on a company's strategy, business model and outlook, and details of material climate-related targets or goals. Disclosure of material Scope 1 and 2 GHG emissions is also required for certain filers. The SEC subsequently voluntarily stayed the rule pending completion of judicial review by the Court of Appeals for the Eighth Circuit. While such rules do not apply to Fortis, as a foreign private issuer filing in the U.S. using Form 40-F, management is reviewing the standard, in conjunction with the proposals in Canada, to assess the potential impact on the Corporation's disclosures.


10
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
REGULATORY MATTERS

ITC
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, and remanded the matter to FERC for further process. This matter dates back to complaints filed at FERC in 2013 and 2015 challenging the MISO base ROE then in effect.

In October 2024, FERC issued an order that removed the use of the risk premium model from the calculation of the base ROE, while maintaining other modifications to the methodology. The updated methodology revised the base ROE from 10.02% to 9.98%, with a maximum ROE inclusive of incentives not to exceed 12.58%. The order also directed the payment of certain refunds, with interest, by December 2025, for the 15-month period from November 2013 through February 2015, and prospectively from September 2016. The application of the order will result in a regulatory liability of approximately $35 million (US$26 million) to be recognized by ITC in the fourth quarter of 2024. Fortis' 80.1% share of the related after-tax earnings impact will be approximately $22 million, of which the vast majority relates to periods prior to January 1, 2024.

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. Although the timing and outcome of this proceeding remain unknown, every 10-basis point change in ROE at ITC impacts Fortis' annual EPS by approximately $0.01.

Transmission ROFR: In December 2023, the Iowa District Court ruled that the manner in which Iowa's ROFR statute was passed is unconstitutional. The statute granted incumbent electric transmission owners, including ITC, a ROFR to construct, own and maintain certain electric transmission assets in the state. The District Court did not make any determination on the merits of the ROFR itself, but did issue a permanent injunction preventing ITC and others from taking further action to construct the MISO LRTP tranche 1 Iowa projects in reliance on the ROFR.

MISO's decision with respect to the assignment of the tranche 1 LRTP projects was finalized on July 25, 2022. MISO is the only entity charged with determining what projects are to be competitively bid pursuant to its tariff. In May 2024, MISO commenced a variance analysis process as a result of the inability to construct a portion of the tranche 1 LRTP projects in Iowa due to the injunction imposed by the District Court. In August 2024, MISO concluded the variance analysis, which reaffirmed the original allocation of projects to ITC and other incumbent transmission owners. Approximately US$800 million of capital expenditures associated with the first tranche of MISO's LRTP in Iowa is reflected in Fortis' 2025-2029 capital plan. While the results of MISO's variance analysis process allow ITC to move forward with the development of its portion of tranche 1 LRTP projects in Iowa, various legal proceedings with respect to this matter are ongoing for which the timing and outcome are unknown.

Central Hudson
2024 General Rate Application: In July 2024, the PSC approved a one-year rate plan for Central Hudson with retroactive application to July 1, 2024, including an allowed ROE of 9.5%, an increase from the previous allowed ROE of 9.0%. The decision also maintained the 48% common equity component of capital structure.

CIS Implementation: In June 2024, the PSC issued an order that concluded the investigation concerning Central Hudson's billing system implementation. The PSC also released the final report issued by an independent third-party which determined that the CIS is stable and the critical issues have been resolved. As part of the order, total costs of US$63 million were agreed to not be recovered from customers, of which the majority were recognized prior to 2024. The remaining costs associated with the order, including Central Hudson's US$4 million contribution to a customer benefit fund recognized in the second quarter of 2024, are not expected to be material.

2025 General Rate Application: In August 2024, Central Hudson filed a general rate application with the PSC requesting an increase in electric and gas delivery rates effective July 1, 2025. The application includes a request to set Central Hudson's allowed ROE at 10% and a 48% common equity component of capital structure. The timing and outcome of this proceeding are unknown.

Show Cause Order: In October 2024, the PSC issued a Show Cause Order which directed Central Hudson to explain why the PSC should not initiate an enforcement proceeding in connection with a gas-related explosion that occurred in November 2023. Central Hudson will file a response to the order within 30 days. The timing and outcome of this proceeding are unknown.

FortisBC Energy and FortisBC Electric
2025-2027 Rate Framework: In April 2024, FortisBC filed an application with the BCUC requesting approval of a rate framework for the period 2025 through 2027. The rate framework builds upon the current multi-year rate plan and includes, amongst other items, a revised level of operation and maintenance expense per customer indexed for inflation less a fixed productivity adjustment factor, a similar approach to growth capital, a forecast approach to sustaining and other capital, continued collection of an innovation fund recognizing the need to accelerate investment in clean energy innovation, and the continued sharing with customers of variances from the allowed ROE. The rate framework also proposes the continuation of deferral mechanisms currently in place. The regulatory process will continue throughout 2024, with a decision expected in mid-2025.


11
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
FortisAlberta
GCOC Decision: In October 2023, the AUC issued a decision on the 2024 GCOC proceeding. In November 2023, FortisAlberta sought permission to appeal the GCOC decision to the Court of Appeal on the basis that the AUC erred in its decision to not adjust FortisAlberta's ROE and common equity component of capital structure to address incremental business risk associated with competition from REAs located in FortisAlberta's service area, as well as heightened regulatory risk due to the non-recovery of costs attributable to REAs. In April 2024, the Court of Appeal granted FortisAlberta permission to appeal, which is expected to be completed in the first quarter of 2025.

Third PBR Term Decision: In October 2023, the AUC issued a decision establishing the parameters for the third PBR term for the period of 2024 through 2028. In November 2023, FortisAlberta sought permission to appeal the decision to the Court of Appeal on the basis that the AUC erred in its decision to determine capital funding using 2018-2022 historical capital investments without consideration for funding of new capital programs included in the company's 2023 COS revenue requirement as approved by the AUC. FortisAlberta's application for permission to appeal the decision will be heard by the Court of Appeal in the fourth quarter of 2024.


FINANCIAL POSITION

Significant Changes between September 30, 2024 and December 31, 2023
Balance Sheet AccountIncrease (Decrease)
($ millions)FXOtherExplanation
Cash and cash equivalents11 260 Primarily due to the issuance of unsecured senior notes at UNS Energy in August 2024. UNS Energy plans to utilize the unused net proceeds from this issuance to repay maturing long-term debt. Balances on hand have been largely invested in interest-bearing accounts.
Accounts receivable and other current assets21 (149)Due to the seasonality of sales, particularly in Canada, and a lower income tax receivable at FortisBC Energy due to the receipt of a tax refund in the third quarter of 2024.
Regulatory assets (current and long-term)31 139 Due to changes associated with various regulatory mechanisms, including an increase in deferred income taxes, partially offset by the normal operations of rate stabilization accounts.
Property, plant and equipment, net599 2,346 Due to capital expenditures, partially offset by depreciation.
Deferred income taxes59 286 Due to higher temporary differences associated with ongoing capital investments.
Long-term debt (including current portion)409 1,634 Reflects debt issuances, partially offset by debt repayments, as well as higher borrowings under committed credit facilities, in support of the Corporation's capital plan.
Shareholders' equity322 672 
Due primarily to: (i) Common Equity Earnings for the nine months ended September 30, 2024, 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 credit facilities, the operation of the DRIP, as well as issuances of long-term debt, preference equity, and common shares including those issued through the ATM Program. 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.

12
FORTIS INC.SEPTEMBER 30, 2024 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 $5.6 billion of the total credit facilities are committed with maturities ranging from 2024 through 2029. Available credit facilities are summarized in the following table.

Credit Facilities
As atRegulated
Utilities		Corporate
and Other		September 30,
2024		December 31,
2023
($ millions)
Total credit facilities (1)
4,211 1,912 6,123 6,176 
Credit facilities utilized:
Short-term borrowings(97)— (97)(119)
Long-term debt (including current portion)(1,025)(695)(1,720)(1,572)
Letters of credit outstanding(55)(21)(76)(101)
Credit facilities unutilized3,034 1,196 4,230 4,384 
(1)    See Note 14 in the 2023 Annual Financial Statements for a description of the credit facilities as at December 31, 2023.

In April 2024, FortisBC Energy increased its operating credit facility from $700 million to $900 million and extended the maturity to July 2028. In May 2024, FortisBC Electric increased its operating credit facility from $150 million to $200 million and extended the maturity to April 2028.

In May 2024, the Corporation extended the maturity on its unsecured US$500 million non-revolving term credit facility to May 2025. Half of the term credit facility was repaid in the third quarter of 2024 and the remaining US$250 million has been fully utilized as at September 30, 2024. The facility is repayable at any time without penalty. In June 2024, the Corporation amended its $1.3 billion revolving term committed credit facility to extend the maturity to July 2029.

In August 2024, Newfoundland Power increased its operating credit facility from $100 million to $130 million and extended the maturity to August 2029.

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 September 30, 2024, consolidated fixed-term debt maturities/repayments are expected to average $1,489 million annually over the next five years and approximately 75% 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. In September 2023, Fortis established an ATM Program pursuant to the short-form base shelf prospectus, that allows the Corporation to issue up to $500 million of common shares from treasury to the public from time to time, at the Corporation's discretion, effective until December 22, 2024. As at September 30, 2024, $500 million remained available under the ATM Program and $1.5 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.

Fortis and its subsidiaries were in compliance with debt covenants as at September 30, 2024 and are expected to remain compliant in 2024.

13
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
Cash Flow Summary
Summary of Cash Flows
Periods ended September 30QuarterYear-to-Date
($ millions)2024 2023 Variance2024 2023 Variance
Cash and cash equivalents, beginning of period561 690 (129)625 209 416 
Cash from (used in):
Operating activities1,338 940 398 2,920 2,799 121 
Investing activities(1,313)(1,040)(273)(3,599)(2,994)(605)
Financing activities316 150 166 939 747 192 
Effect of exchange rate changes on cash and cash equivalents(6)15 (21)11 13 (2)
Change in cash associated with assets held for sale— 10 (10)— (9)9 
Cash and cash equivalents, end of period896 765 131 896 765 131 
Operating Activities
See "Performance at a Glance - Operating Cash Flow" on page 4.

Investing Activities
The increase in cash used in investing activities reflects higher capital expenditures. The Corporation's Capital Expenditures for 2024 are forecasted to be $5.2 billion. See "Capital Plan" on page 16.

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. See "Cash Flow Requirements" on page 12.

Debt Financing
Significant Long-Term Debt Issuances
Year-to-date September 30, 2024MonthInterest RateUse of Proceeds

($ millions, except as noted)
Issued
(%)
MaturityAmount
ITC
Secured senior notesJanuary5.98 2034     US85 
(1) (2) (3)
First mortgage bondsJanuary5.11 2029     US75 
(1) (2) (3)
First mortgage bondsJanuary5.38 2034     US75 
(1) (2) (3)
Unsecured senior notesMay5.65 2034     US400 
(3) (4)
UNS Energy
Unsecured senior notesJune5.60 2036     US30 
(1) (3)
Unsecured senior notesAugust5.20 2034     US400 
(3) (4)
Central Hudson
Senior notesApril5.59 2031     US25 
(1) (3)
Senior notesApril5.69 2034     US35 
(1) (3)
FortisBC Electric
Unsecured debenturesAugust4.92 2054100 
(1)
FortisAlberta
Unsecured debenturesMay4.90 2054300 
(1) (2) (3) (4)
Caribbean Utilities
Unsecured senior notesMay6.17 2039     US40 
(1) (2) (3) (5)
Unsecured senior notesMay6.37 2049     US40 
(1) (2) (3) (5)
FortisOntario
Unsecured senior notesAugust5.05 205455 
(1)
Fortis
Unsecured senior notesSeptember4.17 2031500 
(1) (3) (4)
(1)    Repay short-term and/or credit facility borrowings
(2)    Fund capital expenditures
(3)    General corporate purposes
(4)     Repay maturing long-term debt
(5)     Total of US$50 million expected to be used to fund or refinance a portfolio of new and/or existing qualifying green initiatives
14
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
UNS Energy issued US$400 million of unsecured senior notes in August 2024, as noted in the previous table. The unused net proceeds from this issuance have been invested in interest-bearing accounts as at September 30, 2024. The balance will be used to repay maturing long-term debt within the next 12-month period.

In September 2024, ITC priced US$250 million of first mortgage bonds with funding expected in December 2024. The related issuances will consist of US$125 million of 11-year, 4.88% bonds and US$125 million of 19-year, 5.25% bonds. Proceeds are expected to be used to repay maturing long-term debt, repay credit facility borrowings, fund capital expenditures and for general corporate purposes.

In October 2024, Central Hudson issued US$25 million of 5-year, 4.88% senior notes, US$44 million of 10-year, 5.30% senior notes and US$35 million 12-year, 5.40% senior notes. Proceeds will be used to refinance long-term debt and for general corporate purposes.

Common Equity Financing
Common Equity Issuances and Dividends Paid
Periods ended September 30QuarterYear-to-Date
($ millions, except as indicated)2024 2023 Variance2024 2023 Variance
Common shares issued:
Cash (1)
13 6 7 34 34 — 
Non-cash (2)
107 99 8 324 304 20 
Total common shares issued120 105 15 358 338 20 
Number of common shares issued (# millions)
2.1 2.1 — 6.7 6.3 0.4 
Common share dividends paid:
Cash(186)(175)(11)(549)(517)(32)
Non-cash (3)
(106)(99)(7)(324)(304)(20)
Total common share dividends paid(292)(274)(18)(873)(821)(52)
Dividends paid per common share ($)
0.59 0.565 0.025 1.771.695 0.075 
(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 8, 2024 and July 30, 2024, Fortis declared a dividend of $0.59 per common share paid on June 1, 2024 and September 1, 2024, respectively. On September 25, 2024, Fortis declared a dividend of $0.615 per common share payable on December 1, 2024. The payment of dividends is at the discretion of the Board and depends on the Corporation's financial condition and other factors.

On March 1, 2024, the annual fixed dividend per share for the First Preference Shares, Series K was reset from $0.9823 to $1.3673 for the five-year period up to but excluding March 1, 2029.

On December 1, 2024, the annual fixed dividend per share for the First Preference Shares, Series M will reset from $0.9783 to $1.3733 for the five-year period up to but excluding December 1, 2029.

Contractual Obligations
There were no material changes to the contractual obligations disclosed in the 2023 Annual MD&A, other than issuances of long-term debt and credit facility utilization (see "Cash Flow Summary" on page 14), except that in August 2024, TEP entered into a US$268 million Engineering, Procurement, and Construction Agreement for the development of the Roadrunner Reserve 2 battery energy storage system facility. The facility is expected to be placed in service in 2026 (see "Capital Plan - Major Capital Projects" on page 17).

Off-Balance Sheet Arrangements
There were no material changes to off-balance sheet arrangements from those disclosed in the 2023 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.

15
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
Consolidated Capital StructureSeptember 30, 2024December 31, 2023
As at($ millions)(%)($ millions)(%)
Debt (1)
31,122 56.1 29,364 55.7 
Preference shares1,623 2.9 1,623 3.1 
Common shareholders' equity and non-controlling interests (2)
22,770 41.0 21,709 41.2 
55,515 100.0 52,696 100.0 
(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 3.4% as at September 30, 2024 (December 31, 2023 - 3.5%)

Outstanding Share Data
As at November 4, 2024, the Corporation had issued and outstanding 497.3 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.

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 November 4, 2024, an additional 1.6 million common shares would be issued and outstanding.

Credit Ratings
The Corporation's credit ratings shown below reflect its low business 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 September 30, 2024RatingTypeOutlook
S&PA-IssuerNegative
BBB+Unsecured debt
Morningstar DBRSA (low)IssuerStable
A (low)Unsecured debtStable
Moody'sBaa3IssuerStable
Baa3Unsecured debt

In February 2024, Moody's confirmed the Corporation's Baa3 issuer and senior unsecured debt credit ratings and stable outlook.

In February 2024, Fitch revised Central Hudson's senior unsecured debt rating from A- to BBB+ and changed the outlook from negative to stable. Fitch indicated the rating reflects its view of limited visibility associated with Central Hudson's 2024 general rate application, as well as the company's pressured credit metrics and elevated accounts receivable balance.

In May 2024, Morningstar DBRS confirmed the Corporation's A (low) issuer and senior unsecured debt credit ratings and stable outlook.

In October 2024, S&P confirmed the Corporation's A- issuer and BBB+ senior unsecured debt credit ratings and negative outlook.

Capital Plan
Year-to-date Capital Expenditures of $3.6 billion are consistent with expectations and the annual forecast of $5.2 billion is on track.

Capital Expenditures (1)
Year-to-date September 30, 2024Regulated Utilities
UNS EnergyCentral HudsonFortisBC EnergyFortis AlbertaFortisBC ElectricOther ElectricTotal Regulated UtilitiesNon-Regulated Corporate and Other
($ millions, except as indicated)ITC
Total (1)
Total1,021 726 294 660 410 89 351 3,551 3 3,554 
(1)    See "Non-U.S. GAAP Financial Measures" on page 9

16
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
New Five-Year Capital Plan
The Corporation's five-year 2025-2029 capital plan is targeted at $26.0 billion.

($ billions)20252026202720282029
Total (1)
Five-Year Capital Plan5.2 5.2 5.6 5.4 4.6 26.0 
(1)    Reflects an assumed U.S. dollar-to-Canadian dollar exchange rate of 1.30. On average, Fortis estimates that a five-cent increase or decrease in the U.S. dollar relative to the Canadian dollar would increase or decrease Capital Expenditures by approximately $600 million over the five-year planning period
The Corporation's 2025-2029 capital plan of $26.0 billion is $1.0 billion higher than the previous five-year plan. The increase is driven by projects associated with the MISO LRTP and resiliency investments at ITC, as well as distribution investments largely due to customer growth at FortisAlberta.

Approximately $6.7 billion of the five-year capital plan supports energy transition investments which focus on interconnecting renewables to the grid, renewable, storage and new natural gas investments supporting the exit from coal, and cleaner fuel solutions. Fortis remains focused on maintaining customer affordability by controlling costs, investing in cleaner energy resulting in fuel savings for customers, utilizing available tax credits, and implementing innovative practices, among other initiatives.

The five-year capital plan is low risk and highly executable, with nearly all investments being regulated and only 23% relating to Major Capital Projects. Geographically, 58% of planned expenditures are expected in the U.S., including 29% at ITC, with 38% in Canada and the remaining 4% in the Caribbean.

The five-year capital plan is expected to be funded primarily by cash from operations and regulated utility debt. Common equity proceeds are expected to be provided by the Corporation's DRIP, assuming current participation levels. The Corporation's $500 million ATM Program remains available and provides funding flexibility as required.

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 Projects
ForecastPlanExpected
($ millions)2024 2025-2029Completion
ITC
MISO LRTP27 1,739 Post-2029
UNS Energy
IRP Related Generation— 1,621 Various
Roadrunner Reserve Battery Storage Project 1313 23 2025 
Roadrunner Reserve Battery Storage Project 2114 325 2026 
Vail-to-Tortolita Transmission Project78 223 2027 
FortisBC Energy
Eagle Mountain Pipeline Project (1)
379 317 2027 
Tilbury LNG Storage Expansion7 584 2029 
AMI Project66 697 2028 
Tilbury 1B Project1 343 2029
Total985 5,872 
(1)Net of customer contributions

MISO LRTP
Reflects investments associated with two tranches of the MISO LRTP. In 2022, the MISO board approved the first tranche of projects representing 18 transmission projects across the MISO Midwest subregion with total associated costs estimated at US$10 billion. Six of these projects run through ITC's MISO operating companies' service territories. ITC estimates transmission investments of US$1.4 billion to US$1.8 billion through 2030 associated with six of the 18 projects, with investments of approximately $1.6 billion (US$1.2 billion) included in the Corporation's 2025-2029 capital plan.

Investments of approximately $0.2 billion (US$0.1 billion) have been included in the Corporation's 2025-2029 capital plan associated with tranche 2.1. Significant additional investment opportunities remain for tranche 2.1 (see "Additional Investment Opportunities" on page 18).

17
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
IRP Related Generation
Includes capital expenditures supporting the transition to cleaner energy as outlined in the 2023 IRPs for TEP and UNS Electric including renewable generation, energy storage systems and natural gas generation. Investments support approximately 950 MW of generation, subject to an all-source request for proposal.

Roadrunner Reserve Battery Storage Projects
Consists of two, 200 MW, battery energy storage systems which will facilitate the integration of renewable energy into the electric grid. Each system is capable of storing 800 MW hours of energy, enough to serve approximately 42,000 homes for four hours when deployed at full capacity. TEP will own and operate the systems.

Construction of Roadrunner Reserve 1 has commenced and is scheduled for completion in 2025. In October 2024, TEP filed an application with the ACC requesting approval to defer certain costs associated with owning and operating Roadrunner Reserve 1 for future recovery. TEP cannot predict the timing or outcome of this application.

In August 2024, TEP entered into an engineering, procurement and construction agreement to develop Roadrunner Reserve 2, which is scheduled for completion in 2026.

Vail-to-Tortolita Transmission Project
Includes investment in one circuit of a new double circuit 230 kV transmission line to tie infrastructure into the TEP system, improving service and reliability to customers. Construction commenced in late 2023, and is scheduled for completion in 2027.

Eagle Mountain Pipeline Project
The project consists of a 50-km pipeline expansion to a small-scale LNG facility owned by Woodfibre LNG near Squamish, British Columbia. FortisBC Energy commenced construction of the project in 2023 which is scheduled for completion in 2027.

Tilbury LNG Storage Expansion Project
This project replaces the original LNG storage tank at the Tilbury site and increases the available regasification capacity to provide backup gas supply for lower mainland customers. The regulatory process was adjourned in 2023 in order for FortisBC Energy to prepare further information in support of the CPCN application. FortisBC Energy plans to file additional evidence in late 2024, with a decision from the BCUC expected in 2025.

AMI Project
The project includes replacement of residential, commercial and industrial meters with advanced gas meters to support the safety, resiliency, and efficient operation of FortisBC Energy's gas distribution system. The project will enable remote meter reading and remote shutoff of gas. The CPCN application was approved by the BCUC in 2023, and installation of the advanced meters is expected to commence in 2025 and be substantially complete in 2028.

Tilbury 1B Project
Construction of additional liquefaction and dispensing, including on-shore piping, in support of marine bunkering and to further optimize the Tilbury Phase 1A Expansion Project. This FortisBC Energy project received an Order in Council from the Government of British Columbia in 2017. An initial project scope has been filed with regulators to support the federal impact assessment and provincial environmental assessment required to further expand the Tilbury site.

Additional Investment Opportunities
ITC - MISO LRTP
In September 2024, MISO released a final portfolio outlining LRTP tranche 2.1 investments in the MISO Midwest subregion of approximately US$22 billion. MISO board approval of the portfolio is expected in December 2024. ITC estimates at least US$3 billion in capital expenditures for the MISO tranche 2.1 projects located in Michigan and Minnesota where ROFRs are in effect. The majority of this investment is expected beyond 2029.

FortisBC Energy - LNG
During 2024, provincial and federal environmental assessment certificates were issued for the Tilbury Marine Jetty project. The construction of the jetty supports further expansion of FortisBC's Tilbury LNG facility, which is uniquely positioned to meet customer demand for LNG. The site is scalable, can accommodate additional storage and liquefaction equipment and is close to international shipping lanes. Once constructed, the jetty would utilize FortisBC Energy's assets at the Tilbury site, including the Tilbury Phase 1B Expansion Project yet to be constructed, to service marine bunkering.


BUSINESS RISKS

The Corporation's business risks remain substantially unchanged from those disclosed in its 2023 Annual MD&A. See "Regulatory Matters" on page 11 and "Outlook" on page 21 for applicable updates.

18
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
ACCOUNTING MATTERS

Accounting Policies
The Interim Financial Statements have been prepared following the same accounting policies and methods as those used to prepare the 2023 Annual Financial Statements.

Future Accounting Pronouncements
Segment Reporting: ASU No. 2023-07, Improvements to Reportable Segment Disclosures, is effective for Fortis' December 31, 2024 annual financial statements, and for interim periods beginning in 2025, on a retrospective basis. The ASU requires disclosure of incremental segment information, including significant segment expenses and other items that are included in segment profit or loss. This ASU is not expected to materially impact Fortis' disclosures.

Income Taxes: ASU No. 2023-09, Improvements to Income Tax Disclosures, is effective for Fortis on January 1, 2025 on a prospective basis, with retrospective application and early adoption permitted. The ASU requires additional disclosure of income tax information by jurisdiction to reflect an entity's exposure to potential changes in tax legislation, and associated risks and opportunities. This ASU is not expected to materially impact Fortis' disclosures.

Income Tax
In June 2024, the Government of Canada enacted legislation with respect to interest deductibility limitations and global minimum tax, both of which are applicable to Fortis as of January 1, 2024. The Corporation does not expect these tax changes to have a material impact on its financial results, Operating Cash Flow or credit ratings.

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 2023 Annual MD&A.


FINANCIAL INSTRUMENTS

Long-Term Debt and Other
As at September 30, 2024, the carrying value of long-term debt, including the current portion, was $31.8 billion (December 31, 2023 - $29.7 billion) compared to an estimated fair value of $30.6 billion (December 31, 2023 - $27.9 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 2023 Annual MD&A, except for interest rate contracts utilized at ITC and Fortis as disclosed in Note 14 of the Interim Financial Statements.


19
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
SUMMARY OF QUARTERLY RESULTS
Common Equity
RevenueEarningsBasic EPSDiluted EPS
Quarter ended($ millions)($ millions)($)($)
September 30, 20242,771 420 0.85 0.85 
June 30, 20242,670 331 0.67 0.67 
March 31, 20243,118 459 0.93 0.93 
December 31, 20232,885 381 0.78 0.78 
September 30, 20232,719 394 0.81 0.81 
June 30, 20232,594 294 0.61 0.61 
March 31, 20233,319 437 0.90 0.90 
December 31, 20223,168 370 0.77 0.77 

Generally, within each calendar year, quarterly results fluctuate in accordance with seasonality. Given the diversified nature of the Corporation's subsidiaries, seasonality varies. 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.

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 at UNS Energy; (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.

September 2024/September 2023
See "Performance at a Glance" on page 2.

June 2024/June 2023
Common Equity Earnings increased by $37 million and basic EPS increased by $0.06 in comparison to the second quarter of 2023. The increase was driven by strong earnings in Arizona, reflecting new customer rates at TEP effective September 1, 2023 and higher retail electricity sales associated with warmer weather. Rate Base growth across our utilities and the timing of recognition of new cost of capital parameters approved for FortisBC in 2023 also contributed to earnings growth. The increase was partially offset by lower earnings for Central Hudson and the Other Electric segment, largely reflecting higher operating 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.

March 2024/March 2023
Common Equity Earnings increased by $22 million and basic EPS increased by $0.03 in comparison to the first quarter of 2023. The increase was due to the timing of recognition of new cost of capital parameters approved for FortisBC in 2023 and Rate Base growth across our utilities. The increase was partially offset by higher holding company costs, including finance charges and unrealized losses on derivative contracts, and the November 1, 2023 disposition of Aitken Creek. In addition, the change in EPS reflected an increase in the weighted average number of common shares outstanding, largely associated with the Corporation's DRIP.

December 2023/December 2022
Common Equity Earnings increased by $11 million and basic EPS increased by $0.01 in comparison to the fourth quarter of 2022. The increase was driven by: (i) Rate Base growth; (ii) higher retail revenue in Arizona, due to new customer rates at TEP; and (iii) the new cost of capital parameters approved for FortisBC effective January 1, 2023. The increase was partially offset by lower earnings at Aitken Creek, due to the November 1, 2023 disposition, as well as the recognition of mark-to-market accounting gains on natural gas derivatives and margins on gas sold in the fourth quarter of 2022. 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 nine months ended September 30, 2024 and 2023.

As of September 30, 2024, accounts receivable included $17 million due from Belize Electricity (December 31, 2023 - $8 million).
20
FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
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 September 30, 2024 and December 31, 2023, there were no material inter-segment loans outstanding. Interest charged on inter-segment loans was not material for the three and nine months ended September 30, 2024 and 2023.


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. The Corporation's $26 billion five-year capital plan is expected to increase midyear Rate Base from $38.8 billion in 2024 to $53.0 billion by 2029, translating into a five-year CAGR of 6.5%.

Beyond the five-year capital plan, 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, transmission investments associated with the MISO LRTP tranches 1, 2.1 and 2.2 as well as regional transmission in New York; climate adaptation and grid resiliency investments; RNG and LNG infrastructure in British Columbia; and the acceleration of cleaner energy infrastructure and load growth 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 2029, and is premised on the assumptions and material factors listed under "Forward-Looking Information".

Fortis is on track to achieve its corporate-wide targets to reduce direct GHG emissions by 50% by 2030 and 75% by 2035 from a 2019 base year. The Corporation's additional 2050 net-zero direct GHG emissions target reinforces Fortis' commitment to further decarbonize over the long-term, while continuing our focus on reliability and affordability.


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 impact of the disposition of Aitken Creek on earnings for the annual period; targeted annual dividend growth through 2029; forecast capital expenditures for 2024 and 2025 through 2029, including investments which support the energy transition; the 2030 and 2035 direct GHG emissions reduction targets; the 2050 net-zero direct GHG emissions target; the expected timing, outcome and impact of legal and regulatory proceedings and decisions; the expected funding sources for operating expenses, interest costs, capital expenditures and working capital requirements; the expected consolidated fixed-term debt maturities and repayments through to 2029; 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 expectation that the Corporation and its subsidiaries will continue to have access to long-term capital and will remain compliant with debt covenants in 2024; the expected funding date and use of proceeds of debt securities to be issued by ITC; expected sources of funding for the capital plan, including the expected source of common equity proceeds; the nature, timing, benefits and expected costs of certain capital projects including ITC's transmission projects associated with the MISO LRTP, resiliency investments at ITC, UNS Energy's IRP Related Generation, Roadrunner Reserve Battery Storage, and Vail-to-Tortolita Transmission projects, as well as FortisBC Energy's Eagle Mountain Pipeline, Tilbury LNG Storage Expansion, AMI and Tilbury 1B projects, and additional opportunities beyond the capital plan, including transmission investments associated with MISO LRTP tranches 1, 2.1 and 2.2, further expansion of FortisBC’s Tilbury LNG facility related to the construction of the Tilbury Marine Jetty project, further expansion in the U.S. to facilitate the interconnection of cleaner energy, transmission investments associated with regional transmission in New York, climate adaptation and grid resiliency investments, RNG and LNG infrastructure in British Columbia, and the acceleration of cleaner energy infrastructure and load growth investments across our jurisdictions; the potential impact of future accounting pronouncements on the Corporation's disclosures; the expectation that changes to Canadian tax legislation with respect to interest deductibility limitations and global minimum tax will not have a material impact on financial results, Operating Cash Flow or credit ratings; forecast Rate Base and Rate Base growth through 2029; and the expectation that long-term growth in Rate Base will drive earnings that support dividend growth guidance of 4-6% annually through 2029.

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: reasonable outcomes for legal and regulatory proceedings 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; no material changes in the assumed U.S. dollar to Canadian dollar exchange rate; the continuation of current participation levels in the Corporation's DRIP; 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 2023 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 2024 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 November 4, 2024. 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.

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FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT


Interim Management Discussion and Analysis
GLOSSARY

2023 Annual Financial Statements: the Corporation's audited consolidated financial statements and notes thereto for the year ended December 31, 2023

2023 Annual MD&A: the Corporation's management discussion and analysis for the year ended December 31, 2023

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 9

Aitken Creek: Aitken Creek Gas Storage ULC, a 93.8%-owned subsidiary of FortisBC Holdings Inc., sold on November 1, 2023

ASU: accounting standards update

ATM Program: at-the-market equity program

AUC: Alberta Utilities Commission

BCUC: British Columbia Utilities Commission

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

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 9

Caribbean Utilities: Caribbean Utilities Company, Ltd., an indirect approximately 60%-owned (as at December 31, 2023) 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.

COS: cost of service

Court of Appeal: Court of Appeal of Alberta

CPCN: Certificate of Public Convenience and Necessity

CSA: Canadian Securities Administrators

CSDS: Canadian Sustainability Disclosure Standard




CSSB: Canadian Sustainability Standards Board

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

DRIP: dividend reinvestment plan

EPS: earnings per common share

FERC: Federal Energy Regulatory Commission

Fitch: Fitch Ratings Inc.

Fortis: Fortis Inc.

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

FortisBC: FortisBC Energy and FortisBC Electric

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)

Interim Financial Statements: the Corporation's unaudited condensed consolidated interim financial statements and notes thereto for the three and nine months ended September 30, 2024

Interim MD&A: the Corporation's management discussion and analysis for the three and nine months ended September 30, 2024

IRP: integrated resource plan

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 LLC, and ITC Great Plains, 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
22
FORTIS INC.SEPTEMBER 30, 2024 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.

Morningstar DBRS: DBRS Limited

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

RNG: renewable natural gas

ROE: rate of return on common equity

ROFR: right of first refusal

RTO: regional transmission organization

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

SEC: U.S. Securities and Exchange Commission

SEDAR+: Canadian System for Electronic Document Analysis and Retrieval

TCFD: Task Force for Climate-Related Financial Disclosures

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

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

UNS Energy: UNS Energy Corporation, an indirect wholly owned subsidiary of Fortis, together with its subsidiaries, including TEP, UNS Electric, Inc. 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
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FORTIS INC.SEPTEMBER 30, 2024 QUARTER REPORT
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