Slides
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Q3 2026 EARNINGS CONFERENCE CALL November 3, 2026 1
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Fortis includes forward-looking information in this presentation within the meaning of applicable Canadian securities laws and forward-looking statements within the meaning of the 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 2026 and 2027-2031; expected timing, outcome, and impact of legal and regulatory proceedings; forecast five-year CAGR to 2031; annual dividend growth guidance through 2031; forecast Rate Base for 2026 through 2031; forecast three-year CAGR to 2029; the expectation that the proportion of ITC's FERC-regulated assets in the Corporation's consolidated Rate Base will increase during the Capital Plan period; expected nature, timing, benefits, and costs of certain opportunities above and beyond the Capital Plan at ITC, including investments associated with the MISO LRTP Tranche 2.1 projects, other MISO LRTP and MTEP projects, and customer connections associated with load growth; expected in-service dates and total cost of the MARS project; expected nature, timing, benefits, and costs of certain opportunities above and beyond the Capital Plan at UNS Energy, including investments associated with load growth for new and existing customers, integrated resource plans, and FERC-regulated transmission; expected timing and resources for TEP to serve load pursuant to an energy supply agreement with its data center customer; estimated costs of incremental generation and associated transmission investments associated with the approximately 800 MW high-growth scenario in TEP's IRP; planned resource additions under TEP's and UNS Electric's base case IRPs; projected average system cost per kWh under various scenarios included in TEP's IRP; TEP's planned retirement of coal-fired generation by 2032; expected nature, timing, benefits, and costs of certain opportunities above and beyond the Capital Plan at FortisBC, including investments associated with the Tilbury LNG Expansion post-2031, Regional Transmission Pipeline Expansion, and customer and load growth in the Okanagan electric service territory; estimated potential incremental capital above and beyond the Capital Plan; expected and potential impacts on rates associated with various affordability initiatives, including O&M savings targets at Central Hudson, beneficial load growth at ITC Midwest and TEP, capital optimization related to the UNS Springerville Natural Gas Generation, and rate benefits associated with LNG projects at FortisBC and the Eagle Mountain Pipeline Project; expected sources of funding for the Capital Plan, including common equity provided through the DRIP at current participation levels; the expectation of a consistent capital structure over the planning period; the expectation that the funding plan supports existing investment-grade credit ratings; planned re-establishment of the short-form base shelf prospectus and ATM Program; expected issuances of common shares under ATM Program over next 12 months; forecast credit metrics for 2026 and 2027-2031; forecast Capital Expenditures for 2027-2031 by business unit; forecast capital expenditures for pre-2027, 2027-2031, post-2031, total project cost and estimated completion dates of Major Capital Projects, including ITC MISO LRTP – Tranche 1, ITC MISO LRTP – Tranche 2.1, ITC Big Cedar Load Expansion, UNS Transmission Project at TEP, UNS Gas Generation Project at UNS Electric, UNS Springerville Natural Gas Generation, FortisBC Tilbury 1B Project, FortisBC LNG Storage Tank Expansion, FortisBC AMI Project, and FortisBC Eagle Mountain Pipeline Project; expected construction timing of Tilbury 1B; expected stakeholder consultation related to Tilbury Phase 2 LNG Expansion; potential additional capacity of, ability to supply domestic or bulk LNG export markets from, and expected staged development of the Tilbury Phase 2 Liquefaction Expansion; forecast Rate Base for 2026 through 2031 and five-year CAGR to 2031 by business unit; estimated impact of the U.S. dollar-to-Canadian dollar exchange rate, inclusive of hedging activities, on the Capital Plan and EPS; the Corporation's commitment to a coal-free generation mix by 2032; the Corporation's 2050 net-zero greenhouse gas emissions target; and forecast debt maturities for 2027-2036. 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: 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 Board exercising its discretion to declare dividends, taking into account the financial performance and condition of the Corporation; reasonable legal and regulatory decisions and the expectation of regulatory stability; 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 policies, environmental laws and regulations that could have a material negative impact; maintenance of adequate insurance coverage; the ability to obtain and maintain licenses 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 the results 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. For additional information with respect to certain of these risks or 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 presentation. 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. Unless otherwise specified, all financial information is in Canadian dollars and rate base refers to midyear rate base. Note: U.S. dollar-denominated five-year Capital Plan and forecast rate base converted at a forecast USD:CAD foreign exchange rate of 1.35 for 2027-2031. 2 FORWARD-LOOKING INFORMATION
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3 David Hutchens President and Chief Executive Officer, Fortis Inc. Jocelyn Perry EVP and Chief Financial Officer, Fortis Inc.
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Delivered Safe & Reliable Service Top Quartile Safety and Reliability Relative to Industry Peers Capital Expenditures of $4.2B Through YTD September Annual Capital Forecast of $6.0B, increased from $5.6B Q3 2026 Actual & Adjusted EPS of $0.92 Compared to Adjusted EPS of $0.87 in Q3 2025 New $32.2B 2027-2031 Capital Plan Largest in Fortis History Environmental Approval Received for Tilbury LNG Storage Tank & Phase 2 Expansion Significantly Advancing Capital Investment Opportunities in British Columbia Competitive Project in Iowa Awarded to ITC Advancing Capital Investment Opportunity Q4 Dividend Increase of 4% 53 Consecutive Years of Increases in Dividends Paid 4 Q3 2026 BUSINESS HIGHLIGHTS
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THIRD QUARTER & YEAR-TO-DATE RESULTS 5 $2.57 $0.06 $2.63 $2.69 YTD 2025 Actual EPS Disposition of FortisTCI YTD 2025 Adjusted EPS YTD 2026 Actual & Adjusted EPS $0.81 $0.06 $0.87 $0.92 Q3 2025 Actual EPS Disposition of FortisTCI Q3 2025 Adjusted EPS Q3 2026 Actual & Adjusted EPS Third Quarter Year-to-Date Adjusted EPS ↑ $0.05 Note: Adjusted EPS is a Non-U.S. GAAP financial measure. Refer to Slide 26 for the Non-U.S. GAAP reconciliation. Adjusted EPS ↑ $0.06
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$0.87 $0.03 $0.02 $0.02 ($0.01) ($0.01) $0.01 ($0.01) $0.92 Q3 2025 Adjusted Basic EPS U.S. Transmission (ITC) U.S. Electric & Gas Western Canadian Electric & Gas Other Electric Corporate & Other Foreign Exchange Weighted Average Shares Q3 2026 Actual & Adjusted Basic EPS Q3 2026 ADJUSTED EPS DRIVERS 6 Q3 2026 Adjusted EPS $0.05 compared to Q3 2025 (1) Fortis sold its utility in Turks and Caicos in September 2025, and its investments in Belize, including the non-regulated hydroelectric generation facilities, in October 2025. On an EPS basis, the dispositions had a $0.02 dilutive impact on Q3 2026 results, net of finance cost savings. (2) Includes UNS Energy and Central Hudson. (3) Includes FortisBC Energy, FortisAlberta and FortisBC Electric. (4) Reflects average foreign exchange of 1.40 in Q3 2026 compared to 1.38 in Q3 2025. (2) (3) (4) Note: Adjusted EPS is a Non-U.S. GAAP financial measure. Refer to Slide 26 for the Non-U.S. GAAP reconciliation. Q3 2026 EPS reflects $0.02 dilution associated with the 2025 dispositions(1)
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YEAR-TO-DATE SEPTEMBER 2026 ADJUSTED EPS DRIVERS 7 $2.63 $0.07 $0.07 $0.03 ($0.01) ($0.03) ($0.03) ($0.04) $2.69 YTD 2025 Adjusted Basic EPS U.S. Transmission (ITC) Western Canadian Electric & Gas U.S. Electric & Gas Other Electric Corporate & Other Foreign Exchange Weighted Average Shares YTD 2026 Actual & Adjusted Basic EPS (1) Fortis sold its utility in Turks and Caicos in September 2025, and its investments in Belize, including the non-regulated hydroelectric generation facilities, in October 2025. On an EPS basis, the dispositions had a $0.05 dilutive impact on year-to-date results, net of finance cost savings. (2) Includes FortisBC Energy, FortisAlberta and FortisBC Electric. (3) Includes UNS Energy and Central Hudson. (4) Reflects average foreign exchange of 1.38 in YTD 2026 compared to 1.40 in YTD 2025, and foreign exchange gains recorded in 2025 associated with the revaluation of U.S. dollar denominated short-term liabilities (2) (3) (4) YTD 2026 Adjusted EPS $0.06 compared to YTD 2025 Note: Adjusted EPS is a Non-U.S. GAAP financial measure. Refer to Slide 26 for the Non-U.S. GAAP reconciliation. YTD September 2026 EPS reflects $0.05 dilution associated with the 2025 dispositions(1)
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REGULATORY UPDATE 8 • In 2021, FERC issued a supplemental NOPR proposing to eliminate the 50 bps RTO ROE incentive adder for transmission owners that have been RTO members for longer than three years • The timing and outcome of this proceeding are unknown • In May 2026, the AUC approved the negotiated settlement agreement that had been reached with respect to FortisAlberta's depreciation study • The corresponding reduction in FortisAlberta's depreciation rates has resulted in a true-up of $130M • FortisAlberta has proposed that the true-up be returned to customers over multiple years in order to moderate future increases with the decision on the true-up expected from the AUC in Q4 2026 • No impact to earnings is anticipated • In October 2026, the ACC ALJ issued a ROO recommending an allowed ROE of 9.65% and a 55.5% common equity component of capital structure • The ROO supported an annual formulaic rate adjustment mechanism including a range of +/- 50 bps around the allowed ROE, the inclusion of post-test year adjustments, the elimination of certain adjustor mechanisms and the deferral of certain costs associated with Roadrunner Reserve II for future recovery • The ROO proposes implementation of new rates by December 1, 2026 and ACC decision is expected in November 2026 Transmission Incentives Depreciation StudyTEP General Rate Application • In 2023, the AUC established the parameters for the 2024-2028 PBR term • FortisAlberta filed an appeal with respect to the AUC decision establishing the parameters for the third PBR term for the period of 2024 through 2028 • The appeal was largely focused on the AUC's use of historical capital additions rather than forecast capital investments approved in the 2023 cost of service proceeding • In Q3 2026, the Court of Appeal of Alberta dismissed the appeal Third PBR Term Decision
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FIVE-YEAR PLAN AT A GLANCE Capital Expenditures Rate Base Dividend Growth 2027-2031 Capital Plan $32.2B $3.4B 7.5% 5-Year CAGR 50 Over Prior Plan 4% 4-6% Annual Dividend Growth Guidance Extended to 2031 Increase in Q4 2026 Dividend Over Prior Plan 9 bps
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$3.4B Increase in 5-Year Capital Plan 10 Note: U.S. dollar-denominated capital expenditures converted at a USD:CAD foreign exchange rate of 1.35. 2026-2030 Capital Plan 2027-2031 Capital Plan Incremental Capital Drivers ITC - $1.7B MISO LRTP Tranche 2.1 projects, baseline reliability projects and interconnections FortisBC - $1.0B Tilbury Phase 1B, Tilbury LNG Storage Tank Expansion and baseline reliability projects Other Regulated Utilities - $0.7B FortisAlberta, Central Hudson and Newfoundland Power 2027-2031 CAPITAL PLAN DRIVEN BY TRANSMISSION & LNG INVESTMENTS $28.8B $32.2B
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HIGHLY EXECUTABLE, LOW-RISK FIVE-YEAR CAPITAL PLAN SUPPORTS RATE BASE GROWTH Transmission 47% Distribution 29% Generation 6% LNG & Renewable Gases 7% IT 6% Other 5% Capital Plan $32.2B 2027-2031 100% Regulated Capital Geographic Diversity ✓ 62% U.S. ✓ 36% Canada ✓ 2% Cayman Islands Consolidated Rate Base $45.3B $48.2B $52.4B $55.8B $58.9B $63.9B 2026F 2027F 2028F 2029F 2030F 2031F 11 Note: U.S. dollar-denominated capital expenditures converted at a forecast USD:CAD foreign exchange rate of 1.35. Rate base reflects a USD:CAD exchange rate of 1.38 for 2026F and 1.35 for 2027-2031F. CAGR calculated on a constant foreign exchange rate basis.
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12 Marshalltown – Lehigh – Sub T – Montezuma – East Adair (MARS) Project (No. 38 & 39) • Primarily located in ITC Midwest’s current footprint and connects to existing ITC assets • Projects consists of two new 345 kV & two new 765 kV lines connecting Marshalltown, Lehigh, Sub T, Montezuma and East Adair • ~300 miles of transmission lines • Expected in-service dates: 2029-2034 • Expected total cost: ~US$1B, with US$0.5B included in five-year plan COMPETITIVE PROJECT IN IOWA AWARDED TO ITC ~US$0.5B included in 2027-2031 Capital Plan
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$11.6B 2027-2031 ITC - ROBUST TRANSMISSION GROWTH CONTINUES 13 Infrastructure Investments 45% Interconnections 22% MISO Long Range Transmission Plan 28% IT, General & Other 5% Opportunities Above and Beyond the Plan: MISO LRTP Tranche 2.1 • ROFR projects in Michigan / Minnesota and Iowa system upgrades (US$2.9–$3.4B) • MARS competitive project in Iowa (US$0.5B) Customer Connections 10,000 MW+ of potential load growth, primarily data centers and economic development Future MISO LRTP / MTEP ~32 GW of large-load requests being studied through MTEP26; further information on development of next round of LRTP in MISO Midwest expected in late 2026 Rate Base $14.8B $21.9B 2026F 2031F 8.6% CAGR Capital Plan Note: U.S. dollar-denominated capital expenditures converted at a forecast USD:CAD foreign exchange rate of 1.35. Rate base reflects a USD:CAD exchange rate of 1.38 for 2026F and 1.35 for 2027-2031F. CAGR calculated on a constant foreign exchange rate basis.
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UNS ENERGY – POWERING ARIZONA’S NEXT WAVE OF GROWTH 14 $5.6B 2027-2031 Energy Resources 21% Transmission Infrastructure 38% Distribution Infrastructure 30% IT, General & Other 11% Opportunities Above and Beyond the Plan: Load Growth for New and Existing Customers Driven by customers in data centers, manufacturing, and mining sectors, etc.; 800 MW of new generation could require incremental investment (up to US$1.5B) Integrated Resource Plans Base Case IRPs have opportunity within 2027- 2031 timeframe above the plan at TEP and UNSE subject to RFP (up to US$1.6B) FERC Regulated Transmission Rate BaseCapital Plan $9.1B $12.7B 2026F 2031F 7.4% CAGR Note: U.S. dollar-denominated capital expenditures converted at a forecast USD:CAD foreign exchange rate of 1.35. Rate base reflects a USD:CAD exchange rate of 1.38 for 2026F and 1.35 for 2027-2031F. CAGR calculated on a constant foreign exchange rate basis.
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IRPs SUPPORT LEAST-COST & HIGH-GROWTH OPTIONS 15 2027 160 MW 80 MW Solar + 80 MW Storage 2029 400 MW 200 MW Solar + 200 MW Storage 2030 730 MW Springerville gas conversion 2031 300 MW New combined cycle 2034 – 2041 800 MW 400 MW Solar + 400 MW Storage COAL EXIT Springerville Units #1 & 2 Coal-fired generation converting to natural gas (793 MW) Four Corners Planned Exit from Coal-fired generation (110 MW) ✓ On Track to Meet a Coal-Free Generation Mix by 2032 ✓ TEP Base Case IRP assumes 5-Year average annual retail sales growth of 5.7% ✓ Base Case IRPs have opportunity within 2027-2031 timeframe above and beyond the plan subject to RFPs of up to: ✓ TEP ~US$1.3B ✓ UNSE ~US$0.3B TEP BASE CASE IRP 15.52 15.76 14.31 15.19 Base Scenario Clean Energy Scenario High-Growth Scenario High-Growth, Clean Scenario TEP’s IRP Average System Cost per kWh (US¢/kWh) UNS ELECTRIC BASE CASE IRP 2028 280 MW 140 MW Solar + 140 MW Storage 2030 196 MW Gas Generation 2031 125 MW Gas Generation 2034 – 2041 100 MW 50 MW Solar + 50 MW Storage Contracted/ PPA Generation Generation included in the Capital Plan Opportunity Above and Beyond the Plan
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FORTISBC – NATURAL GAS & LNG INFRASTRUCTURE IN FOCUS 16 $6.0B 2027-2031 Reliability & Integrity 40% LNG Projects & Renewable Gases 40% IT, General & Other 13% AMI Project 7% Opportunities Above and Beyond the Plan: Tilbury LNG Expansion • Tilbury 1B • Tilbury LNG Storage Tank • Tilbury Phase 2 LNG Expansion ($2-$4B) Regional Transmission Pipeline Expansion Customer & Load Growth In electric service territory for Okanagan infrastructure upgrades to meet capacity constraints Rate Base $8.7B $12.8B 2026F 2031F Capital Plan 7.9% CAGR
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($ Billions) Pre- 2027 Spend 2027– 2031 Capital Beyond 2031 Capital Total Project Cost In- Service Date Tilbury Phase 1A – – – 0.5 2018 Tilbury Phase 1B / Marine Jetty(1) 0.2 1.1 0.4 1.7 2031(2) Tilbury LNG Storage Tank Expansion 0.1 0.8 0.2 1.1 2031(2) Tilbury Phase 2 LNG Expansion – TBD TBD 2.0-4.0 Post-2031 Total Tilbury LNG Opportunity $0.3 $1.9 $0.6 $5.3-$7.3 Various TILBURY LNG FACILITIES AT A GLANCE 17 (1) Estimated total spend for the life of the project is $1.8B, including AFUDC. (2) Substantially complete by 2031. Tilbury Phase 1A Status: CompleteTilbury Phase 1B Status: OIC Approved (subject to permitting) Tilbury LNG Storage Tank Status: Approved Tilbury Pacific Marine Jetty Status: Approved Tilbury Phase 2 LNG Expansion Status: Environmental Approval Received (subject to FID & permitting)
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ROBUST GROWTH PIPELINE BEYOND THE PLAN 18 ITC • LRTP Tranche 2.1 • LRTP Tranche 2.1 MARS Project • Customer Connections • Future MISO LRTP/ MTEP & SPP ITP Projects UNS Energy • TEP Load Growth (e.g., data centers and other large load customers) • Integrated Resource Plan Investments • Transmission Investments FortisBC • Tilbury Phase 1B • Tilbury Phase 2 LNG Expansion • Regional Transmission • Customer & Load Growth Investments Other • Investments associated with Canadian Nation-Building Projects • Electrification and Customer Connections • Regional Transmission
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19 ITC Midwest and TEP Beneficial load growth supports affordability At ITC Midwest, network transmission rates are expected to be reduced by ~20% by the end of the decade from the 2026 projected rate resulting from projected data center load growth, with a 13% reduction already reflected in the 2027 projected network rate At TEP, a new data center will require ~300 MW of load, with future expansion subject to approvals. Approved ESA is expected to save a typical residential customer ~US$13 per month TEP Capital optimization supports affordability FortisBC LNG projects drive real savings for customers Tilbury 1A Facility & 1B Expansion Increased sales of LNG into the marine fueling market associated with the Tilbury 1A facility have provided a rate benefit for customers of ~1.5% since 2024; further expansion of Tilbury 1B is expected to build on this rate benefit for customers Eagle Mountain Pipeline Project Increased demand served through the project will increase the utilization of FortisBC’s gas system, and once complete and in service, is expected to provide a rate benefit for customers of ~1.5% Central Hudson Established O&M savings targets Central Hudson is targeting zero O&M growth from the 2025 rate order, focusing on technology enabled work management and support function optimization, along with improved vegetation management FOCUSED ON AFFORDABILITY – KEY INITIATIVES TEP plans to convert two coal-fired generating units to natural gas at the Springerville Generating Station This approach reduces O&M at Springerville and is ~10% of the capital cost of building new natural gas generation. The conversion also extends the life of existing infrastructure
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A BALANCED APPROACH TO FUNDING GROWTH 20 FUNDING PLAN LARGELY CONSISTENT WITH PRIOR FIVE-YEAR PLAN (1) Net debt reflects regulated and non-regulated debt issuances, net of repayments. (2) Non-U.S. GAAP financial measures. Reflects cash from operating activities, net of dividends, and including customer contributions. (3) Equity reflects common shares issued under the Corporation’s DRIP at current participation levels, stock option and employee share purchase plans (~$250M) and ATM program (~$250M). (4) ~$240M remains available under the current ATM program. Following expiry of the current base shelf prospectus in January 2027, Fortis intends to file a new base shelf prospectus and re-establish a $500M ATM program. Cash from Operations 57% Net Debt 32% Equity 11% 5-Year Capital Plan $32.2B 2027-2031 Equity Funding Plan Capital structure expected to remain consistent over planning period (1) (2) • Equity funding over next five years predominantly supported by DRIP • Assumes DRIP participation remains at current levels (~37%) • The corporation advanced a portion of its equity funding requirements in Q3 2026 through the issuance of US$1B of hybrid debt, which was used to repay maturing corporate debt, as well as $260M of ATM equity • $500M ATM program expected to be re-established and available for flexibility as required(4) • Funding plan supports existing investment-grade credit ratings (3)
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5.9x 2027-2031F Avg. 12.3% 2027-2031F Avg. S&P FFO/Debt FUNDING PLAN SUPPORTS INVESTMENT-GRADE CREDIT RATINGS 21 Note: S&P FFO/Debt and Fitch FFO Leverage are Non-U.S. GAAP financial measures calculated in accordance with applicable rating agency adjustments. (1) All credit rating agencies confirmed the Corporation’s credit ratings and outlook in Q2 2026. (2) S&P rating reflects the issuer credit rating. Fortis’ unsecured debt rating is BBB+. >12.0% Key Credit Strengths Strong business risk profile Geographic and regulatory diversity 100% regulated – stable and predictable cash flows Constructive regulatory frameworks Rating Agency Threshold Credit Ratings (1) & Outlooks A-(2) BBB+ A (low) StableStable Stable Fitch FFO Leverage <6.2x
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22 73 75 77 79 81 83 85 87 89 91 93 95 97 99 01 03 05 07 09 11 13 15 17 19 21 23 25 53 Years of Consecutive Increases in Dividends Paid 4-6% Annual Dividend Growth Guidance through 2031 4% Dividend Increase in Q4 2026 26F DIVIDEND GUIDANCE SUPPORTED BY LONG-TERM GROWTH STRATEGY
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WHY INVEST IN FORTIS? 23 SUSTAINABLE GROWTH Transparent Funding Plan Robust Transmission Pipeline FOCUSED ON EXECUTING LOW-RISK SAFE, WELL-RUN UTILITIES Regulatory & Geographic Diversity Strong Governance Investments to Strengthen Resiliency Local Business Model Investment-Grade Credit Ratings 4-6% Annual Dividend Growth Strong Rate Base Growth Constructive Regulatory Relationships Primarily Transmission & Distribution Assets 100% Regulated
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Expected Earnings Release Dates Q4 2026 – February 11, 2027
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APPENDIX 25
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NON-U.S. GAAP RECONCILIATION 26 ($MILLIONS, EXCEPT EPS) Q3 2026 Q3 2025 VARIANCE YTD SEPT. 2026 YTD SEPT. 2025 VARIANCE Adjusted Net Earnings Net Earnings 474 409 65 1,371 1,292 79 Adjusting item: Disposition of FortisTCI(1) - 32 (32) - 32 (32) Adjusted Net Earnings 474 441 33 1,371 1,324 47 Adjusted Net Earnings per Share $0.92 $0.87 $0.05 $2.69 $2.63 $0.06 Capital Expenditures Additions to property, plant and equipment 1,758 1,362 396 4,862 4,324 538 Additions to intangible assets 35 91 (56) 143 216 (73) Adjusting item: Eagle Mountain Pipeline Project(2) (301) (137) (164) (787) (369) (418) Capital Expenditures 1,492 1,316 176 4,218 4,171 47 (1) Reflects income taxes and closing costs associated with the disposition of FortisTCI, included in the Corporate and Other segment. (2) Represents CIACs received for the Eagle Mountain Pipeline project, included in the FortisBC Energy segment.
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THIRD QUARTER RESULTS BY SEGMENT 27 (1) Non-U.S. GAAP financial measure. Refer to Slide 26 for the Non-U.S. GAAP reconciliation. Third Quarter Earnings Variance Analysis by Business Unit ($MILLIONS, EXCEPT WEIGHTED AVERAGE SHARES AND EPS) Q3 2026 ADJUSTMENT ADJUSTED Q3 2026 (1) Q3 2025 ADJUSTMENT ADJUSTED Q3 2025 (1) VARIANCE Regulated – Independent Electric Transmission ITC 167 - 167 149 - 149 18 Regulated – U.S. Electric & Gas UNS Energy 225 - 225 209 - 209 16 Central Hudson 33 - 33 31 - 31 2 258 - 258 240 - 240 18 Regulated – Canadian & Caribbean Electric & Gas FortisBC Energy 6 - 6 - - - 6 FortisAlberta 58 - 58 54 - 54 4 FortisBC Electric 15 - 15 15 - 15 - Other Electric 36 - 36 41 - 41 (5) 115 - 115 110 - 110 5 Corporate and Other (66) - (66) (90) 32 (58) (8) Common Equity Earnings 474 - 474 409 32 441 33 Weighted Average Shares (# millions) 513.1 - 513.1 504.5 - 504.5 8.6 EPS $0.92 - $0.92 $0.81 $0.06 $0.87 $0.05
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Year-to-Date September Earnings Variance Analysis by Business Unit ($MILLIONS, EXCEPT WEIGHTED AVERAGE SHARES AND EPS) YTD SEPT. 2026 ADJUSTMENT ADJUSTED YTD SEPT. 2026 (1) YTD SEPT. 2025 ADJUSTMENT ADJUSTED YTD SEPT. 2025 (1) VARIANCE Regulated – Independent Electric Transmission ITC 472 - 472 442 - 442 30 Regulated – U.S. Electric & Gas UNS Energy 390 - 390 394 - 394 (4) Central Hudson 137 - 137 121 - 121 16 527 - 527 515 - 515 12 Regulated – Canadian & Caribbean Electric & Gas FortisBC Energy 226 - 226 202 - 202 24 FortisAlberta 142 - 142 132 - 132 10 FortisBC Electric 61 - 61 57 - 57 4 Other Electric 122 - 122 129 - 129 (7) 551 551 520 - 520 31 Corporate and Other (179) (179) (185) 32 (153) (26) Common Equity Earnings 1,371 - 1,371 1,292 32 1,324 47 Weighted Average Shares (# millions) 510.4 510.4 502.5 - 502.5 7.9 EPS $2.69 - $2.69 $2.57 $0.06 $2.63 $0.06 YEAR-TO-DATE RESULTS BY SEGMENT 28 (1) Non-U.S. GAAP financial measure. Refer to Slide 26 for the Non-U.S. GAAP reconciliation.
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2027-2031 CAPITAL PLAN BY BUSINESS UNIT 29 Capital Plan ($MILLIONS) 2027F 2028F 2029F 2030F 2031F 2027-2031 TOTAL Regulated – Independent Electric Transmission ITC 2,317 2,387 2,251 2,274 2,356 11,585 Regulated – U.S. Electric & Gas UNS Energy 1,068 1,006 1,659 1,123 763 5,619 Central Hudson 464 518 524 586 657 2,749 Total Regulated – U.S. Electric & Gas 1,532 1,524 2,183 1,709 1,420 8,368 Regulated – Canadian & Caribbean Electric & Gas FortisBC Energy 1,039 1,059 840 806 820 4,564 FortisAlberta 662 713 764 759 773 3,671 FortisBC Electric 252 246 288 317 315 1,418 Other Electric 531 483 491 501 574 2,580 Total Regulated – Canadian & Caribbean Electric & Gas 2,484 2,501 2,383 2,383 2,482 12,233 Total Capital Plan 6,333 6,412 6,817 6,366 6,258 32,186 Note: U.S. dollar-denominated capital expenditures converted at a USD:CAD foreign exchange rate of 1.35.
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MAJOR CAPITAL PROJECTS 30 ($ Billions) Pre-2027 Spend 2027-2031F Capital Beyond 2031 Capital Total Project Cost Estimated Completion Date ITC MISO LRTP – Tranche 1 0.7 1.5 - 2.2 2030 ITC MISO LRTP – Tranche 2.1 (ROFR Awarded)(1) 0.1 1.1 3.9-4.6 5.1-5.8 Post-2031 ITC MISO LRTP – Tranche 2.1 (MARS Project)(2) - 0.6 0.8 1.4 Various ITC Big Cedar Load Expansion 0.3 0.5 - 0.8 2029 UNS Transmission Project at TEP - 0.6 - 0.6 2030 UNS Gas Generation Project at UNS Electric 0.1 0.4 - 0.5 2030 UNS Springerville Natural Gas Generation - 0.2 - 0.2 2030 FortisBC Tilbury 1B Project(3) 0.2 1.1 0.4 1.7 2031(5) FortisBC LNG Storage Tank Expansion 0.1 0.8 0.2 1.1 2031(5) FortisBC AMI Project 0.4 0.4 - 0.8 2029 FortisBC Eagle Mountain Pipeline Project(4) 0.4 0.4 - 0.8 2027 Note: Projects, other than ongoing maintenance projects, individually costing $200M or more in the forecast/planning period. (1) Reflects ROFRs in Michigan and Minnesota. Also includes projects requiring system upgrades in Iowa which are not subject to a competitive bidding process. (2) MARS project awarded through MISO's competitive process. Its rate of return construct is defined by the bid parameters and reflects the competitive nature of the process. (3) Estimated total spend for the life of the project is $1.8B, including AFUDC. (4) Net of customer contributions. (5) Substantially complete by 2031. Plan includes 11 major capital projects
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• Federal and provincial environmental approvals received in September 2026 • Remaining permits and authorizations are required before construction can begin • FortisBC will continue working with Indigenous Nations, local governments, community members and other stakeholders as planning and permitting advance 31 TILBURY LNG APPROVALS ADVANCING CAPITAL INVESTMENTS AT FORTISBC ✓ In July 2026, the Province of B.C. issued an OIC approving the Phase 1B expansion which will support LNG marine fueling services and the transition to lower-emission marine fuels ✓ The OIC also provided the required approvals to implement a minority equity partnership with the Musqueam Indian Band; the equity percentage is expected to be below the BCUC threshold for review of 20% ✓ Also includes a marine jetty and associated on-shore infrastructure to enable the loading of LNG onto marine bunkering in the Port of Vancouver ✓ $1.1B included in 2027-2031 capital plan ✓ Construction as early as mid-2027; in service as early as 2031 Tilbury Phase 1B Tilbury Phase 2 LNG Expansion Tilbury LNG Storage Tank Expansion ✓ Regulated reliability and resiliency project comprising of a new 142,400 m3, ~3 Bcf LNG, storage tank and associated regasification/ send-out facilities ✓ CPCN approved by BCUC in October 2025 ✓ $0.8B included in 2027-2031 capital plan ✓ Substantially complete in 2031 Phase 2 Liquefaction Expansion ✓ Up to 2.5 mtpa of additional liquefaction capacity ✓ Supply domestic markets, including marine fueling, or bulk LNG export markets ✓ Potential capital opportunity of ~$2-$4B beyond the plan period ✓ Development could occur in stages, remaining subject to such things as market demand, permitting and final investment decision
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2026-2031 RATE BASE BY BUSINESS UNIT 32 Rate Base ($BILLIONS) 2026F 2027F 2028F 2029F 2030F 2031F 5-YEAR CAGR TO 2031 Regulated – Independent Electric Transmission ITC (1) 14.8 15.7 17.3 18.9 20.4 21.9 8.6% Regulated – U.S. Electric & Gas UNS Energy 9.1 9.7 10.4 10.9 11.9 12.7 7.4% Central Hudson 4.0 4.2 4.4 4.7 4.9 5.3 6.0% Total Regulated – U.S. Electric & Gas 13.1 13.9 14.8 15.6 16.8 18.0 7.0% Regulated – Canadian & Caribbean Electric & Gas FortisBC Energy 6.9 7.4 8.5 8.8 8.8 10.1 8.2% FortisAlberta 4.9 5.2 5.5 5.8 6.1 6.4 5.5% FortisBC Electric 1.9 2.0 2.1 2.3 2.3 2.7 7.0% Other Electric 3.7 4.0 4.2 4.4 4.5 4.8 5.7% Total Regulated – Canadian & Caribbean Electric & Gas 17.4 18.6 20.3 21.3 21.7 24.0 6.8% Total Rate Base Forecast 45.3 48.2 52.4 55.8 58.9 63.9 7.5% Note: U.S. dollar-denominated rate base converted at a USD:CAD foreign exchange rate of 1.38 for 2026 and 1.35 for 2027-2031. CAGR is calculated on a constant foreign exchange rate basis. (1) Fortis has an 80.1% controlling ownership interest in ITC; rate base represents 100% ownership.
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SENSITIVITY EXPOSURE & HEDGING 33 (1) Non-U.S. GAAP financial measure for year ended December 31, 2025. Excludes Net Expenses of Corporate and Other segment. (2) As of September 30, 2026, the contracts had a combined notional value of US$518M. (3) As of September 30, 2026, the contracts had a combined notional value of US$200M. Foreign Exchange ROE & Equity Ratio ROE +/- 25 bps Equity +/- 100 bps ITC $0.040 $0.035 UNS Energy $0.030 $0.020 FortisBC $0.020 $0.020 Central Hudson $0.010 $0.010 FortisAlberta $0.010 $0.010Hedging Activities • FX contracts (primarily forwards and collars)(2) • US$1.2B in U.S. dollar-denominated debt outstanding at Fortis Inc. as a natural hedge • US$400M cross-currency interest rate swaps • Interest rate swap contracts at ITC(3) • Assumed USD:CAD FX rate of 1.35 for 2027-2031 Capital Plan • 65% of regulated earnings(1)/ 64% of capital plan in USD at U.S. & Cayman Islands utilities • +/- $0.05 change in USD:CAD ▪ Five-year capital plan: $800M ▪ EPS: $0.06, inclusive of hedging activities
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OUR SUSTAINABILITY STRATEGY GROUNDED IN BUSINESS FUNDAMENTALS 34 SUSTAINABILITY PRIORITIES Integrating climate risk with business planning Reducing emissions and delivering cleaner energy Strengthening governance foundations and partnering with local communities 2026 Climate Resiliency Report • Utilities completed enhanced, location-specific climate risk and vulnerability assessments grounded in climate scenario analysis and external expertise • Climate hazards are now mapped by geography and asset category, identifying areas of higher and lower exposure and risk level across Fortis utilities • The analysis includes more assets, providing deeper insights to support capital planning and resiliency investments • Expanded information on climate resiliency and mitigation actions • Achieved a 38% reduction in Scope 1 emissions (2019-2025) • Committed to a coal-free generation mix by 2032 • Advancing towards net-zero emissions by 2050 • The GHG intensity of delivered energy has consistently decreased over the last five years • A governance model grounded in local leadership and independence • Executive compensation linked to climate and sustainability initiatives • 50% of Fortis board members are women; 2 of 12 identify as a visible minority • Partnered with First Nations communities in northern Ontario to connect 17 remote communities to the power grid • $14M of community investment in 2025 and $60M over the last five years • $320M on energy efficiency customer programs in 2025 – the highest spending level ever GROUNDED IN BUSINESS FUNDAMENTALS OUR SUSTAINABILITY STRATEGY
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CLEANER ENERGY, DELIVERED SAFELY, RELIABLY & AFFORDABLY 35 12,308 10,418 9,742 8,748 8,155 8,069 7,559 2019 2020 2021 2022 2023 2024 2025 ~38% reduction in scope 1 GHG emissions since 2019 Scope 1 Emissions (ktonnes of CO₂e) • GHG intensity of energy delivered has declined each year since 2019, reaching a record low in 2025 • Since 2019, coal generation declined 58% while renewable generation increased 24% • Committed to a coal-free generation mix by 2032 2026 marks 10 years of Fortis sustainability reporting 2026 Sustainability Report Released YEARS
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Q3 2026 SALES TRENDS 36 (1) Excludes wholesale sales at UNS Energy. Other Electric CHANGE IN ENERGY SALES Q3 2026 vs. Q3 2025 SALES TRENDS N/A • Peak load up 7% mainly driven by warmer weather +1% • Higher average consumption, particularly by industrial and residential customers, as well as customer growth, partially offset by the impact of milder weather; on a weather-normalized basis retail sales up 2% -1% • Lower average consumption by residential customers associated with lower air conditioning load due to milder weather +7% • Increase in gas sales due to higher consumption by industrial, residential, and commercial customers, including increased residential and commercial space-heating demand due to cooler weather, partially offset by lower transportation consumption -3% • Decrease in electricity sales primarily due to lower average consumption by industrial, residential and commercial customers as a result of lower air conditioning load due to cooler weather +4% • Residential and C&I sales up 5% and 4%, respectively; primarily due to customer growth and higher residential consumption from warmer weather -1% • Eastern Canadian residential and C&I sales up 3% and 2%, respectively; Caribbean sales down due to the disposition of FortisTCI (1)
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LONG-TERM DEBT MATURITIES 37 $- $0.5 $1.0 $1.5 $2.0 $2.5 $3.0 2027F 2028F 2029F 2030F 2031F 2032F 2033F 2034F 2035F 2036F Regulated Utilities ITC Holdings Fortis Inc. billions 10-Year Debt Maturities Note: U.S. dollar-denominated debt translated at September 30, 2026 USD:CAD closing foreign exchange rate of 1.42.
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CREDIT RATINGS Preference shares S&P P-2 Fitch BBB- Morningstar DBRS Pfd-2 (low) Stable outlook EQUITY CREDIT TREATMENT S&P and Fitch assign 50% equity credit to the preference shares, while Morningstar DBRS assigns 75% 38 Fixed & Floating Rate Reset Schedule Series G $230M 5YR GoC + 2.13% September 1, 2028 Series K $250M 5YR GoC + 2.05% March 1, 2029 Series M $600M 5YR GoC + 2.48% December 1, 2029 Series H $198M 5YR GoC + 1.45% June 1, 2030 Perpetual Fixed Rate Series F $125M 4.90% fixed Series J $200M 4.75% fixed Series I $52M Floating: 3-mo T-bill + 1.45% Quarterly Perpetual capital with periodic rate resets PREFERENCE SHARES
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STRONG INVESTMENT-GRADE CREDIT RATINGS 39 Company Fortis Inc. A-(1) A (low) BBB+ -(2) ITC Holdings Corp. A-(1) - - Baa2 ITC Regulated Subsidiaries A+ - - A1 TEP A- - - A3 Central Hudson BBB+ - BBB+ Baa1 FortisBC Energy - A - A3 FortisBC Electric - A (low) - Baa1 FortisAlberta A- A (low) - Baa1 Newfoundland Power - A - A2 (1) S&P credit ratings for Fortis Inc. and ITC Holdings Corp. reflect the issuer credit ratings. The unsecured debt rating for Fortis Inc. and ITC Holdings Corp. is BBB+. (2) In January 2026, Moody's withdrew its ratings for Fortis Inc. at the Corporation's request. The withdrawal does not impact the subsidiary credit ratings.
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GLOSSARY 40 ACC Arizona Corporation Commission ALJ Administrative Law Judge AMI Advanced Metering Infrastructure ATM At-the-market equity program AUC Alberta Utilities Commission Bcf billion cubic feet Board Board of Directors of the Corporation bps basis points C&I Commercial & Industrial CAGR 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, less CIACs received by FortisBC Energy associated with the Eagle Mountain Pipeline project. See "Non-U.S. GAAP Financial Measures" in the Q3 2026 MD&A. Capital Plan forecast Capital Expenditures. Represents a non-U.S. GAAP financial measure calculated in the same manner as Capital Expenditures Central Hudson CH Energy Group, Inc., an indirect wholly-owned subsidiary of Fortis, together with its subsidiaries, including Central Hudson Gas & Electric Corporation CIACs Contributions in Aid of Construction Corporation Fortis Inc. COS Cost of Service Court of Appeal Court of Appeal of Alberta CPCN certificate of public convenience and necessity DRIP dividend reinvestment plan EPS earnings per common share EVP Executive Vice President FERC Federal Energy Regulatory Commission FFO funds from operations 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 FortisTCI FortisTCI Limited, an indirect wholly owned subsidiary of Fortis, together with its subsidiary, sold on September 2, 2025 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 GHG greenhouse gas 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 ITP Integrated transmission planning kV kilovolt kWh kilowatt-hours LNG liquefied natural gas LRTP Long-Range Transmission Plan Major Capital Projects projects, other than ongoing maintenance projects, individually costing $200M or more in the forecast/ planning period MARS Marshalltown - Lehigh - Sub T - Montezuma - East Adair 345/765 kV competitive transmission project MD&A the Corporation's management discussion and analysis MISO Midcontinent Independent System Operator, Inc. Moody’s Moody’s Investor Services, Inc. Morningstar DBRS DBRS Limited MTEP MISO transmission expansion plan MTPA million tonnes per annum MW megawatts Newfoundland Power Newfoundland Power Inc., a direct wholly-owned subsidiary of Fortis Non-U.S. GAAP Financial Measure financial measures that do not have a standardized meaning prescribed by U.S. GAAP NOPR notice of proposed rulemaking O&M operations and maintenance expenses OIC Order In Council PBR performance-based rate-setting 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 RFP request for proposal ROE rate of return on common equity ROO recommended opinion and order RTO regional transmission organization S&P Standard & Poor's Financial Services LLC Scope 1 Emissions the direct GHG emissions from Fortis-owned or controlled operations, including electricity generation facilities, natural gas infrastructure, vehicles, and other operational equipment SPP Southwest Power Pool TEP Tucson Electric Power Company U.S. United States of America U.S. GAAP accounting principles generally accepted in the U.S. UNS UNS Energy Corporation, an indirect wholly owned subsidiary of Fortis, together with its subsidiaries, including TEP, UNS Electric, Inc. and UNS Gas, Inc. UNS Electric UNS Electric, Inc. UNS Gas UNS Gas, Inc. USD:CAD U.S. Dollar to Canadian Dollar foreign exchange rate YTD Year-to-date