CHESAPEAKE UTILITIES CORPORATION REPORTS THIRD QUARTER 2025 RESULTS

Net income and earnings per share ("EPS")* were $19.4 million and $0.82, respectively, for the third quarter of 2025 and $94.2 million and $4.03, respectively, for the nine months ended September 30, 2025 Adjusted net income and Adjusted EPS**, which exclude transaction and transition-related expenses attributable to the acquisition and integration of Florida City Gas ("FCG"), were $19.5 million and $0.82, respectively, for the third quarter of 2025 and $94.9 million and $4.06, respectively, for the nine months ended September 30, 2025 Adjusted gross margin** growth of $15.2 million and $49.3 million, respectively, for the three- and nine-month periods ended September 30, 2025 driven primarily by natural gas organic growth and transmission expansion projects, regulatory initiatives and infrastructure programs, and increased compressed natural gas, renewable natural gas and liquified natural gas services 2025 Adjusted EPS guidance of $6.15 - $6.35 re-affirmed, assuming a successful outcome on the FCG Depreciation Study The Company is increasing its 2025 capital guidance range to $425-$450 million The Company continues to affirm 2028 EPS and 2024-2028 capital expenditure guidance , /PRNewswire/ -- Chesapeake Utilities Corporation (NYSE: CPK) ("Chesapeake Utilities" or the "Company") today announced financial results for the three and nine months ended September 30, 2025. Net income for the third quarter of 2025 was $19.4 million ($0.82 per share) compared to $17.5 million ($0.78 per share) in the third quarter of 2024. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, adjusted net income was $19.5 million ($0.82 per share) compared to $18.1 million ($0.80 per share) in the prior-year period. The adjusted EPS growth reflects a $0.04 per share impact from $92.0 million of equity issued over the last twelve months to restore the Company's equity to total capitalization ratio closer to the target ratio. Adjusted earnings for the third quarter of 2025 were largely driven by contributions from regulatory initiatives and infrastructure programs, organic growth in the natural gas distribution businesses and pipeline expansion projects driven by natural gas demand, and increased compressed natural gas (CNG), renewable natural gas (RNG) and liquified natural gas (LNG) services. During the first nine months of 2025, net income was $94.2 million ($4.03 per share) compared to $81.9 million ($3.66 per share) in the prior-year period. Excluding the transaction and transition-related expenses, adjusted net income was $94.9 million ($4.06 per share) compared to $84.2 million ($3.76 per share) in the prior-year period. This resulted in EPS and adjusted EPS growth of 10.1 percent and 8.0 percent, respectively, compared to the prior-year period. Year-to-date adjusted earnings for 2025 were primarily impacted by the factors discussed for the third quarter as well as additional adjusted gross margin from increased customer consumption experienced earlier in the year. "Our performance in the third quarter of 2025 demonstrated continued operational excellence across our businesses to serve our customers and communities. In both the quarter and the year-to-date periods, we delivered double-digit growth in Adjusted Gross Margin and Operating Income relative to the prior year and we continued to strengthen our balance sheet with incremental long-term debt and equity issuances during the quarter," said Jeff Householder, the Company's Chair of the Board, President and Chief Executive Officer. "These results demonstrate that we continue to deliver on our three growth pillars. Within the third quarter, we invested $123 million of capital and generated over $20 million of gross margin from transmission, infrastructure, and transportation projects. We also reached final completion of our Delaware rate case, with a settlement on tariff-related changes, including rate design. And finally, we took the next pivotal step in our continuous business transformation efforts, including officially kicking off our multi-year Enterprise Resource Plan (ERP) process, which was a primary driver in the increase and extension of our 2025 capital guidance to $425-$450 million. We remain focused on achieving our earnings and increased capital guidance in 2025, demonstrating record performance and reaching new heights of growth for the Company." Earnings and Capital Investment Guidance The Company continues to re-affirm its 2025 EPS guidance range of $6.15 to $6.35 per share, pending a successful outcome of the FCG excess depreciation filing. Given the Company's progress on a multitude of capital projects, the Company is further increasing and refining its 2025 capital guidance range to $425 million to $450 million. Looking to the future, the Company also continues to re-affirm its 2028 EPS guidance range of $7.75 to $8.00 per share, as well as its capital expenditure guidance range for the five-year period ending 2028 of $1.5 billion to $1.8 billion. *Unless otherwise noted, EPS and Adjusted EPS information are presented on a diluted basis. Non-GAAP Financial Measures **This press release including the tables herein, include references to both Generally Accepted Accounting Principles ("GAAP") and non-GAAP financial measures, including Adjusted Gross Margin, Adjusted Net Income and Adjusted EPS. A "non-GAAP financial measure" is generally defined as a numerical measure of a company's historical or future performance that includes or excludes amounts, or that is subject to adjustments, so as to be different from the most directly comparable measure calculated or presented in accordance with GAAP. The Company's management believes certain non-GAAP financial measures, when considered together with GAAP financial measures, provide information that is useful to investors in understanding period-over-period operating results separate and apart from items that may, or could, have a disproportionately positive or negative impact on results in any particular period. The Company calculates Adjusted Gross Margin by deducting the purchased cost of natural gas, propane and electricity and the cost of labor spent on direct revenue-producing activities from operating revenues. The costs included in Adjusted Gross Margin exclude depreciation and amortization and certain costs presented in operations and maintenance expenses in accordance with regulatory requirements. The Company calculates Adjusted Net Income and Adjusted EPS by deducting costs and expenses associated with significant acquisitions that may affect the comparison of period-over-period results. These non-GAAP financial measures are not in accordance with, or an alternative to, GAAP and should be considered in addition to, and not as a substitute for, the comparable GAAP measures. The Company believes that these non-GAAP measures are useful and meaningful to investors as a basis for making investment decisions, and provide investors with information that demonstrates the profitability achieved by the Company under allowed rates for regulated energy operations and under the Company's competitive pricing structures for unregulated energy operations. The Company's management uses these non-GAAP financial measures in assessing a business unit and Company performance. Other companies may calculate these non-GAAP financial measures in a different manner. The following tables reconcile Gross Margin, Net Income, and EPS, all as defined under GAAP, to the Company's non-GAAP measures of Adjusted Gross Margin, Adjusted Net Income and Adjusted EPS for each of the periods presented. Adjusted Gross Margin For the Three Months Ended September 30, 2025 (in millions) Regulated Energy Unregulated Energy Other Businesses and Eliminations Total Operating Revenues $ 146.4 $ 40.7 $ (7.5) $ 179.6 Cost of Sales: Natural gas, propane and electric costs (31.7) (18.3) 7.6 (42.4) Depreciation & amortization (18.2) (5.1) — (23.3) Operations & maintenance expenses (1) (12.6) (9.5) — (22.1) Gross Margin (GAAP) 83.9 7.8 0.1 91.8 Operations & maintenance expenses (1) 12.6 9.5 — 22.1 Depreciation & amortization 18.2 5.1 — 23.3 Adjusted Gross Margin (Non-GAAP) $ 114.7 $ 22.4 $ 0.1 $ 137.2 For the Three Months Ended September 30, 2024 (in millions) Regulated Energy Unregulated Energy Other Businesses and Eliminations Total Operating Revenues $ 130.6 $ 35.6 $ (6.0) $ 160.2 Cost of Sales: Natural gas, propane and electric costs (28.4) (15.8) 6.0 (38.2) Depreciation & amortization (12.3) (4.5) — (16.8) Operations & maintenance expenses (1) (10.7) (8.1) — (18.8) Gross Margin (GAAP) 79.2 7.2 — 86.4 Operations & maintenance expenses (1) 10.7 8.1 — 18.8 Depreciation & amortization 12.3 4.5 — 16.8 Adjusted Gross Margin (Non-GAAP) $ 102.2 $ 19.8 $ — $ 122.0 For the Nine Months Ended September 30, 2025 (in millions) Regulated Energy Unregulated Energy Other Businesses and Eliminations Total Operating Revenues $ 497.8 $ 195.3 $ (22.0) $ 671.1 Cost of Sales: Natural gas, propane and electric costs (137.3) (93.4) 22.0 (208.7) Depreciation & amortization (52.6) (15.1) — (67.7) Operations & maintenance expenses (1) (40.5) (29.0) (0.1) (69.6) Gross Margin (GAAP) 267.4 57.8 (0.1) 325.1 Operations & maintenance expenses (1) 40.5 29.0 0.1 69.6 Depreciation & amortization 52.6 15.1 — 67.7 Adjusted Gross Margin (Non-GAAP) $ 360.5 $ 101.9 $ — $ 462.4 For the Nine Months Ended September 30, 2024 (in millions) Regulated Energy Unregulated Energy Other Businesses and Eliminations Total Operating Revenues $ 429.7 $ 160.1 $ (17.6) $ 572.2 Cost of Sales: Natural gas, propane and electric costs (105.7) (70.9) 17.5 (159.1) Depreciation & amortization (39.5) (12.2) — (51.7) Operations & maintenance expenses (1) (35.7) (24.4) — (60.1) Gross Margin (GAAP) 248.8 52.6 (0.1) 301.3 Operations & maintenance expenses (1) 35.7 24.4 — 60.1 Depreciation & amortization 39.5 12.2 — 51.7 Adjusted Gross Margin (Non-GAAP) $ 324.0 $ 89.2 $ (0.1) $ 413.1 (1) Operations & maintenance expenses within the condensed consolidated statements of income are presented in accordance with regulatory requirements and to provide comparability within the industry. Operations & maintenance expenses which are deemed to be directly attributable to revenue producing activities have been separately presented above in order to calculate Gross Margin as defined under GAAP. Adjusted Net Income and Adjusted EPS Three Months Ended Nine Months Ended September 30, September 30, (dollars in millions, shares in thousands (except per share data)) 2025 2024 2025 2024 Net Income (GAAP) $ 19.4 $ 17.5 $ 94.2 $ 81.9 FCG transaction and transition-related expenses, net (1) 0.1 0.6 0.7 2.3 Adjusted Net Income (Non-GAAP) $ 19.5 $ 18.1 $ 94.9 $ 84.2 Weighted average common shares outstanding - diluted 23,629 22,564 23,360 22,402 Earnings Per Share - Diluted (GAAP) $ 0.82 $ 0.78 $ 4.03 $ 3.66 FCG transaction and transition-related expenses, net (1) — 0.02 0.03 0.10 Adjusted Earnings Per Share - Diluted (Non-GAAP) $ 0.82 $ 0.80 $ 4.06 $ 3.76 (1) Transaction and transition-related expenses represent non-recurring costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transition services, consulting, system integration, rebranding, and legal fees. Operating Results for the Quarters Ended September 30, 2025 and 2024 Consolidated Results Three Months Ended September 30, (in millions) 2025 2024 Change Percent Change Adjusted gross margin** $ 137.2 $ 122.0 $ 15.2 12.5 % Depreciation, amortization and property taxes (1) 32.7 25.0 (7.7) (30.8) % Other operating expenses 59.3 55.3 (4.0) (7.2) % FCG transaction and transition-related expenses 0.2 0.8 0.6 NMF Operating income $ 45.0 $ 40.9 $ 4.1 10.0 % (1) Includes the absence of an RSAM adjustment from FCG which represented a $3.2 million benefit in the third quarter of 2024. Operating income for the third quarter of 2025 was $45.0 million, an increase of $4.1 million or 10.0 percent compared to the same period in 2024. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $3.5 million or 8.4 percent compared to the prior-year period. The increase in adjusted gross margin in the third quarter of 2025 was driven by incremental margin from regulatory initiatives and infrastructure programs, pipeline expansion projects, increased CNG, RNG and LNG services and natural gas organic growth. The increase in operating expenses was driven largely by higher depreciation attributable to growth projects and the absence of a reserve surplus amortization mechanism ("RSAM") adjustment from FCG (which represented a $3.2 million benefit in the third quarter of 2024). Higher expenses associated with facilities, maintenance and outside services compared to the prior-year period also contributed to the increase. Regulated Energy Segment Three Months Ended September 30, (in millions) 2025 2024 Change Percent Change Adjusted gross margin** $ 114.7 $ 102.2 $ 12.5 12.2 % Depreciation, amortization and property taxes (1) 26.9 19.8 (7.1) (35.9) % Other operating expenses 38.7 37.6 (1.1) (2.9) % FCG transaction and transition-related expenses 0.2 0.8 0.6 NMF Operating income $ 48.9 $ 44.0 $ 4.9 11.1 % (1) Includes the absence of an RSAM adjustment from FCG which represented a $3.2 million benefit in the third quarter of 2024. The key components of the increase in adjusted gross margin** are shown below: (in millions) Natural gas transmission service expansions, including interim services $ 5.6 Contributions from regulated infrastructure programs 3.9 Rate changes associated with recent rate case activities (1) 3.6 Natural gas growth including conversions (excluding service expansions) 1.5 Changes in customer consumption (0.9) Other variances (1.2) Quarter-over-quarter increase in adjusted gross margin** $ 12.5 (1) Includes adjusted gross margin contributions from both interim and permanent base rates. Refer to Major Projects and Initiatives discussion for additional information. The major components of the increase in other operating expenses are as follows: (in millions) Facilities expenses, maintenance costs and outside services $ (2.1) Payroll, benefits and other employee-related expenses 0.9 Other variances 0.1 Quarter-over-quarter increase in other operating expenses $ (1.1) Unregulated Energy Segment Three Months Ended September 30, (in millions) 2025 2024 Change Percent Change Adjusted gross margin** $ 22.4 $ 19.8 $ 2.6 13.1 % Depreciation, amortization and property taxes 5.8 5.1 (0.7) (13.7) % Other operating expenses 20.5 17.8 (2.7) (15.2) % Operating income (loss) $ (3.9) $ (3.1) $ (0.8) 25.8 % Operating results for the second and third quarters historically have been lower due to reduced customer demand during warmer periods of the year. The impact to operating income may not align with the seasonal variations in adjusted gross margin as many of the operating expenses are recognized ratably over the course of the year. The major components of the increase in adjusted gross margin** are shown below: (in millions) Propane Operations Change in propane margins and service fees $ (0.7) CNG/RNG/LNG Transportation and Infrastructure Increased CNG/RNG/LNG services 3.1 Aspire Energy Increased performance from Aspire Energy 0.4 Other variances (0.2) Quarter-over-quarter increase in adjusted gross margin** $ 2.6 The major components of the increase in other operating expenses are as follows: (in millions) Payroll, benefits and other employee-related expenses $ (1.5) Facilities expenses, maintenance costs and outside services (1.3) Other variances 0.1 Quarter-over-quarter increase in other operating expenses $ (2.7) Operating Results for the Nine Months Ended September 30, 2025 and 2024 Consolidated Results Nine Months Ended September 30, (in millions) 2025 2024 Change Percent Change Adjusted gross margin** $ 462.4 $ 413.1 $ 49.3 11.9 % Depreciation, amortization and property taxes (1) 95.2 77.8 (17.4) (22.4) % Other operating expenses 184.1 170.9 (13.2) (7.7) % FCG transaction and transition-related expenses 1.0 3.1 2.1 NMF Operating income $ 182.1 $ 161.3 $ 20.8 12.9 % (1) Includes the absence of an RSAM adjustment from FCG which represented an $8.9 million benefit during the nine months ended September 30, 2024. Operating income for the nine months ended September 30, 2025 was $182.1 million, an increase of $20.8 million or 12.9 percent compared to the same period in 2024. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $18.7 million or 11.4 percent compared to the prior-year period. The increase in adjusted gross margin in the first nine months of 2025 was driven by incremental margin from regulatory initiatives and infrastructure programs, increased CNG, RNG and LNG services, pipeline expansion projects and natural gas organic growth, and increased customer consumption resulting from year-over-year colder temperatures in the Company's Mid-Atlantic and Ohio service territories. These increases were partially offset by lower margins per gallon and related fees in the Company's propane distribution business and a reduced volume of off-system sales and service fees in its natural gas business. Higher operating expenses were driven largely by the absence of an RSAM adjustment from FCG (which represented an $8.9 million benefit during the nine months ended September 30, 2024) and higher depreciation attributable to growth projects. Higher facilities, maintenance and outside services, insurance, and payroll, benefits and other employee-related expenses compared to the prior-year period also contributed to the increase. Regulated Energy Segment Nine Months Ended September 30, (in millions) 2025 2024 Change Percent Change Adjusted gross margin** $ 360.5 $ 324.0 $ 36.5 11.3 % Depreciation, amortization and property taxes (1) 78.3 63.6 (14.7) (23.1) % Other operating expenses 120.0 114.7 (5.3) (4.6) % FCG transaction and transition-related expenses 1.0 3.1 2.1 NMF Operating income $ 161.2 $ 142.6 $ 18.6 13.0 % (1) Includes the absence of an RSAM adjustment from FCG which represented an $8.9 million benefit during the nine months ended September 30, 2024. The key components of the increase in adjusted gross margin** are shown below: (in millions) Natural gas transmission service expansions, including interim services $ 11.7 Contributions from regulated infrastructure programs 11.0 Rate changes associated with recent rate case activities (1) 9.2 Natural gas growth including conversions (excluding service expansions) 5.5 Changes in customer consumption 0.9 Change in off-system natural gas capacity sales (0.7) Other variances (1.1) Period-over-period increase in adjusted gross margin** $ 36.5 (1) Includes adjusted gross margin contributions from both interim and permanent base rates. Refer to Major Projects and Initiatives discussion for additional information. The major components of the increase in other operating expenses are as follows: (in millions) Facilities expenses, maintenance costs and outside services $ (4.5) Insurance related costs (1.1) Other variances 0.3 Period-over-period increase in other operating expenses $ (5.3) Unregulated Energy Segment Nine Months EndedSeptember 30, (in millions) 2025 2024 Change Percent Change Adjusted gross margin** $ 101.9 $ 89.2 $ 12.7 14.2 % Depreciation, amortization and property taxes 16.8 14.1 (2.7) (19.1) % Other operating expenses 64.2 56.4 (7.8) (13.8) % Operating income $ 20.9 $ 18.7 $ 2.2 11.8 % The major components of the increase in adjusted gross margin** are shown below: (in millions) Propane Operations Increased propane customer consumption $ 2.8 Change in propane margins and service fees (1.3) CNG/RNG/LNG Transportation and Infrastructure Increased CNG/RNG/LNG services 10.1 Aspire Energy Increased customer consumption 1.1 Period-over-period increase in adjusted gross margin** $ 12.7 The major components of the increase in other operating expenses are as follows: (in millions) Payroll, benefits and other employee-related expenses $ (3.9) Facilities expenses, maintenance costs and outside services (3.7) Other variances (0.2) Period-over-period increase in other operating expenses $ (7.8) Forward-Looking Statements Matters included in this release may include forward-looking statements that involve risks and uncertainties. Actual results may differ materially from those in the forward-looking statements. Please refer to the Safe Harbor for Forward-Looking Statements in the Company's 2024 Annual Report on Form 10-K and Quarterly Report on Form 10-Q for the third quarter of 2025 for further information on the risks and uncertainties related to the Company's forward-looking statements. Conference Call Chesapeake Utilities (NYSE: CPK) will host a conference call on Friday, November 7, 2025, at 8:30 a.m. Eastern Time to discuss the Company's financial results for the three and nine months ended September 30, 2025. To listen to the Company's conference call via live webcast, please visit the Events & Presentations section of the Investors page on www.chpk.com. For investors and analysts that wish to participate by phone for the question and answer portion of the call, please use the following dial-in information: Toll-free: 800.579.2543International: 785.424.1789Conference ID: CPKQ325 A replay of the presentation will be made available on the previously noted website following the conclusion of the call. About Chesapeake Utilities Corporation Chesapeake Utilities Corporation is a diversified energy delivery company, listed on the New York Stock Exchange. Chesapeake Utilities Corporation offers sustainable energy solutions through its natural gas transmission and distribution, electricity generation and distribution, propane gas distribution, mobile compressed natural gas utility services and solutions, and other businesses. For more information, contact: Beth W. CooperExecutive Vice President, Chief Financial Officer, Treasurer and Assistant Corporate Secretary302.363.2467 Michael D. GaltmanSenior Vice President and Chief Accounting Officer302.217.7036 Lucia M. DempseyHead of Investor Relations347.804.9067 Financial Summary Highlights Key variances between the third quarter of 2024 and 2025 included: (in millions, except per share data) Pre-tax Income Net Income Earnings Per Share Third Quarter of 2024 Adjusted Results (1) $ 25.1 $ 18.1 $ 0.80 Change in Adjusted Gross Margins: Natural gas transmission service expansions, including interim services (2) 5.6 4.0 0.17 Contributions from regulated infrastructure programs (2) 3.9 2.8 0.12 Rate changes associated with recent rate case activities (2) 3.6 2.6 0.11 Increased CNG/RNG/LNG services (2) 3.1 2.2 0.09 Natural gas growth (excluding service expansions) 1.5 1.1 0.05 Increased Aspire Energy performance - rate changes and gathering fees 0.4 0.3 0.01 Changes in customer consumption (0.9) (0.6) (0.03) Change in propane margins and service fees (0.7) (0.5) (0.02) 16.5 11.9 0.50 Increased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs): Depreciation, amortization and property tax costs (7.7) (5.6) (0.24) Facilities expenses, maintenance costs and outside services (3.4) (2.5) (0.10) Payroll, benefits and other employee-related expenses (0.6) (0.4) (0.01) Insurance related costs (0.4) (0.3) (0.01) (12.1) (8.8) (0.36) Interest charges (1.1) (0.8) (0.03) Increase in shares outstanding due to 2024 and 2025 equity offerings (3) — — (0.04) Net other changes (1.3) (0.9) (0.05) (2.4) (1.7) (0.12) Third Quarter of 2025 Adjusted Results (1) $ 27.1 $ 19.5 $ 0.82 (1) Transaction and transition-related expenses attributable to the acquisition and integration of FCG have been excluded from the Company's non-GAAP measures of adjusted net income and adjusted EPS. See reconciliations above for a detailed comparison to the related GAAP measures. (2) Refer to Major Projects and Initiatives table for additional information. (3) Reflects the impact of common shares issued under the Dividend Reinvestment and Direct Stock Purchase Plan ("DRIP") and At-the-market ("ATM") program. Key variances between the nine months ended September 30, 2024 and September 30, 2025 included: (in millions, except per share data) Pre-tax Income Net Income Earnings Per Share Nine months ended September 30, 2024 Adjusted Results (1) $ 115.2 $ 84.2 $ 3.76 Change in Adjusted Gross Margins: Natural gas transmission service expansions, including interim services (2) 11.7 8.5 0.37 Contributions from regulated infrastructure programs (2) 11.0 8.0 0.34 Increased CNG/RNG/LNG services (2) 10.1 7.3 0.31 Rate changes associated with recent rate case activities (2) 9.2 6.7 0.29 Natural gas growth including conversions (excluding service expansions) 5.5 4.0 0.17 Changes in customer consumption 4.8 3.5 0.15 Increased Aspire Energy performance - rate changes and gathering fees 0.2 0.2 0.01 Change in propane margins and service fees (1.3) (0.9) (0.04) Change in service fees and off-system sales (0.7) (0.5) (0.02) 50.5 36.8 1.58 Increased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs): Depreciation, amortization and property taxes (17.4) (12.7) (0.54) Facilities expenses, maintenance costs and outside services (8.2) (6.0) (0.26) Payroll, benefits and other employee-related expenses (3.8) (2.8) (0.12) Insurance related costs (0.7) (0.5) (0.02) (30.1) (22.0) (0.94) Interest charges (3.2) (2.4) (0.10) Increase in shares outstanding due to 2024 and 2025 equity offerings (3) — — (0.17) Net other changes (2.3) (1.7) (0.07) (5.5) (4.1) (0.34) Nine months ended September 30, 2025 Adjusted Results (1) $ 130.1 $ 94.9 $ 4.06 (1) Transaction and transition-related expenses attributable to the acquisition and integration of FCG have been excluded from the Company's non-GAAP measures of adjusted net income and adjusted EPS. See reconciliations above for a detailed comparison to the related GAAP measures. (2) Refer to Major Projects and Initiatives table for additional information. (3) Reflects the impact of common shares issued under the DRIP and ATM program. Recently Completed and Ongoing Major Projects and Initiatives The Company continuously pursues and develops additional projects and regulatory initiatives to serve existing and new customers, further grow its businesses and earnings, and increase shareholder value. The following table includes all major projects and initiatives that are currently underway or recently completed. The Company's practice is to add incremental margin associated with new projects and regulatory initiatives to this table once negotiations or details are substantially final and/or the associated earnings can be estimated. Major projects and initiatives that have generated consistent year-over-year adjusted gross margin contributions are removed from the table at the beginning of the next calendar year. The related descriptions of projects and initiatives that accompany the table include only new items and/or items where there have been significant developments, as compared to the Company's prior quarterly filings. A comprehensive discussion of all projects and initiatives reflected in the table below can be found in the Company's third quarter 2025 Quarterly Report on Form 10-Q. Adjusted Gross Margin Three Months Ended Nine Months Ended Year Ended Estimate for September 30, September 30, December 31, Fiscal (in millions) 2025 2024 2025 2024 2024 2025 2026 Pipeline Expansions: St. Cloud / Twin Lakes Expansion $ 1.0 $ 0.1 $ 1.9 $ 0.4 $ 0.6 $ 2.8 $ 3.8 Wildlight 0.5 0.6 1.5 1.0 1.5 3.0 4.3 Newberry 0.6 0.6 1.8 0.7 1.4 2.6 2.6 Worcester Resiliency Upgrade — — — — — — 10.2 Boynton Beach 0.9 — 2.3 — — 3.0 3.4 New Smyrna Beach 0.6 — 0.9 — — 1.6 2.6 Central Florida Reinforcement 0.9 — 1.5 — 0.1 2.6 4.3 Warwick 0.5 — 1.5 — 0.4 1.9 1.9 Renewable Natural Gas Supply Projects 1.0 — 1.5 — — 2.5 5.4 Miami Inner Loop 0.9 — 0.9 — — 2.8 7.6 Duncan Plains — — — — — — — Total Pipeline Expansions 6.9 1.3 13.8 2.1 4.0 22.8 46.1 CNG/RNG/LNG Transportation and Infrastructure 6.6 3.5 20.5 10.4 16.4 25.5 26.5 Regulatory Initiatives: Florida GUARD program 1.9 0.9 5.1 2.4 3.6 6.9 9.9 FCG SAFE Program 2.3 1.1 6.2 2.2 3.8 8.5 12.0 Capital Cost Surcharge Programs 1.4 0.8 4.3 2.4 3.2 5.7 7.1 Electric Storm Protection Plan 1.8 0.7 4.4 2.0 3.2 5.9 8.8 Maryland Rate Case 0.5 — 1.1 — — 1.5 3.5 Delaware Rate Case (1) 0.7 — 2.9 — 0.6 4.5 6.1 Electric Rate Case (1) 2.4 — 5.2 — 0.3 7.1 8.6 Total Regulatory Initiatives 11.0 3.5 29.2 9.0 14.7 40.1 56.0 Total $ 24.5 $ 8.3 $ 63.5 $ 21.5 $ 35.1 $ 88.4 $ 128.6 (1) Includes adjusted gross margin attributable to interim rates during 2024 and 2025. See additional information provided below. Detailed Discussion of Major Projects and Initiatives Pipeline Expansions Worcester Resiliency Upgrade In August 2023, Eastern Shore filed an application with the Federal Energy Regulatory Commission ("FERC") requesting authorization to construct the Worcester Resiliency Upgrade, which consists of a mixture of storage and transmission facilities in Sussex County, Delaware and Wicomico, Worcester, and Somerset Counties in Maryland. The project will provide long-term incremental supply necessary to support the growing demand of the participating shippers. In January 2025, the FERC approved the project. Construction has commenced and the project is expected to be placed into service in mid-2026 dependent on final FERC approval. In June 2025, Eastern Shore filed a limited amended application with the FERC requesting revised initial transportation rates for the project. The revised rates reflected increased capital costs associated with unanticipated changes in global markets and supply chains, including the availability of skilled laborers with the requisite certifications to work on this project. Eastern Shore requested expedited action by the FERC in relation to this matter and an approved order was issued in July 2025. The project is expected to generate $10.2 million in adjusted gross margin in 2026 and $17.6 million in 2027 and thereafter. East Coast Reinforcement Projects (Boynton Beach and New Smyrna Beach) In December 2023, Peninsula Pipeline filed a petition with the Florida Public Service Commission ("PSC") for approval of its Transportation Service Agreements with Florida Public Utilities Company ("FPU") for projects that will provide additional supply to coastal communities on the East Coast of Florida, which are experiencing significant population growth. Peninsula Pipeline proposed several pipeline extensions to support FPU's distribution system in the areas of Boynton Beach and New Smyrna Beach with an additional 15,000 Dts/day and 3,400 Dts/day, respectively. The Florida PSC approved the projects in March 2024. New Smyrna Beach was placed into service during May 2025 and construction is projected to be complete for Boynton Beach in the fourth quarter of 2025. Central Florida Reinforcement Projects (Plant City and Lake Mattie) In February 2024, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreements with FPU for projects that will support additional supply to communities located in Central Florida which are also experiencing significant population growth. Peninsula Pipeline proposed to construct several pipeline extensions which will support FPU's distribution system around the Plant City and Lake Mattie areas of Florida with an additional 5,000 Dts/day and 8,700 Dts/day, respectively. The Florida PSC approved the projects in May 2024. The Plant City project was completed in the fourth quarter of 2024, and the Lake Mattie project went into service in July 2025. Renewable Natural Gas Supply Projects In February 2024, Peninsula Pipeline filed a petition with the Florida PSC for approval of Transportation Service Agreements with FCG for projects that will support the transportation of additional renewable energy supply to FCG. The projects, located in Florida's Brevard, Indian River and Miami-Dade counties, will bring renewable natural gas produced from local landfills into FCG's natural gas distribution system. Peninsula Pipeline will construct several pipeline extensions which will support FCG's distribution system in Brevard County, Indian River County, and Miami-Dade County. Benefits of these projects include increased gas supply to serve expected FCG growth, strengthened system reliability and additional system flexibility. The Florida PSC approved the petition at its July 2024 meeting with the projects estimated to be completed in the first half of 2026. In October 2025, the Florida PSC approved amendments to the Transportation Service Agreements that were filed to include Peninsula Pipeline as a party to the related interconnection agreements. Miami Inner Loop Pipeline Projects In September 2024, Peninsula Pipeline filed a petition with the Florida PSC for approval of the Transportation Service Agreement with FCG for a series of projects that will enhance the infrastructure in Miami-Dade County. The proposed expansion consists of the development of several pipeline projects to support growth and FCG's distribution system in the area, as well as enhance FCG's access to obtain gas from various points in the Miami-Dade County area. The expansion was approved in February 2025 and interim services began in August 2025 with permanent facilities expected to be in service by the second quarter of 2026. Duncan Plains Pipeline Project In July 2025, Aspire Energy Express entered into an agreement with American Electric Power to construct and operate an intrastate natural gas pipeline in central Ohio to serve a new fuel-cell facility, which will provide on-site electric power to a data center. This new transmission infrastructure is expected to be in service in the first half of 2027. Regulatory Initiatives Maryland Natural Gas Rate Case In January 2024, the Company's natural gas distribution businesses in Maryland, CUC-Maryland Division, Sandpiper Energy, Inc., and Elkton Gas Company (collectively, the "Maryland natural gas distribution businesses") filed a joint application for a natural gas rate case with the Maryland PSC. In connection with the application, the Company sought approval of the following: (i) permanent rate relief of approximately $6.9 million with a return on equity ("ROE") of 11.5 percent; (ii) authorization to make certain changes to tariffs to include a unified rate structure and to consolidate the Maryland natural gas distribution businesses; and (iii) authorization to establish a rider for recovery of the costs associated with the Company's new technology systems. In August 2024, the Maryland natural gas distribution businesses, the Maryland Office of People's Counsel (the "Maryland OPC") and PSC staff reached a settlement which provided for, among other things, an increase in annual base rates of $2.6 million. In September 2024, the Maryland Public Utility Judge issued an order approving the related settlement agreement in part. The $2.6 million increase in annual base rates was approved and the Company filed a Phase II filing in November 2024 to determine rate design across the Maryland natural gas distribution businesses, consolidation of the applicable tariffs and recovery of technology costs. The hearing was held in March 2025, during which Phase II was approved, including an additional $0.9 million in revenue requirement, for a total cumulative increase of $3.5 million. A final order was issued in April 2025 and included approval of the consolidation of the operations and the assets of CUC-Maryland Division, Sandpiper Energy, and Elkton Gas into one entity which was renamed and will operate as Chesapeake Utilities of Maryland, Inc. Maryland Natural Gas Depreciation Study In January 2024, the Company's natural gas distribution businesses in Maryland filed a joint petition for approval of its proposed unified depreciation rates with the Maryland PSC. A settlement among the Company, PSC staff and the Maryland OPC was reached and the final order approving the related settlement agreement went into effect in July 2024, with new depreciation rates effective as of January 1, 2023. The approved depreciation rates resulted in an annual reduction in depreciation expense of approximately $1.2 million. Delaware Natural Gas Rate Case In August 2024, the Company's Delaware natural gas division filed an application for a natural gas rate case with the Delaware PSC seeking approval of the following: (i) permanent rate relief of approximately $12.1 million with a ROE of 11.5 percent; (ii) proposed changes to depreciation rates which were part of a depreciation study also submitted with the filing; and (iii) authorization to make certain changes to tariffs. Annualized interim rates were approved by the Delaware PSC in the amount of $2.5 million and became effective in October 2024. A settlement among the Company, PSC staff and the Delaware Division of the Public Advocate was reached and approved by the Delaware PSC in June 2025 providing an annual revenue increase of $6.1 million, as well as dividing the rate case into two phases. Rates set to recover the approved components of the increase were effective in March 2025. In October 2025, a settlement among the Company, PSC staff and the Delaware Division of the Public Advocate was reached for Phase II of the rate case addressing tariff-related changes including rate design and approved by the Delaware Public Service Commission with rates effective as of October 15, 2025. FPU Electric Rate Case In August 2024, the Company's Florida Electric division filed a petition with the Florida PSC seeking a general base rate increase of $12.6 million with a ROE of 11.3 percent based on a 2025 projected test year. Annualized interim rates of approximately $1.8 million were approved with an effective date of November 1, 2024. In March 2025, the Florida PSC approved the permanent rate increase, but the order was subsequently protested. In May 2025, the Company reached a settlement agreement with the interested parties to resolve all outstanding issues in its current base rate case, which was filed as a joint motion for approval with the Florida PSC. This settlement which was approved by the Florida PSC in July 2025, provides for a total revenue increase of approximately $8.6 million on an annual basis, with $1.0 million of the increase deferred from the first year's base rate increase and recovered over three years. A step-up rate increase was also approved for up to $0.7 million, upon completion of the purchase and refurbishment of certain substations, which is expected in December 2026. FCG Depreciation Study In February 2025, FCG filed a depreciation study with the Florida PSC. The application is requesting approval of revised annual depreciation rates, as well as a reduction related to a reserve imbalance that would be amortized over a two-year period. The outcome of the application is subject to review and approval by the Florida PSC. The Florida OPC filed a motion to hold this filing in abeyance, which was denied in April 2025. The OPC has since filed motions to reconsider and dismiss the docket, which were denied by the Florida PSC in September 2025. At this time, the docket is set for hearing in December 2025. Other Major Factors Influencing Adjusted Gross Margin Weather and Consumption For the nine months ended September 30, 2025, increased customer consumption, which includes the effects of colder weather conditions, largely in the Company's Ohio and Delmarva service areas, compared to the prior-year period resulted in a $4.8 million increase in adjusted gross margin. The following table summarizes heating degree-day (HDD) and cooling degree-day (CDD) variances from the 10-year average HDD/CDD ("Normal") for the three and nine months ended September 30, 2025 and 2024. Three Months Ended Nine Months Ended September 30, September 30, 2025 2024 Variance 2025 2024 Variance Delmarva Peninsula Actual HDD 4 6 (2) 2,505 2,287 218 10-Year Average HDD ("Normal") 19 27 (8) 2,538 2,635 (97) Variance from Normal (15) (21) (33) (348) Florida Actual HDD 1 — 1 611 511 100 10-Year Average HDD ("Normal") 1 1 — 526 512 14 Variance from Normal — (1) 85 (1) Florida City Gas Actual HDD — — — 310 231 79 10-Year Average HDD ("Normal") — — — 234 239 (5) Variance from Normal — — 76 (8) Ohio Actual HDD 107 43 64 3,881 3,180 701 10-Year Average HDD ("Normal") 55 65 (10) 3,480 3,661 (181) Variance from Normal 52 (22) 401 (481) Florida Actual CDD 1,298 1,528 (230) 2,602 2,824 (222) 10-Year Average CDD ("Normal") 1,429 1,420 9 2,624 2,615 9 Variance from Normal (131) 108 (22) 209 Natural Gas Distribution Growth The average number of residential customers served on the Delmarva Peninsula increased by approximately 4.3 percent for both the three and nine months ended September 30, 2025. The average number of residential customers served by Florida Public Utilities Company increased by approximately 3.5 percent and 3.9 percent for the three and nine months ended September 30, 2025, respectively, while the average number of residential customers served by Florida City Gas increased by approximately 2.2 percent and 2.1 percent for the three and nine months ended September 30, 2025, respectively. The details of the adjusted gross margin increase are provided in the following table: Three Months Ended Nine Months Ended September 30, 2025 September 30, 2025 (in millions) Delmarva Peninsula Florida Delmarva Peninsula Florida Customer Growth: Residential $ 0.3 $ 0.6 $ 1.2 $ 2.4 Commercial and industrial — 0.6 0.2 1.7 Total Customer Growth $ 0.3 $ 1.2 $ 1.4 $ 4.1 Capital Investment Growth and Capital Structure Updates The Company's capital expenditures were $335.6 million for the nine months ended September 30, 2025. The following table shows a range of the forecasted 2025 capital expenditures by segment and by business line: 2025 (in millions) Low High Regulated Energy: Natural gas distribution $ 170.0 $ 175.0 Natural gas transmission 170.0 175.0 Electric distribution 35.0 40.0 Total Regulated Energy 375.0 390.0 Unregulated Energy: Propane distribution 12.0 15.0 Energy transmission 8.0 10.0 Other unregulated energy 12.0 15.0 Total Unregulated Energy 32.0 40.0 Other: Corporate and other businesses 18.0 20.0 Total 2025 Forecasted Capital Expenditures $ 425.0 $ 450.0 The capital expenditure projection is subject to continuous review and modification. Actual capital requirements may vary from the above estimates due to a number of factors, including changing political and economic conditions, supply chain disruptions, capital delays that are greater than currently anticipated, customer growth in existing areas, regulation, new growth or acquisition opportunities and availability of capital. At September 30, 2025, the Company further increased and refined its 2025 capital guidance range to $425 million to $450 million given progress on its capital projects. The Company's target ratio of equity to total capitalization, including short-term borrowings, is between 50 and 60 percent. The Company's equity to total capitalization ratio, including short-term borrowings, was approximately 49 percent as of September 30, 2025, as the Company continues to remain focused on moving back closer to this target ratio. In the last twelve months, the Company has issued $92.0 million of new equity via its DRIP and ATM program, representing 729 thousand incremental shares. Chesapeake Utilities Corporation and Subsidiaries Condensed Consolidated Statements of Income (Unaudited) Three Months Ended Nine Months Ended September 30, September 30, 2025 2024 2025 2024 (in millions, except shares (thousands) and per share data) Operating Revenues Regulated Energy $ 146.4 $ 130.6 $ 497.8 $ 429.7 Unregulated Energy 40.7 35.6 195.3 160.1 Other Businesses and Eliminations (7.5) (6.0) (22.0) (17.6) Total Operating Revenues 179.6 160.2 671.1 572.2 Operating Expenses Regulated natural gas and electricity costs 31.7 28.4 137.3 105.7 Unregulated propane and natural gas costs 10.7 9.8 71.4 53.4 Operations 53.6 49.5 166.5 153.4 Maintenance 6.1 5.1 17.5 16.6 Depreciation and amortization 23.3 16.8 67.7 51.7 Other taxes 9.0 8.9 27.6 27.0 FCG transaction and transition-related expenses 0.2 0.8 1.0 3.1 Total Operating Expenses 134.6 119.3 489.0 410.9 Operating Income 45.0 40.9 182.1 161.3 Other income, net 0.2 0.5 1.2 1.7 Interest charges 18.2 17.1 54.1 50.9 Income Before Income Taxes 27.0 24.3 129.2 112.1 Income taxes 7.6 6.8 35.0 30.2 Net Income $ 19.4 $ 17.5 $ 94.2 $ 81.9 Weighted Average Common Shares Outstanding: Basic 23,526 22,501 23,265 22,346 Diluted 23,629 22,564 23,360 22,402 Earnings Per Share of Common Stock: Basic $ 0.82 $ 0.78 $ 4.05 $ 3.67 Diluted $ 0.82 $ 0.78 $ 4.03 $ 3.66 Adjusted Net Income and Adjusted Earnings Per Share Net Income (GAAP) $ 19.4 $ 17.5 $ 94.2 $ 81.9 FCG transaction and transition-related expenses, net (1) 0.1 0.6 0.7 2.3 Adjusted Net Income (Non-GAAP)** $ 19.5 $ 18.1 $ 94.9 $ 84.2 Earnings Per Share - Diluted (GAAP) $ 0.82 $ 0.78 $ 4.03 $ 3.66 FCG transaction and transition-related expenses, net (1) — 0.02 0.03 0.10 Adjusted Earnings Per Share - Diluted (Non-GAAP)** $ 0.82 $ 0.80 $ 4.06 $ 3.76 (1) Transaction and transition-related expenses represent costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transition services, consulting, system integration, rebranding and legal fees. Chesapeake Utilities Corporation and Subsidiaries Consolidated Balance Sheets (Unaudited) Assets September 30, 2025 December 31, 2024 (in millions, except shares and per share data) Property, Plant and Equipment Regulated Energy $ 2,848.6 $ 2,661.8 Unregulated Energy 481.8 463.7 Other Businesses and Eliminations 38.4 29.9 Total property, plant and equipment 3,368.8 3,155.4 Less: Accumulated depreciation and amortization (617.7) (567.6) Plus: Construction work in progress 254.4 148.1 Net property, plant and equipment 3,005.5 2,735.9 Current Assets Cash and cash equivalents 1.8 7.9 Trade and other receivables 82.3 80.0 Less: Allowance for credit losses (4.2) (3.3) Trade and other receivables, net 78.1 76.7 Accrued revenue 25.2 37.8 Propane inventory, at average cost 6.7 8.9 Other inventory, at average cost 18.2 18.0 Regulatory assets 30.0 23.9 Storage gas prepayments 5.6 3.8 Income taxes receivable 28.7 6.8 Prepaid expenses 21.4 17.3 Derivative assets, at fair value 0.1 0.6 Other current assets 3.0 2.6 Total current assets 218.8 204.3 Deferred Charges and Other Assets Goodwill 507.5 507.7 Other intangible assets, net 13.7 15.0 Investments, at fair value 16.8 14.4 Derivative assets, at fair value — 0.1 Operating lease right-of-use assets 9.6 10.5 Regulatory assets 75.3 77.4 Receivables and other deferred charges 14.2 11.7 Total deferred charges and other assets 637.1 636.8 Total Assets $ 3,861.4 $ 3,577.0 Chesapeake Utilities Corporation and Subsidiaries Consolidated Balance Sheets (Unaudited) Capitalization and Liabilities September 30, 2025 December 31, 2024 (in millions, except shares and per share data) Capitalization Stockholders' equity Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no shares issued and outstanding $ — $ — Common stock, par value $0.4867 per share (authorized 50,000,000 shares) 11.5 11.1 Additional paid-in capital 913.2 830.5 Retained earnings 597.2 550.3 Accumulated other comprehensive loss (3.2) (1.7) Deferred compensation obligation 12.5 9.8 Treasury stock (12.5) (9.8) Total stockholders' equity 1,518.7 1,390.2 Long-term debt, net of current maturities 1,437.9 1,261.7 Total capitalization 2,956.6 2,651.9 Current Liabilities Current portion of long-term debt 34.5 25.5 Short-term borrowing 95.8 196.5 Accounts payable 89.2 78.3 Customer deposits and refunds 44.9 45.7 Accrued interest 17.4 4.8 Dividends payable 16.1 14.7 Accrued compensation 12.1 23.9 Regulatory liabilities 13.1 16.1 Derivative liabilities, at fair value 0.5 — Other accrued liabilities 27.6 13.9 Total current liabilities 351.2 419.4 Deferred Credits and Other Liabilities Deferred income taxes 338.8 296.1 Regulatory liabilities 186.4 184.0 Environmental liabilities 2.8 2.2 Other pension and benefit costs 15.0 13.2 Derivative liabilities, at fair value 1.3 0.1 Operating lease - liabilities 8.0 8.7 Deferred investment tax credits and other liabilities 1.3 1.4 Total deferred credits and other liabilities 553.6 505.7 Environmental and other commitments and contingencies (1) Total Capitalization and Liabilities $ 3,861.4 $ 3,577.0 (1) Refer to Note 6 and 7 in the Company's Quarterly Report on Form 10-Q for further information. Chesapeake Utilities Corporation and Subsidiaries Distribution Utility Statistical Data (Unaudited) For the Three Months Ended September 30, 2025 For the Three Months Ended September 30, 2024 Delmarva NG Distribution Florida Natural Gas Distribution FPU Electric Distribution Delmarva NG Distribution Florida Natural Gas Distribution FPU Electric Distribution Operating Revenues (in millions) Residential $ 9.3 $ 23.2 $ 15.4 $ 8.3 $ 21.6 $ 16.0 Commercial and Industrial 8.6 46.0 12.9 7.1 38.6 14.4 Other (1) 1.6 13.9 2.4 2.4 10.1 (0.5) Total Operating Revenues $ 19.5 $ 83.1 $ 30.7 $ 17.8 $ 70.3 $ 29.9 Volumes (in Dts for natural gas and MWHs for electric) Residential 254,152 705,262 99,088 237,744 689,005 100,207 Commercial and Industrial 1,900,478 11,068,460 110,078 1,913,091 11,757,062 118,214 Other 70,386 1,772,152 — 59,512 2,156,255 — Total 2,225,016 13,545,874 209,166 2,210,347 14,602,322 218,421 Average Customers Residential 106,028 212,061 26,067 101,635 206,325 25,776 Commercial and Industrial 8,445 17,331 7,504 8,322 17,061 7,354 Other 27 131 — 27 118 — Total 114,500 229,523 33,571 109,984 223,504 33,130 For the Nine Months Ended September 30, 2025 For the Nine Months Ended September 30, 2024 Delmarva NG Distribution Florida Natural Gas Distribution FPU Electric Distribution Delmarva NG Distribution Florida Natural Gas Distribution FPU Electric Distribution Operating Revenues (in millions) Residential $ 74.2 $ 84.0 $ 39.5 $ 60.0 $ 76.2 $ 38.7 Commercial and Industrial 40.8 145.4 32.7 35.0 132.8 37.3 Other (1) (1.7) 34.7 7.9 (2.2) 17.6 (3.6) Total Operating Revenues $ 113.3 $ 264.1 $ 80.1 $ 92.8 $ 226.6 $ 72.4 Volumes (in Dts for natural gas and MWHs for electric) Residential 4,142,289 3,158,849 253,347 3,499,276 3,082,323 243,454 Commercial and Industrial 7,906,328 35,529,998 281,913 7,588,547 37,774,530 301,687 Other 223,124 5,038,164 — 207,213 6,528,899 — Total 12,271,741 43,727,011 535,260 11,295,036 47,385,752 545,141 Average Customers Residential 105,344 210,928 26,031 101,045 204,978 25,747 Commercial and Industrial 8,480 17,315 7,493 8,361 17,029 7,361 Other 26 129 — 26 109 — Total 113,850 228,372 33,524 109,432 222,116 33,108 (1) Operating Revenues from "Other" sources include unbilled revenue, under (over) recoveries of fuel cost, conservation revenue, other miscellaneous charges, fees for billing services provided to third parties and adjustments for pass-through taxes. SOURCE Chesapeake Utilities Corporation

CHESAPEAKE UTILITIES CORPORATION REPORTS THIRD QUARTER 2025 RESULTS

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