CHESAPEAKE UTILITIES CORPORATION REPORTS SECOND QUARTER 2025 RESULTS

— Net income and earnings per share (“EPS”)* were $23.9 million and $1.02, respectively, for the second quarter of 2025 and $74.8 million and $3.22, respectively, for the six months ended June 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 $24.3 million and $1.04, respectively, for the second quarter of 2025 and $75.4 million and $3.25, respectively, for the six months ended June 30, 2025

— Adjusted gross margin** growth of $16.2 million and $34.1 million, respectively, for the three- and six-month periods ended June 30, 2025 driven by natural gas organic growth and transmission expansion projects, regulatory initiatives and infrastructure programs, increased compressed natural gas, renewable natural gas and liquified natural gas services, and increased customer consumption

— Continued to execute the Company's 2025 financing plan by issuing equity and increasing debt capacity, including a $200 million long-term debt agreement in August 2025

— Re-affirming 2025 Adjusted EPS guidance of $6.15 – $6.35, which assumes a successful outcome on the FCG Depreciation Study

— The Company is increasing its 2025 capital guidance range to $375-$425 million in light of advances on various capital projects

— The Company continues to affirm 2028 EPS and 2024-2028 capital expenditure guidance

Chesapeake Utilities Corporation (NYSE:CPK) (“Chesapeake Utilities” or the “Company”) today announced financial results for the three and six months ended June30, 2025.

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Net income for the second quarter of 2025 was $23.9 million ($1.02 per share) compared to $18.2 million ($0.82 per share) in the second quarter of 2024. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, adjusted net income was $24.3 million, or $1.04 per share compared to $0.86 per share reported in the same prior-year period. This resulted in EPS and adjusted EPS growth of 24.4 percent and 20.9 percent, respectively, compared to the second quarter of 2024.

Adjusted earnings for the second 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 half of 2025, net income was $74.8 million ($3.22 per share) compared to $64.4 million ($2.89 per share) in the prior-year period. Excluding the transaction and transition-related expenses, adjusted net income was $75.4 million ($3.25 per share) compared to $66.1 million ($2.96 per share) for the same period in 2024. This resulted in EPS and adjusted EPS growth of 11.4 percent and 9.8 percent, respectively, compared to the prior-year period.

Year-to-date adjusted earnings for 2025 were primarily impacted by the factors discussed for the second quarter as well as additional adjusted gross margin from increased customer consumption experienced earlier in the year.

“Our second quarter 2025 results demonstrate yet another outstanding quarter of growth and solid execution by the team. Adjusted Gross Margin increased by 13 percent, which, alongside operational efficiency improvements, resulted in Adjusted EPS up 21 percent relative to the second quarter of 2024. This performance reinforces our ability to operate our regulated and unregulated businesses safely and efficiently to meet the rising demand for natural gas across the communities we serve,” said Jeff Householder, the Company's Chair of the Board, President and Chief Executive Officer.

“We also continued to make significant progress within each of the three pillars of our growth strategy, starting with year-to-date capital deployment of $213 million, which enabled us to raise our full-year 2025 capital expenditure guidance by $50 million to $375 – $425 million. Our regulatory successes included resolution of all three active rate cases as well as FERC issuing a notice to proceed with site preparation work and approving updated rates for the Worcester Resiliency Upgrade project which will drive an additional $3.9 million of margin once the facility is in service. And finally, we made further strides in transforming the business for our next stage of growth as we concluded the Transition Services Agreement for FCG, expanded our debt capacity on multiple fronts and reached our target equity capitalization of 50 percent.”

Earnings and Capital Investment Guidance

The Company continues to re-affirm its 2025 EPS guidance range of $6.15 to $6.35 per share, which includes approval of the pending FCG excess depreciation filing. The Company also continues to re-affirm the 2028 EPS guidance range of $7.75 to $8.00 per share.

The Company also continues to re-affirm its capital expenditure guidance range for the five-year period ended 2028 of $1.5 billion to $1.8 billion and has increased its projected guidance range for 2025 to $375 million to $425 million given its investments to date and expected level of spending in the second half of 2025.

*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. Our 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 our 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 June 30, 2025(in millions) Regulated Energy Unregulated Other Businesses Total Energy and EliminationsOperating Revenues $ 151.8 $ 47.9 $ (6.9) $ 192.8Cost of Sales:Natural gas, propane and electric costs (34.1) (22.9) 7.0 (50.0)Depreciation & amortization (16.8) (5.1) – (21.9)Operations & maintenance expenses (1) (14.6) (9.8) 0.4 (24.0)Gross Margin (GAAP) 86.3 10.1 0.5 96.9Operations & maintenance expenses (1) 14.6 9.8 (0.4) 24.0Depreciation & amortization 16.8 5.1 – 21.9Adjusted Gross Margin (Non-GAAP) $ 117.7 $ 25.0 $ 0.1 $ 142.8 For the Three Months Ended June 30, 2024(in millions) Regulated Energy Unregulated Other Businesses Total Energy and EliminationsOperating Revenues $ 130.7 $ 41.4 $ (5.8) $ 166.3Cost of Sales:Natural gas, propane and electric costs (27.4) (18.0) 5.7 (39.7)Depreciation & amortization (14.7) (3.2) – (17.9)Operations & maintenance expenses (1) (12.3) (7.9) – (20.2)Gross Margin (GAAP) 76.3 12.3 (0.1) 88.5Operations & maintenance expenses (1) 12.3 7.9 – 20.2Depreciation & amortization 14.7 3.2 – 17.9Adjusted Gross Margin (Non-GAAP) $ 103.3 $ 23.4 $ (0.1) $ 126.6 For the Six Months Ended June 30, 2025(in millions) Regulated Energy Unregulated Other Businesses Total Energy and EliminationsOperating Revenues $ 351.4 $ 154.6 $ (14.5) $ 491.5Cost of Sales:Natural gas, propane and electric costs (105.6) (75.1) 14.4 (166.3)Depreciation & amortization (34.4) (10.0) – (44.4)Operations & maintenance expenses (1) (27.9) (19.5) 0.7 (46.7)Gross Margin (GAAP) 183.5 50.0 0.6 234.1Operations & maintenance expenses (1) 27.9 19.5 (0.7) 46.7Depreciation & amortization 34.4 10.0 – 44.4Adjusted Gross Margin (Non-GAAP) $ 245.8 $ 79.5 $ (0.1) $ 325.2 For the Six Months Ended June 30, 2024(in millions) Regulated Energy Unregulated Other Businesses Total Energy and EliminationsOperating Revenues $ 299.1 $ 124.5 $ (11.6) $ 412.0Cost of Sales:Natural gas, propane and electric costs (77.3) (55.1) 11.5 (120.9)Depreciation & amortization (27.2) (7.7) – (34.9)Operations & maintenance expenses (1) (25.0) (16.3) – (41.3)Gross Margin (GAAP) 169.6 45.4 (0.1) 214.9Operations & maintenance expenses (1) 25.0 16.3 – 41.3Depreciation & amortization 27.2 7.7 – 34.9Adjusted Gross Margin (Non-GAAP) $ 221.8 $ 69.4 $ (0.1) $ 291.1(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 Six Months Ended June 30, June 30,(dollars in millions, shares in thousands (except per share data)) 2025 2024 2025 2024Net Income (GAAP) $ 23.9 $ 18.2 $ 74.8 $ 64.4FCG transaction and transition-related expenses, net (1) 0.4 1.1 0.6 1.7Adjusted Net Income (Non-GAAP) $ 24.3 $ 19.3 $ 75.4 $ 66.1Weighted average common shares outstanding – diluted 23,402 22,335 23,223 22,320Earnings Per Share – Diluted (GAAP) $ 1.02 $ 0.82 $ 3.22 $ 2.89FCG transaction and transition-related expenses, net (1) 0.02 0.04 0.03 0.07Adjusted Earnings Per Share – Diluted (Non-GAAP) $ 1.04 $ 0.86 $ 3.25 $ 2.96(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 June 30, 2025 and 2024

Consolidated Results

Three Months Ended June 30,(in millions) 2025 2024 Change Percent ChangeAdjusted gross margin** $ 142.8 $ 126.6 $ 16.2 12.8%Depreciation, amortization and property taxes 31.2 26.7 (4.5) (16.9)%Other operating expenses 60.8 57.7 (3.1) (5.4)%FCG transaction and transition-related expenses 0.5 1.4 0.9 NMFOperating income $ 50.3 $ 40.8 $ 9.5 23.3%

Operating income for the second quarter of 2025 was $50.3 million, an increase of $9.5 million or 23.3 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 $8.6 million or 20.4 percentcompared to the prior-year period. The increase in adjusted gross margin in the second 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. Operating expenses were driven largely by the absence of a reserve surplus amortization mechanism (“RSAM”) adjustment from FCG (representing $2.3 million in the second quarter of 2024), higher depreciation attributable to growth projects and expenses associated with facilities, maintenance and outside services. These increases were partially offset by reduced payroll, benefits and other employee-related expenses compared to the prior-year period.

Regulated Energy Segment

Three Months Ended June 30,(in millions) 2025 2024 Change Percent ChangeAdjusted gross margin** $ 117.7 $ 103.3 $ 14.4 13.9%Depreciation, amortization and property taxes 25.5 22.8 (2.7) (11.8)%Other operating expenses 39.9 38.6 (1.3) (3.4)%FCG transaction and transition-related expenses 0.5 1.4 0.9 NMFOperating income $ 51.8 $ 40.5 $ 11.3 27.9%

The key components of the increase in adjusted gross margin** are shown below:

(in millions)Rate changes associated with recent rate case activities (1) $ 4.1Natural gas transmission service expansions, including interim services 3.9Contributions from regulated infrastructure programs 3.7Natural gas growth including conversions (excluding service expansions) 1.8Changes in customer consumption 1.1Other variances (0.2)Quarter-over-quarter increase in adjusted gross margin** $ 14.4(1)Includes adjusted gross margin contributions from both interim and permanent base rates. Refer to Major Projects 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 $ (3.1)Payroll, benefits and other employee-related expenses 1.7Other variances 0.1Quarter-over-quarter increase in other operating expenses $ (1.3)

Unregulated Energy Segment

Three Months Ended June 30,(in millions) 2025 2024 Change Percent ChangeAdjusted gross margin** $ 25.0 $ 23.4 $ 1.6 6.8%Depreciation, amortization and property taxes 5.5 3.8 (1.7) (44.7)%Other operating expenses 21.0 19.2 (1.8) (9.4)%Operating income (loss) $ (1.5) $ 0.4 $ (1.9) NMF

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 OperationsDecreased propane customer consumption $ (1.3)Decreased propane margins and service fees (1.0)CNG/RNG/LNG Transportation and InfrastructureIncreased CNG/RNG/LNG services 3.5Aspire EnergyIncreased customer consumption 0.4Quarter-over-quarter increase in adjusted gross margin** $ 1.6

The major components of theincrease in other operating expenses are as follows:

(in millions)Facilities expenses, maintenance costs and outside services $ (1.2)Payroll, benefits and other employee-related expenses (0.4)Other variances (0.2)Quarter-over-quarter increase in other operating expenses $ (1.8)

Operating Results for the Six Months Ended June 30, 2025 and 2024

Consolidated Results

Six Months Ended June 30,(in millions) 2025 2024 Change Percent ChangeAdjusted gross margin** $ 325.2 $ 291.1 $ 34.1 11.7%Depreciation, amortization and property taxes 62.5 52.8 (9.7) (18.4)%Other operating expenses 124.8 115.6 (9.2) (8.0)%FCG transaction and transition-related expenses 0.8 2.3 1.5 NMFOperating income $ 137.1 $ 120.4 $ 16.7 13.9%

Operating income for the six months ended June 30, 2025 was $137.1 million, an increase of $16.7 million compared to the same period in 2024. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $15.2 million or 12.4 percentcompared to the prior-year period. The increase in adjusted gross margin in the first halfof 2025 was driven by incremental margin from regulatory initiatives and infrastructure programs, increased CNG, RNG and LNG services, pipeline expansion projects, increased customer consumption resulting from year-over-year colder temperatures in our Mid-Atlantic and Ohio service territories and natural gas organic growth. These increases were partially offset by a reduced volume of off system sales and service fees and lower margins per gallon and related fees in our propane distribution business. Higher operating expenses were driven largely by the absence of a RSAM adjustment from FCG (representing $5.7 million during the first half of 2024), higher depreciation attributable to growth projects, increased facilities, maintenance and outside services, and increased payroll, benefits and other employee-related expenses. Additional expenses associated with insurance related costs also contributed to the increase compared to the prior-year period.

Regulated Energy Segment

Six Months Ended June 30,(in millions) 2025 2024 Change Percent ChangeAdjusted gross margin** $ 245.8 $ 221.8 $ 24.0 10.8%Depreciation, amortization and property taxes 51.4 43.8 (7.6) (17.4)%Other operating expenses 81.3 77.1 (4.2) (5.4)%FCG transaction and transition-related expenses 0.8 2.3 1.5 NMFOperating income $ 112.3 $ 98.6 $ 13.7 13.9%

The key components of the increase in adjusted gross margin** are shown below:

(in millions)Contributions from regulated infrastructure programs $ 7.1Natural gas transmission service expansions, including interim services 6.1Rate changes associated with recent rate case activities (1) 5.6Natural gas growth including conversions (excluding service expansions) 4.0Changes in customer consumption 1.8Adjusted gross margin from off-system natural gas capacity sales (0.7)Other variances 0.1Period-over-period increase in adjusted gross margin** $ 24.0(1)Includes adjusted gross margin contributions from both interim and permanent base rates. Refer to Major Projects 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 $ (2.4)Insurance related costs (0.8)Payroll, benefits and other employee-related expenses (0.8)Other variances (0.2)Period-over-period increase in other operating expenses $ (4.2)

Unregulated Energy Segment

Six Months Ended June 30,(in millions) 2025 2024 Change Percent ChangeAdjusted gross margin** $ 79.5 $ 69.4 $ 10.1 14.6%Depreciation, amortization and property taxes 11.0 9.0 (2.0) (22.2)%Other operating expenses 43.7 38.6 (5.1) (13.2)%Operating income $ 24.8 $ 21.8 $ 3.0 13.8%

The major components of the increase in adjusted gross margin** are shown below:

(in millions)Propane OperationsIncreased propane customer consumption $ 2.9Decreased propane margins and service fees (0.6)CNG/RNG/LNG Transportation and InfrastructureIncreased CNG/RNG/LNG services 7.1Aspire EnergyIncreased customer consumption 1.0Other variances (0.3)Period-over-period increase in adjusted gross margin** $ 10.1

The major components of the increase in other operating expenses are as follows:

(in millions)Payroll, benefits and other employee-related expenses $ (2.4)Facilities expenses, maintenance costs and outside services (2.4)Other variances (0.3)Period-over-period increase in other operating expenses $ (5.1)

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 second 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, August8, 2025, at 8:30 a.m. Eastern Time to discuss the Company's financial results for the three and six months ended June30, 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: 800.579.2543 International: 785.424.1789 Conference ID: CPKQ225

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. Cooper Executive Vice President, Chief Financial Officer, Treasurer and Assistant Corporate Secretary 302.734.6022

Michael D. Galtman Senior Vice President and Chief Accounting Officer 302.217.7036

Lucia M. Dempsey Head of Investor Relations 347.804.9067

Financial Summary Highlights

Key variances between the second quarter of 2024 and 2025 included:

(in millions, except per share data) Pre-tax Net Earnings Income Income PerShareSecond Quarter of 2024 Adjusted Results (1) $ 26.4 $ 19.3 $ 0.86Change in Adjusted Gross Margins:Rate changes associated with recent rate case activities (2) 4.1 3.0 0.13Natural gas transmission service expansions, including interim services (2) 3.9 2.9 0.12Contributions from regulated infrastructure programs (2) 3.7 2.7 0.11Increased CNG/RNG/LNG services 3.5 2.5 0.11Natural gas growth (excluding service expansions) 1.8 1.3 0.06Decreased propane margins and service fees (1.0) (0.7) (0.03) 16.0 11.7 0.50(Increased) Decreased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs):Depreciation, amortization and property tax costs (4.5) (3.3) (0.14)Facilities expenses, maintenance costs and outside services (4.3) (3.1) (0.13)Payroll, benefits and other employee-related expenses 1.3 1.0 0.04 (7.5) (5.4) (0.23)Interest charges (1.0) (0.7) (0.03)Increase in shares outstanding due to 2024 and 2025 equity offerings (3) – – (0.05)Net other changes (0.6) (0.6) (0.01) (1.6) (1.3) (0.09)Second Quarter of 2025 Adjusted Results (1) $ 33.3 $ 24.3 $ 1.04(1) Transaction and transition-related expenses attributable to the acquisition and integration of FCG have been excluded from the Company'snon-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.

Key variances between the six months ended June 30, 2024 and June 30, 2025 included:

(in millions, except per share data) Pre-tax Net Earnings Income Income PerShareSix months ended June 30, 2024 Adjusted Results (1) $ 90.1 $ 66.1 $ 2.96Change in Adjusted Gross Margins:Increased CNG/RNG/LNG services 7.1 5.2 0.22Contributions from regulated infrastructure programs (2) 7.1 5.2 0.22Natural gas transmission service expansions, including interim services (2) 6.1 4.5 0.19Changes in customer consumption 5.7 4.2 0.18Rate changes associated with recent rate case activities (2) 5.6 4.1 0.18Natural gas growth including conversions (excluding service expansions) 4.0 2.9 0.13Decreased service fees and off system sales (0.7) (0.5) (0.02)Decreased propane margins and service fees (0.6) (0.4) (0.02) 34.3 25.2 1.08Increased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs):Depreciation, amortization and property taxes (9.7) (7.1) (0.30)Facilities expenses, maintenance costs and outside services (4.8) (3.5) (0.15)Payroll, benefits and other employee-related expenses (3.2) (2.3) (0.10)Credit, collections and customer service (0.4) (0.3) (0.01) (18.1) (13.2) (0.56)Interest charges (2.1) (1.5) (0.07)Increase in shares outstanding due to 2024 and 2025 equity offerings (3) – – (0.13)Net other changes (1.2) (1.2) (0.03) (3.3) (2.7) (0.23)Six months ended June 30, 2025 Adjusted Results (1) $ 103.0 $ 75.4 $ 3.25(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 second quarter 2025 Quarterly Report on Form 10-Q.

Adjusted Gross Margin Three Months Ended Six Months ended Year Ended Estimate for June 30, June 30, December 31, Fiscal(in millions) 2025 2024 2025 2024 2024 2025 2026Pipeline Expansions:St. Cloud / Twin Lakes Expansion $ 0.8 $ 0.2 $ 0.9 $ 0.3 $ 0.6 $ 2.8 $ 3.8Wildlight 0.5 0.2 1.0 0.4 1.5 3.0 4.3Newberry 0.6 0.1 1.2 0.1 1.4 2.6 2.6Worcester Resiliency Upgrade – – – – – – 10.2Boynton Beach 0.9 – 1.4 – – 3.0 3.4New Smyrna Beach 0.3 – 0.3 – – 1.6 2.6Central Florida Reinforcement 0.3 – 0.6 – 0.1 2.6 4.3Warwick 0.5 – 1.0 – 0.4 1.9 1.9Renewable Natural Gas Supply Projects 0.5 – 0.5 – – 2.5 4.6Miami Inner Loop – – – – – 2.8 7.6Duncan Plains – – – – – – -Total Pipeline Expansions 4.4 0.5 6.9 0.8 4.0 22.8 45.3CNG/RNG/LNG Transportation and Infrastructure 6.9 3.5 13.9 6.9 16.4 22.0 22.7Regulatory Initiatives:Florida GUARD program 1.7 0.9 3.2 1.5 3.6 6.9 9.9FCG SAFE Program 2.2 0.7 3.9 1.1 3.8 8.5 12.0Capital Cost Surcharge Programs 1.4 0.8 2.9 1.6 3.2 5.7 7.1Electric Storm Protection Plan 1.5 0.7 2.6 1.3 3.2 5.9 8.8Maryland Rate Case 0.6 – 0.6 – – 2.0 3.5Delaware Rate Case (1) 1.4 – 2.2 – 0.6 4.0 6.1Electric Rate Case (1) 2.1 – 2.8 – 0.3 7.1 8.6Total Regulatory Initiatives 10.9 3.1 18.2 5.5 14.7 40.1 56.0Total $ 22.2 $ 7.1 $ 39.0 $ 13.2 $ 35.1 $ 84.9 $ 124.0(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, and construction is expected to be complete in the second quarter of 2026.

In June 2025, Eastern Shore filed a limited amended application with the FERC requesting that it issue an order authorizing revised initial transportation rates for the project. The revised rates were requested to address increased capital costs being incurred related to unanticipated changes in global markets and supply chains. 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 support additional supply to communities on the East Coast of Florida. The projects are driven by the need for increased supply to coastal portions of the state that are experiencing significant population growth. Peninsula Pipeline will construct several pipeline extensions which will 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 FloridaPSC for approval of its Transportation Service Agreements with FPU for projects that will support additional supply to communities located in Central Florida. The projects are driven by the need for increased supply to communities in central Florida that are experiencing significant population growth. Peninsula Pipeline will 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.

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 support FCG's distribution system in the area and also enhance FCG's ability to obtain gas from various access points in the Miami-Dade county area. The expansion was approved in February 2025 and the projects are expected to be in service in the third quarter of 2025.

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 $6.9million 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. Phase II of the rate case which will address tariff-related changes including rate design began in July 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.

Other Major Factors Influencing Adjusted Gross Margin

Weather and Consumption Weather was not a significant factor to adjusted gross margin in the second quarter of 2025 compared to the same period in 2024.

For the six months ended June 30, 2025, increased customer consumption, which includes the effects of colder weather conditions, largely in our Ohio and Delmarva service areas, compared to the prior-year period resulted in a $5.7 million increase in adjusted gross margin.

The following table summarizes HDD and CDD variances from the 10-year average HDD/CDD (“Normal”) for the three and six months ended June 30, 2025 and 2024.

Three Months Ended Six Months Ended June 30, June 30, 2025 2024 Variance 2025 2024 VarianceDelmarva PeninsulaActual HDD 291 319 (28) 2,501 2,281 22010-Year Average HDD (“Normal”) 373 387 (14) 2,519 2,608 (89)Variance from Normal (82) (68) (18) (327)FloridaActual HDD 30 41 (11) 610 511 9910-Year Average HDD (“Normal”) 42 41 1 525 511 14Variance from Normal (12) – 85 -Florida City GasActual HDD 10 17 (7) 310 231 7910-Year Average HDD (“Normal”) 13 12 1 234 239 (5)Variance from Normal (3) 5 76 (8)OhioActual HDD 687 478 209 3,774 3,137 63710-Year Average HDD (“Normal”) 624 631 (7) 3,425 3,596 (171)Variance from Normal 63 (153) 349 (459)FloridaActual CDD 1,115 1,115 – 1,304 1,296 810-Year Average CDD (“Normal”) 978 978 – 1,195 1,195 -Variance from Normal 137 137 109 101

Natural Gas Distribution Growth The average number of residential customers served on the Delmarva Peninsula increased by approximately 4.4 percent and 4.2 percent, for the three and six months ended June 30, 2025, respectively, while the Company's Florida natural gas distribution service territories increased by approximately 2.9 percent and 3.0 percent, for the three and six months ended June 30, 2025, respectively.

The details of the adjusted gross margin increase are provided in the following table:

Three Months Ended Six Months Ended June 30, 2025 June 30, 2025(in millions) Delmarva Florida Delmarva Florida Peninsula PeninsulaCustomer Growth:Residential $ 0.3 $ 0.7 $ 0.9 $ 1.8Commercial and industrial 0.1 0.7 0.2 1.1Total Customer Growth $ 0.4 $ 1.4 $ 1.1 $ 2.9

Capital Investment Growth and Capital Structure Updates

The Company's capital expenditures were $212.8 million for the six months ended June 30, 2025. The following table shows a range of the forecasted 2025 capital expenditures by segment and by business line:

2025(in millions) Low HighRegulated Energy:Natural gas distribution $ 145.0 $ 155.0Natural gas transmission 155.0 175.0Electric distribution 35.0 45.0Total Regulated Energy 335.0 375.0Unregulated Energy:Propane distribution 10.0 15.0Energy transmission 10.0 12.0Other unregulated energy 13.0 15.0Total Unregulated Energy 33.0 42.0Other:Corporate and other businesses 7.0 8.0Total 2025 Forecasted Capital Expenditures $ 375.0 $ 425.0

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. During the second quarter of 2025, the Company increased its projected guidance range for 2025 and now expects a range of between $375.0 million to $425.0 million given its investments to date and expected level of spending in the second half of 2025.

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 50 percent as of June 30, 2025.

Chesapeake Utilities Corporation and SubsidiariesCondensed Consolidated Statements of Income (Unaudited) Three Months Ended Six Months Ended June 30, June 30, 2025 2024 2025 2024(in millions, except shares (thousands) and per share data)Operating RevenuesRegulated Energy $ 151.8 $ 130.7 $ 351.4 $ 299.1Unregulated Energy 47.9 41.4 154.6 124.5Other Businesses and Eliminations (6.9) (5.8) (14.5) (11.6)Total Operating Revenues 192.8 166.3 491.5 412.0Operating ExpensesRegulated natural gas and electricity costs 34.1 27.4 105.6 77.3Unregulated propane and natural gas costs 15.9 12.3 60.7 43.6Operations 54.9 52.3 112.9 103.9Maintenance 6.0 5.6 11.4 11.5Depreciation and amortization 21.9 17.9 44.4 34.9Other taxes 9.2 8.6 18.6 18.1FCG transaction and transition-related expenses 0.5 1.4 0.8 2.3Total operating expenses 142.5 125.5 354.4 291.6Operating Income 50.3 40.8 137.1 120.4Other income, net 0.4 1.0 1.0 1.2Interest charges 17.8 16.8 35.9 33.8Income Before Income Taxes 32.9 25.0 102.2 87.8Income taxes 9.0 6.8 27.4 23.4Net Income $ 23.9 $ 18.2 $ 74.8 $ 64.4Weighted Average Common Shares Outstanding:Basic 23,307 22,284 23,133 22,267Diluted 23,402 22,335 23,223 22,320Earnings Per Share of Common Stock:Basic $ 1.03 $ 0.82 $ 3.23 $ 2.89Diluted $ 1.02 $ 0.82 $ 3.22 $ 2.89Adjusted Net Income and Adjusted Earnings Per ShareNet Income (GAAP) $ 23.9 $ 18.2 $ 74.8 $ 64.4FCG transaction and transition-related expenses, net (1) 0.4 1.1 0.6 1.7Adjusted Net Income (Non-GAAP)** $ 24.3 $ 19.3 $ 75.4 $ 66.1Earnings Per Share – Diluted (GAAP) $ 1.02 $ 0.82 $ 3.22 $ 2.89FCG transaction and transition-related expenses, net (1) 0.02 0.04 0.03 0.07Adjusted Earnings Per Share – Diluted (Non-GAAP)** $ 1.04 $ 0.86 $ 3.25 $ 2.96(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 SubsidiariesConsolidated Balance Sheets (Unaudited)Assets June 30, December 31, 2025 2024(in millions, except shares and per share data)Property, Plant and EquipmentRegulated Energy $ 2,789.2 $ 2,661.8Unregulated Energy 482.2 463.7Other Businesses and Eliminations 37.7 29.9Total property, plant and equipment 3,309.1 3,155.4Less: Accumulated depreciation and amortization (600.3) (567.6)Plus: Construction work in progress 199.2 148.1Net property, plant and equipment 2,908.0 2,735.9Current AssetsCash and cash equivalents 1.5 7.9Trade and other receivables 89.1 80.0Less: Allowance for credit losses (5.0) (3.3)Trade and other receivables, net 84.1 76.7Accrued revenue 26.9 37.8Propane inventory, at average cost 6.7 8.9Other inventory, at average cost 18.4 18.0Regulatory assets 20.8 23.9Storage gas prepayments 3.6 3.8Income taxes receivable 10.7 6.8Prepaid expenses 16.4 17.3Derivative assets, at fair value 0.3 0.6Other current assets 2.9 2.6Total current assets 192.3 204.3Deferred Charges and Other AssetsGoodwill 507.7 507.7Other intangible assets, net 14.0 15.0Investments, at fair value 15.9 14.4Derivative assets, at fair value 0.1 0.1Operating lease right-of-use assets 9.6 10.5Regulatory assets 76.1 77.4Receivables and other deferred charges 14.1 11.7Total deferred charges and other assets 637.5 636.8Total Assets $ 3,737.8 $ 3,577.0Chesapeake Utilities Corporation and SubsidiariesConsolidated Balance Sheets (Unaudited)Capitalization and Liabilities June 30, December 31, 2025 2024(in millions, except shares and per share data)CapitalizationStockholders' equityPreferred 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) 11.4 11.1Additional paid-in capital 896.4 830.5Retained earnings 594.1 550.3Accumulated other comprehensive loss (2.8) (1.7)Deferred compensation obligation 12.5 9.8Treasury stock (12.5) (9.8)Total stockholders' equity 1,499.1 1,390.2Long-term debt, net of current maturities 1,249.6 1,261.7Total capitalization 2,748.7 2,651.9Current LiabilitiesCurrent portion of long-term debt 25.5 25.5Short-term borrowing 245.3 196.5Accounts payable 69.1 78.3Customer deposits and refunds 48.1 45.7Accrued interest 4.9 4.8Dividends payable 16.0 14.7Accrued compensation 12.2 23.9Regulatory liabilities 16.1 16.1Derivative liabilities, at fair value 0.2 -Other accrued liabilities 22.4 13.9Total current liabilities 459.8 419.4Deferred Credits and Other LiabilitiesDeferred income taxes 315.7 296.1Regulatory liabilities 185.9 184.0Environmental liabilities 2.8 2.2Other pension and benefit costs 14.3 13.2Derivative liabilities, at fair value 1.2 0.1Operating lease – liabilities 8.0 8.7Deferred investment tax credits and other liabilities 1.4 1.4Total deferred credits and other liabilities 529.3 505.7Environmental and other commitments and contingencies (1)Total Capitalization and Liabilities $ 3,737.8 $ 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 SubsidiariesDistribution Utility Statistical Data (Unaudited) For the Three Months Ended June 30, 2025 For the Three Months Ended June 30, 2024 Delmarva NG Florida FPU Electric Delmarva NG Florida FPU Electric Distribution Natural Gas Distribution Distribution Natural Gas Distribution Distribution DistributionOperating Revenues(in millions)Residential $ 18.1 $ 27.4 $ 11.9 $ 15.9 $ 24.2 $ 11.3Commercial and Industrial 10.0 48.3 10.3 10.3 43.7 12.1Other (1) (1.9) 10.4 4.0 (2.9) 4.6 (0.9)Total Operating Revenues $ 26.2 $ 86.1 $ 26.2 $ 23.3 $ 72.5 $ 22.5Volumes (in Dts for natural gas and MWHs for electric)Residential 788,353 960,135 73,256 823,378 952,940 71,226Commercial and Industrial 2,049,542 11,814,935 87,551 2,248,283 12,917,289 95,646Other 62,650 1,553,304 – 58,603 2,042,895 -Total 2,900,545 14,328,374 160,807 3,130,264 15,913,124 166,872Average CustomersResidential 105,402 211,084 26,061 100,964 205,112 25,762Commercial and Industrial 8,477 17,333 7,518 8,367 17,037 7,359Other 24 128 – 25 110 -Total 113,903 228,545 33,579 109,356 222,259 33,121 For the Six Months Ended June 30, 2025 For the Six Months Ended June 30, 2024 Delmarva NG Florida FPU Electric Delmarva NG Florida FPU Electric Distribution Natural Gas Distribution Distribution Natural Gas Distribution Distribution DistributionOperating Revenues(in millions)Residential $ 64.9 $ 60.8 $ 24.1 $ 51.7 $ 54.6 $ 22.7Commercial and Industrial 32.2 99.4 19.8 27.9 94.2 22.9Other (1) (3.3) 20.8 5.5 (4.6) 7.5 (3.1)Total Operating Revenues $ 93.8 $ 181.0 $ 49.4 $ 75.0 $ 156.3 $ 42.5Volumes (in Dts for natural gas and MWHs for electric)Residential 3,888,137 2,453,587 154,259 3,261,532 2,393,318 143,247Commercial and Industrial 6,005,850 24,461,538 171,835 5,675,456 26,017,468 183,473Other 152,738 3,266,012 – 147,701 4,372,644 -Total 10,046,725 30,181,137 326,094 9,084,689 32,783,430 326,720Average CustomersResidential 105,003 210,362 26,014 100,749 204,305 25,733Commercial and Industrial 8,501 17,308 7,488 8,382 17,015 7,365Other 26 128 – 25 105 -Total 113,530 227,798 33,502 109,156 221,425 33,098(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.

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