Form 8-K

8-K — CHESAPEAKE UTILITIES CORP

Accession: 0001628280-26-031368

Filed: 2026-05-06

Period: 2026-05-06

CIK: 0000019745

SIC: 4923 (NATURAL GAS TRANSMISSION & DISTRIBUTION)

Item: Results of Operations and Financial Condition

Item: Regulation FD Disclosure

Item: Financial Statements and Exhibits

Documents

8-K — cpk-20260506.htm (Primary)

EX-99.1 (exhibit99-prq12026.htm)

EX-99.2 (exhibit992-firstquarter2.htm)

GRAPHIC (chesapeakelogova18a.jpg)

GRAPHIC (exhibit992-firstquarter2001.jpg)

GRAPHIC (exhibit992-firstquarter2002.jpg)

GRAPHIC (exhibit992-firstquarter2003.jpg)

GRAPHIC (exhibit992-firstquarter2004.jpg)

GRAPHIC (exhibit992-firstquarter2005.jpg)

GRAPHIC (exhibit992-firstquarter2006.jpg)

GRAPHIC (exhibit992-firstquarter2007.jpg)

GRAPHIC (exhibit992-firstquarter2008.jpg)

GRAPHIC (exhibit992-firstquarter2009.jpg)

GRAPHIC (exhibit992-firstquarter2010.jpg)

GRAPHIC (exhibit992-firstquarter2011.jpg)

GRAPHIC (exhibit992-firstquarter2012.jpg)

GRAPHIC (exhibit992-firstquarter2013.jpg)

GRAPHIC (exhibit992-firstquarter2014.jpg)

GRAPHIC (exhibit992-firstquarter2015.jpg)

GRAPHIC (exhibit992-firstquarter2016.jpg)

GRAPHIC (exhibit992-firstquarter2017.jpg)

GRAPHIC (exhibit992-firstquarter2018.jpg)

GRAPHIC (exhibit992-firstquarter2019.jpg)

GRAPHIC (exhibit992-firstquarter2020.jpg)

GRAPHIC (exhibit992-firstquarter2021.jpg)

GRAPHIC (exhibit992-firstquarter2022.jpg)

GRAPHIC (exhibit992-firstquarter2023.jpg)

GRAPHIC (exhibit992-firstquarter2024.jpg)

GRAPHIC (exhibit992-firstquarter2025.jpg)

XML — IDEA: XBRL DOCUMENT (R1.htm)

8-K

8-K (Primary)

Filename: cpk-20260506.htm · Sequence: 1

cpk-20260506

0000019745falseMay 6, 2026falseNYSE00000197452026-05-062026-05-06

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the

Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): May 6, 2026

CHESAPEAKE UTILITIES CORPORATION

(Exact name of registrant as specified in its charter)

Delaware 001-11590 51-0064146

(State or other jurisdiction of (Commission (I.R.S. Employer

incorporation or organization) File Number) Identification No.)

500 Energy Lane, Dover, DE 19901

(Address of principal executive offices, including Zip Code)

(302) 734-6799

(Registrant's Telephone Number, including Area Code)

(Former name, former address and former fiscal year, if changed since last report.)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class Trading Symbol(s) Name of each exchange on which registered

Common Stock - par value per share $0.4867 CPK New York Stock Exchange, Inc.

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

☐ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

☐

Item 2.02. Results of Operations and Financial Condition.

On May 6, 2026, Chesapeake Utilities Corporation issued a press release announcing its financial results for the three months ended March 31, 2026. A copy of the press release is attached as Exhibit 99.1 hereto and is incorporated by reference herein.

Item 7.01 Regulation FD Disclosure.

On May 6, 2026, Chesapeake Utilities Corporation posted a presentation that will be used during its conference call on May 7, 2026, to discuss the Company’s financial results for the three months ended March 31, 2026, on its website (www.chpk.com) under the “Investors” section. This presentation is being furnished as Exhibit 99.2 to this Current Report on Form 8-K.

Item 9.01. Financial Statements and Exhibits.

(d) Exhibits.

Exhibit 99.1 - Press Release of Chesapeake Utilities Corporation, dated May 6, 2026.

Exhibit 99.2 - First Quarter 2026 Earnings Call Presentation.

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersigned hereunto duly authorized.

CHESAPEAKE UTILITIES CORPORATION

/s/ Beth W. Cooper

Beth W. Cooper

Executive Vice President and Chief Financial Officer

Date: May 6, 2026

EX-99.1

Filename: exhibit99-prq12026.htm · Sequence: 2

Document

FOR IMMEDIATE RELEASE

May 6, 2026

NYSE Symbol: CPK

CHESAPEAKE UTILITIES CORPORATION REPORTS

FIRST QUARTER 2026 RESULTS

•Net income and earnings per share ("EPS")* were $59.3 million and $2.47, respectively, representing an EPS growth rate of 11.8 percent compared to the prior year

•Adjusted gross margin** growth of $23.8 million during the first quarter of 2026 driven primarily by regulatory initiatives and infrastructure programs, natural gas organic growth and transmission expansion projects, and increased customer consumption

•Capital investment of $121.9 million during the first quarter of 2026

•Florida City Gas ("FCG") filed a petition in April 2026 seeking a general rate base increase, subject to review and approval by the Florida Public Service Commission ("PSC")

•The Company continues to re-affirm its 2026 and 2024-2028 capital expenditure guidance ranges, as well as its 2028 EPS guidance range

Dover, Delaware — Chesapeake Utilities Corporation (NYSE: CPK) (“Chesapeake Utilities” or the “Company”) today announced financial results for the three months ended March 31, 2026.

Net income for the first quarter of 2026 was $59.3 million ($2.47 per share) compared to $50.9 million ($2.21 per share) in the first quarter of 2025. Adjusted net income for the first quarter of 2026 was $59.3 million ($2.47 per share) compared with $51.1 million ($2.22 per share) in the prior-year period.

First quarter 2026 highlights include:

•Organic customer growth across all service areas drove $2.0 million of incremental adjusted gross margin or $0.06 per share

•Transmission system expansions to support increased distribution demand generated an incremental $6.9 million of adjusted gross margin or $0.21 per share

•Infrastructure programs to enhance reliability provided an incremental $5.5 million of adjusted gross margin or $0.17 per share

•Colder weather within the first quarter produced an incremental $4.5 million of adjusted gross margin or $0.14 per share

•Improved rates from three rate cases completed in 2025 provided an incremental $4.1 million of adjusted gross margin or $0.13 per share

“Our performance in the first quarter reflects a strong start to 2026, as we remain focused on our growth strategy: prudently deploying capital, proactively managing our regulatory agenda and transforming operations across the business," said Jeff Householder, the Company’s Chair of the Board, President and Chief Executive Officer. “Our theme for the year is ‘Transforming for Growth, Powered by People’. Achieving meaningful growth and delivering reliable and affordable service to customers depends on our dedicated teammates working together. I’m especially grateful for the exemplary performance of our team and the resilience of our system during the winter storms earlier this year.”

--more--

2-2-2-2

“We are also recognizing the significant contributions of Beth Cooper, who announced her retirement in March following 36 years of service at the Company. In the last 18 years as our Chief Financial Officer, Beth's strategic and financial leadership has led to incomparable growth, including a $3 billion increase in our market capitalization, 10x growth in total assets and net income, as well as a 366 percent increase in earnings per share. Most importantly, Beth embodies the best of Chesapeake Utilities, including an authentic passion for delivering results and an impressive ability to build connections and relationships internally and externally,” continued Householder. “While Beth is not easily replaced, I am confident in the abilities of Jeff Sylvester, our current Chief Operating Officer, who will assume the Chief Financial Officer role on July 1, 2026. Under his leadership, we are well-positioned to continue our long-standing track record.”

Earnings and Capital Investment Guidance

The Company continues to re-affirm its 2026 full year capital guidance range of $450 million to $500 million. The Company also continues to re-affirm its five-year (2024-2028) capital guidance range of $1.5 billion to $1.8 billion and 2028 EPS guidance range of $7.75 to $8.00 per share.

*Unless otherwise noted, EPS and Adjusted EPS information are presented on a diluted basis.

--more--

3-3-3-3

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.

--more--

4-4-4-4

Adjusted Gross Margin

For the Three Months Ended March 31, 2026

(in millions) Regulated Energy Unregulated Energy Other Businesses and Eliminations Total

Operating Revenues $ 249.3 $ 113.7 $ (9.9) $ 353.1

Cost of Sales:

Natural gas, propane and electric costs (101.6) (55.1) 9.8 (146.9)

Depreciation & amortization (16.1) (5.4) — (21.5)

Operations & maintenance expenses (1)

(16.7) (10.9) 0.1 (27.5)

Gross Margin (GAAP) 114.9 42.3 — 157.2

Operations & maintenance expenses (1)

16.7 10.9 (0.1) 27.5

Depreciation & amortization 16.1 5.4 — 21.5

Adjusted Gross Margin (Non-GAAP) $ 147.7 $ 58.6 $ (0.1) $ 206.2

For the Three Months Ended March 31, 2025

(in millions) Regulated Energy Unregulated Energy Other Businesses and Eliminations Total

Operating Revenues $ 199.6 $ 106.7 $ (7.6) $ 298.7

Cost of Sales:

Natural gas, propane and electric costs (71.5) (52.2) 7.4 (116.3)

Depreciation & amortization (17.6) (4.9) — (22.5)

Operations & maintenance expenses (1)

(13.3) (9.7) 0.3 (22.7)

Gross Margin (GAAP) 97.2 39.9 0.1 137.2

Operations & maintenance expenses (1)

13.3 9.7 (0.3) 22.7

Depreciation & amortization 17.6 4.9 — 22.5

Adjusted Gross Margin (Non-GAAP) $ 128.1 $ 54.5 $ (0.2) $ 182.4

(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.

--more--

5-5-5-5

Adjusted Net Income and Adjusted EPS

Three Months Ended

March 31,

(dollars in millions, shares in thousands (except per share data)) 2026 2025

Net Income (GAAP) $ 59.3 $ 50.9

FCG transaction and transition-related expenses, net (1)

— 0.2

Adjusted Net Income (Non-GAAP) $ 59.3 $ 51.1

Weighted average common shares outstanding - diluted 24,053 23,041

Earnings Per Share - Diluted (GAAP) $ 2.47 $ 2.21

FCG transaction and transition-related expenses, net (1)

— 0.01

Adjusted Earnings Per Share - Diluted (Non-GAAP) $ 2.47 $ 2.22

(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.

--more--

6-6-6-6

Operating Results for the Quarters Ended March 31, 2026 and 2025

Consolidated Results

Three Months Ended

March 31,

(in millions) 2026 2025 Change Percent Change

Adjusted gross margin** $ 206.2 $ 182.4 $ 23.8 13.0 %

Depreciation, amortization and property taxes 30.9 31.3 0.4 1.3 %

Other operating expenses 75.9 64.0 (11.9) (18.6) %

FCG transaction and transition-related expenses — 0.3 0.3 NMF

Operating income $ 99.4 $ 86.8 $ 12.6 14.5 %

Operating income for the first quarter of 2026 was $99.4 million, an increase of $12.6 million compared to the same period in 2025. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $12.3 million or 14.1 percent compared to the prior-year period. The increase in adjusted gross margin for the first quarter of 2026 was primarily driven by incremental margin from regulatory initiatives and infrastructure programs, pipeline expansion projects and natural gas organic growth, increased customer consumption resulting from year-over-year colder temperatures largely in the Company's Delmarva service areas, and improved performance at Aspire Energy. Higher operating expenses were driven largely by increased payroll, benefits and other employee-related expenses and higher facilities, maintenance costs and outside services compared to the prior-year period. Depreciation and amortization expense for the current period includes decreases related to certain regulatory items including the absence of recovered costs associated with Hurricane Michael and the impact of the FCG depreciation study. These amounts were largely offset by additional depreciation, amortization and property taxes associated with growth.

Regulated Energy Segment

Three Months Ended

March 31,

(in millions) 2026 2025 Change Percent Change

Adjusted gross margin (1) **

$ 147.7 $ 128.1 $ 19.6 15.3 %

Depreciation, amortization and property taxes (1)

25.0 25.9 0.9 3.5 %

Other operating expenses 51.6 41.4 (10.2) (24.6) %

FCG transaction and transition-related expenses — 0.3 0.3 NMF

Operating income $ 71.1 $ 60.5 $ 10.6 17.5 %

(1) The current period includes offsetting reductions in both adjusted gross margin and depreciation and amortization expense related to the absence of recovered costs associated with Hurricane Michael. See Key variances table below for additional information.

--more--

7-7-7-7

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

(in millions)

Natural gas transmission service expansions, including interim services $ 6.9

Contributions from regulated infrastructure programs 5.5

Rate changes associated with recent rate case activities (1)

4.1

Natural gas growth including conversions (excluding service expansions) 2.0

Changes in customer consumption 1.7

Change in off-system natural gas capacity sales 1.1

Absence of recovered costs associated with Hurricane Michael (2)

(2.0)

Other variances 0.3

Quarter-over-quarter increase in adjusted gross margin** $ 19.6

(1) Includes adjusted gross margin contributions from permanent base rates. Refer to Major Projects and Initiatives discussion for additional information.

(2) The current period includes offsetting reductions in both adjusted gross margin and depreciation and amortization expense related to the absence of recovered costs associated with Hurricane Michael.

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

(in millions)

Payroll, benefits and other employee-related expenses $ (5.0)

Facilities expenses, maintenance costs and outside services (2.7)

Credit, collections and customer service costs (1.4)

Other variances (1.1)

Quarter-over-quarter increase in other operating expenses $ (10.2)

Unregulated Energy Segment

Three Months Ended

March 31,

(in millions) 2026 2025 Change Percent Change

Adjusted gross margin** $ 58.6 $ 54.5 $ 4.1 7.5 %

Depreciation, amortization and property taxes 5.8 5.5 (0.3) (5.5) %

Other operating expenses 24.5 22.7 (1.8) (7.9) %

Operating income $ 28.3 $ 26.3 $ 2.0 7.6 %

--more--

8-8-8-8

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

(in millions)

Propane Operations

Increased propane customer consumption $ 2.4

Aspire Energy

Increased performance from Aspire Energy - rate changes and gathering fees 1.4

Increased customer consumption 0.4

Other variances (0.1)

Quarter-over-quarter increase in adjusted gross margin** $ 4.1

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

(in millions)

Payroll, benefits and other employee-related expenses $ (1.6)

Facilities expenses, maintenance costs and outside services (0.4)

Other variances 0.2

Quarter-over-quarter increase in other operating expenses $ (1.8)

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 2025 Annual Report on Form 10-K and Quarterly Report on Form 10-Q for the first quarter of 2026 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 Thursday, May 7, 2026, at 8:30 a.m. Eastern Time to discuss the Company’s financial results for the three months ended March 31, 2026. 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: 800.245.3047

International: 203.518.9765

Conference ID: CPKQ126

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.

--more--

9-9-9-9

For more information, contact:

Beth W. Cooper

Executive Vice President and Chief Financial Officer

302.363.2467

Lucia M. Dempsey

Head of Investor Relations

347.804.9067

--more--

10-10-10-10

Financial Summary Highlights

Key variances between the three months ended March 31, 2025 and March 31, 2026 included:

(in millions, except per share data) Pre-tax

Income Net

Income Earnings

Per Share

Three Months Ended March 31, 2025 Adjusted Results (1)

$ 69.7 $ 51.1 $ 2.22

Change in Adjusted Gross Margins:

Natural gas transmission service expansions, including interim services (2)

6.9 5.1 0.21

Contributions from regulated infrastructure programs (2)

5.5 4.0 0.17

Changes in customer consumption 4.5 3.3 0.14

Rate changes associated with recent rate case activities (2)

4.1 3.0 0.13

Natural gas growth including conversions (excluding service expansions) 2.0 1.5 0.06

Increased Aspire Energy performance - rate changes and gathering fees 1.4 1.0 0.04

Change in off-system natural gas capacity sales 1.1 0.8 0.03

Absence of recovered costs associated with Hurricane Michael (3)

(2.0) (1.5) (0.06)

23.5 17.2 0.72

Increased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs):

Payroll, benefits and other employee-related expenses (6.6) (4.9) (0.20)

Facilities expenses, maintenance costs and outside services (3.1) (2.2) (0.09)

Depreciation, amortization and property taxes (1.5) (1.1) (0.05)

Credit, collections and customer service costs (1.4) (1.1) (0.04)

Absence of amortization of costs associated with Hurricane Michael recovery (3)

2.0 1.5 0.06

(10.6) (7.8) (0.32)

Interest charges (0.6) (0.4) (0.02)

Increase in shares outstanding due to 2025 and 2026 equity offerings (4)

— — (0.09)

Net other changes (1.3) (0.8) (0.04)

(1.9) (1.2) (0.15)

Three Months Ended March 31, 2026 Adjusted Results (1)

$ 80.7 $ 59.3 $ 2.47

(1) Transaction and transition-related expenses attributable to the acquisition and integration of FCG have been excluded from 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) The current period includes offsetting reductions in both adjusted gross margin and depreciation and amortization expense related to the absence of recovered costs associated with Hurricane Michael.

(4) Reflects the impact of approximately 0.8 million common shares issued under the Company's dividend reinvestment and direct stock purchase plan and at the market program.

--more--

11-11-11-11

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 first quarter 2026 Quarterly Report on Form 10-Q.

Adjusted Gross Margin

Three Months Ended Year Ended Estimate for

March 31, December 31, Fiscal

(in millions) 2026 2025 2025 2026 2027

Pipeline Expansions:

St. Cloud / Twin Lakes Expansion $ 1.0 $ 0.1 $ 2.9 $ 3.8 $ 3.8

Wildlight 1.1 0.5 2.6 4.3 4.3

Worcester Resiliency Upgrade 0.4 — 0.3 1.5 17.1

Boynton Beach 0.9 0.5 3.0 3.4 3.4

New Smyrna Beach 0.6 — 1.6 2.6 2.6

Central Florida Reinforcement 1.1 0.3 2.6 4.3 4.3

Renewable Natural Gas Supply Projects 1.3 — 2.5 5.4 6.4

Miami Inner Loop 1.9 — 2.8 7.6 7.6

Duncan Plains — — — — 1.1

Total Pipeline Expansions 8.3 1.4 18.3 32.9 50.6

Regulatory Initiatives:

Florida GUARD program 2.4 1.5 7.1 10.1 13.0

FCG SAFE Program 2.8 1.7 8.4 12.7 16.4

Capital Cost Surcharge Programs 2.3 1.5 5.7 9.0 10.1

Electric Storm Protection Plan 3.3 1.1 6.4 10.7 11.0

Florida Mandatory Relocates 0.5 — — 1.5 1.5

Maryland Rate Case (1)

1.3 — 1.5 3.5 3.5

Delaware Rate Case (1)

2.1 0.8 4.7 6.1 6.1

Electric Rate Case (1)

2.2 0.7 7.3 8.6 9.1

FCG Rate Case — — — TBD TBD

Total Regulatory Initiatives 16.9 7.3 41.1 62.2 70.7

Total $ 25.2 $ 8.7 $ 59.4 $ 95.1 $ 121.3

(1) Includes adjusted gross margin attributable to interim and permanent rates. See additional information provided below.

--more--

12-12-12-12

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.

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. Construction commenced shortly after approval and is well underway. The weather during the first quarter resulted in several brief slowdowns which had a cumulative impact on the overall timeline. Project construction and commissioning are expected to be complete in the latter part of the year with the FERC approval process to immediately follow. The Company expects to receive full approval for in-service of the facility by the beginning of 2027.

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 second quarter of 2026.

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. 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. The projects are underway and are estimated to be completed in the second 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 gas infrastructure in Miami-Dade County. The proposed expansion consists of the development of several pipeline projects to support growth and FCG's distribution system, 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

--more--

13-13-13-13

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 September 2024, the Maryland Public Utility Judge approved a $2.6 million increase in annual base rates, which was followed by the Company submitting 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. In March 2025 the 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.

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 all interested parties 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 and approved tariff-related changes including rate design were 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. This settlement which was approved by the Florida PSC in July 2025, provided for a total base rate 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 to be completed in December 2026.

--more--

14-14-14-14

Florida Mandatory Relocates

In October 2025, FPU and FCG filed a joint petition for approval to establish a recovery surcharge for actual, estimated and projected relocation costs pursuant to the Florida Administrative Code which enables companies to recover the costs associated with relocating or reconstructing facilities that have been required by governmental entities. The projected revenue requirement for 2026 is $0.5 million for FPU and $1.0 million for FCG. The Florida PSC approved the petition in February 2026, with the surcharge effective in March 2026.

FCG Rate Case

In April 2026, FCG filed a petition with the Florida PSC. In connection with the application, we are seeking approval of the following: (i) interim rate relief of approximately $16.2 million, subject to refund, pending the outcome of the rate case proceeding; (ii) general base rate increase of $46.9 million with a ROE of 11.25 percent based on a 2027 projected test year; (iii) reclassification of approximately $16.4 million in the existing Safety, Access, and Facility Enhancement (“SAFE”) program revenues from surcharge recovery to base rates; (iv) authorization to retain the unamortized portion of the previously approved acquisition adjustment; and (v) further implementation of the advanced metering infrastructure (“AMI”). The outcome of the application will be subject to review and approval by the Florida PSC.

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. In February 2026, the Florida PSC approved a $6.8 million reserve imbalance to be amortized over the remaining life of the assets.

Other Major Factors Influencing Adjusted Gross Margin

Weather and Consumption

For the three months ended March 31, 2026, increased customer consumption, which includes the effects of colder weather conditions, largely in the Company's Delmarva service areas, compared to the prior-year period resulted in a $4.5 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 months ended March 31, 2026 and 2025.

--more--

15-15-15-15

Three Months Ended

March 31,

2026 2025 Variance

Delmarva Peninsula

Actual HDD 2,348 2,210 138

10-Year Average HDD ("Normal") 2,085 2,146 (61)

Variance from Normal 263 64

Florida

Actual HDD 594 580 14

10-Year Average HDD ("Normal") 471 483 (12)

Variance from Normal 123 97

FCG

Actual HDD 357 300 57

10-Year Average HDD ("Normal") 229 221 8

Variance from Normal 128 79

Ohio

Actual HDD 3,022 3,087 (65)

10-Year Average HDD ("Normal") 2,751 2,801 (50)

Variance from Normal 271 286

Florida

Actual CDD 226 189 37

10-Year Average CDD ("Normal") 220 217 3

Variance from Normal 6 (28)

Natural Gas Distribution Growth

The average number of residential customers served on the Delmarva Peninsula, by FPU and by FCG increased by approximately 3.3 percent, 2.2 percent, and 2.0 percent, respectively, for the three months ended March 31, 2026.

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

Three Months Ended

March 31, 2026

(in millions) Delmarva Peninsula Florida

Customer Growth:

Residential $ 0.5 $ 0.8

Commercial and industrial — 0.7

Total Customer Growth $ 0.5 $ 1.5

--more--

16-16-16-16

Capital Investment Growth and Capital Structure Updates

The Company's capital expenditures were $121.9 million for the three months ended March 31, 2026. The following table shows a range of the forecasted 2026 capital expenditures by type:

2026

(in millions) Low High

Regulated distribution $ 110.0 $ 120.0

Regulated transmission 135.0 145.0

Regulated infrastructure 90.0 100.0

Unregulated business 25.0 35.0

Technology 90.0 100.0

Total 2026 Forecasted Capital Expenditures $ 450.0 $ 500.0

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.

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 March 31, 2026.

--more--

17-17-17-17

Chesapeake Utilities Corporation and Subsidiaries

Condensed Consolidated Statements of Income (Unaudited)

Three Months Ended

March 31,

2026 2025

(in millions, except shares (thousands) and per share data)

Operating Revenues

Regulated Energy $ 249.3 $ 199.6

Unregulated Energy 113.7 106.7

Other Businesses and Eliminations (9.9) (7.6)

Total Operating Revenues 353.1 298.7

Operating Expenses

Regulated natural gas and electricity costs 101.6 71.5

Unregulated propane and natural gas costs 45.3 44.8

Operations 67.3 58.0

Maintenance 8.0 5.4

Depreciation and amortization 21.5 22.5

Other taxes 10.0 9.4

FCG transaction and transition-related expenses — 0.3

Total Operating Expenses 253.7 211.9

Operating Income 99.4 86.8

Other income, net — 0.6

Interest charges 18.7 18.1

Income Before Income Taxes 80.7 69.3

Income taxes 21.4 18.4

Net Income $ 59.3 $ 50.9

Weighted Average Common Shares Outstanding:

Basic 23,937 22,957

Diluted 24,053 23,041

Earnings Per Share of Common Stock:

Basic $ 2.48 $ 2.22

Diluted $ 2.47 $ 2.21

Adjusted Net Income and Adjusted Earnings Per Share

Net Income (GAAP) $ 59.3 $ 50.9

FCG transaction and transition-related expenses, net (1)

— 0.2

Adjusted Net Income (Non-GAAP)** $ 59.3 $ 51.1

Earnings Per Share - Diluted (GAAP) $ 2.47 $ 2.21

FCG transaction and transition-related expenses, net (1)

— 0.01

Adjusted Earnings Per Share - Diluted (Non-GAAP)** $ 2.47 $ 2.22

(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.

--more--

18-18-18-18

Chesapeake Utilities Corporation and Subsidiaries

Consolidated Balance Sheets (Unaudited)

Assets March 31,

2026 December 31,

2025

(in millions, except shares and per share data)

Property, Plant and Equipment

Regulated Energy $ 3,009.0 $ 2,941.6

Unregulated Energy 507.2 492.4

Other Businesses and Eliminations 39.3 38.3

Total property, plant and equipment 3,555.5 3,472.3

Less: Accumulated depreciation and amortization (652.1) (637.6)

Plus: Construction work in progress 320.5 283.7

Net property, plant and equipment 3,223.9 3,118.4

Current Assets

Cash and cash equivalents 4.7 1.8

Trade and other receivables 120.7 106.9

Less: Allowance for credit losses (6.8) (5.4)

Trade and other receivables, net 113.9 101.5

Accrued revenue 49.0 50.1

Propane inventory, at average cost 8.2 8.8

Other inventory, at average cost 17.1 17.9

Regulatory assets 24.5 29.7

Storage gas prepayments 0.7 4.5

Income taxes receivable — —

Prepaid expenses 17.0 19.7

Derivative assets, at fair value 0.8 —

Other current assets 3.2 3.0

Total current assets 239.1 237.0

Deferred Charges and Other Assets

Goodwill 507.5 507.5

Other intangible assets, net 12.9 13.2

Investments, at fair value 16.4 17.2

Derivative assets, at fair value 0.1 —

Operating lease right-of-use assets 9.4 9.9

Regulatory assets 73.7 74.3

Receivables and other deferred charges 12.9 17.3

Total deferred charges and other assets 632.9 639.4

Total Assets $ 4,095.9 $ 3,994.8

--more--

19-19-19-19

Chesapeake Utilities Corporation and Subsidiaries

Consolidated Balance Sheets (Unaudited)

Capitalization and Liabilities March 31,

2026 December 31,

2025

(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 75,000,000 shares) 11.7 11.6

Additional paid-in capital 972.2 962.8

Retained earnings 669.3 626.8

Accumulated other comprehensive loss (1.5) (2.7)

Deferred compensation obligation 17.4 12.6

Treasury stock (17.4) (12.6)

Total stockholders’ equity 1,651.7 1,598.5

Long-term debt, net of current maturities 1,325.3 1,327.1

Total capitalization 2,977.0 2,925.6

Current Liabilities

Current portion of long-term debt 134.6 134.6

Short-term borrowing 199.6 158.0

Accounts payable 101.1 115.2

Customer deposits and refunds 41.8 45.1

Accrued interest 17.6 8.7

Dividends payable 16.4 16.4

Accrued compensation 10.5 21.6

Regulatory liabilities 11.6 14.5

Derivative liabilities, at fair value 0.2 0.8

Other accrued liabilities 20.3 15.0

Total current liabilities 553.7 529.9

Deferred Credits and Other Liabilities

Deferred income taxes 333.7 313.3

Regulatory liabilities 188.8 188.1

Environmental liabilities 3.0 2.9

Other pension and benefit costs 13.1 14.0

Derivative liabilities, at fair value 0.5 0.6

Operating lease - liabilities 7.5 7.9

Deferred investment tax credits and other liabilities 18.6 12.5

Total deferred credits and other liabilities 565.2 539.3

Environmental and other commitments and contingencies (1)

Total Capitalization and Liabilities $ 4,095.9 $ 3,994.8

(1) Refer to Note 6 and 7 in the Company's Quarterly Report on Form 10-Q for further information.

--more--

20-20-20-20

Chesapeake Utilities Corporation and Subsidiaries

Distribution Utility Statistical Data (Unaudited)

For the Three Months Ended March 31, 2026 For the Three Months Ended March 31, 2025

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 $ 58.4 $ 40.9 $ 12.8 $ 46.8 $ 33.4 $ 12.2

Commercial and Industrial 28.2 60.7 11.6 22.2 51.1 9.5

Other (1)

(4.1) 22.9 3.2 (1.4) 10.4 1.5

Total Operating Revenues $ 82.5 $ 124.5 $ 27.6 $ 67.6 $ 94.9 $ 23.2

Volumes (in Dts for natural gas and MWHs for electric)

Residential 3,200,165 1,477,523 77,259 3,099,784 1,493,452 81,003

Commercial and Industrial 4,709,222 13,016,899 89,717 3,956,308 12,646,603 84,284

Other 93,677 333,084 — 90,088 1,712,708 —

Total 8,003,064 14,827,506 166,976 7,146,180 15,852,763 165,287

Average Customers

Residential 108,025 214,040 26,040 104,602 209,640 25,966

Commercial and Industrial 8,584 17,411 7,478 8,521 17,283 7,457

Other 27 137 — 27 127 —

Total 116,636 231,588 33,518 113,150 227,050 33,423

(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.

EX-99.2

Filename: exhibit992-firstquarter2.htm · Sequence: 3

exhibit992-firstquarter2

Q1 2026 Earnings Call Presentation Thursday, May 7, 2026

Safe Harbor for Forward-Looking Statements 2 Safe Harbor Statement Some of the statements in this presentation are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 and other applicable law. Such forward-looking statements may be identified by the use of words, such as “project,” “believe,” “expect,” “anticipate,” “intend,” “plan,” “estimate,” “continue,” “potential,” “forecast” or other similar words, or future or conditional verbs such as “may,” “will,” “should,” “would” or “could.” These statements represent our intentions, plans, expectations, assumptions and beliefs about our future financial performance, business strategy, projected plans and objectives. These statements are subject to many risks and uncertainties and actual results may materially differ from those expressed in these forward-looking statements. Please refer to Chesapeake Utilities' Annual Report on Form 10-K for the year ended December 31, 2025 and subsequent quarterly reports on Form 10-Q filed with the SEC and other SEC filings concerning factors that could cause those results to be different than contemplated in this presentation. Non-GAAP Financial Information This presentation includes non-GAAP financial measures including Adjusted Gross Margin, Adjusted Net Income and Adjusted Earnings Per Share (“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. See Appendix for a reconciliation of 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. *Unless otherwise noted, EPS and Adjusted EPS information is presented on a diluted basis.

Q1 2026 Safety Moment: Electrical Safety Month 3

Titles Should Be Font Size 40 – 44 4 Jeff Householder Chair of the Board, President & Chief Executive Officer Beth Cooper Executive Vice President and Chief Financial Officer Jeff Sylvester Senior Vice President and Chief Operating Officer Jim Moriarty Executive Vice President, General Counsel, Corporate Secretary & Chief Policy and Risk Officer oday's Presenters

$47M FCG RATE CASE REVENUE REQUEST 11% ADJ. EPS GROWTH vs. Q1'25 Growth Trajectory Continues in Q1 2026 5 $2.22 $2.47 Q1 2025 Q1 2026 Q1 Diluted EPS1 1 See appendix for a reconciliation of non-GAAP metrics. +11% $122M Q1'26 CAPITAL EXPENDITURES 16% ADJ. NET INCOME GROWTH vs. Q1'25 $12.4M TRANSMISSION & INFRASTRUCTURE $10.6M DISTRIBUTION GROWTH & USAGE INCREMENTAL ADJUSTED MARGIN:

Growth Remains Core to Long-Term Strategy Average Residential Customer Growth 6 3.3% 2.2% 2.0%Q 1' 26 v s. Q 1' 25 DELMARVA FPU FCG

Q1 2026 CapEx In Line with Full-Year Guidance $500.0 2026 Guidance 2026 Guidance 2026 Guidance Includes: $450 - $500M $ in millions Q1 2026 Spend Distribution $110 - $120M • Ongoing distribution system expansion and reliability projects across our Delmarva & Florida service areas $32M Transmission $135 - $145M • Worcester Resiliency Upgrade • Miami Inner Loop • Duncan Plains Data Center Pipeline • RNG Transportation Projects • Other Transmission Expansion Projects $40M Infrastructure $90 - $100M • FPU's GUARD & FCG's SAFE Programs • ESNG Capital Cost Surcharge Program • Electric Storm Protection Plan $18M Technology $90 - $100M • Enterprise Resource Plan (ERP) • Additional technology, cybersecurity investments $17M Unregulated $25 - $35M • Marlin Virtual Pipeline, Propane, Aspire Energy $14M $122M 7

Transmission Projects Advance to Meet Demand 8 # Project Name Status1 In-Service Total CapEx Adj. Gross Margin ($M) 2025A 2026E 2027E 1 Boynton Beach In-Service Q1 2025 ~$21M $3.0 $3.4 $3.4 2 Indian River RNG In-Service Q1-Q2 2025 ~$18M $2.5 $5.4 $6.43 Brevard RNG In-Service ~$6M 4 Medley RNG In-Service ~$22M 5 New Smyrna Beach In-Service Q2 2025 ~$15M $1.6 $2.6 $2.6 6 St. Cloud Expansion In-Service Q2 2025 ~$20M $2.9 $3.8 $3.8 7 Wildlight Phase 1 & 2 In-Service 2023-2025 ~$25M $2.6 $4.3 $4.3 8 Miami Inner Loop In-Service 2H 2025 ~$40M $2.8 $7.6 $7.6 9 Lake Mattie, Plant City In-Service Q3 2025 ~$18M $2.6 $4.3 $4.3 10 Worcester Resiliency Upgrade (WRU) In-Progress Q1 2027 ~$100M $0.3 $1.5 $17.1 11 AEX Duncan Plains In-Progress 2027 ~$10M — — $1.1 Totals: ~295M $18.3 $32.9 $50.6 1 May reflect interim in-service status using Marlin Virtual Pipeline Services while construction is being completed.

9 Worcester Resiliency Upgrade (WRU) Project • FERC delays in Notice to Proceed permitting process in Fall 2025 • Severe winter weather impacted site access and work hours throughout January / February • Building in additional time for FERC commissioning • Winter season reinforced need for LNG storage 500K-gal LNG Storage Facility in Bishopville, MD $(0.10) FY 2026 EPS IMPACT $17.1M FY 2027 MARGIN Q1 2027 EXPECTED IN-SERVICE Q4 2026 EXPECTED COMPLETION

Significant Upside with Future Growth Projects 10 • DELMARVA REGIONAL ENHANCEMENT (DRE) $75M, 20+ mile ESNG transmission expansion project to add firm capacity and improve system reliability; evaluating possibilities for further future expansion • ACCOMACK COUNTY EXPLORATION PROJECT Determining feasibility, design and engineering to develop a potential new natural gas system on Virginia's Eastern Shore supported by a $6.5 million county grant • CAPE CANAVERAL LNG OPPORTUNITIES Identifying alternative LNG storage sites and pipeline development opportunities to serve cruise, space and port industries • SOUTH FLORIDA CAPACITY EXPANSION Assessing opportunities to increase natural gas transmission capacity in south Florida to serve the significant demand growth

Florida City Gas Rate Case Overview 11 Date Milestone February 18, 2026 Notice of Intent filed April 20, 2026 General rate case filed Q3 2026 Interim rates (if approved) expected to be in effect Q4 2026 Estimated hearing date Q4 2026 / Early 2027 Final rates expected to be effective • Forward Test Year: Ending 12/31/2027 • Adjusted 2027 Rate Base: $780 million • Interim rate request: $16 million • Revenue Requirement Request: $47 million • ROE Request: 11.25% • Overall ROR Request: 8.3% • Key Recovery Request Items: ◦ Investment in reliability & efficiency ◦ Inflationary O&M increases ◦ Insurance, D&A, Property Taxes Key Highlights of the Filing

Transforming for Growth… Powered by People 12 PARTNERS COMMUNITIES CUSTOMERSTEAMMATES Members of CPK Leadership team volunteer at the Barnabas Center in Fernandina Beach, Florida (April 2026)

People-centered talent development and change management Project Insight unifying and improving data access and analytics Transforming for Growth Building a Platform for Significant Scale 13 CUSTOMER EXPERIENCE OPERATIONAL EXCELLENCE DIGITAL AGILITY EMPLOYEE EXPERIENCE FINANCIAL MODERNIZATION 2026 Initiatives Multi-Year ERP Project • Named for "One Company" approach to Centralize, Optimize, Reimagine & Energize • SAP S4Hana for Asset Management, Supply Chain, Human Resources & Finance • System Go-Live targeted for Q2 2027 • Expected capital investment of $75 million in 2026 Transformation Themes Modernizing interactions through automation and digital platforms Enterprise Committees for risk management & governance

$2.22 $2.47 Q1 2025 Q1 2026 +11% $182.4 $206.2 Q1 2025 Q1 2026 $51.1 $59.3 Q1 2025 Q1 2026 1 See appendix for a reconciliation of non-GAAP metrics. Adjusted Gross Margin1 Adjusted Earnings Per Share1Adjusted Net Income1 14 Consistent Growth in Q1 2026 $ millions except per share amounts +16%+13%

$2.22 $0.21 $0.17 $0.14 $0.13 $0.06 $0.04 $0.03 $(0.20) $(0.09) $(0.05) $(0.04) $(0.02) $(0.09) $(0.04) $2.47 Q1 2025 Adj. EPS Natural Gas Trans. Expansions Infra. Program Growth Usage from Colder Weather Regulatory Rate Increases Natural Gas Dist. Growth Aspire Perf. Off- System Gas Sales Gain Increased Payroll and Benefits Increased O&M Expense Increased D&A Credit, Collections, Customer Service Interest Expense Share Dilution Other Q1 2026 Adj. EPS 1 See appendix for a reconciliation of non-GAAP metrics. Adjusted Earnings Per Share1 15 Q1 2026 Key Performance Drivers

$147.7 $128.1 Q1 2026 Q1 2025 Regulated Adjusted Gross Margin1 Unregulated Adjusted Gross Margin1 + 15% 16 Strong Operational Gross Margin Growth 1See appendix for a reconciliation of non-GAAP metrics. $58.6 $54.5 Q1 2026 Q1 2025 +8% • $19.6 million increase driven by: ◦ Transmission system expansions ◦ Infrastructure program growth ◦ Rate case outcomes for MD, DE, FL Electric ◦ Distribution growth & colder weather • $10.6 million increase in Operating Income • $4.1 million increase driven by: ◦ Increased propane customer consumption ◦ Increased Aspire rates and gathering fees ◦ Higher Aspire customer consumption • $2.0 million increase in Operating Income $ millions except per share amounts

Equity Short-Term Debt1 Long-Term Debt 50% 9% 41% 50% 10% 40% 1 Short-term debt for both periods includes short-term borrowing as well as the current portion of long-term debt. 2 Total liquidity includes the $450M Revolver and $343M of Private Placement Shelf Agreements. Equity Issuances & Shares Outstanding • 107 thousand shares issued throughout Q1 2026 • 24,004,761 shares outstanding as of 5/4/2026 $ in millions Executing on Our Financing Strategy $3,218 $3,311 $1,327 $1,325 $293 $334 $1,599 $1,652 12/31/2025 3/31/202617 • 74% of total liquidity available as of 3/31/2026 ◦ Out of total capacity of $$793.3M million2 Debt & Liquidity Update • EQUITY: Expect to issue ~$60M through existing ATM and waiver programs • DEBT: Expect to issue $200 - $250M ◦ First tranche of FCG debt due in 2026; expected to be refinanced at lower rates 2026 Financing Updates Total Capitalization

$1.22 $1.32 $1.48 $1.62 $1.76 $1.92 $2.14 $2.36 $2.56 $2.74 $2.94 $1.22 $1.32 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 1 Calculated through 12/31/2025. 10-Year Dividend CAGR of 9.2% Dividend and Earnings Growth Drive Industry-Leading Annual Shareholder Return ~10.2%+ 10-Year CAGR1 Performance Track Record of Strong Earnings Growth 9.1% CAGR since 201618 Dividend Policy Drives Increased Shareholder Value Annualized Dividend Per Share 50 - 55% Earnings Reinvestment Supports robust capital program 45 - 50% Target Payout Ratio: 9.2% Dividend Growth CAGR 8% 12% 9% 9% 9% 11% 10% 8% 7% 7%Annual Growth Rate

1 See appendix for a reconciliation of non-GAAP metrics. 19 Industry-Leading Adjusted EPS Growth Building on track record of 19 consecutive years of growth and 9.1% EPS CAGR $1.15 $1.29 $1.32 $1.43 $1.82 $1.91 $1.99 $2.26 $2.47 $2.72 $2.86 $2.89 $3.47 $3.72 $4.21 $4.73 $5.04 $5.31 $5.39 $6.01 $8.00 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2028E 12% 2% 8% 27% 5% 4% 14% 9% 10% 5% 1% 20% 7% 13% 12% 7% 5% 2% 12%Annual Growth Rate 19 Years of Consecutive Earnings Growth 9.1% EPS CAGR + $7.75 2028 EPS Guidance

Transforming for Growth in 2026 & Beyond 20 Top-Quartile Growth & Total Shareholder Return Maintaining Our Financial Discipline Delivering on Our Promises Focusing on the Three Pillars of Growth Powered By All Stakeholders “As my chapter as CFO of this great organization comes to an end, CPK stands ready to build on a secure foundation, powered by the next set of leaders who will imprint their unique stamp on a transforming company that continues to reach new heights.” --Beth W. Cooper, EVP and CFO

Chesapeake Utilities Corporation Confidential 2025 Additional InformationAPPENDIX

$135 $132 $197 $157 $212 $152 $58 $159 $59 $52 $43 $111 $100 $100 $160 $100 $150 $90 $100 $35 $32 $37 $57 $62 $62 $59 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037+ $ in millions 22 Long-Term Debt Maturity Profile Amortizing Principal Payments Bullet Maturities First tranche of FCG debt due in 2026; refinancing expected to generate interest rate savings

First Quarter Results Year-to-Date Results Consolidated Reconciliation Q1 2026 Q1 2025 $ % YTD 2026 YTD 2025 $ % GAAP Operating Revenues $ 353.1 $ 298.7 $ 54.4 18% $ 353.1 $ 298.7 $ 54.4 18% Cost of Sales Nat Gas, Propane, & Electric (146.9) (116.3) (30.6) 26% (146.9) (116.3) (30.6) 26% Operating Expense1 (27.5) (22.7) (4.8) 21% (27.5) (22.7) (4.8) 21% D&A (21.5) (22.5) 1.0 (4)% (21.5) (22.5) 1.0 (4)% GAAP Gross Margin $ 157.2 $ 137.2 $ 20.0 15% $ 157.2 $ 137.2 $ 20.0 15% Add Back: Operating Expense1 27.5 22.7 4.8 21% 27.5 22.7 4.8 21% Add Back: D&A 21.5 22.5 (1.0) (4)% 21.5 22.5 (1.0) (4)% Adjusted Gross Margin $ 206.2 $ 182.4 $ 23.8 13% $ 206.2 $ 182.4 $ 23.8 13% $ in millions 23 GAAP to Non-GAAP Reconciliation: Consolidated Note: D&A refers to Depreciation and Amortization Expense. 1 Operations & maintenance expenses within the 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 US GAAP. See Chesapeake Utilities’ Annual Report on Form 10-K for the year ended December 31, 2025 for additional details.

Note: D&A refers to Depreciation and Amortization Expense. 1 Operations & maintenance expenses within the 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 US GAAP. See Chesapeake Utilities’ Annual Report on Form 10-K for the year ended December 31, 2025 for additional details. First Quarter Results Year-to-Date Results Regulated Segment Q1 2026 Q1 2025 $ % YTD 2026 YTD 2025 $ % GAAP Operating Revenues $ 249.3 $ 199.6 $ 49.7 25% $ 249.3 $ 199.6 $ 49.7 25% Cost of Sales Nat Gas, Propane, & Electric (101.6) (71.5) (30.1) 42% (101.6) (71.5) (30.1) 42% Operating Expense1 (16.7) (13.3) (3.4) 26% (16.7) (13.3) (3.4) 26% D&A (16.1) (17.6) 1.5 (9)% (16.1) (17.6) 1.5 (9)% GAAP Gross Margin $ 114.9 $ 97.2 $ 17.7 18% $ 114.9 $ 97.2 $ 17.7 18% Add Back: Operating Expense1 16.7 13.3 3.4 26% 16.7 13.3 3.4 26% Add Back: D&A 16.1 17.6 (1.5) (9)% 16.1 17.6 (1.5) (9)% Adjusted Gross Margin $ 147.7 $ 128.1 $ 19.6 15% $ 147.7 $ 128.1 $ 19.6 15% Unregulated Segment Q1 2026 Q1 2025 $ % YTD 2026 YTD 2025 $ % GAAP Operating Revenues $ 113.7 $ 106.7 $ 7.0 7% $ 113.7 $ 106.7 $ 7.0 7% Cost of Sales Nat Gas, Propane, & Electric (55.1) (52.2) (2.9) 6% (55.1) (52.2) (2.9) 6% Operating Expense1 (10.9) (9.7) (1.2) 12% (10.9) (9.7) (1.2) 12% D&A (5.4) (4.9) (0.5) 10% (5.4) (4.9) (0.5) 10% GAAP Gross Margin $ 42.3 $ 39.9 $ 2.4 6% $ 42.3 $ 39.9 $ 2.4 6% Add Back: Operating Expense1 10.9 9.7 1.2 12% 10.9 9.7 1.2 12% Add Back: D&A 5.4 4.9 0.5 10% 5.4 4.9 0.5 10% Adjusted Gross Margin $ 58.6 $ 54.5 $ 4.1 8% $ 58.6 $ 54.5 $ 4.1 8%24 GAAP to Non-GAAP Reconciliation: Segment Results $ in millions

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. First Quarter Results Year-to-Date Results Non-GAAP Reconciliation: Net Income /EPS Q1 2026 Q1 2025 $ % YTD 2026 YTD 2025 $ % GAAP Net Income $ 59.3 $ 50.9 $ 8.4 17% $ 59.3 $ 50.9 $ 8.4 17% FCG Transaction+Transition Expenses1 $ — $ 0.2 $ (0.2) (100)% $ — $ 0.2 $ (0.2) (100)% Adjusted Net Income $ 59.3 $ 51.1 $ 8.2 16% $ 59.3 $ 51.1 $ 8.2 16% Diluted Weighted Avg. Common Shares Outstanding 24,053 23,041 24,053 23,041 GAAP Diluted EPS $2.47 $2.21 $ 0.26 12% $2.47 $2.21 $ 0.25 12% FCG Transaction+Transition Expenses1 — 0.01 (0.01) (100)% — 0.01 (0.01) (100)% Adjusted Diluted EPS $2.47 $2.22 $ 0.25 11% $2.47 $2.22 $ 0.25 11% $ in millions except per-share amounts shares in thousands 25 GAAP to Non-GAAP Reconciliation: Adj. Net Income & EPS

GRAPHIC

Filename: chesapeakelogova18a.jpg · Sequence: 8

Binary file (9511 bytes)

Download chesapeakelogova18a.jpg

GRAPHIC

Filename: exhibit992-firstquarter2001.jpg · Sequence: 9

Binary file (95496 bytes)

Download exhibit992-firstquarter2001.jpg

GRAPHIC

Filename: exhibit992-firstquarter2002.jpg · Sequence: 10

Binary file (235901 bytes)

Download exhibit992-firstquarter2002.jpg

GRAPHIC

Filename: exhibit992-firstquarter2003.jpg · Sequence: 11

Binary file (103474 bytes)

Download exhibit992-firstquarter2003.jpg

GRAPHIC

Filename: exhibit992-firstquarter2004.jpg · Sequence: 12

Binary file (96723 bytes)

Download exhibit992-firstquarter2004.jpg

GRAPHIC

Filename: exhibit992-firstquarter2005.jpg · Sequence: 13

Binary file (125531 bytes)

Download exhibit992-firstquarter2005.jpg

GRAPHIC

Filename: exhibit992-firstquarter2006.jpg · Sequence: 14

Binary file (94330 bytes)

Download exhibit992-firstquarter2006.jpg

GRAPHIC

Filename: exhibit992-firstquarter2007.jpg · Sequence: 15

Binary file (110076 bytes)

Download exhibit992-firstquarter2007.jpg

GRAPHIC

Filename: exhibit992-firstquarter2008.jpg · Sequence: 16

Binary file (149206 bytes)

Download exhibit992-firstquarter2008.jpg

GRAPHIC

Filename: exhibit992-firstquarter2009.jpg · Sequence: 17

Binary file (184133 bytes)

Download exhibit992-firstquarter2009.jpg

GRAPHIC

Filename: exhibit992-firstquarter2010.jpg · Sequence: 18

Binary file (194414 bytes)

Download exhibit992-firstquarter2010.jpg

GRAPHIC

Filename: exhibit992-firstquarter2011.jpg · Sequence: 19

Binary file (121138 bytes)

Download exhibit992-firstquarter2011.jpg

GRAPHIC

Filename: exhibit992-firstquarter2012.jpg · Sequence: 20

Binary file (160628 bytes)

Download exhibit992-firstquarter2012.jpg

GRAPHIC

Filename: exhibit992-firstquarter2013.jpg · Sequence: 21

Binary file (156355 bytes)

Download exhibit992-firstquarter2013.jpg

GRAPHIC

Filename: exhibit992-firstquarter2014.jpg · Sequence: 22

Binary file (74352 bytes)

Download exhibit992-firstquarter2014.jpg

GRAPHIC

Filename: exhibit992-firstquarter2015.jpg · Sequence: 23

Binary file (72975 bytes)

Download exhibit992-firstquarter2015.jpg

GRAPHIC

Filename: exhibit992-firstquarter2016.jpg · Sequence: 24

Binary file (108158 bytes)

Download exhibit992-firstquarter2016.jpg

GRAPHIC

Filename: exhibit992-firstquarter2017.jpg · Sequence: 25

Binary file (122090 bytes)

Download exhibit992-firstquarter2017.jpg

GRAPHIC

Filename: exhibit992-firstquarter2018.jpg · Sequence: 26

Binary file (125414 bytes)

Download exhibit992-firstquarter2018.jpg

GRAPHIC

Filename: exhibit992-firstquarter2019.jpg · Sequence: 27

Binary file (114126 bytes)

Download exhibit992-firstquarter2019.jpg

GRAPHIC

Filename: exhibit992-firstquarter2020.jpg · Sequence: 28

Binary file (122220 bytes)

Download exhibit992-firstquarter2020.jpg

GRAPHIC

Filename: exhibit992-firstquarter2021.jpg · Sequence: 29

Binary file (100268 bytes)

Download exhibit992-firstquarter2021.jpg

GRAPHIC

Filename: exhibit992-firstquarter2022.jpg · Sequence: 30

Binary file (77116 bytes)

Download exhibit992-firstquarter2022.jpg

GRAPHIC

Filename: exhibit992-firstquarter2023.jpg · Sequence: 31

Binary file (90920 bytes)

Download exhibit992-firstquarter2023.jpg

GRAPHIC

Filename: exhibit992-firstquarter2024.jpg · Sequence: 32

Binary file (122235 bytes)

Download exhibit992-firstquarter2024.jpg

GRAPHIC

Filename: exhibit992-firstquarter2025.jpg · Sequence: 33

Binary file (91275 bytes)

Download exhibit992-firstquarter2025.jpg

XML — IDEA: XBRL DOCUMENT

XML

Filename: R1.htm · Sequence: 35

v3.26.1

Document And Entity Information

May 06, 2026

Cover [Abstract]

Title of 12(b) Security

Common Stock - par value per share $0.4867

Document Type

8-K

Document Period End Date

May 06, 2026

Entity Registrant Name

CHESAPEAKE UTILITIES CORPORATION

Entity Incorporation, State or Country Code

Entity File Number

001-11590

Entity Tax Identification Number

51-0064146

Entity Address, Address Line One

500 Energy Lane

Entity Address, City or Town

Dover

Entity Address, State or Province

Entity Address, Postal Zip Code

19901

City Area Code

302

Local Phone Number

734-6799

Written Communications

false

Soliciting Material

false

Pre-commencement Tender Offer

false

Pre-commencement Issuer Tender Offer

false

Entity Central Index Key

0000019745

Amendment Flag

false

Entity Emerging Growth Company

false

Trading Symbol

CPK

Security Exchange Name

NYSE

Document Information [Line Items]

Entity Central Index Key

0000019745

Amendment Flag

false

Document Period End Date

May 06, 2026

Entity Emerging Growth Company

false

Security Exchange Name

NYSE

Entity Registrant Name

CHESAPEAKE UTILITIES CORPORATION

- Definition

Boolean flag that is true when the XBRL content amends previously-filed or accepted submission.

+ References

No definition available.

+ Details

Name:

dei_AmendmentFlag

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

duration

- Definition

Area code of city

+ References

No definition available.

+ Details

Name:

dei_CityAreaCode

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Cover page.

+ References

No definition available.

+ Details

Name:

dei_CoverAbstract

Namespace Prefix:

dei_

Data Type:

xbrli:stringItemType

Balance Type:

Period Type:

duration

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References

No definition available.

+ Details

Name:

dei_DocumentInformationLineItems

Namespace Prefix:

dei_

Data Type:

xbrli:stringItemType

Balance Type:

Period Type:

duration

- Definition

For the EDGAR submission types of Form 8-K: the date of the report, the date of the earliest event reported; for the EDGAR submission types of Form N-1A: the filing date; for all other submission types: the end of the reporting or transition period. The format of the date is YYYY-MM-DD.

+ References

No definition available.

+ Details

Name:

dei_DocumentPeriodEndDate

Namespace Prefix:

dei_

Data Type:

xbrli:dateItemType

Balance Type:

Period Type:

duration

- Definition

The type of document being provided (such as 10-K, 10-Q, 485BPOS, etc). The document type is limited to the same value as the supporting SEC submission type, or the word 'Other'.

+ References

No definition available.

+ Details

Name:

dei_DocumentType

Namespace Prefix:

dei_

Data Type:

dei:submissionTypeItemType

Balance Type:

Period Type:

duration

- Definition

Address Line 1 such as Attn, Building Name, Street Name

+ References

No definition available.

+ Details

Name:

dei_EntityAddressAddressLine1

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Name of the City or Town

+ References

No definition available.

+ Details

Name:

dei_EntityAddressCityOrTown

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Code for the postal or zip code

+ References

No definition available.

+ Details

Name:

dei_EntityAddressPostalZipCode

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Name of the state or province.

+ References

No definition available.

+ Details

Name:

dei_EntityAddressStateOrProvince

Namespace Prefix:

dei_

Data Type:

dei:stateOrProvinceItemType

Balance Type:

Period Type:

duration

- Definition

A unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityCentralIndexKey

Namespace Prefix:

dei_

Data Type:

dei:centralIndexKeyItemType

Balance Type:

Period Type:

duration

- Definition

Indicate if registrant meets the emerging growth company criteria.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityEmergingGrowthCompany

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

duration

- Definition

Commission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.

+ References

No definition available.

+ Details

Name:

dei_EntityFileNumber

Namespace Prefix:

dei_

Data Type:

dei:fileNumberItemType

Balance Type:

Period Type:

duration

- Definition

Two-character EDGAR code representing the state or country of incorporation.

+ References

No definition available.

+ Details

Name:

dei_EntityIncorporationStateCountryCode

Namespace Prefix:

dei_

Data Type:

dei:edgarStateCountryItemType

Balance Type:

Period Type:

duration

- Definition

The exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityRegistrantName

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

The Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityTaxIdentificationNumber

Namespace Prefix:

dei_

Data Type:

dei:employerIdItemType

Balance Type:

Period Type:

duration

- Definition

Local phone number for entity.

+ References

No definition available.

+ Details

Name:

dei_LocalPhoneNumber

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 13e

-Subsection 4c

+ Details

Name:

dei_PreCommencementIssuerTenderOffer

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

duration

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14d

-Subsection 2b

+ Details

Name:

dei_PreCommencementTenderOffer

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

duration

- Definition

Title of a 12(b) registered security.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b

+ Details

Name:

dei_Security12bTitle

Namespace Prefix:

dei_

Data Type:

dei:securityTitleItemType

Balance Type:

Period Type:

duration

- Definition

Name of the Exchange on which a security is registered.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection d1-1

+ Details

Name:

dei_SecurityExchangeName

Namespace Prefix:

dei_

Data Type:

dei:edgarExchangeCodeItemType

Balance Type:

Period Type:

duration

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14a

-Subsection 12

+ Details

Name:

dei_SolicitingMaterial

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

duration

- Definition

Trading symbol of an instrument as listed on an exchange.

+ References

No definition available.

+ Details

Name:

dei_TradingSymbol

Namespace Prefix:

dei_

Data Type:

dei:tradingSymbolItemType

Balance Type:

Period Type:

duration

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Securities Act

-Number 230

-Section 425

+ Details

Name:

dei_WrittenCommunications

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

duration