CHESAPEAKE UTILITIES CORP 10-Q

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations Management’s Discussion and Analysis of Financial Condition and Results of Operations is designed to provide a reader of the financial statements with a narrative report on our financial condition, results of operations and liquidity. This discussion and analysis should be read in conjunction with the attached unaudited condensed consolidated financial statements and notes thereto and our Annual Report on Form 10-K for the year ended December 31, 2023, including the audited consolidated financial statements and notes thereto. Safe Harbor for Forward-Looking Statements We make statements in this Quarterly Report on Form 10-Q (this "Quarterly Report") that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995. One can typically identify forward-looking statements by the use of forward-looking 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 future financial performance, business strategy, projected plans and objectives of the Company. Forward-looking statements speak only as of the date they are made or as of the date indicated and we do not undertake any obligation to update forward-looking statements as a result of new information, future events or otherwise. These statements are subject to many risks and uncertainties. In addition to the risk factors described under Item 1A., Risk Factors in our 2023 Annual Report on Form 10-K, the following important factors, among others, could cause actual future results to differ materially from those expressed in the forward-looking statements: • state and federal legislative and regulatory initiatives that affect cost and investment recovery, have an impact on rate structures, and affect the speed and the degree to which competition enters the electric and natural gas industries; • the outcomes of regulatory, environmental and legal matters, including whether pending matters are resolved within current estimates and whether the related costs are adequately covered by insurance or recoverable in rates; • the impact of climate change, including the impact of greenhouse gas emissions or other legislation or regulations intended to address climate change; • the impact of significant changes to current tax regulations and rates; • the timing of certification authorizations associated with new capital projects and the ability to construct facilities at or below estimated costs; • changes in environmental and other laws and regulations to which we are subject and environmental conditions of property that we now, or may in the future, own or operate; • changes in the current political environment; • possible increased federal, state and local regulation of the safety of our operations; • the availability and reliability of adequate technology, including our ability to adapt to technological advances, effectively implement new technologies and manage the related costs; • the inherent hazards and risks involved in transporting and distributing natural gas, electricity and propane; • the economy in our service territories or markets, the nation, and worldwide, including the impact of economic conditions (which we do not control) on demand for natural gas, electricity, propane or other fuels; • risks related to cyber-attacks or cyber-terrorism that could disrupt our business operations or result in failure of information technology systems or result in the loss or exposure of confidential or sensitive customer, employee or Company information; • adverse weather conditions, including the effects of hurricanes, ice storms and other damaging weather events; • customers' preferred energy sources; • industrial, commercial and residential growth or contraction in our markets or service territories; • the effect of competition on our businesses from other energy suppliers and alternative forms of energy; • the timing and extent of changes in commodity prices and interest rates; • the effect of spot, forward and future market prices on our various energy businesses; • the extent of our success in connecting natural gas and electric supplies to our transmission systems, establishing and maintaining key supply sources, and expanding natural gas and electric markets; • the creditworthiness of counterparties with which we are engaged in transactions; • the capital-intensive nature of our regulated energy businesses; • our ability to access the credit and capital markets to execute our business strategy, including our ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general economic conditions; • the ability to successfully execute, manage and integrate a merger, acquisition or divestiture of assets or businesses and the related regulatory or other conditions associated with the merger, acquisition or divestiture; • the impact on our costs and funding obligations, under our pension and other postretirement benefit plans, of potential downturns in the financial markets, lower discount rates, and costs associated with health care legislation and regulation; 30 Table of Contents • the ability to continue to hire, train and retain appropriately qualified personnel; • the availability of, and competition for, qualified personnel supporting our natural gas, electricity and propane businesses; • the effect of accounting pronouncements issued periodically by accounting standard-setting bodies; and • the impacts associated with a pandemic, including the duration and scope of the pandemic the corresponding impact on our supply chains, our personnel, our contract counterparties, general economic conditions and growth, the financial markets and any costs to comply with governmental mandates. Introduction Chesapeake Utilities is a Delaware corporation formed in 1947. We are a diversified energy company engaged, through our operating divisions and subsidiaries, in regulated energy, unregulated energy and other businesses. We operate primarily on the east coast of the United States and provide natural gas distribution and transmission; electric distribution and generation; propane gas distribution; mobile compressed natural gas services; steam generation; and other energy-related services. Our strategy is focused on growing earnings from a stable regulated energy delivery foundation and investing in related businesses and services that provide opportunities for returns greater than traditional utility returns. We seek to identify and develop opportunities across the energy value chain, with emphasis on midstream and downstream investments that are accretive to earnings per share, consistent with our long-term growth strategy and create opportunities to continue our record of top tier returns on equity relative to our peer group. Our growth strategy includes the continued investment and expansion of our regulated operations that provide a stable base of earnings, as well as investments in other related non-regulated businesses and services including sustainable energy initiatives. By investing in these related business and services, we create opportunities to sustain our track record of higher returns, as compared to a traditional utility. Currently, our growth strategy is focused on the following platforms, including: • Optimizing the earnings growth in our existing businesses, which includes organic growth, territory expansions, and new products and services as well as increased opportunities to transform the Company with a focus on people, process, technology and organizational structure. • Identification and pursuit of additional pipeline expansions, including new interstate and intrastate transmission projects. • Growth of Marlin Gas Services’ CNG transport business and expansion into LNG and RNG transport services as well as methane capture. • Identifying and undertaking additional strategic propane acquisitions that provide a larger foundation in current markets and expand our brand and presence into new strategic growth markets. • Pursuit of growth opportunities that enable us to utilize our integrated set of energy delivery businesses to participate in sustainable energy opportunities. Due to the seasonality of our business, results for interim periods are not necessarily indicative of results for the entire fiscal year. Revenue and earnings are typically greater during the first and fourth quarters, when consumption of energy is normally highest due to colder temperatures. Sustainability Initiatives We continue to remain steadfast in regards to our sustainability commitments, including the following: • Maintaining a leading role in the journey to a lower carbon future in our service areas. • Continuing to promote a diverse and inclusive workplace and further the sustainability of the communities we serve. • Operating our businesses with integrity and the highest ethical standards. These commitments guide our mission to deliver energy that makes life better for the people and communities we serve. They impact every aspect of the relationships we have with our stakeholders. In April of 2024, we unveiled our first in a series of sustainability micro-reports, with the first report focused on Safety and Reliability. The Safety and Reliability Report will be followed by at least two additional micro-reports. The second report, expected to be published this summer, will focus on the Company’s environmental stewardship, including progress on environmental sustainability initiatives and mitigation of greenhouse gas emissions. The third micro-report, planned for distribution in the fall, will focus on community impact, reporting on Diversity, Equity and Inclusion ("DEI") initiatives and investments in people, communities and customers. 31 Table of Contents Transitioning from a single large sustainability report to these micro-reports will provide a steadier release of information throughout the year, including progress updates and new or expanded initiatives and programs. In addition to the micro-reports, the Company will publish investor-focused tables later this year. We encourage our investors to review the Safety and Reliability micro-report, as well as prior sustainability reports, which can be accessed on our website, and welcome feedback as we continue to enhance our sustainability disclosures. Acquisition of Florida City Gas On November 30, 2023, we completed the acquisition of FCG for $ 922.8 million in cash, which included working capital adjustments as defined in the agreement that were settled during the first quarter of 2024, pursuant to the previously disclosed stock purchase agreement with Florida Power & Light Company. Upon completion of the acquisition, FCG became a wholly-owned subsidiary of the Company and is included within our Regulated Energy segment. FCG serves approximately 120,000 residential and commercial natural gas customers across eight counties in Florida, including Miami-Dade, Broward, Brevard, Palm Beach, Hendry, Martin, St. Lucie and Indian River. Its natural gas system includes approximately 3,800 miles of distribution main and 80 miles of transmission pipe. In June 2023, FCG received approval from the Florida PSC for a $23.3 million total increase in base revenue in connection with its May 2022 rate case filing. The new rates, which became effective as of May 1, 2023, included the transfer of its SAFE program provisions from a rider clause to base rates, an increase in rates associated with a liquefied natural gas facility, and approval of FCG's proposed RSAM with a $25.0 million reserve amount. The RSAM is recorded as either an increase or decrease to accrued removal costs on the balance sheet, with a corresponding increase or decrease to depreciation and amortization expense. The impact of FCG's results from the acquisition date and effects on our liquidity are discussed further below and throughout Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations. Unless otherwise noted, EPS and Adjusted EPS information are presented on a diluted basis. Non-GAAP Financial Measures This document, 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. We calculate 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. We calculate Adjusted Net Income and Adjusted EPS by deducting non-recurring 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 financial 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's and the overall 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 financial measures of Adjusted Gross Margin, Adjusted Net Income and Adjusted EPS for the three and six months ended June 30, 2024 and 2023: 32 Table of Contents Adjusted Gross Margin For the Three Months Ended June 30, 2024 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Operating Revenues $ 130,625 $ 41,419 $ (5,772) $ 166,272 Cost of Sales: Natural gas, propane and electric costs (27,378) (18,006) 5,744 (39,640) Depreciation & amortization (14,657) (3,223) 3 (17,877) Operations & maintenance expenses (1) (12,255) (7,893) 3 (20,145) Gross Margin (GAAP) 76,335 12,297 (22) 88,610 Operations & maintenance expenses (1) 12,255 7,893 (3) 20,145 Depreciation & amortization 14,657 3,223 (3) 17,877 Adjusted Gross Margin (Non-GAAP) $ 103,247 $ 23,413 $ (28) $ 126,632 For the Three Months Ended June 30, 2023 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Operating Revenues $ 101,141 $ 40,751 $ (6,299) $ 135,593 Cost of Sales: Natural gas, propane and electric costs (23,886) (18,116) 6,209 (35,793) Depreciation & amortization (13,035) (4,269) 1 (17,303) Operations & maintenance expenses (1) (9,240) (7,520) (2) (16,762) Gross Margin (GAAP) 54,980 10,846 (91) 65,735 Operations & maintenance expenses (1) 9,240 7,520 2 16,762 Depreciation & amortization 13,035 4,269 (1) 17,303 Adjusted Gross Margin (Non-GAAP) $ 77,255 $ 22,635 $ (90) $ 99,800 For the Six Months Ended June 30, 2024 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Operating Revenues $ 299,051 $ 124,522 $ (11,557) $ 412,016 Cost of Sales: Natural gas, propane and electric costs (77,296) (55,060) 11,499 (120,857) Depreciation & amortization (27,194) (7,704) 5 (34,893) Operations & maintenance expenses (1) (24,991) (16,315) 1 (41,305) Gross Margin (GAAP) 169,570 45,443 (52) 214,961 Operations & maintenance expenses (1) 24,991 16,315 (1) 41,305 Depreciation & amortization 27,194 7,704 (5) 34,893 Adjusted Gross Margin (Non-GAAP) $ 221,755 $ 69,462 $ (58) $ 291,159 33 Table of Contents For the Six Months Ended June 30, 2023 (in thousands) Regulated Energy Unregulated Energy Other and Eliminations Total Operating Revenues $ 243,411 $ 123,916 $ (13,605) $ 353,722 Cost of Sales: Natural gas, propane and electric costs (79,174) (58,687) 13,479 (124,382) Depreciation & amortization (25,987) (8,503) 4 (34,486) Operations & maintenance expenses (1) (18,527) (15,996) 3 (34,520) Gross Margin (GAAP) 119,723 40,730 (119) 160,334 Operations & maintenance expenses (1) 18,527 15,996 (3) 34,520 Depreciation & amortization 25,987 8,503 (4) 34,486 Adjusted Gross Margin (Non-GAAP) $ 164,237 $ 65,229 $ (126) $ 229,340 (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 U.S. GAAP. 2024 to 2023 Gross Margin (GAAP) Variance – Regulated Energy Gross Margin (GAAP) for the Regulated Energy segment for the quarter ended June 30, 2024 was $76.4 million, an increase of $21.4 million, or 38.8 percent, compared to the same period in 2023. The increase in gross margin reflects incremental margin attributable to FCG, organic growth in our natural gas distribution businesses and continued pipeline expansion projects, and incremental margin from regulatory initiatives. Gross Margin (GAAP) for the Regulated Energy segment for the six months ended June 30, 2024 was $169.6 million, an increase of $49.8 million, or 41.6 percent, compared to the same period in 2023. The increase in gross margin reflects incremental margin attributable to FCG, organic growth in our natural gas distribution businesses and continued pipeline expansion projects, and incremental margin from regulatory initiatives. 2024 to 2023 Gross Margin (GAAP) Variance – Unregulated Energy Gross Margin (GAAP) for the Unregulated Energy segment for the quarter ended June 30, 2024 was $12.3 million, an increase of $1.5 million, or 13.4 percent, compared to the same period in 2023. The increase in gross margin was primarily attributable to contributions from an increased level of virtual pipeline services and improved performance at Aspire. Gross Margin (GAAP) for the Unregulated Energy segment for the six months ended June 30, 2024 was $45.4 million, an increase of $4.7 million, or 11.6 percent, compared to the same period in 2023. Higher gross margin reflects higher contributions from propane including increased customer consumption, incremental margin from the JT Lee and Son's acquisition in late 2023, and higher margins and service fees; improved performance at Aspire; and an increased level of virtual pipeline services. 34 Table of Contents Adjusted Net Income and Adjusted EPS Three Months Ended Six Months Ended June 30, June 30, (in thousands, except per share data) 2024 2023 2024 2023 Net Income (GAAP) $ 18,271 $ 16,133 $ 64,439 $ 52,477 FCG transaction and transition-related expenses, net (1) 1,006 — 1,683 — Adjusted Net Income (Non-GAAP) $ 19,277 $ 16,133 $ 66,122 $ 52,477 Weighted average common shares outstanding - diluted (2) 22,335 17,852 22,320 17,842 Earnings Per Share - Diluted (GAAP) $ 0.82 $ 0.90 $ 2.89 $ 2.94 FCG transaction and transition-related expenses, net (1) 0.04 — 0.07 — Adjusted Earnings Per Share - Diluted (Non-GAAP) $ 0.86 $ 0.90 $ 2.96 $ 2.94 (1) Transaction and transition-related expenses represent non-recurring costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transaction costs, transition services, consulting, system integration, rebranding, and legal fees. (2) Weighted average shares for the three and six months ended June 30, 2024 reflect the impact of 4.4 million common shares issued in November 2023 in connection with the acquisition of FCG. See Notes 3 and 9 for additional details on the acquisition and related equity offering. 2024 to 2023 Net Income (GAAP) Variance Net income (GAAP) for the quarter ended June 30, 2024 was $18.3 million, or $0.82 per share, compared to $16.1 million, or $0.90 per share, for the same quarter of 2023. Net income for the three months ended June 30, 2024 included $1.0 million of transaction and transition-related expenses in connection with the acquisition and integration of FCG. Excluding these costs, net income increased by $3.1 million or 19.5 percent compared to the same period in the prior year. Net income (GAAP) for the six months ended June 30, 2024 was $64.4 million, or $2.89 per share, compared to $52.5 million, or $2.94 per share, for the same period in 2023. Net income for the six months ended June 30, 2024 included $1.7 million of transaction and transition-related expenses in connection with the acquisition and integration of FCG. Excluding these costs, net income increased by $13.6 million or 26.0 percent compared to the same period in the prior year. 35 Table of Contents Results of Operations for the Three and Six Months Ended June 30, 2024 Operational Highlights Our adjusted net income for the three months ended June 30, 2024 was $19.3 million, or $0.86 per share, compared to $16.1 million, or $0.90 per share, for the same quarter of 2023. The improvements in business unit operating results discussed below were offset by the effects of increased interest expense and common shares issued in connection with the acquisition of FCG. Operating income for the second quarter of 2024 was $40.8 million, an increase of $12.4 million or 43.9 percent compared to the same period in 2023. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $13.8 million or 48.7 percent compared to the prior-year period. An increase in adjusted gross margin in the second quarter of 2024 was driven by contributions from the acquisition of FCG, natural gas organic growth and continued pipeline expansion projects, incremental margin from regulatory initiatives, and improvements from our unregulated businesses. Higher operating expenses in the second quarter of 2024 were largely associated with FCG, increased payroll, benefits and other employee-related expenses, and higher insurance and vehicle expenses compared to the prior-year period. Increases in depreciation, amortization and property taxes attributable to growth projects and FCG were partially offset by a $2.3 million RSAM adjustment from FCG and lower depreciation from our electric operations due to revised rates from an approved electric depreciation study. 36 Table of Contents Three Months Ended June 30, Increase 2024 2023 (Decrease) (in thousands, except per share data) Adjusted Gross Margin Regulated Energy segment $ 103,247 $ 77,255 $ 25,992 Unregulated Energy segment 23,413 22,635 778 Other businesses and eliminations (28) (90) 62 Total Adjusted Gross Margin $ 126,632 $ 99,800 $ 26,832 Operating Income (Loss) Regulated Energy segment $ 40,505 $ 29,291 $ 11,214 Unregulated Energy segment 238 (993) 1,231 Other businesses and eliminations 47 48 (1) Total Operating Income 40,790 28,346 12,444 Other income, net 1,110 831 279 Interest charges 16,813 6,964 9,849 Income Before Income Taxes 25,087 22,213 2,874 Income taxes 6,816 6,080 736 Net Income $ 18,271 $ 16,133 $ 2,138 Weighted Average Common Shares Outstanding: (1) Basic 22,284 17,794 4,490 Diluted 22,335 17,852 4,483 Earnings Per Share of Common Stock Basic $ 0.82 $ 0.91 $ (0.09) Diluted $ 0.82 $ 0.90 $ (0.08) Adjusted Net Income and Adjusted Earnings Per Share Net Income (GAAP) $ 18,271 $ 16,133 $ 2,138 FCG transaction and transition-related expenses, net (2) 1,006 — 1,006 Adjusted Net Income (Non-GAAP) $ 19,277 $ 16,133 $ 3,144 Earnings Per Share - Diluted (GAAP) $ 0.82 $ 0.90 $ (0.08) FCG transaction and transition-related expenses, net (2) 0.04 — 0.04 Adjusted Earnings Per Share - Diluted (Non-GAAP) $ 0.86 $ 0.90 $ (0.04) (1) Weighted average shares for the quarter ended June 30, 2024 reflect the impact of 4.4 million common shares issued in November 2023 in connection with the acquisition of FCG. (2) Transaction and transition-related expenses represent costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transaction costs, transition services, consulting, system integration, rebranding and legal fees. 37 Table of Contents Key variances between the second quarter of 2023 and 2024 included: (in thousands, except per share data) Pre-tax Income Net Income Earnings Per Share Second Quarter of 2023 Adjusted Results $ 22,213 $ 16,133 $ 0.90 Increased Adjusted Gross Margins: Contributions from acquisitions 23,527 17,135 0.77 Margin from regulated infrastructure programs* 1,340 976 0.04 Natural gas growth including conversions (excluding service expansions) 1,253 912 0.04 Increased level of virtual pipeline services 587 428 0.02 Natural gas transmission service expansions, including interim services* 563 410 0.02 Improved Aspire Energy performance - rate changes and gathering fees 251 183 — 27,521 20,044 0.89 Increased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs): FCG operating expenses (9,720) (7,079) (0.32) Payroll, benefits and other employee-related expenses (772) (562) (0.02) Insurance related costs (559) (407) (0.02) Vehicle expenses (250) (182) (0.01) Depreciation, amortization and property tax costs (includes FCG) (1,951) (1,421) (0.06) (13,252) (9,651) (0.43) Interest charges (9,849) (7,173) (0.32) Increase in shares outstanding due to 2023 and 2024 equity offerings*** — — (0.18) Net other changes (172) (76) — (10,021) (7,249) (0.50) Second Quarter of 2024 Adjusted Results** $ 26,461 $ 19,277 $ 0.86 * See the Major Projects and Initiatives table. ** 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. *** Reflects the impact of 4.4 million common shares issued in November 2023 in connection with the acquisition of FCG. Our adjusted net income for the six months ended June 30, 2024 was $66.1 million, or $2.96 per share, compared to $52.5 million, or $2.94 per share, for the same period of 2023. Adjusted net income for the first half of 2023 included a non-recurring gain of $1.3 million related to a reduction in the Pennsylvania state tax rate. The improvements in business unit operating results discussed below were largely offset by increased interest expense and common shares issued in connection with the acquisition of FCG. Operating income for the first half of 2024 was $120.4 million, an increase of $37.1 million or 44.6 percent compared to the same period in 2023. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $39.4 million or 47.3 percent compared to the prior-year period. An increase in adjusted gross margin in the first half of 2024 was driven by contributions from the acquisition of FCG, natural gas organic growth and continued pipeline expansion projects, incremental margin from regulatory initiatives, higher customer consumption, and improvements from our unregulated businesses. Higher operating expenses in the first half of 2024 were largely associated with FCG, as well as higher insurance and vehicle expenses compared to the prior-year period. These increases were partially offset by lower payroll, benefits and other employee-related expenses. Increases in depreciation and amortization expense attributable to growth projects and FCG were partially offset by a $5.7 million RSAM adjustment from FCG and lower depreciation from our electric operations due to revised rates from an approved electric depreciation study. 38 Table of Contents Six Months Ended June 30, Increase 2024 2023 (Decrease) (in thousands, except per share data) Adjusted Gross Margin Regulated Energy segment $ 221,755 $ 164,237 $ 57,518 Unregulated Energy segment 69,462 65,229 4,233 Other businesses and eliminations (58) (126) 68 Total Adjusted Gross Margin $ 291,159 $ 229,340 $ 61,819 Operating Income Regulated Energy segment $ 98,614 $ 66,916 $ 31,698 Unregulated Energy segment 21,667 16,252 5,415 Other businesses and eliminations 94 93 1 Total Operating Income 120,375 83,261 37,114 Other income, net 1,305 1,107 198 Interest charges 33,839 14,196 19,643 Income Before Income Taxes 87,841 70,172 17,669 Income taxes 23,402 17,695 5,707 Net Income $ 64,439 $ 52,477 $ 11,962 Weighted Average Common Shares Outstanding: (1) Basic 22,267 17,777 4,490 Diluted 22,320 17,842 4,478 Earnings Per Share of Common Stock Basic $ 2.89 $ 2.95 $ (0.06) Diluted $ 2.89 $ 2.94 $ (0.05) Adjusted Net Income and Adjusted Earnings Per Share Net Income (GAAP) $ 64,439 $ 52,477 $ 11,962 FCG transaction and transition-related expenses, net (2) 1,683 — 1,683 Adjusted Net Income (Non-GAAP) $ 66,122 $ 52,477 $ 13,645 Earnings Per Share - Diluted (GAAP) $ 2.89 $ 2.94 $ (0.05) FCG transaction and transition-related expenses, net (2) 0.07 — 0.07 Adjusted Earnings Per Share - Diluted (Non-GAAP) $ 2.96 $ 2.94 $ 0.02 (1) Weighted average shares for the six months ended June 30, 2024 reflect the impact of 4.4 million common shares issued in November 2023 in connection with the acquisition of FCG. (2) Transaction and transition-related expenses represent costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transaction costs, transition services, consulting, system integration, rebranding and legal fees. 39 Table of Contents Key variances between the six months ended June 30, 2023 and June 30, 2024 included: (in thousands, except per share data) Pre-tax Income Net Income Earnings Per Share Six months ended June 30, 2023 Adjusted Results $ 70,172 $ 52,477 $ 2.94 Non-recurring Items: Absence of benefit associated with a reduction in the PA state tax rate — (1,284) (0.06) — (1,284) (0.06) Increased Adjusted Gross Margins: Contributions from acquisitions 48,924 35,891 1.61 Natural gas growth including conversions (excluding service expansions) 3,169 2,325 0.10 Margin from regulated infrastructure programs* 2,618 1,921 0.09 Natural gas transmission service expansions, including interim services* 2,154 1,580 0.07 Changes in customer consumption 1,842 1,352 0.06 Rate changes associated with the Florida natural gas base rate proceeding* 1,630 1,196 0.05 Improved Aspire Energy performance - rate changes and gathering fees 1,189 872 0.04 Increased level of virtual pipeline services 487 358 0.02 Increased propane margins and fees 463 340 0.01 62,476 45,835 2.05 (Increased) Decreased Operating Expenses (Excluding Natural Gas, Propane, and Electric Costs): FCG operating expenses (20,133) (14,770) (0.66) Insurance related costs (1,084) (795) (0.04) Vehicle expenses (403) (295) (0.01) Payroll, benefits and other employee-related expenses 2,192 1,608 0.07 Depreciation, amortization and property tax costs (includes FCG) (3,449) (2,530) (0.11) (22,877) (16,782) (0.75) Interest charges (19,643) (14,410) (0.65) Increase in shares outstanding due to 2023 and 2024 equity offerings*** — — (0.59) Net other changes 8 286 0.02 (19,635) (14,124) (1.22) Six months ended June 30, 2024 Adjusted Results** $ 90,136 $ 66,122 $ 2.96 * See the Major Projects and Initiatives table. ** 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. *** Reflects the impact of 4.4 million common shares issued in November 2023 in connection with the acquisition of FCG. 40 Table of Contents Summary of Key Factors Recently Completed and Ongoing Major Projects and Initiatives We continuously pursue and develop additional projects and initiatives to serve existing and new customers, further grow our businesses and earnings, and increase shareholder value. The following table includes all major projects and initiatives that are currently underway or recently completed. Our practice is to add new projects and 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. Adjusted Gross Margin Three Months Ended Six Months ended Year Ended Estimate for June 30, June 30, December 31, Fiscal (in thousands) 2024 2023 2024 2023 2023 2024 2025 Pipeline Expansions: Southern Expansion $ 586 $ 455 $ 1,172 $ 486 $ 586 $ 2,344 $ 2,344 Beachside Pipeline Expansion 603 603 1,206 603 1,810 2,451 2,414 North Ocean City Connector — — — — — — 494 St. Cloud / Twin Lakes Expansion 146 — 292 — 264 584 2,752 Wildlight 205 67 404 93 471 1,423 2,038 Lake Wales 114 38 228 38 265 454 454 Newberry 72 — 72 — — 1,364 2,585 Boynton Beach — — — — — — 3,342 New Smyrna Beach — — — — — — 1,710 Central Florida Reinforcement — — — — — 476 1,182 Warwick — — — — — 258 1,858 Renewable Natural Gas Supply Projects — — — — — — 5,460 Total Pipeline Expansions 1,726 1,163 3,374 1,220 3,396 9,354 26,633 CNG/RNG/LNG Transportation and Infrastructure 3,505 2,905 6,940 6,426 11,181 13,500 14,500 Regulatory Initiatives: Florida GUARD program 865 — 1,454 — 353 3,231 5,602 FCG SAFE Program 689 — 1,101 — — 2,683 5,293 Capital Cost Surcharge Programs 777 703 1,608 1,423 2,829 3,979 4,374 Florida Rate Case Proceeding (1) 4,005 3,873 9,600 7,970 15,835 17,153 17,153 Maryland Rate Case (2) — — — — — TBD TBD Electric Storm Protection Plan 677 436 1,307 642 1,326 2,433 3,951 Total Regulatory Initiatives 7,013 5,012 15,070 10,035 20,343 29,479 36,373 Total $ 12,244 $ 9,080 $ 25,384 $ 17,681 $ 34,920 $ 52,333 $ 77,506 (1) Includes adjusted gross margin during 2023 comprised of both interim rates and permanent base rates which became effective in March 2023. (2) Rate case application and depreciation study filed with the Maryland PSC in January 2024. See additional information provided below. 41 Table of Contents Detailed Discussion of Major Projects and Initiatives Pipeline Expansions Southern Expansion Eastern Shore installed a new natural gas driven compressor skid unit at its existing Bridgeville, Delaware compressor station that provides 7,300 Dts of incremental firm transportation pipeline capacity. The project was placed in service in the fourth quarter of 2023. The project generated additional adjusted gross margin of $0.1 million and $0.7 million, for the three and six months ended June 30, 2024, respectively, and is expected to produce adjusted gross margin of $2.3 million in 2024 and thereafter. Beachside Pipeline Expansion In June 2021, Peninsula Pipeline and FCG entered into a Transportation Service Agreement for an incremental 10,176 Dts/d of firm service in Indian River County, Florida, to support FCG's growth along the Indian River's barrier island. As part of this agreement, Peninsula Pipeline constructed approximately 11.3 miles of pipeline from its existing pipeline in Sebastian, Florida. The project went into service in April 2023. Subsequent to the acquisition of FCG, the agreement is now an affiliate agreement. The project generated additional adjusted gross margin of $0.6 million for the six months ended June 30, 2024, and is expected to produce adjusted gross margin of approximately $2.4 million in 2024 and thereafter. North Ocean City Connector Our Delaware natural gas division and Sandpiper installed approximately 5.4 miles of pipeline across southern Sussex County, Delaware to Fenwick Island, Delaware and Worcester County, Maryland. The project reinforces our existing system in Ocean City, Maryland and enables incremental growth along the pipeline. Construction of this project was completed in the second quarter of 2023. The Company filed a natural gas rate case application with the PSC for the state of Maryland in January 2024 as discussed below. Adjusted gross margin in connection with this project is contingent upon the completion of the rate case and inclusion of the project in rate base. As a result, we expect this expansion to generate annual adjusted gross margin of approximately $0.5 million beginning in 2025, with additional margin opportunities from incremental growth. St. Cloud / Twin Lakes Expansion In July 2022, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 2,400 Dts/d of firm service in the St. Cloud, Florida area. As part of this agreement, Peninsula Pipeline constructed a pipeline extension and regulator station for FPU. The extension supports new incremental load due to growth in the area, including providing service, most immediately, to the residential development, Twin Lakes. The expansion also improves reliability and provides operational benefits to FPU’s existing distribution system in the area, supporting future growth. This project was placed into service during July 2023 and generated additional adjusted gross margin of $0.2 million and $0.3 million for the three and six months ended June 30, 2024, respectively. We expect this extension to generate annual adjusted gross margin of $0.6 million in 2024 and thereafter. In February 2024, Peninsula Pipeline filed a petition with the Florida PSC for approval of an amendment to its Transportation Service Agreement with FPU for an additional 10,000 Dts/d of firm service in the St. Cloud, Florida area. Peninsula Pipeline will construct pipeline expansions that will allow FPU to serve the future communities that are expected in that area. The Florida PSC approved the project in May 2024, and it is expected to be complete in the fourth quarter of 2025. We expect this expansion to generate approximately $2.2 million of adjusted gross margin in 2025. Wildlight Expansion In August 2022, Peninsula Pipeline and FPU filed a joint petition with the Florida PSC for approval of its Transportation Service Agreement associated with the Wildlight planned community located in Nassau County, Florida. The project enables us to meet the significant growing demand for service in Yulee, Florida. The agreement enables us to build the project during the construction and build-out of the community, and charge the reservation rate as each phase of the project goes into service. Construction of the pipeline facilities will occur in two separate phases. Phase one consists of three extensions with associated facilities, and a gas injection interconnect with associated facilities. Phase two will consist of two additional pipeline extensions. Various phases of the project commenced in the first quarter of 2023, with construction on the overall project continuing through 2025. The project generated additional adjusted gross margin of $0.1 million and $0.3 million for the three and six months ended June 30, 2024, respectively, and is expected to contribute adjusted gross margin of approximately $1.4 million in 2024 and $2.0 million thereafter. Lake Wales Expansion 42 Table of Contents In February 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 9,000 Dts/d of firm service in the Lake Wales, Florida area. The PSC approved the petition in April 2023 and Peninsula Pipeline completed the acquisition of an existing pipeline in May 2023 that is being utilized to serve both current and new natural gas customers. The project generated additional adjusted gross margin of $0.1 million and $0.2 million for the three and six months ended June 30, 2024, respectively, and is expected to contribute adjusted gross margin of approximately $0.5 million in 2024 and beyond. Newberry Expansion In April 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with FPU for an additional 8,000 Dts/d of firm service in the Newberry, Florida area. The petition was approved by the Florida PSC in the third quarter of 2023. Peninsula Pipeline will construct a pipeline extension, which will be used by FPU to support the development of a natural gas distribution system to provide gas service to the City of Newberry. A filing to address the acquisition and conversion of existing Company owned propane community gas systems in Newberry was made in November 2023. The Florida PSC approved it in April 2024. The Company began the conversions of the community gas systems in the second quarter of 2024. The project generated additional adjusted gross margin of $0.1 million for the three and six months ended June 30, 2024, and is expected to contribute adjusted gross margin of approximately $1.4 million in 2024 and $2.6 million thereafter. Worcester Resiliency Upgrade In August 2023, Eastern Shore filed an application with the FERC requesting authorization to construct the Worcester Resiliency Upgrade, which consists of a mixture of storage and transmission facilities in Sussex County, DE 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. Eastern Shore has requested certificate authorization by December 2024, with a target in-service date by the third quarter of 2025. In December 2023, the FERC issued its schedule for preparation of the Environmental Assessment. In April 2024, the FERC issued their environmental assessment with no significant impacts noted. East Coast Reinforcement Projects In December 2023, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreements with FPU for projects that will support additional supply to communities 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/d and 3,400 Dts/d, respectively. The Florida PSC approved the projects in March 2024. Construction is projected to be complete in the first and second quarters of 2025 for Boynton Beach and New Smyrna Beach, respectively. The projects are expected to contribute adjusted gross margin of approximately $5.1 million in 2025 and $6.3 million in 2026 and beyond. Central Florida Reinforcement Projects In February 2024, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreements with FPU for projects that will support additional supply to communities located in Central Florida. 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/d and 8,700 Dts/d, respectively. The Florida PSC approved the projects in May 2024. Completion of the projects is projected for the fourth quarter of 2024 for Plant City and the fourth quarter of 2025 for Lake Mattie. The projects are expected to contribute adjusted gross margin of approximately $0.5 million in 2024 and $1.2 million in 2025 and beyond. Warwick Pipeline Project In July 2024, we announced plans to extend Eastern Shore's transmission deliverability by constructing an additional 4.4 miles of six inch steel pipeline. The project will reinforce the supply and growth for our Delaware division distribution system and expand further into Maryland for anticipated future growth. The project is estimated to be in service during the fourth quarter of 2024. The project is expected to contribute adjusted gross margin of approximately $0.3 million in 2024 and $1.9 million in 2025 and beyond. Pioneer Supply Header Pipeline Project In March 2024, Peninsula Pipeline filed a petition with the Florida PSC for its approval of Firm Transportation Service Agreements with both FCG and FPU for a project that will support greater supply growth of natural gas service in southeast Florida. The project consists of the transfer of a pipeline asset from FCG to Peninsula Pipeline. Peninsula Pipeline will proceed 43 Table of Contents to provide transportation service to both FCG and FPU using the pipeline asset, which supports continued customer growth and system reinforcement of these distribution systems. The Florida PSC approved the petition in July 2024. Renewable Natural Gas Supply Projects In February 2024, Peninsula Pipeline filed a petition with the Florida PSC for its approval of its 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 it's July 2024 meeting with the projects estimated to be completed in the first half of 2025. These three renewable projects cumulatively are projected to generate adjusted gross margin of approximately $5.5 million in 2025. CNG/RNG/LNG Transportation and Infrastructure We have made a commitment to meet customer demand for CNG, RNG and LNG in the markets we serve. This has included making investments within Marlin Gas Services to be able to transport these products through its virtual pipeline fleet to customers. To date, we have also made an infrastructure investment in Ohio, enabling RNG to fuel a third party landfill fleet and to transport RNG to end use customers off our pipeline system. We are also involved in various other projects, all at various stages and all with different opportunities to participate across the energy value chain. In many of these projects, Marlin will play a key role in ensuring the RNG is transported to one of our many pipeline systems where it will be injected. We include our RNG transportation services and infrastructure related adjusted gross margin from across the organization in combination with our CNG and LNG projects. We estimate annual adjusted gross margin, including amounts attributable to the Full Circle Dairy and Noble Road projects described below, of approximately $13.5 million in 2024 and $14.5 million in 2025 for these transportation related services, with potential for additional growth in future years. Full Circle Dairy In February 2023, we announced plans to construct, own and operate a dairy manure RNG facility at Full Circle Dairy in Madison County, Florida. The project consists of a facility converting dairy manure to RNG and transportation assets to bring the gas to market. The first injection of RNG is projected to occur in the second half of 2024. Noble Road Landfill RNG Project In October 2021, Aspire Energy completed construction of its Noble Road Landfill RNG pipeline project, a 33.1-mile pipeline, which transports RNG generated from the Noble Road landfill to Aspire Energy’s pipeline system, displacing conventionally produced natural gas. In conjunction with this expansion, Aspire Energy also upgraded an existing compressor station and 44 Table of Contents installed two new metering and regulation sites. The RNG volume represents more than 10 percent of Aspire Energy’s gas gathering volumes. Regulatory Initiatives Florida GUARD Program In February 2023, FPU filed a petition with the Florida PSC for approval of the GUARD program. GUARD is a ten-year program to enhance the safety, reliability, and accessibility of portions of our natural gas distribution system. We identified various categories of projects to be included in GUARD, which include the relocation of mains and service lines located in rear easements and other difficult to access areas to the front of the street, the replacement of problematic distribution mains, service lines, and maintenance and repair equipment and system reliability projects. In August 2023, the Florida PSC approved the GUARD program, which included $205.0 million of capital expenditures projected to be spent over a 10-year period. For t he three and six months ended June 30, 2024 , there was $0.9 million and $1.5 million, respectively, of incremental adjusted gross margin generated pursuant to the program. The program is expected to generate $3.2 million of adjusted gross margin in 2024 and $5.6 million in 2025. FCG SAFE Program In June 2023, the Florida PSC issued the approval order for the continuation of the SAFE program beyond its 2025 expiration date and inclusion of 150 miles of additional mains and services located in rear property easements. The SAFE program is designed to relocate certain mains and facilities associated with rear lot easements to street front locations to improve FCG's ability to inspect and maintain the facilities and reduce opportunities for damage and theft. In the same order, the Commission approved a replacement of 160 miles of pipe that was used in the 1970s and 1980s and shown through industry research to exhibit premature failure in the form of cracking. The program includes projected capital expenditures of $205.0 million over a 10-year period. For t he three and six months ended June 30, 2024 , there was $0.7 million and $1.1 million, respectively, of incremental adjusted gross margin generated pursuant to the program. The program is expected to generate $2.7 million of adjusted gross margin in 2024 and $5.3 million in 2025. In April 2024, FCG filed a petition with the Florida PSC to more closely align the SAFE Program with FPU's GUARD program. Specifically, the requested modifications will enable FCG to accelerate remediation related to problematic pipe and facilities consisting of obsolete and exposed pipe. If approved, these efforts will serve to improve the safety and reliability of service to FCG's customers. These modifications, if approved, will result in an estimated additional $50.0 million in capital expenditures associated with the SAFE Program which would increase the total projected capital expenditures to $255.0 million over a 10-year period. The Commission decision is expected in September 2024. Capital Cost Surcharge Programs In December 2019, the FERC approved Eastern Shore’s capital cost surcharge to become effective January 1, 2020. The surcharge, an approved item in the settlement of Eastern Shore’s last general rate case, allows Eastern Shore to recover capital costs associated with mandated highway or railroad relocation projects that required the replacement of existing Eastern Shore facilities. For t he three and six months ended June 30, 2024 , there was $0.1 million and $0.2 million , respectively, of incremental adjusted gross margin generated pursuant to the program. Eastern Shore expects to produce adjusted gross margin of approximately $4.0 million in 2024 and $4.4 million in 2025 from relocation projects, which is ultimately dependent upon the timing of filings and the completion of construction. Florida Natural Gas Base Rate Proceeding In May 2022, our legacy natural gas distribution businesses in Florida filed a consolidated natural gas rate case with the Florida PSC. The application included a request for the following: (i) permanent rate relief of approximately $24.1 million, effective January 1, 2023, (ii) a depreciation study also submitted with the filing; (iii) authorization to make certain changes to tariffs to include the consolidation of rates and rate structure across the businesses and to unify the Florida Natural Gas distribution business under FPU; (iv) authorization to retain the acquisition adjustment recorded at the time of the FPU merger in our revenue requirement; and (v) authorization to establish an environmental remediation surcharge for the purposes of addressing future expected remediation costs for FPU MGP sites. In August 2022, interim rates were approved by the Florida PSC in the amount of approximately $7.7 million on an annualized basis, effective for all meter readings in September 2022. The discovery process and related hearings were concluded during the fourth quarter of 2022 and briefs were submitted in the same quarter of 2022. In January 2023, the Florida PSC approved the application for consolidation and permanent rate relief of approximately $17.2 million on an annual basis. Actual rates in connection with the rate relief were approved by the Florida PSC in February 2023 with an effective date of March 1, 2023. The proceeding is expected to generate $17.2 million of total adjusted gross margin in 2024 and thereafter. 45 Table of Contents Maryland Natural Gas Rate Case In January 2024, our natural gas distribution businesses in Maryland, CUC-Maryland Division, Sandpiper Energy, Inc., and Elkton Gas Company (collectively, “Maryland natural gas distribution businesses”) filed a joint application for a natural gas rate case with the Maryland PSC. In connection with the application, we are seeking approval of the following: (i) permanent rate relief of approximately $6.9 million; (ii) authorization to make certain changes to tariffs to include a unified rate structure and to consolidate the Maryland natural gas distribution businesses which we anticipate will be called Chesapeake Utilities of Maryland, Inc.; and (iii) authorization to establish a rider for recovery of the costs associated with our new technology systems. The outcome of the application is subject to review and approval by the Maryland PSC. Rate changes are suspended until December 2024. Maryland Natural Gas Depreciation Study In January 2024, our Maryland natural gas distribution businesses filed a joint petition for approval of their proposed unified depreciation rates with the Maryland PSC. A settlement agreement between the Company, PSC staff and the OPC was reached and the final order approving the settlement agreement went into effect in July 2024 which will include an annual benefit of $1.2 million. Storm Protection Plan In 2020, the Florida PSC implemented the Storm Protection Plan ("SPP") and Storm Protection Plan Cost Recovery Clause ("SPPCRC"), which require electric utilities to petition the Florida PSC for approval of a Transmission and Distribution Storm Protection Plan that covers the utility’s immediate 10-year planning period with updates to the plan at least every 3 years. The SPPCRC rules allow the utility to file for recovery of associated costs related to its SPP. Our Florida electric distribution operation's SPP and SPPCRC were filed d uring the first quarter of 2022 and approved in the fourth quarter of 2022, with modifications, by the Florida PSC. For the three and six months ended June 30, 2024, this initiative generated additional adjusted gross margin of $0.3 million and $0.7 million, respectively, and is expected to generate $2.4 million of adjusted gross margin in 2024 and $4.0 million in 2025. We expect continued investment under the SPP going forward. Delaware Natural Gas Rate Case In May 2024, our Delaware natural gas division provided notice to the Delaware PSC of its intent to file a petition seeking a general rate base increase based on a test period ending in December 2024. The filing is expected to be submitted to the Delaware PSC in August 2024 and the outcome of the application will be subject to review and approval by the Delaware PSC. FPU Electric Rate Case In June 2024, our Florida Electric division provided notice to the Florida PSC of its intent to file a petition seeking a general rate base increase based on a 2025 projected test year. The filing is expected to be submitted to the Florida PSC in August 2024 and the outcome of the application will be subject to review and approval by the Florida PSC. Other Major Factors Influencing Adjusted Gross Margin Weather Impact Weather was not a significant factor to adjusted gross margin in the second quarter of 2024 compared to the same period in 2023. For the six months ended June 30, 2024, higher consumption which includes the effects of colder weather conditions compared to the prior-year period resulted in a $1.8 million increase in adjusted gross margin. While temperatures through June 30, 2024 were colder than the prior-year period, they were approximately 12.5 percent and 12.8 percent warmer, respectively, compared to normal temperatures in our Delmarva and Ohio service territories. 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, 2024 and 2023. 46 Table of Contents Three Months Ended Six Months Ended June 30, June 30, 2024 2023 Variance 2024 2023 Variance Delmarva Peninsula Actual HDD 319 276 43 2,281 2,050 231 10-Year Average HDD ("Normal") 387 408 (21) 2,608 2,693 (85) Variance from Normal (68) (132) (327) (643) Florida Actual HDD 41 26 15 511 370 141 10-Year Average HDD ("Normal") 41 44 (3) 511 549 (38) Variance from Normal — (18) — (179) Ohio Actual HDD 478 678 (200) 3,137 3,062 75 10-Year Average HDD ("Normal") 631 631 — 3,596 3,596 — Variance from Normal (153) 47 (459) (534) Florida Actual CDD 1,115 937 178 1,296 1,260 36 10-Year Average CDD ("Normal") 978 952 26 1,195 1,144 51 Variance from Normal 137 (15) 101 116 Natural Gas Distribution Growth The average number of residential customers served on the Delmarva Peninsula increased by approximately 3.7 percent and 3.9 percent, respectively, for the three and six months ended June 30, 2024 while our legacy Florida Natural Gas distribution business increased by approximately 3.7 percent and 3.6 percent, respectively, for the three and six month periods. The details of the adjusted gross margin increase are provided in the following table: Three Months Ended Six Months Ended June 30, 2024 June 30, 2024 (in thousands) Delmarva Peninsula Florida Delmarva Peninsula Florida Customer Growth: Residential $ 352 $ 647 $ 842 $ 1,527 Commercial and industrial 124 130 280 520 Total Customer Growth (1) $ 476 $ 777 $ 1,122 $ 2,047 (1) Customer growth amounts for our legacy Florida operations include the effects of revised rates associated with the Company's natural gas base rate proceeding, but exclude the effects of FCG. Regulated Energy Segment For the quarter ended June 30, 2024 compared to the quarter ended June 30, 2023: 47 Table of Contents Three Months Ended June 30, 2024 2023 Increase (in thousands) Revenue $ 130,625 $ 101,141 $ 29,484 Regulated natural gas and electric costs 27,378 23,886 3,492 Adjusted gross margin (1) 103,247 77,255 25,992 Operations & maintenance 39,314 29,362 9,952 Depreciation & amortization 14,657 13,035 1,622 FCG transaction and transition-related expenses (2) 1,374 — 1,374 Other taxes 7,397 5,567 1,830 Total operating expenses 62,742 47,964 14,778 Operating income $ 40,505 $ 29,291 $ 11,214 (1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above. (2) Transaction and transition-related expenses represent costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transaction costs, transition services, consulting, system integration, rebranding and legal fees. Operating income for the Regulated Energy segment for the second quarter of 2024 was $40.5 million, an increase of $11.2 million, or 38.3 percent, over the same period in 2023. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $12.6 million or 43.0 percent compared to the same period in 2023. Higher operating income reflects incremental contributions from the acquisition of FCG, organic growth in our natural gas distribution businesses and continued pipeline expansion projects, and incremental margin from regulatory initiatives. Excluding the transaction and transition-related expenses described above, the increase in total operating expenses of $13.4 million was largely attributable to FCG's operating expenses, higher depreciation and amortization expense, and increased payroll, benefits and other employee-related expenses. Increases in depreciation and amortization expense attributable to growth projects and FCG were partially offset by reductions related to revised rates from an approved electric depreciation study and a $2.3 million RSAM adjustment from FCG. 48 Table of Contents Items contributing to the quarter-over-quarter increase in adjusted gross margin are listed in the following table: (in thousands) Contribution from FCG $ 23,367 Margin from regulated infrastructure programs 1,340 Natural gas growth including conversions (excluding service expansions) 1,253 Natural gas transmission service expansions, including interim services 563 Other variances (531) Quarter-over-quarter increase in adjusted gross margin $ 25,992 (1) Includes adjusted gross margin contributions from permanent base rates that became effective in March 2023. The following narrative discussion provides further detail and analysis of the significant items in the foregoing table. Contribution from Acquisition of FCG FCG contributed adjusted gross margin of $23.4 million for the three months ended June 30, 2024. Margin from Regulated Infrastructure Programs Regulated infrastructure programs generated incremental adjusted gross margin of $1.3 million in the second quarter of 2024. The increase in adjusted gross margin was primarily related to Florida's GUARD program and FPU Electric's storm protection plan. Refer to Note 5, Rates and Other Regulatory Activities , in the condensed consolidated financial statements for additional information. Natural Gas Distribution Customer Growth We generated additional adjusted gross margin of $1.3 million from natural gas customer growth. Adjusted gross margin increased by $0.8 million for our Florida Natural Gas distribution business and $0.5 million on the Delmarva Peninsula for the three months ended June 30, 2024, as compared to the same period in 2023, due primarily to residential customer growth of 3.7 percent both in Florida and on the Delmarva Peninsula. Natural Gas Transmission Service Expansions, including interim services We generated increased adjusted gross margin of $0.6 million for the three months ended June 30, 2024 from natural gas transmission service expansions of Peninsula Pipeline and Eastern Shore. Operating Expenses Items contributing to the quarter-over-quarter increase in operating expenses are listed in the following table: (in thousands) FCG operating expenses $ 9,720 Depreciation, amortization and property tax costs 2,884 FCG transaction and transition-related expenses (1) 1,374 Payroll, benefits and other employee-related expenses 679 Other variances 121 Quarter-over-quarter increase in operating expenses $ 14,778 (1) Transaction and transition-related expenses represent costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transaction costs, transition services, consulting, system integration, rebranding and legal fees. 49 Table of Contents For the six months ended June 30, 2024 compared to the six months ended June 30, 2023: Six Months Ended June 30, Increase 2024 2023 (Decrease) (in thousands) Revenue $ 299,051 $ 243,411 $ 55,640 Regulated natural gas and electric costs 77,296 79,174 (1,878) Adjusted gross margin (1) 221,755 164,237 57,518 Operations & maintenance 78,273 59,698 18,575 Depreciation & amortization 27,194 25,987 1,207 FCG transaction and transition-related expenses (2) 2,295 — 2,295 Other taxes 15,379 11,636 3,743 Total operating expenses 123,141 97,321 25,820 Operating income $ 98,614 $ 66,916 $ 31,698 (1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above. (2) Transaction and transition-related expenses represent costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transaction costs, transition services, consulting, system integration, rebranding and legal fees. Operating income for the Regulated Energy segment for the six months ended June 30, 2024 was $98.6 million, an increase of $31.7 million, or 47.4 percent, over the same period in 2023. Excluding transaction and transition-related expenses associated with the acquisition and integration of FCG, operating income increased $34.0 million or 50.8 percent compared to the same period in 2023. Higher operating income reflects incremental contributions from the acquisition of FCG, organic growth in our natural gas distribution businesses and continued pipeline expansion projects, and incremental margin from regulatory initiatives. Excluding the transaction and transition-related expenses described above, the increase in total operating expenses of $23.5 million was largely attributable to FCG's operating expenses, higher depreciation and amortization expense, and higher property taxes, partially offset by lower payroll, benefits and other employee-related expenses compared to the prior-year period. Increases in depreciation and amortization expense attributable to growth projects and FCG were partially offset by reductions related to revised rates from an approved electric depreciation study and a $5.7 million RSAM adjustment from FCG. Items contributing to the period-over-period increase in adjusted gross margin are listed in the following table: (in thousands) Contribution from FCG $ 48,326 Natural gas growth including conversions (excluding service expansions) 3,169 Margin from regulated infrastructure programs 2,618 Natural gas transmission service expansions, including interim services 2,154 Rate changes associated with the Florida natural gas base rate proceeding (1) 1,630 Other variances (379) Period-over-period increase in adjusted gross margin $ 57,518 (1) Includes adjusted gross margin contributions from permanent base rates that became effective in March 2023. The following narrative discussion provides further detail and analysis of the significant items in the foregoing table. Contribution from Acquisition of FCG FCG contributed adjusted gross margin of $48.3 million for the six months ended June 30, 2024. Natural Gas Distribution Customer Growth We generated additional adjusted gross margin of $3.2 million from natural gas customer growth. Adjusted gross margin increased by $2.1 million for our Florida Natural Gas distribution business and $1.1 million on the Delmarva Peninsula for the six months ended June 30, 2024, as compared to the same period in 2023, due primarily to residential customer growth of 3.6 percent and 3.9 percent in Florida and on the Delmarva Peninsula, respectively. 50 Table of Contents Margin from Regulated Infrastructure Programs Regulated infrastructure programs generated incremental adjusted gross margin of $2.6 million for the six months ended June 30, 2024. The increase in adjusted gross margin was primarily related to Florida's GUARD program and FPU Electric's storm protection plan. Refer to Note 5, Rates and Other Regulatory Activities , in the condensed consolidated financial statements for additional information. Natural Gas Transmission Service Expansions, including interim services We generated increased adjusted gross margin of $2.2 million for the six months ended June 30, 2024 from natural gas transmission service expansions of Peninsula Pipeline and Eastern Shore. Rate Changes Associated with the Florida Natural Gas Base Rate Proceeding Permanent rates associated with the Florida Natural Gas base rate proceeding, effective on March 1, 2023, contributed additional adjusted gross margin of $1.6 million for the six months ended June 30, 2024. Refer to Note 5, Rates and Other Regulatory Activities , in the condensed consolidated financial statements for additional information. Operating Expenses Items contributing to the period-over-period increase in operating expenses are listed in the following table: (in thousands) FCG operating expenses $ 20,133 Depreciation, amortization and property taxes 4,048 FCG transaction and transition-related expenses (1) 2,295 Insurance related costs 429 Payroll, benefits and other employee-related expenses (1,109) Other variances 24 Period-over-period increase in operating expenses $ 25,820 (1) Transaction and transition-related expenses represent costs incurred attributable to the acquisition and integration of FCG including, but not limited to, transaction costs, transition services, consulting, system integration, rebranding and legal fees. 51 Table of Contents Unregulated Energy Segment For the quarter ended June 30, 2024 compared to the quarter ended June 30, 2023: Three Months Ended June 30, Increase 2024 2023 (Decrease) (in thousands) Revenue $ 41,419 $ 40,751 $ 668 Unregulated propane and natural gas costs 18,006 18,116 (110) Adjusted gross margin (1) 23,413 22,635 778 Operations & maintenance 18,661 18,196 465 Depreciation & amortization 3,223 4,269 (1,046) Other taxes 1,291 1,163 128 Total operating expenses 23,175 23,628 (453) Operating income (loss) $ 238 $ (993) $ 1,231 (1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above. Operating income for the Unregulated Energy segment for the second quarter of 2024 reflects a $1.2 million improvement compared to the same period in 2023. Adjusted gross margin in the Unregulated Energy segment increased during the second quarter of 2024 primarily due to increased levels of virtual pipeline services, as well as increased rates and gathering fees at Aspire. Items contributing to the quarter-over-quarter increase in adjusted gross margin are listed in the following table: (in thousands) Propane Operations Contributions from acquisition $ 160 Increased propane customer consumption 117 CNG/RNG/LNG Transportation and Infrastructure Increased level of virtual pipeline services 587 Aspire Energy Increased margins - rate changes and gathering fees 251 Other variances (337) Quarter-over-quarter increase in adjusted gross margin $ 778 The following narrative discussion provides further detail and analysis of the significant items in the foregoing table. Propane Operations • Contributions from acquisition - Adjusted gross margin increased by $0.2 million from the acquisition of J.T. Lee and Son's that was completed in December 2023. • Propane customer consumption - Adjusted gross margin increased by $0.1 million due to increased customer consumption. CNG/RNG/LNG Transportation and Infrastructure • Increased level of virtual pipeline services - Adjusted gross margin increased by $0.6 million during the second quarter of 2024 as compared to the same period in the prior year due to higher levels of CNG hold services. Aspire Energy • Increased margins - Adjusted gross margin increased by $0.3 million primarily due to favorable rate changes and increased gathering charges associated with a large commercial customer. Operating Expenses 52 Table of Contents Items contributing to the quarter-over-quarter decrease in operating expenses are listed in the following table: (in thousands) Decreased depreciation, amortization and property tax costs $ (935) Increased insurance related costs 283 Increased vehicle expenses 246 Other variances (47) Quarter-over-quarter decrease in operating expenses $ (453) For the six months ended June 30, 2024 compared to the six months ended June 30, 2023: Six Months Ended June 30, Increase 2024 2023 (Decrease) (in thousands) Revenue $ 124,522 $ 123,916 $ 606 Unregulated propane and natural gas costs 55,060 58,687 (3,627) Adjusted gross margin (1) 69,462 65,229 4,233 Operations & maintenance 37,239 37,810 (571) Depreciation & amortization 7,704 8,503 (799) Other taxes 2,852 2,664 188 Total operating expenses 47,795 48,977 (1,182) Operating income $ 21,667 $ 16,252 $ 5,415 (1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above. Operating results for the Unregulated Energy segment for the six months ended June 30, 2024 reflect a $5.4 million improvement compared to the same period in 2023. Adjusted gross margin in the Unregulated Energy segment increased during the first half of 2024 primarily due to improved contributions from propane, higher rates and gathering fees at Aspire, and increased levels of virtual pipeline services. Additionally, decreased operating expenses associated with lower employee costs were partially offset by higher insurance and vehicle costs compared to the prior-year period. Items contributing to the period-over-period increase in adjusted gross margin are listed in the following table: (in thousands) Propane Operations Increased propane customer consumption $ 1,505 Contributions from acquisition 598 Increased propane margins and service fees 463 CNG/RNG/LNG Transportation and Infrastructure Increased level of virtual pipeline services 487 Aspire Energy Increased margins - rate changes and gathering fees 1,189 Other variances (9) Period-over-period increase in adjusted gross margin $ 4,233 The following narrative discussion provides further detail and analysis of the significant items in the foregoing table. Propane Operations • Propane customer consumption - Adjusted gross margin increased by $1.5 million due to increased customer consumption including the impact of colder weather during the first half of the year compared 2023. 53 Table of Contents • Contributions from acquisition - Adjusted gross margin increased by $0.6 million from the acquisition of J.T. Lee and Son's that was completed in December 2023. • Increased propane margins and service fees - Adjusted g ross margin increased by $0.5 million for the six months ended June 30, 2024, mainly due to increased margins and customer service fees. These market conditions, which include market pricing and competition with other propane suppliers, as well as the availability and price of alternative energy sources, may fluctuate based on changes in demand, supply and other energy commodity prices. CNG/RNG/LNG Transportation and Infrastructure • Increased level of virtual pipeline services - Adjusted gross margin increased by $0.5 million during the first six months of 2024 as compared to the same period in the prior year due to increased levels of CNG hold services. Aspire Energy • Increased margins - Adjusted gross margin increased by $1.2 million primarily due to favorable rate changes and increased gathering charges associated with a large commercial customer. Operating Expenses Items contributing to the period-over-period decrease in operating expenses are listed in the following table: (in thousands) Decreased payroll, benefits and other employee-related expenses $ (1,083) Increased insurance related costs 655 Decreased depreciation, amortization and property tax costs (600) Increased vehicle expenses 386 Other variances (540) Period-over-period decrease in operating expenses $ (1,182) O THER I NCOME , N ET For the quarter ended June 30, 2024 compared to the quarter ended June 30, 2023 Other income, net, which includes non-operating investment income, interest income, late fees charged to customers, gains or losses from the sale of assets and pension and other benefits expense, was $1.1 million in the second quarter of 2024 compared to $0.8 million during the prior-year period. For the six months ended June 30, 2024 compared to the six months ended June 30, 2023 Other income, net, was $1.3 million for the six months ended June 30, 2024 compared to $1.1 million during the prior-year period. I NTEREST C HARGES For the quarter ended June 30, 2024 compared to the quarter ended June 30, 2023 Interest charges for the three months ended June 30, 2024 increased by $9.8 million compared to the same period in 2023, attributable primarily to the Senior Notes issued in November 2023 in connection with the FCG acquisition. Higher interest expense on Revolver borrowings driven by higher average outstanding borrowings and interest rates compared to the prior year also contributed to the increase. The weighted-average interest rate on our Revolver borrowings was 5.9 percent for the three months ended June 30, 2024 compared to 5.3 percent during the prior-year period as a result of the Federal Reserve raising interest rates throughout 2023. These factors were partially offset by higher capitalized interest during the current period of $0.7 million associated with capital projects. For the six months ended June 30, 2024 compared to the six months ended June 30, 2023 Interest charges for the six months ended June 30, 2024 increased by $19.6 million compared to the same period in 2023, attributable primarily to the Senior Notes issued in November 2023 in connection with the FCG acquisition. Higher interest expense on Revolver borrowings of driven by higher average outstanding borrowings and interest rates compared to the prior year also contributed to the increase. The weighted-average interest rate on our Revolver borrowings was 5.9 percent for the six months ended June 30, 2024 compared to 5.2 percent during the prior-year period as a result of the Federal Reserve raising interest rates throughout 2023. These factors were partially offset by higher capitalized interest during the current period of $1.2 million associated with capital projects. 54 Table of Contents I NCOME T AXES For the quarter ended June 30, 2024 compared to the quarter ended June 30, 2023 Income tax expense was $6.8 million and $6.1 million for the quarters ended June 30, 2024 and June 30, 2023, respectively, resulting in an effective income tax rate of 27.2 percent and 27.4 percent, respectively, during the periods then ended. For the six months ended June 30, 2024 compared to the six months ended June 30, 2023 Income tax expense was $23.4 million and $17.7 million for the six months ended June 30, 2024 and 2023, respectively, resulting in an effective income tax rate of 26.6 percent and 25.2 percent, respectively, during the periods then ended. Income tax expense for the six months ended June 30, 2023 included a $1.3 million benefit in deferred tax expense resulting from a reduction in the Pennsylvania state income tax rate. Excluding this change, our effective income tax rate was 27.0 percent for the six months ended June 30, 2023. 55 Table of Contents F INANCIAL P OSITION , L IQUIDITY AND C APITAL R ESOURCES Our capital requirements reflect the capital-intensive and seasonal nature of our business and are principally attributable to investment in new plant and equipment, retirement of outstanding debt and seasonal variability in working capital. We rely on cash generated from operations, short-term borrowings, and other sources to meet normal working capital requirements and to temporarily finance capital expenditures. We may also issue long-term debt and equity to fund capital expenditures and to maintain our capital structure within our target capital structure range. We maintain an effective shelf registration statement with the SEC for the issuance of shares of common stock in various types of equity offerings, including the DRIP and previously, shares of common stock under an ATM equity program. Depending on our capital needs and subject to market conditions, in addition to other possible debt and equity offerings, we may consider issuing additional shares under the direct share purchase component of the DRIP and/or under an ATM equity program. Our energy businesses are weather-sensitive and seasonal. We normally generate a large portion of our annual net income and subsequent increases in our accounts receivable in the first and fourth quarters of each year due to significant volumes of natural gas, electricity, and propane delivered by our distribution operations, and our natural gas transmission operations to customers during the peak-heating season. In addition, our natural gas and propane inventories, which usually peak in the fall months, are largely drawn down in the heating season and provide a source of cash as the inventory is used to satisfy winter sales demand. Capital expenditures for investments in new or acquired plant and equipment are our largest capital requirements. Our capital expenditures were $159.5 million for the six months ended June 30, 2024. In the table below, we have provided the range of our forecasted capital expenditures for 2024: 2024 (in thousands) Low High Regulated Energy: Natural gas distribution $ 150,000 $ 170,000 Natural gas transmission 90,000 120,000 Electric distribution 25,000 28,000 Total Regulated Energy 265,000 318,000 Unregulated Energy: Propane distribution 13,000 15,000 Energy transmission 5,000 6,000 Other unregulated energy 13,000 15,000 Total Unregulated Energy 31,000 36,000 Other: Corporate and other businesses 4,000 6,000 Total 2024 Forecasted Capital Expenditures $ 300,000 $ 360,000 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 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 and other factors discussed in Item 1A., Risk Factors, in our 2023 Annual Report on Form 10-K. The timing of capital expenditures can vary based on delays in regulatory approvals, securing environmental approvals and other permits. The regulatory application and approval process has lengthened in the past few years, and we expect this trend to continue. 56 Table of Contents Capital Structure We are committed to maintaining a sound capital structure and strong credit ratings. This commitment, along with adequate and timely rate relief for our regulated energy operations, is intended to ensure our ability to attract capital from outside sources at a reasonable cost, which will benefit our customers, creditors, employees and stockholders. The following table presents our capitalization, excluding and including short-term borrowings, as of June 30, 2024 and December 31, 2023: June 30, 2024 December 31, 2023 (in thousands) Long-term debt, net of current maturities $ 1,174,762 48 % $ 1,187,075 49 % Stockholders’ equity 1,290,554 52 % 1,246,104 51 % Total capitalization, excluding short-term debt $ 2,465,316 100 % $ 2,433,179 100 % June 30, 2024 December 31, 2023 (in thousands) Short-term debt $ 207,091 8 % $ 179,853 7 % Long-term debt, including current maturities 1,193,354 44 % 1,205,580 46 % Stockholders’ equity 1,290,554 48 % 1,246,104 47 % Total capitalization, including short-term debt $ 2,690,999 100 % $ 2,631,537 100 % Our target ratio of equity to total capitalization, including short-term borrowings, is between 50 and 60 percent. Our equity to total capitalization ratio, including short-term borrowings, was 48 percent as of June 30, 2024. We seek to align permanent financing with the in-service dates of our capital projects. We may utilize more temporary short-term debt when the financing cost is attractive as a bridge to the permanent long-term financing or if the equity markets are volatile. In November 2023, in connection with our acquisition of FCG, we completed an equity offering resulting in the issuance of approximately 4.4 million shares of our common stock at a price per share of $82.72 (net of underwriter discounts and commissions). We received net proceeds of $366.4 million which were used to partially finance the acquisition. During the first half of 2024, we received net proceeds of $2.5 million under the DRIP. In 2023, there were no issuances under the DRIP. Shelf Agreements We have entered into Shelf Agreements with Prudential and MetLife with terms that extend through February 2026, however neither of such lenders have any obligation to purchase debt thereunder. At June 30, 2024, a total of $255.0 million of borrowing capacity was available under these agreements. The Uncollateralized Senior Notes set forth certain business covenants to which we are subject when any note is outstanding, including covenants that limit or restrict our ability, and the ability of our subsidiaries, to incur indebtedness, or place or permit liens and encumbrances on any of our property or the property of our subsidiaries. 57 Table of Contents Short-term Borrowings As of June 30, 2024, we are authorized by our Board of Directors to borrow up to $375.0 million of short-term debt, as required. At June 30, 2024 and December 31, 2023, we had $207.1 million and $179.9 million, respectively, of short-term borrowings outstanding at a weighted average interest rate of 5.95 percent and 5.83 percent, respectively. There were no borrowings outstanding under the sustainable investment sublimit of the 364-day tranche at June 30, 2024. In August 2024, we amended and restated our Revolver which increased the total borrowing capacity to $450.0 million, including $250.0 million available under the 364-day tranche which now expires in August 2025 and $200.0 million available under the five-year tranche which now expires in August 2029. Borrowings under both tranches of the amended and restated Revolver continue to be subject to a pricing grid, including the commitment fee and the interest rate charged based upon our total indebtedness to total capitalization ratio for the prior quarter. The 364-day tranche continues to bear interest (i) based upon the SOFR, plus a 10-basis point credit spread adjustment, and an applicable margin of 1.05 percent or less, with such margin based on total indebtedness as a percentage of total capitalization or (ii) the base rate, solely at our discretion. The five-year tranche continues to bear interest (i) based upon the SOFR, plus a 10-basis point credit spread adjustment, and an applicable margin of 1.25 percent or less, with such margin based on total indebtedness as a percentage of total capitalization or (ii) the base rate, solely at our discretion. As of June 30, 2024, the pricing under the 364-day tranche of the Revolver included a commitment fee of 10-basis points on undrawn amounts and an interest rate of 80-basis points over SOFR plus a 10-basis point SOFR adjustment on outstanding balances. As of June 30, 2024, the pricing under the five-year tranche of the Revolver included a commitment fee of 10-basis points on undrawn amounts and an interest rate of 100-basis points over SOFR plus a 10-basis point SOFR adjustment on outstanding balances. We also utilize interest rate swaps to manage rate risk under our Revolver. For additional information on interest rate swaps, including swaps currently in place related to our short-term borrowings, see Note 12, Derivative Instruments . The availability of funds under the Revolver is subject to conditions specified in the credit agreement, all of which we currently satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and warranties contained in the Revolver's loan documents. We are required by the financial covenants in the Revolver to maintain, at the end of each fiscal year, a funded indebtedness ratio as described above. As of June 30, 2024, we were in compliance with this covenant. Our total available credit under the Revolver at June 30, 2024 was $163.0 million. As of June 30, 2024, we had issued $7.0 million in letters of credit to various counterparties under the Revolver. These letters of credit are not included in the outstanding short-term borrowings and we do not anticipate that they will be drawn upon by the counterparties. The letters of credit reduce the available borrowings under the Revolver. In connection with our acquisition of FCG, we entered into a 364-day Bridge Facility commitment with Barclays Bank PLC and other lending parties for up to $965.0 million. Upon closing of the FCG acquisition in November 2023, and with the completion of other financing activities as defined in the lending agreement, this facility was terminated with no funds drawn to finance the transaction. For additional information regarding the acquisition and related financing, see Note 3, Acquisitions, Note 9, Stockholders Equity , and Note 14, Long-Term Debt. Long-Term Debt On November 20, 2023, we issued Senior Notes in the aggregate principal amount of $550.0 million at an average interest rate of 6.54 percent that were used to partially finance our acquisition of FCG which closed during the fourth quarter of 2023. These notes have varying final maturity dates of between three and 15 years, and the outstanding principal balance of the notes (net of annual payments on the 6.73 percent notes which begin in 2029) will be due on their respective maturity dates with interest payments payable semiannually until the principal has been paid in full. These Senior Notes have similar covenants and default provisions as our other Senior Notes. On March 14, 2023 we issued 5.43 percent Senior Notes due in March 2038 in the aggregate principal amount of $80.0 million and used the proceeds received from the issuances of the Senior Notes to reduce short-term borrowings under our Revolver and to fund capital expenditures. These Senior Notes have similar covenants and default provisions as our other Senior Notes, and have an annual principal payment beginning in the sixth year after the issuance. 58 Table of Contents Cash Flows The following table provides a summary of our operating, investing and financing cash flows for the six months ended June 30, 2024 and 2023: Six Months Ended June 30, (in thousands) 2024 2023 Net cash provided by (used in): Operating activities $ 167,378 $ 148,983 Investing activities (155,795) (88,991) Financing activities (10,057) (62,027) Net increase (decrease) in cash and cash equivalents 1,526 (2,035) Cash and cash equivalents—beginning of period 4,904 6,204 Cash and cash equivalents—end of period $ 6,430 $ 4,169 Cash Flows Provided by Operating Activities Changes in our cash flows from operating activities are attributable primarily to changes in net income, adjusted for non-cash items such as depreciation and amortization, changes in deferred income taxes, share-based compensation expense and working capital. Working capital requirements are determined by a variety of factors, including weather, the prices of natural gas, electricity and propane, the timing of customer collections, payments for purchases of natural gas, electricity and propane, and deferred fuel cost recoveries. During the six months ended June 30, 2024, net cash provided by operating activities was $167.4 million. Operating cash flows were primarily impacted by the following: • Net income, adjusted for non-cash adjustments, provided a $107.8 million source of cash; • Changes in net regulatory assets and liabilities due primarily to the change in fuel costs collected through the various cost recovery mechanisms resulted in a $12.2 million source of cash; • An increased level of deferred taxes associated with incremental tax depreciation from growth investments resulted in a source of cash of $23.8 million; and • Other working capital changes, impacted largely by a reduction in net receivables and propane inventory levels, resulted in a $23.8 million source of cash. Cash Flows Used in Investing Activities Net cash used in investing activities totaled $155.8 million during the six months ended June 30, 2024, largely driven by $158.0 million for new capital expenditures. Cash Flows Used in Financing Activities Net cash used in financing activities totaled $10.1 million during the six months ended June 30, 2024 and included the following: • A $25.8 million use of cash for dividend payments in 2024; • Long-term debt repayments of $12.5 million; partially offset by • Net borrowings under lines of credit resulting in a source of cash of $27.0 million. Off-Balance Sheet Arrangements The Board of Directors has authorized us to issue corporate guarantees securing obligations of our subsidiaries and to obtain letters of credit securing our subsidiaries' obligations. The maximum authorized liability under such guarantees and letters of credit as of June 30, 2024 was $35.0 million. The aggregate amount guaranteed related to our subsidiaries at June 30, 2024 was $27.0 million, with the guarantees expiring on various dates through June 2025. In addition, the Board has authorized us to issue specific purpose corporate guarantees. The amount of specific purpose guarantees outstanding at June 30, 2024 was $4.0 million. As of June 30, 2024, we have issued letters of credit totaling $7.0 million related to various transportation, transmission, capacity and storage agreements as well as our primary insurance carriers. These letters of credit have various expiration dates through February 2025 and to date, none have been used. We do not anticipate that the counterparties will draw upon these letters of credit 59 Table of Contents and we expect that they will be renewed to the extent necessary in the future. Additional information is presented in Note 7 , Other Commitments and Contingencies, in the condensed consolidated financial statements. Contractual Obligations There has been no material change in the contractual obligations presented in our 2023 Annual Report on Form 10-K. Rates and Regulatory Matters Our natural gas distribution operations in Delaware, Maryland and Florida and electric distribution operation in Florida are subject to regulation by the respective state PSC; Eastern Shore is subject to regulation by the FERC; and Peninsula Pipeline and Aspire Energy Express, our intrastate pipeline subsidiaries, are subject to regulation (excluding cost of service) by the Florida PSC and Public Utilities Commission of Ohio, respectively. We regularly are involved in regulatory matters in each of the jurisdictions in which we operate. Our significant regulatory matters are fully described in Note 5 , Rates and Other Regulatory Activities , to the condensed consolidated financial statements in this Quarterly Report on Form 10-Q. Recent Authoritative Pronouncements on Financial Reporting and Accounting Recent accounting developments, applicable to us, and their expected impact on our financial position, results of operations and cash flows, are described in Note 1 , Summary of Accounting Policies , to the condensed consolidated financial statements in this Quarterly Report on Form 10-Q. 60 Table of Contents