Attached files
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| 8-K - 8-K - CHESAPEAKE UTILITIES CORP | cpkform8-k6302018.htm |
1-1-1-1
FOR IMMEDIATE RELEASE
August 9, 2018
NYSE Symbol: CPK
CHESAPEAKE UTILITIES CORPORATION REPORTS
SECOND QUARTER 2018 RESULTS
• | Second quarter net income rose 5.6 percent to $6.4 million or $0.39 per share |
• | Profitable growth in the natural gas, electric and propane distribution and natural gas transmission businesses continued to drive increased earnings for the quarter and year-to-date |
• | The Company has paid or reserved a total of $5.4 million in refunds to regulated energy customers from the pass-through of lower Federal income taxes |
• | The Northwest Florida Pipeline expansion project was completed and placed into service during the quarter |
• | Eastern Shore Natural Gas Company's (“Eastern Shore”) $117 million pipeline expansion project and associated earnings remains on track |
• | The 2018 capital spending forecast has been increased from $181.6 million to $216.4 million based on additional profitable opportunities identified across the Company |
Dover, Delaware — Chesapeake Utilities Corporation (NYSE: CPK) (“Chesapeake Utilities” or the “Company”) today announced second quarter financial results. The Company's net income for the quarter ended June 30, 2018 was $6.4 million, compared to $6.0 million for the same quarter of 2017. Earnings per share ("EPS") for the quarter ended June 30, 2018 were $0.39, compared to $0.37 per share for the same quarter of 2017. For the six months ended June 30, 2018, the Company reported net income of $33.2 million, or $2.03 per share. This represents an increase of $8.1 million or $0.49 per share compared to the same period in 2017. The second quarter of 2018 and year-to-date EPS reflect the impact of a $0.09 charge for nonrecurring separation expenses associated with a former executive. Absent that charge, earnings for the quarter and six months ended June 30, 2018 would have been $0.48 and $2.12, respectively.
Higher quarterly and year-to-date earnings reflect the benefits of investments in system expansions and reliability and continued growth in regulated natural gas and electric operations, as well as enhanced profitability and growth from the Company’s propane operations and the benefit of the lower effective tax rate from the Tax Cuts and Jobs Act ("TCJA") on Unregulated Energy earnings. The results also reflect more normal weather during the quarter and six months ended June 30, 2018. Weather during the first half of 2018 was 1.8 percent warmer than normal compared to 22.2 percent warmer than normal during the first six months of 2017. A detailed discussion of operating results begins on page 3.
“Results for the second quarter and year-to-date highlight the strong leadership team we have built at Chesapeake Utilities and the dedication of our employees to achieving our earnings, capital investment and return targets,” stated Michael P. McMasters, President and Chief Executive Officer of Chesapeake Utilities Corporation. "Our business units continue to execute on our growth and expansion initiatives including the completion of the Northwest Florida Pipeline expansion project, significant progress on the construction of Eastern Shore’s largest ever expansion project, as well as several other projects that support attainment of our strategic growth targets in future years," Mr. McMasters added. "I am very excited about the potential growth opportunities we have in front of us, the leadership we have in place to accomplish our strategic plan and our energized employees’ ability to turn these opportunities into executable projects that will continue to drive our future earnings growth and further increase shareholder value,” he concluded.
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Significant Items Impacting Earnings
Results for the three and six months ended June 30, 2018 were impacted by the following significant items:
For the period ended June 30, | Second quarter | Year-to-date | |||||||||||||
Net Income | EPS | Net Income | EPS | ||||||||||||
(in thousands, except per share data) | |||||||||||||||
Reported (GAAP) Earnings | $ | 6,387 | $ | 0.39 | $ | 33,241 | $ | 2.03 | |||||||
Less: Realized Mark-to-Market ("MTM") gain | — | — | (4,008 | ) | (0.24 | ) | |||||||||
Add: Nonrecurring separation expenses associated with a former executive | 1,421 | 0.09 | 1,421 | 0.09 | |||||||||||
Adjusted (Non-GAAP) Earnings* | $ | 7,808 | $ | 0.48 | $ | 30,654 | $ | 1.88 | |||||||
Excluding the one-time separation expenses for a former executive, earnings for the second quarter of 2018 would have been $0.48 per share, an increase of 29.7 percent over EPS for the same quarter in 2017. Excluding both the one-time separation expenses and the realized MTM gain recorded by Peninsula Energy Services Company, Inc. ("PESCO") during the first quarter, EPS for the six months ended June 30, 2018 would have been $1.88, an increase of 22.1 percent over EPS of $1.54 for the six months ended June 30, 2017.
*This press release includes references to non-Generally Accepted Accounting Principles ("GAAP") financial measures, including gross margin, adjusted earnings and Adjusted EPS. A "non-GAAP financial measure" is generally defined as a numerical measure of a company's historical or future performance that includes or excludes amounts, or that is subject to adjustments, so as to be different from the most directly comparable measure calculated or presented in accordance with GAAP. Our management believes certain non-GAAP financial measures, when considered together with GAAP financial measures, provide information that is useful to investors in understanding period-over-period operating results separate and apart from items that may, or could, have a disproportionately positive or negative impact on results in any particular period.
The Company calculates "gross margin" by deducting the cost of sales from operating revenue. Cost of sales includes the purchased fuel cost for natural gas, electricity and propane, and the cost of labor spent on direct revenue-producing activities and excludes depreciation, amortization and accretion. Other companies may calculate gross margin in a different manner. Gross margin should not be considered an alternative to operating income or net income, both of which are determined in accordance with GAAP. The Company believes that gross margin, although a non-GAAP measure, is useful and meaningful to investors as a basis for making investment decisions. It provides investors with information that demonstrates the profitability achieved by the Company under its allowed rates for regulated operations and under its competitive pricing structures for unregulated businesses. The Company's management uses gross margin in measuring its business units' performance. This press release also includes gross margin that excludes the impact of unusual items, such as one-time impact from the enactment of the TCJA. The Company calculates "adjusted earnings” by adjusting reported (GAAP) earnings to exclude the impact of certain significant non-cash items, including the impact of realized MTM gains (losses) and one-time charges, such as severance charges, and calculates “adjusted EPS” by dividing adjusted earnings by the weighted average common shares outstanding.
Operating Results for the Quarters Ended June 30, 2018 and 2017
Consolidated Results
Three Months Ended | ||||||||||||||
(in thousands) | June 30, 2018 | June 30, 2017 | Change | Percent Change | ||||||||||
Gross margin before the TCJA impact | $ | 69,545 | $ | 60,411 | $ | 9,134 | 15.1 | % | ||||||
Impact of the TCJA reserves for customer refunds | (2,284 | ) | — | (2,284 | ) | N/A | ||||||||
Gross margin | 67,261 | 60,411 | 6,850 | 11.3 | % | |||||||||
Depreciation, amortization and property taxes | 13,749 | 12,752 | 997 | 7.8 | % | |||||||||
Nonrecurring separation expenses | 1,548 | — | 1,548 | N/A | ||||||||||
Other operating expenses | 38,716 | 33,598 | 5,118 | 15.2 | % | |||||||||
Operating income | $ | 13,248 | $ | 14,061 | $ | (813 | ) | (5.8 | )% | |||||
Operating income during the second quarter of 2018 decreased by $813,000, or 5.8 percent, compared to the same period in 2017. The most significant driver of the decrease was the pass-through of lower tax rates to regulated energy customers as a result of the TCJA. While the pass-through reduced margin and operating income by approximately $2.3 million, it was offset by an equal reduction in income taxes. Excluding the impact of the pass-through of refunds, operating income increased by $1.5 million, or 10.5 percent, driven by higher gross margin of $9.1 million, or 15.1 percent.
Regulated Energy Segment
Three Months Ended | ||||||||||||||
(in thousands) | June 30, 2018 | June 30, 2017 | Change | Percent Change | ||||||||||
Gross margin before the TCJA impact | $ | 52,778 | $ | 46,829 | $ | 5,949 | 12.7 | % | ||||||
Impact of the TCJA reserves for customer refunds | (2,284 | ) | — | (2,284 | ) | N/A | ||||||||
Gross margin | 50,494 | 46,829 | 3,665 | 7.8 | % | |||||||||
Depreciation, amortization and property taxes | 11,161 | 10,438 | 723 | 6.9 | % | |||||||||
Other operating expenses | 25,029 | 22,305 | 2,724 | 12.2 | % | |||||||||
Operating income | $ | 14,304 | $ | 14,086 | $ | 218 | 1.5 | % | ||||||
As a result of the implementation of settled rates for Eastern Shore, continued system expansions, customer growth across the Company's regulated operations and more normal weather conditions, operating income for the Regulated Energy segment increased by $218,000, or 1.5 percent, in the second quarter of 2018 compared to the same period in 2017. This increase was driven by a $5.9 million increase in gross margin, before the impact of the TCJA reserve discussed above, offset by $3.4 million in higher depreciation and other operating expenses associated with the margin growth. As discussed above, second quarter gross margin and operating income were also impacted by customer refunds of $2.3 million, associated with the TCJA, which were offset by an equal reduction in income tax expenses. Excluding the estimated customer refunds associated with the TCJA, operating income increased by $2.5 million, or 17.8 percent.
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The significant components of the increase in gross margin are shown below:
(in thousands) | Margin Impact | ||
Implementation of Eastern Shore settled rates | $ | 2,365 | |
Service expansions | 1,652 | ||
Natural gas growth (including customer and consumption growth but excluding service expansions) | 1,575 | ||
Return to more normal weather | 359 | ||
Florida electric reliability/modernization program | 352 | ||
Gas Reliability and Infrastructure Program ("GRIP") in Florida | 306 | ||
Other | (660 | ) | |
Total | 5,949 | ||
Less: TCJA reserve impact for regulated entities* | (2,284 | ) | |
Quarter over quarter increase in gross margin | $ | 3,665 | |
*As a result of the TCJA, an estimated amount of $2.3 million was reserved or refunded to customers during the second quarter of 2018 to reflect the impact of lower tax rates on the Company's regulated businesses. In some jurisdictions, refunds have been made to customers, while in other jurisdictions, the Company has established reserves until final agreements are approved and permanent changes are made to customer rates. The reserves and lower customer rates are equal to the estimated reduction in Federal income taxes due to the TCJA and have no material impact on after-tax earnings from the Regulated Energy segment.
The significant components of the increase in other operating expenses are as follows:
(in thousands) | Other Operating Expenses | ||
Higher outside services, facilities and maintenance costs due to growth | $ | 1,166 | |
Higher payroll expense (increased staffing and annual salary increases) | 1,019 | ||
Higher depreciation, amortization and property taxes associated with recent capital projects | 722 | ||
Higher incentive compensation costs (based on period-over-period results) | 384 | ||
Other | 156 | ||
Quarter over quarter increase in other operating expenses | $ | 3,447 | |
At the present time, we expect the current expense run rate to continue for the remainder of the year.
Unregulated Energy Segment
Three Months Ended | ||||||||||||||
(in thousands) | June 30, 2018 | June 30, 2017 | Change | Percent Change | ||||||||||
Gross margin | $ | 16,915 | $ | 13,736 | $ | 3,179 | 23.1 | % | ||||||
Depreciation, amortization and property taxes | 2,553 | 2,272 | 281 | 12.4 | % | |||||||||
Other operating expenses | 13,872 | 11,462 | 2,410 | 21.0 | % | |||||||||
Operating income | $ | 490 | $ | 2 | $ | 488 | N.M. | |||||||
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Operating income for the Unregulated Energy segment increased by $488,000 for the three months ended June 30, 2018, compared to the same period in 2017. The increase was driven by a $3.2 million, or 23.1 percent, increase in gross margin, which was partially offset by $2.7 million in higher operating expenses associated with growth. The improvement in operating income is largely a result of continued growth and colder weather at the propane operations and higher margins at PESCO.
The significant components of the increase in gross margin are shown below:
(in thousands) | Margin Impact | ||
Nonrecurring margin increase for PESCO (see the discussion included later for the margin drivers) | $ | 1,092 | |
Propane delivery operations - additional customer consumption related to weather | 806 | ||
Incremental margin from PESCO operations (see the discussion included later for the margin drivers) | 592 | ||
Propane delivery operations - increased margin driven by growth and other factors | 536 | ||
Aspire Energy of Ohio LLC ("Aspire Energy") - increased margins largely due to higher commodity pricing on natural gas liquid sales | 207 | ||
Other | (54 | ) | |
Quarter over quarter increase in gross margin | $ | 3,179 | |
The significant components of the increase in other operating expenses are as follows:
(in thousands) | Other Operating Expenses | ||
Incremental operating expenses for PESCO | $ | 764 | |
Higher payroll expense (increased staffing and annual salary increases)(1) | 515 | ||
Higher outside services, facilities and maintenance costs due to growth(1) | 475 | ||
Higher incentive compensation costs (based on period-over-period results)(1) | 427 | ||
Higher benefit and other employee-related expenses(1) | 173 | ||
Higher depreciation, asset removal and property tax costs due to new capital investments(1) | 131 | ||
Other(1) | 206 | ||
Quarter over quarter increase in other operating expenses | $ | 2,691 | |
(1) Excluding incremental operating expenses at PESCO.
At the present time, we expect the current expense run rate to continue for the remainder of the year.
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Operating Results for the Six Months Ended June 30, 2018 and 2017
Consolidated Results
Six Months Ended | ||||||||||||||
(in thousands) | June 30, 2018 | June 30, 2017 | Change | Percent Change | ||||||||||
Gross margin before the TCJA impact | $ | 163,981 | $ | 144,573 | $ | 19,408 | 13.4 | % | ||||||
Impact of the TCJA reserves for customer refunds | (5,421 | ) | — | (5,421 | ) | N/A | ||||||||
Gross margin | 158,560 | 144,573 | 13,987 | 9.7 | % | |||||||||
Depreciation, amortization and property taxes | 27,447 | 25,235 | 2,212 | 8.8 | % | |||||||||
Nonrecurring separation expenses | 1,548 | — | 1,548 | N/A | ||||||||||
Other operating expenses | 75,911 | 70,178 | 5,733 | 8.2 | % | |||||||||
Operating income | $ | 53,654 | $ | 49,160 | $ | 4,494 | 9.1 | % | ||||||
Operating income, during the six months ended June 30, 2018, increased by $4.5 million, or 9.1 percent, compared to the same period in 2017. This increase was driven by a $19.4 million, or 13.4 percent, increase in gross margin before the TCJA impact, which was partially offset by a $2.2 million increase in depreciation, amortization and property taxes and a $5.7 million increase in other operating expenses. Gross margin and operating income for the six months ended June 30, 2018, were also impacted by customer refunds of $5.4 million, associated with the TCJA, which were offset by an equivalent reduction in income tax expenses for the Regulated Energy segment. Excluding the estimated customer refunds associated with the TCJA, operating income increased by $9.9 million, or 20.2 percent.
Regulated Energy Segment
Six Months Ended | ||||||||||||||
(in thousands) | June 30, 2018 | June 30, 2017 | Change | Percent Change | ||||||||||
Gross margin before the TCJA impact | $ | 117,077 | $ | 104,239 | $ | 12,838 | 12.3 | % | ||||||
Impact of the TCJA reserves for customer refunds | (5,421 | ) | — | (5,421 | ) | N/A | ||||||||
Gross margin | 111,656 | 104,239 | 7,417 | 7.1 | % | |||||||||
Depreciation, amortization and property taxes | 22,317 | 20,629 | 1,688 | 8.2 | % | |||||||||
Other operating expenses | 48,324 | 46,129 | 2,195 | 4.8 | % | |||||||||
Operating income | $ | 41,015 | $ | 37,481 | $ | 3,534 | 9.4 | % | ||||||
As a result of the implementation of settled rates for Eastern Shore, continued system expansions, customer growth across the Company's regulated operations and more normal weather conditions, operating income for the Regulated Energy segment increased by $3.5 million, or 9.4 percent, in the six months ended June 30, 2018 compared to the same period in 2017. This increase was driven by a $12.8 million increase in gross margin before the impact of the TCJA reserve discussed above, which was partially offset by $3.9 million in higher depreciation and other operating expenses associated with the margin growth. Excluding the estimated customer refunds associated with the TCJA, operating income increased by $9.0 million, or 23.9 percent.
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The significant components of the increase in gross margin are shown below:
(in thousands) | Margin Impact | ||
Implementation of Eastern Shore settled rates | $ | 5,095 | |
Natural gas growth (including customer and consumption growth but excluding service expansions) | 3,342 | ||
Service expansions | 2,316 | ||
Return to more normal weather | 1,314 | ||
Florida electric reliability/modernization program | 767 | ||
Florida GRIP | 602 | ||
Other | (598 | ) | |
Total | 12,838 | ||
Less: TCJA reserve impact for regulated entities* | (5,421 | ) | |
Period over period increase in gross margin | $ | 7,417 | |
*As a result of the TCJA, an estimated amount of $5.4 million was reserved or refunded to customers during the first six months of 2018 to reflect the impact of lower tax rates on the Company's regulated businesses. In some jurisdictions, refunds have been made to customers, while in other jurisdictions, the Company has established reserves until final agreements are approved and permanent changes are made to customer rates. The reserves and lower customer rates are equal to the estimated reduction in Federal income taxes due to the TCJA and have no material impact on after-tax earnings from the Regulated Energy segment.
The significant components of the increase in other operating expenses are as follows:
(in thousands) | Other Operating Expenses | ||
Higher depreciation, amortization and property taxes associated with recent capital projects | $ | 1,688 | |
Higher payroll expense (increased staffing and annual salary increases) | 1,399 | ||
Higher facilities and maintenance costs largely as a result of growth | 1,149 | ||
Lower regulatory and outside services expenses as there were various regulatory proceedings (including Eastern Shore’s rate case) in 2017 | (1,056 | ) | |
Higher incentive compensation costs (based on period-over-period results) | 592 | ||
Other | 111 | ||
Period over period increase in other operating expenses | $ | 3,883 | |
Unregulated Energy Segment
Six Months Ended | ||||||||||||||
(in thousands) | June 30, 2018 | June 30, 2017 | Change | Percent Change | ||||||||||
Gross margin | $ | 47,216 | $ | 40,555 | $ | 6,661 | 16.4 | % | ||||||
Depreciation, amortization and property taxes | 5,059 | 4,524 | 535 | 11.8 | % | |||||||||
Other operating expenses | 27,983 | 24,454 | 3,529 | 14.4 | % | |||||||||
Operating income | $ | 14,174 | $ | 11,577 | $ | 2,597 | 22.4 | % | ||||||
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Operating income for the Unregulated Energy segment increased by $2.6 million for the six months ended June 30, 2018, compared to the same period in 2017. The increase was driven by a $6.7 million, or 16.4 percent, increase in gross margin, which was partially offset by $4.1 million in higher operating expenses associated with growth. The improvements in gross margin and operating income were driven primarily by more normal weather and continued growth within the Company's propane operations and at Aspire Energy.
The significant components of the increase in gross margin are shown below:
(in thousands) | Margin Impact | ||
Propane delivery operations - additional customer consumption - weather | $ | 2,923 | |
Propane delivery operations - increased margin driven by growth and other factors | 1,789 | ||
Nonrecurring margin decrease at PESCO | (863 | ) | |
Aspire Energy - customer consumption - weather | 921 | ||
Aspire Energy - increased margin driven by growth and other factors | 585 | ||
Growth in wholesale propane margins and sales | 333 | ||
Incremental margin from PESCO operations | 255 | ||
Other | 718 | ||
Period over period increase in gross margin | $ | 6,661 | |
The significant components of the increase in other operating expenses are as follows:
(in thousands) | Other Operating Expenses | ||
Incremental operating expenses for PESCO | $ | 1,715 | |
Higher payroll expense (increased staffing and annual salary increases)(1) | 996 | ||
Absence of Xeron Inc. ("Xeron") 2017 wind-down costs(1) | (870 | ) | |
Higher vehicle, sales and advertising, other taxes and credit collections costs, largely driven by growth(1) | 646 | ||
Higher incentive compensation costs (based on period-over-period results)(1) | 594 | ||
Higher facilities and maintenance costs due to growth(1) | 443 | ||
Higher depreciation, amortization and property taxes associated with recent capital investments(1) | 266 | ||
Higher benefits and employee-related costs(1) | 214 | ||
Other(1) | 60 | ||
Period over period increase in other operating expenses | $ | 4,064 | |
(1) Excluding incremental operating expenses at PESCO.
Matters discussed in this release may include forward-looking statements that involve risks and uncertainties. Actual results may differ materially from those in the forward-looking statements. Please refer to the Safe Harbor for Forward-Looking Statements in the Company’s 2017 Annual Report on Form 10-K for further information on the risks and uncertainties related to the Company’s forward-looking statements.
Unless otherwise noted, earnings per share are presented on a diluted basis.
Conference Call
Chesapeake Utilities will host a conference call on Friday, August 10, 2018 at 10:30 a.m. Eastern Time to discuss the Company’s financial results for the quarter ended June 30, 2018. To participate in this call, dial 855.801.6270 and reference Chesapeake Utilities’ 2018 Second Quarter Results Conference Call. To access
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the replay recording of this call, the accompanying transcript, and other pertinent quarterly information, use the link CPK - Conference Call Audio Replay, or visit the Investors/Events and Presentations section of Company’s website at www.chpk.com.
About Chesapeake Utilities Corporation
Chesapeake Utilities is a diversified energy company engaged in natural gas distribution, transmission, gathering and processing, and marketing; electricity generation and distribution; propane gas distribution; and other businesses. Information about Chesapeake Utilities and its family of businesses is available at http://www.chpk.com or through its IR App.
Please note that Chesapeake Utilities Corporation is not affiliated with Chesapeake Energy, an oil and natural gas exploration company headquartered in Oklahoma City, Oklahoma.
For more information, contact:
Beth W. Cooper
Senior Vice President & Chief Financial Officer
302.734.6799
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Financial Summary
(in thousands, except per share data)
Three Months Ended | Six Months Ended | ||||||||||||||
June 30, | June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
Gross Margin | |||||||||||||||
Regulated Energy segment | $ | 50,494 | $ | 46,829 | $ | 111,656 | $ | 104,239 | |||||||
Unregulated Energy segment | 16,915 | 13,736 | 47,216 | 40,555 | |||||||||||
Other businesses and eliminations | (148 | ) | (154 | ) | (312 | ) | (221 | ) | |||||||
Total Gross Margin | $ | 67,261 | $ | 60,411 | $ | 158,560 | $ | 144,573 | |||||||
Operating Income | |||||||||||||||
Regulated Energy segment | $ | 14,304 | $ | 14,086 | $ | 41,015 | $ | 37,481 | |||||||
Unregulated Energy segment | 490 | 2 | 14,174 | 11,577 | |||||||||||
Other businesses and eliminations | (1,546 | ) | (27 | ) | (1,535 | ) | 102 | ||||||||
Total Operating Income | 13,248 | 14,061 | 53,654 | 49,160 | |||||||||||
Other Expense, net | (262 | ) | (1,002 | ) | (194 | ) | (1,703 | ) | |||||||
Interest Charges | 3,881 | 3,073 | 7,545 | 5,811 | |||||||||||
Pre-tax Income | 9,105 | 9,986 | 45,915 | 41,646 | |||||||||||
Income Taxes | 2,718 | 3,940 | 12,674 | 16,456 | |||||||||||
Net Income | $ | 6,387 | $ | 6,046 | $ | 33,241 | $ | 25,190 | |||||||
Earnings Per Share of Common Stock | |||||||||||||||
Basic | $ | 0.39 | $ | 0.37 | $ | 2.03 | $ | 1.54 | |||||||
Diluted | $ | 0.39 | $ | 0.37 | $ | 2.03 | $ | 1.54 | |||||||
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Financial Summary Highlights
Key variances, between the three months ended June 30, 2017 and 2018, included:
(in thousands, except per share data) | Pre-tax Income | Net Income | Earnings Per Share | |||||||||
Second Quarter of 2017 Reported Results | $ | 9,986 | $ | 6,046 | $ | 0.37 | ||||||
Adjusting for unusual items: | ||||||||||||
One-time separation expenses associated with a former executive | (1,548 | ) | (1,421 | ) | (0.09 | ) | ||||||
Absence of Xeron expenses, including 2017 wind-down expenses | 173 | 122 | 0.01 | |||||||||
(1,375 | ) | (1,299 | ) | (0.08 | ) | |||||||
Increased Gross Margins: | ||||||||||||
Implementation of Eastern Shore settled rates* (1) | 2,365 | 1,659 | 0.10 | |||||||||
TCJA impact - refunds and reserves for future refunds to ratepayers(2) | (2,284 | ) | (1,602 | ) | (0.10 | ) | ||||||
Service expansions* | 1,652 | 1,158 | 0.07 | |||||||||
Natural gas growth (including customer and consumption growth but excluding service expansions) | 1,575 | 1,105 | 0.07 | |||||||||
Return to normal weather | 1,108 | 778 | 0.05 | |||||||||
Nonrecurring margin increase at PESCO | 1,092 | 766 | 0.05 | |||||||||
Incremental margin from PESCO operations | 592 | 415 | 0.03 | |||||||||
Unregulated Energy growth excluding PESCO | 503 | 353 | 0.02 | |||||||||
Florida electric reliability/modernization program* | 352 | 247 | 0.02 | |||||||||
GRIP* | 306 | 215 | 0.01 | |||||||||
7,261 | 5,094 | 0.32 | ||||||||||
Decreased (Increased) Other Operating Expenses: | ||||||||||||
Higher outside services and facilities maintenance costs (3) | (1,602 | ) | (1,124 | ) | (0.07 | ) | ||||||
Higher payroll expense (increased staffing and annual salary increases) (3) | (1,534 | ) | (1,076 | ) | (0.07 | ) | ||||||
Higher depreciation, asset removal and property tax costs due to new capital investments (3) | (848 | ) | (595 | ) | (0.04 | ) | ||||||
Higher incentive compensation costs (based on period-over-period results) (3) | (811 | ) | (569 | ) | (0.03 | ) | ||||||
Incremental operating expenses for PESCO | (764 | ) | (536 | ) | (0.03 | ) | ||||||
Higher benefit and other employee-related expenses (3) | (365 | ) | (256 | ) | (0.02 | ) | ||||||
(5,924 | ) | (4,156 | ) | (0.26 | ) | |||||||
Interest charges | (808 | ) | (567 | ) | (0.03 | ) | ||||||
Income taxes - including TCJA impact - decreased effective tax rate | — | 1,295 | 0.08 | |||||||||
Net other changes | (35 | ) | (26 | ) | (0.01 | ) | ||||||
(843 | ) | 702 | 0.04 | |||||||||
Second Quarter of 2018 Reported Results | $ | 9,105 | $ | 6,387 | $ | 0.39 | ||||||
(1) Excluding amounts refunded to customers associated with the TCJA, which are broken out separately and discussed in footnote 2.
(2) "TCJA impact - refunds and reserves for future refunds to ratepayers" represents the amounts that have already been refunded to customers or reserves established for future refunds to customers in the second quarter of 2018 as a result of lower taxes due to the TCJA. Refunds made to customers are offset by the corresponding decrease in federal income taxes and are expected to have no net impact on net income.
(3) Excluding incremental operating expenses at PESCO.
*See the Major Projects and Initiatives table later in this press release.
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Key variances, between the six months ended June 30, 2017 and 2018, included:
(in thousands, except per share data) | Pre-tax Income | Net Income | Earnings Per Share | |||||||||
Six Months Ended June 30, 2017 Reported Results | $ | 41,646 | $ | 25,190 | $ | 1.54 | ||||||
Adjusting for unusual items: | ||||||||||||
One-time separation expenses associated with a former executive | (1,548 | ) | (1,421 | ) | (0.09 | ) | ||||||
Absence of Xeron expenses, including 2017 wind-down expenses | 870 | 630 | 0.04 | |||||||||
(678 | ) | (791 | ) | (0.05 | ) | |||||||
Increased Gross Margins: | ||||||||||||
TCJA impact - refunds and reserves for future refunds to ratepayers(2) | (5,421 | ) | (3,925 | ) | (0.24 | ) | ||||||
Return to normal weather | 5,159 | 3,735 | 0.23 | |||||||||
Implementation of Eastern Shore settled rates* (1) | 5,095 | 3,689 | 0.22 | |||||||||
Natural gas growth (including customer and consumption growth but excluding service expansions) | 3,342 | 2,420 | 0.15 | |||||||||
Service expansions* | 2,316 | 1,677 | 0.10 | |||||||||
Unregulated Energy growth excluding PESCO | 2,044 | 1,480 | 0.09 | |||||||||
Nonrecurring margin decrease at PESCO | (863 | ) | (625 | ) | (0.04 | ) | ||||||
Florida electric reliability/modernization program* | 767 | 555 | 0.03 | |||||||||
GRIP* | 602 | 436 | 0.03 | |||||||||
Incremental margin from PESCO operations | 255 | 185 | 0.01 | |||||||||
13,296 | 9,627 | 0.58 | ||||||||||
Decreased (Increased) Other Operating Expenses: | ||||||||||||
Higher payroll expense (increased staffing and annual salary increases) (3) | (2,395 | ) | (1,734 | ) | (0.11 | ) | ||||||
Higher depreciation, asset removal and property tax costs due to new capital investments (3) | (1,949 | ) | (1,411 | ) | (0.09 | ) | ||||||
Incremental operating expenses for PESCO | (1,715 | ) | (1,242 | ) | (0.08 | ) | ||||||
Higher facilities maintenance costs (3) | (1,554 | ) | (1,125 | ) | (0.07 | ) | ||||||
Lower regulatory and outside services costs (3) | 1,298 | 940 | 0.06 | |||||||||
Higher incentive compensation costs (based on period-over-period results) (3) | (1,187 | ) | (859 | ) | (0.05 | ) | ||||||
(7,502 | ) | (5,431 | ) | (0.34 | ) | |||||||
Interest charges | (1,734 | ) | (1,255 | ) | (0.08 | ) | ||||||
Income taxes - including TCJA impact - decreased effective tax rate | — | 5,262 | 0.32 | |||||||||
Net other changes | 887 | 639 | 0.06 | |||||||||
(847 | ) | 4,646 | 0.30 | |||||||||
Six Months Ended June 30, 2018 Reported Results | $ | 45,915 | $ | 33,241 | $ | 2.03 | ||||||
(1) Excluding amounts refunded to customers associated with the TCJA, which are broken out separately and discussed in footnote 2.
(2) "TCJA impact - refunds and reserves for future refunds to ratepayers" represents amounts that have already been refunded to customers or reserves established for future refunds to customers in the first six months of 2018 as a result of lower taxes due to the TCJA. Refunds made to customers are offset by the corresponding decrease in federal income taxes and are expected to have no net impact on net income.
(3) Excluding incremental operating expenses at PESCO.
*See the Major Projects and Initiatives table later in this press release.
--more--
12-12-12-12
Recently Completed and Ongoing Major Projects and Initiatives
The Company constantly seeks and develops additional projects and initiatives in order to further increase shareholder value and serve its customers. The following represent the major projects recently completed and currently underway. In the future, the Company will add new projects to this table as projects are initiated.
Gross Margin for the Period | |||||||||||||||||||||||||||
Three Months Ended | Six Months Ended | Year Ended | Estimate for | ||||||||||||||||||||||||
June 30, | June 30, | December 31, | Fiscal | ||||||||||||||||||||||||
in thousands | 2018 | 2017 | 2018 | 2017 | 2017 | 2018 | 2019 | ||||||||||||||||||||
Florida GRIP | $ | 3,647 | $ | 3,341 | $ | 7,211 | $ | 6,609 | $ | 13,454 | $ | 14,287 | $ | 14,370 | |||||||||||||
Eastern Shore Rate Case (1) | 2,365 | — | 5,095 | — | 3,693 | 9,800 | 9,800 | ||||||||||||||||||||
Florida Electric Reliability/Modernization Pilot Program (1) | 352 | — | 767 | — | 94 | 1,558 | 1,558 | ||||||||||||||||||||
New Smyrna Beach, Florida Project (1) | 352 | — | 704 | — | 235 | 1,409 | 1,409 | ||||||||||||||||||||
2017 Eastern Shore System Expansion Project - including interim services (1) | 859 | — | 1,995 | — | 433 | 8,101 | 15,799 | ||||||||||||||||||||
Northwest Florida Expansion Project (1) | 870 | — | 870 | — | — | 3,484 | 6,500 | ||||||||||||||||||||
(Palm Beach County) Belvedere, Florida Project (1) | — | — | — | — | — | 635 | 1,131 | ||||||||||||||||||||
Total | $ | 8,445 | $ | 3,341 | $ | 16,642 | $ | 6,609 | $ | 17,909 | $ | 39,274 | $ | 50,567 | |||||||||||||
(1) Gross margin amounts included in this table have not been adjusted to reflect the impact of the TCJA. Any refunds and/or rate reductions implemented in the Company's regulated businesses will be offset by lower Federal income taxes due to the TCJA.
Ongoing Growth Initiatives
GRIP
GRIP is a natural gas pipe replacement program approved by the Florida PSC that allows automatic recovery in rates of capital related costs and a return on investment, associated with the replacement of mains and services. Since the program's inception in August 2012, we have invested $120.1 million to replace 250 miles of qualifying distribution mains, including $6.4 million during the first six months of 2018. GRIP generated additional gross margin of $306,000 and $602,000 for the three and six months ended June 30, 2018 compared to the same periods in 2017.
Regulatory Proceedings
Eastern Shore Rate Case/Settled Rates
Eastern Shore's rate case settlement agreement became final on April 1, 2018. The final agreement increases Eastern Shore's operating income by $6.6 million consisting of $9.8 million from increased rates and offset by the $3.2 million in lower federal income taxes. For the three and six months ended June 30, 2018, Eastern Shore recognized incremental gross margin of approximately $2.4 million and $5.1 million, respectively. As of June 30, 2018, Eastern Shore refunded its customers a total of $1.7 million related to the decrease in federal income taxes as a result of the TCJA. The settlement rates were effective January 1, 2018.
Florida Electric Reliability/Modernization Program
In December 2017, the Florida PSC approved a $1.6 million annualized rate increase, effective January 2018, for the recovery of a limited number of investments and costs related to reliability, safety and modernization for the Florida Public Utilities Company's (“FPU”) electric distribution system. This increase will continue through at least the last billing cycle of December 2019. For the three and six months ended June 30, 2018, additional margin of $352,000 and $767,000, respectively, was generated.
Major Projects and Initiatives Currently Underway
New Smyrna Beach, Florida Project
In the fourth quarter of 2017, the Company commenced construction of a 14-mile gas transmission pipeline to provide additional capacity to serve current and planned customer growth in the Company's New Smyrna Beach service area. The project was partially placed into service at the end of 2017 and is expected to be fully in service in September 2018. For the three and six months ended June 30, 2018, the project generated incremental gross margin of approximately $352,000 and $704,000, respectively.
--more--
13-13-13-13
2017 Eastern Shore System Expansion Project
In November 2017, Eastern Shore began construction of a $117.0 million system expansion that will increase its capacity by 26 percent once completed. The Company has invested $89.6 million through June 30, 2018 and expects to invest approximately $24.8 million during the remainder of 2018 to substantially complete the project. The first phase of the project was placed into service in December 2017, and generated $859,000 and $2.0 million in incremental gross margin, including margin from interim services, during the three and six months ended June 30, 2018, respectively. With the exception of some minor facilities, the remaining segments are scheduled to be completed and begin generating margin during the second half of 2018. The project is expected to produce approximately $15.8 million in gross margin in its first full year of service.
Northwest Florida Expansion Project
Peninsula Pipeline Company, Inc. ("Peninsula Pipeline"), has completed construction of transmission lines and the Company's Florida natural gas division has completed construction of lateral distribution lines to serve two large customers and other customers close to these facilities. This is the Company’s first expansion of natural gas service into Northwest Florida. The project was placed into service in May 2018 and generated incremental gross margin of $870,000 for the three and six months ended June 30, 2018. The estimated annual gross margin from this project is $6.5 million.
(Palm Beach County) Belvedere, Florida Project
Peninsula Pipeline is constructing a pipeline to bring gas directly to the Company’s natural gas distribution system in West Palm Beach, Florida. The Company expects to complete this project by the end of the third quarter of 2018 and expects the project to generate $1.1 million in annual gross margin.
Other major factors influencing gross margin
Weather and Consumption
Gross margin increased by $1.1 million and $5.2 million in the three and six months ended June 30, 2018, respectively, as a result of colder temperatures, compared to the extremely warm temperatures experienced during the same period in 2017. While temperatures during the first half of 2018 were colder than 2017, temperatures were still warmer than normal, as shown in the table below. The Company estimates that it would have generated an additional $2.4 million in gross margin if temperatures for the six months ended June 30, 2018 had been normal. The following table summarizes heating degree-days ("HDD") and cooling degree-days ("CDD") variances from the 10-year average HDD/CDD ("Normal") for the three and six months ended June 30, 2018 and 2017.
HDD and CDD Information
Three Months Ended | Six Months Ended | ||||||||||||||||
June 30, | June 30, | ||||||||||||||||
2018 | 2017 | Variance | 2018 | 2017 | Variance | ||||||||||||
Delmarva | |||||||||||||||||
Actual HDD | 424 | 288 | 136 | 2,719 | 2,246 | 473 | |||||||||||
10-Year Average HDD ("Delmarva Normal") | 423 | 429 | (6 | ) | 2,785 | 2,783 | 2 | ||||||||||
Variance from Delmarva Normal | 1 | (141 | ) | (66 | ) | (537 | ) | ||||||||||
Florida | |||||||||||||||||
Actual HDD | 17 | 13 | 4 | 507 | 298 | 209 | |||||||||||
10-Year Average HDD ("Florida Normal") | 16 | 19 | (3 | ) | 533 | 555 | (22 | ) | |||||||||
Variance from Florida Normal | 1 | (6 | ) | (26 | ) | (257 | ) | ||||||||||
Ohio | |||||||||||||||||
Actual HDD | 662 | 508 | 154 | 3,652 | 2,992 | 660 | |||||||||||
10-Year Average HDD ("Ohio Normal") | 614 | 637 | (23 | ) | 3,683 | 3,774 | (91 | ) | |||||||||
Variance from Ohio Normal | 48 | (129 | ) | (31 | ) | (782 | ) | ||||||||||
Florida | |||||||||||||||||
Actual CDD | 952 | 935 | 17 | 1,091 | 1,080 | 11 | |||||||||||
10-Year Average CDD ("Florida CDD Normal") | 969 | 955 | 14 | 1,058 | 1,037 | 21 | |||||||||||
Variance from Florida CDD Normal | (17 | ) | (20 | ) | 33 | 43 | |||||||||||
--more--
14-14-14-14
Natural Gas Distribution Customer and Consumption Growth
The Company's natural gas distribution operations generated $1.6 million and $3.3 million of additional margin for the three and six months ended June 30, 2018, respectively. The breakdown of the increased margin is as follows:
Three Months Ended | Six Months Ended | |||||||
In thousands | June 30, 2018 | June 30, 2018 | ||||||
Customer growth: | ||||||||
Residential | $ | 351 | $ | 864 | ||||
Commercial and industrial excluding new service in Northwest Florida | 303 | 604 | ||||||
New service in Northwest Florida | 276 | 305 | ||||||
Total customer growth | 930 | 1,773 | ||||||
Volume growth: | ||||||||
Residential | 151 | 855 | ||||||
Commercial and industrial | 387 | 1,026 | ||||||
Other - including unbilled revenue | 107 | (312 | ) | |||||
Total volume growth | 645 | 1,569 | ||||||
Total natural gas distribution growth | $ | 1,575 | $ | 3,342 | ||||
Customer growth for the Company's Delmarva Peninsula and Florida natural gas distribution operations generated $930,000 and $1.8 million in additional gross margin for the three and six months ended June 30, 2018, respectively, compared to the same periods in 2017. The additional margin was generated from an approximately 3.8 percent increase in the average number of residential customers as well as growth in commercial and industrial customers on the Delmarva Peninsula in the second quarter and first six months of 2018, compared to the corresponding periods in 2017. Residential customer growth on the Delaware Peninsula has averaged 3.0 percent over the past five years. The Company's Florida natural gas distribution operations generated additional gross margin for the three and six months ended June 30, 2018, due to growth in all customer classes and new service to customers in Northwest Florida.
The Company's Delmarva Peninsula and Florida natural gas distribution operations generated $645,000 and $1.6 million in additional gross margin for the three and six months ended June 30, 2018, respectively, compared to the same periods in 2017 from higher sales to residential and commercial customers.
Propane Operations
The Company’s Florida and Delmarva Peninsula propane operations generated $1.6 million and $5.7 million in incremental margin for the three and six months ended June 30, 2018, respectively, compared to the same periods in 2017. A return to more normal temperatures accounted for $806,000 and $2.9 million of the margin increase during the three and six months ended June 30, 2018, respectively. The balance of the increase reflects increased customer consumption driven by growth and other factors, higher sales and revenues from service contracts and increased wholesale sales activities.
PESCO
For the three and six months ended June 30, 2018, PESCO recorded a series of adjustments, MTM gains and recognized extraordinary costs, which impacted reported results. Excluding the impact of these items, PESCO's gross margin increased by $592,000 and $255,000 in the three and six months ended June 30, 2018, respectively, compared to the same periods in 2017. The total of the adjustments increased gross margin by $1.1 million and reduced gross margin by $863,000 for the three and six months ended June 30, 2018, respectively, compared to the same periods in 2017, respectively. The following table summarizes the changes in PESCO’S year-over-year margin for the three and six months ended June 30, 2018:
--more--
15-15-15-15
Three Months Ended | Six Months Ended | ||||||
June 30, 2018 | June 30, 2018 | ||||||
(in thousands) | |||||||
Three and Six Months Ended June 30, 2017 Reported Results | $ | 921 | $ | 4,389 | |||
Incremental Margin from Growth and ARM Acquisition in 2017 | 592 | 255 | |||||
Nonrecurring Margin factors - non-renewal of Supply Agreement, MTM and Other Adjustments | 1,092 | (863 | ) | ||||
2018 Margin | $ | 2,605 | $ | 3,781 | |||
A more detailed discussion of PESCO’s results is provided in the Company’s Form 10-Q for the quarter ended June 30, 2018.
The following table compares the margin, operating expenses and operating income from PESCO for the three and six months ended June 30, 2018 and 2017:
Three Months Ended | Six Months Ended | ||||||||||||||
June 30, | June 30, | ||||||||||||||
in thousands | 2018 | 2017 | 2018 | 2017 | |||||||||||
Total Gross Margin | $ | 2,606 | $ | 921 | $ | 3,781 | $ | 4,389 | |||||||
Operating Expense | (1,918 | ) | (1,154 | ) | (3,857 | ) | (2,143 | ) | |||||||
Operating Income | $ | 688 | $ | (233 | ) | $ | (76 | ) | $ | 2,246 | |||||
Operating income for PESCO improved to $688,000 for the three months ended June 30, 2018, from a loss of $233,000 during the prior year period. The improvement reflects the benefit of several nonrecurring margin adjustments in the business, growth in margins from existing operations as well as the addition of margin from the business purchased from ARM during the third quarter of 2017. This was partially offset by a $764,000 increase in operating expenses, including $262,000 associated with the ARM margins previously mentioned, as well as $501,000 in increased staffing, infrastructure and risk management system costs to ensure the profitable future growth of this business.
For the six months ended June 30, 2018, PESCO reported an operating loss of $76,000, compared to income of $2.2 million during the prior year period. The decline primarily reflects increased expenses incurred to build out the staff, infrastructure and risk management systems necessary for the success of this business, as well as the impact of several nonrecurring margin adjustments, largely during the first quarter of 2018.
Xeron
Xeron's operations were wound down during the second quarter of 2017. Operating income for the three and six months ended June 30, 2018, improved by $173,000 and $870,000, respectively, due to the absence of wind-down expenses and the absence of operating losses for Xeron in 2018.
--more--
16-16-16-16
Capital Investment Growth and Financing Plan
The Company's capital expenditures were $134.7 million for the six months ended June 30, 2018. The Company originally budgeted $181.6 million for capital expenditures in 2018 and is currently projecting capital expenditures of approximately $216.4 million in 2018. The Company's current forecast by segment and by business line is shown below:
2018 | |||
(dollars in thousands) | |||
Regulated Energy: | |||
Natural gas distribution | $ | 65,594 | |
Natural gas transmission | 110,813 | ||
Electric distribution | 8,930 | ||
Total Regulated Energy | 185,337 | ||
Unregulated Energy: | |||
Propane distribution | 13,359 | ||
Other unregulated energy | 7,413 | ||
Total Unregulated Energy | 20,772 | ||
Other: | |||
Corporate and other businesses | 10,289 | ||
Total Other | 10,289 | ||
Total 2018 Forecasted Capital Expenditures | $ | 216,398 | |
Chesapeake Utilities' target ratio of equity to total capitalization, including short-term borrowings, is between 50 and 60 percent. This target capital structure ensures that the Company maintains a strong balance sheet to support continued growth. Over the past several years, the Company has been deploying increased amounts of capital on new projects, many of which have longer construction periods. The Company seeks to align the permanent financing of these capital projects with the in-service dates to the extent feasible.
In 2017, the Company refinanced $70.0 million of short-term debt as 3.25 percent senior notes. The refinancing will result in increased annual interest expense of $2.3 million during 2018, a portion of which impacted the second quarter and year-to-date results; however, the Company locked in a low interest rate for 15 years. The Company previously executed a shelf agreement with New York Life and subsequently issued $50.0 million of unsecured senior notes in May 2018 and will issue an additional tranche by November 2018 at an average interest rate of 3.53 percent for 20 years. The Company expects to access additional permanent capital to align the financing with new investments and to maintain a solid balance sheet to support future capital deployment.
--more--
17-17-17-17
Chesapeake Utilities Corporation and Subsidiaries Condensed Consolidated Statements of Income (Unaudited) (in thousands, except shares and per share data) | |||||||||||||||
Three Months Ended | Six Months Ended | ||||||||||||||
June 30, | June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
Operating Revenues | |||||||||||||||
Regulated Energy | $ | 70,504 | $ | 70,996 | $ | 179,897 | $ | 168,650 | |||||||
Unregulated Energy and other | 66,160 | 54,088 | 196,123 | 141,594 | |||||||||||
Total Operating Revenues | 136,664 | 125,084 | 376,020 | 310,244 | |||||||||||
Operating Expenses | |||||||||||||||
Regulated Energy cost of sales | 20,010 | 24,167 | 68,241 | 64,411 | |||||||||||
Unregulated Energy and other cost of sales | 49,393 | 40,505 | 149,219 | 101,260 | |||||||||||
Operations | 36,281 | 30,013 | 68,983 | 62,502 | |||||||||||
Maintenance | 3,619 | 3,403 | 7,211 | 6,634 | |||||||||||
Gain from a settlement | (130 | ) | (130 | ) | (130 | ) | (130 | ) | |||||||
Depreciation and amortization | 9,839 | 9,094 | 19,543 | 17,906 | |||||||||||
Other taxes | 4,404 | 3,971 | 9,299 | 8,501 | |||||||||||
Total operating expenses | 123,416 | 111,023 | 322,366 | 261,084 | |||||||||||
Operating Income | 13,248 | 14,061 | 53,654 | 49,160 | |||||||||||
Other expense, net | (262 | ) | (1,002 | ) | (194 | ) | (1,703 | ) | |||||||
Interest charges | 3,881 | 3,073 | 7,545 | 5,811 | |||||||||||
Income Before Income Taxes | 9,105 | 9,986 | 45,915 | 41,646 | |||||||||||
Income taxes | 2,718 | 3,940 | 12,674 | 16,456 | |||||||||||
Net Income | $ | 6,387 | $ | 6,046 | $ | 33,241 | $ | 25,190 | |||||||
Weighted Average Common Shares Outstanding: | |||||||||||||||
Basic | 16,369,641 | 16,340,665 | 16,360,540 | 16,329,009 | |||||||||||
Diluted | 16,417,082 | 16,382,207 | 16,410,061 | 16,373,038 | |||||||||||
Earnings Per Share of Common Stock: | |||||||||||||||
Basic | $ | 0.39 | $ | 0.37 | $ | 2.03 | $ | 1.54 | |||||||
Diluted | $ | 0.39 | $ | 0.37 | $ | 2.03 | $ | 1.54 | |||||||
--more--
18-18-18-18
Chesapeake Utilities Corporation and Subsidiaries Condensed Consolidated Balance Sheets (Unaudited) | ||||||||
Assets | June 30, 2018 | December 31, 2017 | ||||||
(in thousands, except shares and per share data) | ||||||||
Property, Plant and Equipment | ||||||||
Regulated Energy | $ | 1,174,407 | $ | 1,073,736 | ||||
Unregulated Energy | 216,125 | 210,682 | ||||||
Other businesses and eliminations | 30,170 | 27,699 | ||||||
Total property, plant and equipment | 1,420,702 | 1,312,117 | ||||||
Less: Accumulated depreciation and amortization | (287,942 | ) | (270,599 | ) | ||||
Plus: Construction work in progress | 101,904 | 84,509 | ||||||
Net property, plant and equipment | 1,234,664 | 1,126,027 | ||||||
Current Assets | ||||||||
Cash and cash equivalents | 4,512 | 5,614 | ||||||
Trade and other receivables (less allowance for uncollectible accounts of $1,076 and $936, respectively) | 53,419 | 77,223 | ||||||
Accrued revenue | 12,353 | 22,279 | ||||||
Propane inventory, at average cost | 6,597 | 8,324 | ||||||
Other inventory, at average cost | 4,791 | 12,022 | ||||||
Regulatory assets | 13,330 | 10,930 | ||||||
Storage gas prepayments | 4,365 | 5,250 | ||||||
Income taxes receivable | 6,420 | 14,778 | ||||||
Prepaid expenses | 5,162 | 13,621 | ||||||
Mark-to-market energy assets | 534 | 1,286 | ||||||
Other current assets | 4,560 | 7,260 | ||||||
Total current assets | 116,043 | 178,587 | ||||||
Deferred Charges and Other Assets | ||||||||
Goodwill | 19,604 | 19,604 | ||||||
Other intangible assets, net | 4,277 | 4,686 | ||||||
Investments, at fair value | 7,486 | 6,756 | ||||||
Regulatory assets | 76,427 | 75,575 | ||||||
Other assets | 4,440 | 3,699 | ||||||
Total deferred charges and other assets | 112,234 | 110,320 | ||||||
Total Assets | $ | 1,462,941 | $ | 1,414,934 | ||||
--more--
19-19-19-19
Chesapeake Utilities Corporation and Subsidiaries Condensed Consolidated Balance Sheets (Unaudited) | ||||||||
Capitalization and Liabilities | June 30, 2018 | December 31, 2017 | ||||||
(in thousands, except shares and per share data) | ||||||||
Capitalization | ||||||||
Stockholders' equity | ||||||||
Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no shares issued and outstanding | $ | — | $ | — | ||||
Common stock, par value $0.4867 per share (authorized 50,000,000 shares) | 7,971 | 7,955 | ||||||
Additional paid-in capital | 255,356 | 253,470 | ||||||
Retained earnings | 250,377 | 229,141 | ||||||
Accumulated other comprehensive loss | (5,718 | ) | (4,272 | ) | ||||
Deferred compensation obligation | 3,782 | 3,395 | ||||||
Treasury stock | (3,782 | ) | (3,395 | ) | ||||
Total stockholders' equity | 507,986 | 486,294 | ||||||
Long-term debt, net of current maturities | 241,596 | 197,395 | ||||||
Total capitalization | 749,582 | 683,689 | ||||||
Current Liabilities | ||||||||
Current portion of long-term debt | 9,977 | 9,421 | ||||||
Short-term borrowing | 235,288 | 250,969 | ||||||
Accounts payable | 60,769 | 74,688 | ||||||
Customer deposits and refunds | 32,018 | 34,751 | ||||||
Accrued interest | 1,891 | 1,742 | ||||||
Dividends payable | 6,060 | 5,312 | ||||||
Accrued compensation | 7,953 | 13,112 | ||||||
Regulatory liabilities | 22,194 | 6,485 | ||||||
Mark-to-market energy liabilities | 886 | 6,247 | ||||||
Other accrued liabilities | 11,495 | 10,273 | ||||||
Total current liabilities | 388,531 | 413,000 | ||||||
Deferred Credits and Other Liabilities | ||||||||
Deferred income taxes | 143,147 | 135,850 | ||||||
Regulatory liabilities | 141,499 | 140,978 | ||||||
Environmental liabilities | 8,090 | 8,263 | ||||||
Other pension and benefit costs | 28,996 | 29,699 | ||||||
Deferred investment tax credits and other liabilities | 3,096 | 3,455 | ||||||
Total deferred credits and other liabilities | 324,828 | 318,245 | ||||||
Total Capitalization and Liabilities | $ | 1,462,941 | $ | 1,414,934 | ||||
--more--
20-20-20-20
Chesapeake Utilities Corporation and Subsidiaries Distribution Utility Statistical Data (Unaudited) | ||||||||||||||||||||||||||||||||
For the Three Months Ended June 30, 2018 | For the Three Months Ended June 30, 2017 | |||||||||||||||||||||||||||||||
Delmarva NG Distribution | Chesapeake Utilities Florida NG Division | FPU NG Distribution | FPU Electric Distribution | Delmarva NG Distribution | Chesapeake Utilities Florida NG Division | FPU NG Distribution | FPU Electric Distribution | |||||||||||||||||||||||||
Operating Revenues (in thousands) | ||||||||||||||||||||||||||||||||
Residential | $ | 14,007 | $ | 1,459 | $ | 7,713 | $ | 9,814 | $ | 11,096 | $ | 1,365 | $ | 7,633 | $ | 10,477 | ||||||||||||||||
Commercial | 7,752 | 1,524 | 6,809 | 9,709 | 6,424 | 1,395 | 7,449 | 10,075 | ||||||||||||||||||||||||
Industrial | 1,987 | 2,854 | 5,218 | 371 | 1,849 | 1,577 | 4,775 | 733 | ||||||||||||||||||||||||
Other (1) | (3,496 | ) | 480 | (1,459 | ) | (1,532 | ) | (3,136 | ) | 966 | (1,271 | ) | (207 | ) | ||||||||||||||||||
Total Operating Revenues | $ | 20,250 | $ | 6,317 | $ | 18,281 | $ | 18,362 | $ | 16,233 | $ | 5,303 | $ | 18,586 | $ | 21,078 | ||||||||||||||||
Volume (in Dts for natural gas and MWHs for electric) | ||||||||||||||||||||||||||||||||
Residential | 759,202 | 85,526 | 329,284 | 66,682 | 583,108 | 76,365 | 304,669 | 69,298 | ||||||||||||||||||||||||
Commercial | 711,690 | 1,134,555 | 432,192 | 73,276 | 614,311 | 2,710,729 | 459,354 | 74,766 | ||||||||||||||||||||||||
Industrial | 1,308,129 | 7,024,154 | 1,245,950 | 3,540 | 1,206,698 | 1,501,779 | 1,100,430 | 4,750 | ||||||||||||||||||||||||
Other | 17,759 | — | 463,846 | 1,907 | 20,216 | — | 459,201 | 1,874 | ||||||||||||||||||||||||
Total | 2,796,780 | 8,244,235 | 2,471,272 | 145,405 | 2,424,333 | 4,288,873 | 2,323,654 | 150,688 | ||||||||||||||||||||||||
Average Customers | ||||||||||||||||||||||||||||||||
Residential | 71,038 | 16,391 | 55,580 | 24,714 | 68,442 | 15,786 | 54,352 | 24,582 | ||||||||||||||||||||||||
Commercial(2) | 6,994 | 1,517 | 3,932 | 7,493 | 6,836 | 1,430 | 4,072 | 7,429 | ||||||||||||||||||||||||
Industrial(2) | 155 | 16 | 2,284 | 2 | 144 | 78 | 2,055 | 2 | ||||||||||||||||||||||||
Other | 4 | — | 11 | — | 7 | — | — | — | ||||||||||||||||||||||||
Total | 78,191 | 17,924 | 61,807 | 32,209 | 75,429 | 17,294 | 60,479 | 32,013 | ||||||||||||||||||||||||
Chesapeake Utilities Corporation and Subsidiaries Distribution Utility Statistical Data (Unaudited) | ||||||||||||||||||||||||||||||||
For the Six Months Ended June 30, 2018 | For the Six Months Ended June 30, 2017 | |||||||||||||||||||||||||||||||
Delmarva NG Distribution | Chesapeake Utilities Florida NG Division | FPU NG Distribution | FPU Electric Distribution | Delmarva NG Distribution | Chesapeake Utilities Florida NG Division | FPU NG Distribution | FPU Electric Distribution | |||||||||||||||||||||||||
Operating Revenues (in thousands) | ||||||||||||||||||||||||||||||||
Residential | $ | 49,321 | $ | 3,219 | $ | 18,888 | $ | 21,346 | $ | 36,806 | $ | 2,917 | $ | 18,401 | $ | 19,804 | ||||||||||||||||
Commercial | 23,582 | 3,246 | 15,135 | 18,866 | 17,836 | 2,918 | 17,043 | 19,489 | ||||||||||||||||||||||||
Industrial | 4,293 | 4,725 | 11,590 | 771 | 3,683 | 3,336 | 10,702 | 1,204 | ||||||||||||||||||||||||
Other (1) | (5,239 | ) | 990 | (4,119 | ) | (3,880 | ) | (1,678 | ) | 1,866 | (4,054 | ) | (1,796 | ) | ||||||||||||||||||
Total Operating Revenues | $ | 71,957 | $ | 12,180 | $ | 41,494 | $ | 37,103 | $ | 56,647 | $ | 11,037 | $ | 42,092 | $ | 38,701 | ||||||||||||||||
Volume (in Dts for natural gas and MWHs for electric) | ||||||||||||||||||||||||||||||||
Residential | 2,999,757 | 226,285 | 852,346 | 145,210 | 2,391,008 | 199,640 | 775,480 | 130,624 | ||||||||||||||||||||||||
Commercial | 2,417,116 | 2,374,462 | 967,736 | 141,015 | 1,995,719 | 5,668,445 | 1,060,557 | 140,628 | ||||||||||||||||||||||||
Industrial | 2,817,168 | 10,089,859 | 2,550,480 | 8,060 | 2,580,496 | 3,269,209 | 2,289,693 | 7,910 | ||||||||||||||||||||||||
Other | 30,292 | — | 984,353 | 3,803 | 30,754 | — | 947,111 | 3,747 | ||||||||||||||||||||||||
Total | 8,264,333 | 12,690,606 | 5,354,915 | 298,088 | 6,997,977 | 9,137,294 | 5,072,841 | 282,909 | ||||||||||||||||||||||||
Average Customers | ||||||||||||||||||||||||||||||||
Residential | 71,136 | 16,307 | 55,430 | 24,679 | 68,572 | 15,725 | 54,196 | 24,510 | ||||||||||||||||||||||||
Commercial(2) | 7,009 | 1,509 | 3,930 | 7,487 | 6,874 | 1,420 | 4,123 | 7,438 | ||||||||||||||||||||||||
Industrial(2) | 154 | 16 | 2,268 | 2 | 143 | 77 | 1,997 | 2 | ||||||||||||||||||||||||
Other | 5 | — | 14 | — | 6 | — | — | — | ||||||||||||||||||||||||
Total | 78,304 | 17,832 | 61,642 | 32,168 | 75,595 | 17,222 | 60,316 | 31,950 | ||||||||||||||||||||||||
(1) | Operating Revenues from "Other" sources include unbilled revenue, under (over) recoveries of fuel cost, conservation revenue, other miscellaneous charges, fees for billing services provided to third parties, and adjustments or changes in taxes, such as the TCJA, which are passed through to customers. This amount also includes the reserve for estimated customer refunds associated with the TCJA. |
(2) | Certain commercial and industrial customers have been reclassified when compared to the prior year. |