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| 8-K - 8-K - CHESAPEAKE UTILITIES CORP | cpkform8-k3312018.htm |
FOR IMMEDIATE RELEASE
May 8, 2018
NYSE Symbol: CPK
CHESAPEAKE UTILITIES CORPORATION REPORTS
FIRST QUARTER 2018 RESULTS
• | Net income rose 40.3 percent to $26.9 million or $1.64 per share |
• | Gross margin* increased $10.3 million, or 12.2 percent, for the quarter, before the pass through of lower Federal income taxes to customers of our regulated businesses |
• | Preliminary estimates of customer refunds from lower Federal income taxes totaled $3.2 million for the quarter |
• | Continued profitable growth in the natural gas, electric and propane distribution, natural gas transmission and combined heat and power businesses drove margin and operating income increases for the quarter |
• | Eastern Shore's largest ever pipeline system expansion is well underway |
Dover, Delaware — Chesapeake Utilities Corporation (NYSE: CPK) (“Chesapeake Utilities” or the “Company”) today announced first quarter financial results. The Company's net income for the quarter ended March 31, 2018 was $26.9 million, compared to $19.1 million for the same quarter of 2017. Earnings per share ("EPS") for the quarter ended March 31, 2018 were $1.64 per share, compared to $1.17 per share for the same quarter of 2017. The higher net income and EPS reflected robust performance and results largely throughout the Company's businesses.
Higher earnings for the first quarter of 2018 reflect continued growth in the regulated natural gas and electric operations, pipeline expansion and favorable regulatory initiatives. Increased profitability and growth from propane delivery operations and Aspire Energy of Ohio, LLC ("Aspire Energy") and the positive impact of the lower effective tax rate from the Tax Cuts and Jobs Act (the "TCJA") in the Unregulated Energy segment generated additional earnings. The results also reflect a return to more normal weather during the first quarter of 2018, compared to weather that was 20.9 percent warmer than normal during the first quarter of 2017. A detailed discussion of operating results begins on page 3.
“We begin 2018 with strong first quarter financial results, which reflect the strength of our natural gas and propane operations under more normal weather conditions and the superior performance of the Company's investments and growth-oriented initiatives led by our dedicated team,” stated Michael P. McMasters, President and Chief Executive Officer of Chesapeake Utilities Corporation. “We look forward to continued growth in our Regulated and Unregulated Energy segments this year and in future years,” Mr. McMasters added. "During 2018, we are focused on completing the construction of Eastern Shore Natural Gas Company’s ("Eastern Shore") largest ever expansion project as well as other projects that are critical to meeting our growth targets in future years," he added. “Our energized employees continue to excel in identifying new growth opportunities and profitably managing current growth, while maintaining operating efficiency and providing safe, reliable service to our customers,” he concluded.
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Significant Item Impacting Earnings
Results for the first quarter of 2018 were impacted by the following significant item:
For the quarter ended March 31, 2018 | Net Income | EPS | |||||
(in thousands, except per share data) | |||||||
Reported (GAAP) Earnings | $ | 26,855 | $ | 1.64 | |||
Less: Realized Mark-to-Market ("MTM") gain | (4,008 | ) | (0.24 | ) | |||
Adjusted (Non-GAAP) Earnings* | $ | 22,847 | $ | 1.40 | |||
Excluding the realized MTM gain, that corresponds to the MTM unrealized loss recorded in the prior quarter (fourth quarter of 2017), earnings for the first quarter would have been $1.40 per share. This represents an increase of 19.7 percent over the first quarter of 2017's EPS of $1.17 per share. A more detailed discussion of the MTM gain can be found in the discussion of Peninsula Energy Services Company, Inc. ("PESCO")'s results under “Other Major Factors Influencing Gross Margin” later in this release.
*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 calculates “adjusted EPS” by dividing adjusted earnings by the weighted average common shares outstanding.
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Operating Results for the Quarters Ended March 31, 2018 and 2017
(in thousands) | March 31, 2018 | March 31, 2017 | Change | Percent Change | ||||||||||
Gross margin before the TCJA impact | $ | 94,454 | $ | 84,162 | $ | 10,292 | 12.2 | % | ||||||
Impact of the TCJA reserves for customer refunds | (3,155 | ) | — | (3,155 | ) | N/A | ||||||||
Gross margin | 91,299 | 84,162 | 7,137 | 8.5 | % | |||||||||
Depreciation, amortization and property taxes | 13,697 | 12,483 | 1,214 | 9.7 | % | |||||||||
Other operating expenses | 37,196 | 36,580 | 616 | 1.7 | % | |||||||||
Operating income | $ | 40,406 | $ | 35,099 | $ | 5,307 | 15.1 | % | ||||||
Operating income during the first quarter of 2018 increased by $5.3 million, or 15.1 percent, compared to the same period in 2017. This increase was driven by a $10.3 million, or 12.2 percent, increase in gross margin, which was partially offset by a $1.2 million increase in depreciation, amortization and property taxes and a $616,000 increase in other operating expenses. First quarter gross margin and operating income were also impacted by a reserve for estimated customer refunds of $3.2 million, associated with the TCJA, which are offset by an equivalent reduction in income tax expenses for the Regulated Energy segment. Excluding the estimated reserve for refunds to customers associated with the TCJA, operating income increased by $8.5 million, or 24.1 percent.
Regulated Energy Segment
(in thousands) | March 31, 2018 | March 31, 2017 | Change | Percent Change | ||||||||||
Gross margin before the TCJA impact | $ | 64,317 | $ | 57,410 | $ | 6,907 | 12.0 | % | ||||||
Impact of the TCJA reserves for customer refunds | (3,155 | ) | — | (3,155 | ) | N/A | ||||||||
Gross margin | 61,162 | 57,410 | 3,752 | 6.5 | % | |||||||||
Depreciation, amortization and property taxes | 11,156 | 10,190 | 966 | 9.5 | % | |||||||||
Other operating expenses | 23,295 | 23,825 | (530 | ) | (2.2 | )% | ||||||||
Operating income | $ | 26,711 | $ | 23,395 | $ | 3,316 | 14.2 | % | ||||||
As a result of continued system expansions, customer growth across our regulated operations and more normal weather conditions, operating income for the Regulated Energy segment increased by $3.3 million, or 14.2 percent, in the first quarter of 2018 compared to the same period in 2017. This increase was driven by a $6.9 million increase in gross margin, offset by the TCJA reserve discussed above and $436,000 in higher operating expenses associated with the margin growth.
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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 | $ | 2,843 | |
Return to more normal weather | 1,017 | ||
Customer consumption (non-weather) | 949 | ||
Natural gas growth (excluding service expansions) | 802 | ||
Service expansions | 565 | ||
Florida electric reliability/modernization program | 372 | ||
Gas Reliability and Infrastructure Program ("GRIP") in Florida | 298 | ||
Sandpiper's margin from an industrial customer and natural gas conversions | 257 | ||
Other | (196 | ) | |
Total | 6,907 | ||
Less: TCJA reserve impact for regulated entities* | (3,155 | ) | |
Quarter over quarter increase in gross margin | $ | 3,752 | |
*As a result of the TCJA, a preliminary reserve of $3.2 million was established during the first quarter of 2018 to reflect the impact of lower tax rates on the Company's regulated businesses, 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 Expense | ||
Higher depreciation, amortization and property taxes associated with recent capital projects | $ | 966 | |
Higher staffing costs for additional personnel to support growth | 589 | ||
Lower outside services and facilities and maintenance costs | (667 | ) | |
Lower benefits and employee-related costs | (413 | ) | |
Other | (39 | ) | |
Quarter over quarter increase in other operating expenses | $ | 436 | |
Unregulated Energy Segment
(in thousands) | March 31, 2018 | March 31, 2017 | Change | Percent Change | ||||||||||
Gross margin | $ | 30,301 | $ | 26,819 | $ | 3,482 | 13.0 | % | ||||||
Depreciation, amortization and property taxes | 2,505 | 2,250 | 255 | 11.3 | % | |||||||||
Other operating expenses | 14,112 | 12,994 | 1,118 | 8.6 | % | |||||||||
Operating income | $ | 13,684 | $ | 11,575 | $ | 2,109 | 18.2 | % | ||||||
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Operating income for the Unregulated Energy segment increased by $2.1 million for the first quarter of 2018 compared to the same period in 2017. The increase was driven by a $3.5 million, or 13.0 percent, increase in gross margin, which was partially offset by $1.4 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 at Aspire Energy and within the Company's propane operations.
The significant components of the increase in gross margin are shown below:
(in thousands) | Margin Impact | ||
PESCO's net margin (see the discussion included later for the margin drivers) | $ | (2,292 | ) |
Propane delivery operations - additional customer consumption related to weather | 1,956 | ||
Propane delivery operations - increased margin driven by growth and other factors | 1,392 | ||
Aspire Energy - higher customer consumption related to weather | 941 | ||
Growth in wholesale propane margins and sales | 379 | ||
Aspire Energy - increased margin driven by growth and other factors | 319 | ||
Other | 787 | ||
Quarter over quarter increase in gross margin | $ | 3,482 | |
The significant components of the increase in other operating expenses are as follows:
(in thousands) | Other Operating Expense | ||
Higher staffing costs for additional personnel to support growth | $ | 969 | |
Higher depreciation, amortization and property taxes associated with recent capital investments | 255 | ||
Higher benefits and employee-related costs | 174 | ||
Other | (25 | ) | |
Quarter over quarter increase in other operating expenses | $ | 1,373 | |
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, May 11, 2018, at 10:30 a.m. Eastern Time to discuss the Company’s financial results for the quarter ended March 31, 2018. To participate in this call, dial 855.801.6270 and reference Chesapeake Utilities' 2018 First Quarter Financial Results Conference Call. To access the replay recording of this call, please visit the Company’s website at http://investor.chpk.com/results.cfm or download the replay on your mobile device by accessing the Audiocast section of the Company's IR App.
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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 | |||||||
March 31, | |||||||
2018 | 2017 | ||||||
Gross Margin | |||||||
Regulated Energy segment | $ | 61,162 | $ | 57,410 | |||
Unregulated Energy segment | 30,301 | 26,819 | |||||
Other businesses and eliminations | (164 | ) | (67 | ) | |||
Total Gross Margin | $ | 91,299 | $ | 84,162 | |||
Operating Income | |||||||
Regulated Energy segment | $ | 26,711 | $ | 23,395 | |||
Unregulated Energy segment | 13,684 | 11,575 | |||||
Other businesses and eliminations | 11 | 129 | |||||
Total Operating Income | 40,406 | 35,099 | |||||
Other Income (Expense), net | 68 | (700 | ) | ||||
Interest Charges | 3,664 | 2,739 | |||||
Pre-tax Income | 36,810 | 31,660 | |||||
Income Taxes | 9,955 | 12,516 | |||||
Net Income | $ | 26,855 | $ | 19,144 | |||
Earnings Per Share of Common Stock | |||||||
Basic | $ | 1.64 | $ | 1.17 | |||
Diluted | $ | 1.64 | $ | 1.17 | |||
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Financial Summary Highlights
Key variances, between the three months ended March 31, 2017 and 2018, included:
(in thousands, except per share data) | Pre-tax Income | Net Income | Earnings Per Share | |||||||||
First Quarter of 2017 Reported Results | $ | 31,660 | $ | 19,144 | $ | 1.17 | ||||||
Increased Gross Margins: | ||||||||||||
Return to more normal weather | 3,914 | 2,855 | 0.17 | |||||||||
TCJA impact - estimated refunds to ratepayers (1) | (3,155 | ) | (2,302 | ) | (0.14 | ) | ||||||
Implementation of Eastern Shore settled rates* (2) | 2,843 | 2,074 | 0.13 | |||||||||
PESCO | (2,292 | ) | (1,672 | ) | (0.10 | ) | ||||||
Unregulated Energy customer consumption (non-weather) | 1,682 | 1,227 | 0.07 | |||||||||
Regulated Energy customer consumption (non-weather) | 949 | 692 | 0.04 | |||||||||
Natural gas growth (excluding service expansions) | 802 | 585 | 0.04 | |||||||||
Service expansions* | 565 | 412 | 0.03 | |||||||||
Florida electric reliability/modernization program* | 372 | 272 | 0.02 | |||||||||
GRIP* | 298 | 217 | 0.01 | |||||||||
Sandpiper's margin from an industrial customer and natural gas conversions | 257 | 188 | 0.01 | |||||||||
6,235 | 4,548 | 0.28 | ||||||||||
Decreased (Increased) Other Operating Expenses: | ||||||||||||
Higher payroll expense | (1,559 | ) | (1,137 | ) | (0.07 | ) | ||||||
Higher depreciation, asset removal and property tax costs due to new capital investments | (1,216 | ) | (887 | ) | (0.05 | ) | ||||||
Absence of Xeron expenses, including wind-down expenses | 697 | 508 | 0.03 | |||||||||
Lower outside services and facilities maintenance costs | 665 | 485 | 0.03 | |||||||||
Lower regulatory expenses | 242 | 177 | 0.01 | |||||||||
Lower benefit and other employee-related expenses | 240 | 175 | 0.01 | |||||||||
(931 | ) | (679 | ) | (0.04 | ) | |||||||
Interest charges | (926 | ) | (675 | ) | (0.04 | ) | ||||||
Income taxes - TCJA impact - decreased effective tax rate | — | 4,594 | 0.28 | |||||||||
Net other changes | 772 | (77 | ) | (0.01 | ) | |||||||
(154 | ) | 3,842 | 0.23 | |||||||||
First Quarter of 2018 Reported Results | $ | 36,810 | $ | 26,855 | $ | 1.64 | ||||||
(1) Offset for the reserve to ratepayers is shown within this table under "Income taxes."
(2) The Company reserved an estimated $900,000 to refund to customers, which is included in the line above "TCJA impact - estimated refunds to ratepayers." The refunds were made to customers through April 30, 2018, are offset by the corresponding decrease in Federal income taxes and are expected to have no net impact on net income.
*See the Major Projects and Initiatives table later in this press release.
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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 currently underway. In the future, the Company will add new projects to this table as projects are initiated.
Gross Margin for the Period (1) | |||||||||||||||||||
(in thousands) | Quarter Ended March 31, 2018 | Quarter Ended March 31, 2017 | Fiscal 2017 | Fiscal 2018 Estimate | Fiscal 2019 Estimate | ||||||||||||||
Florida GRIP | $ | 3,565 | $ | 3,267 | $ | 13,454 | $ | 14,287 | $ | 14,370 | |||||||||
Eastern Shore Rate Case/Settled Rates | 2,843 | — | 3,693 | 9,800 | 9,800 | ||||||||||||||
Florida Electric Reliability/Modernization Program | 372 | — | 94 | 1,558 | 1,558 | ||||||||||||||
New Smyrna Beach, Florida Project | 352 | — | 235 | 1,409 | 1,409 | ||||||||||||||
2017 Eastern Shore System Expansion Project - including interim services | 1,040 | — | 433 | 7,446 | 15,799 | ||||||||||||||
Northwest Florida Expansion Project | — | — | — | 3,484 | 6,032 | ||||||||||||||
(Palm Beach County) Belvedere, Florida Project | — | — | — | 635 | 1,131 | ||||||||||||||
Total | $ | 8,172 | $ | 3,267 | $ | 17,909 | $ | 38,619 | $ | 50,099 | |||||||||
(1) Gross margin amounts included in this table have not been adjusted to reflect the impact of TCJA. Any reductions implemented would 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 Public Service Commission ("Florida PSC") that allows automatic recovery of the costs to replace mains and services. Since the program's inception in August 2012, the Company has invested $117.0 million to replace 250 miles of qualifying distribution mains, including $3.2 million of capital during the first quarter of 2018. For the three months ended March 31, 2018, the Company's Florida natural gas distribution operations generated incremental gross margin of $298,000 over the first quarter of 2017 from GRIP.
Regulatory Proceedings
Eastern Shore Rate Case/Settled Rates
In February 2018, the Federal Energy Regulatory Commission (the "FERC") approved Eastern Shore's rate case settlement agreement, which became final on April 1, 2018 upon the expiration of the right to rehearing. Under the terms of the settlement agreement, Eastern Shore will recover costs of its 2016 System Reliability Project, along with the cost of investments and expenses associated with various expansion, reliability and safety initiatives. Pursuant to the settlement agreement, Eastern Shore will record and recognize an increase in annual base rates of approximately $9.8 million, prior to any impact from the TCJA and will recognize approximately $6.6 million, on an annual basis, which reflects the impact of the change in its Federal corporate income tax rate. Any reductions in rates implemented would be offset by lower Federal income taxes due to TCJA. For the three months ended March 31, 2018, Eastern Shore recognized incremental gross margin of approximately $2.8 million, a portion of which was reserved as a regulatory liability to be refunded to customers. Eastern Shore refunded to its customers, with interest, the difference between the proposed rates and the settlement rates on April 30, 2018. The settlement rates were effective January 1, 2018.
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Florida Electric Reliability/Modernization Program
In December 2017, the Florida PSC approved a $1.6 million annualized rate increase, effective for January 2018 meter readings, for the recovery of a limited number of investments and costs related to reliability, safety and modernization of FPU's electric distribution system. For the three months ended March 31, 2018, FPU generated incremental gross margin of approximately $372,000 as a result of this rate increase. This rate increase will continue in effect at least through the last billing cycle of December 2019. The settlement prescribes the methodology for adjusting the new rates as a result of the TCJA.
Major Projects and Initiatives Currently Underway
New Smyrna Beach, Florida Project
In the fourth quarter of 2017, the Company started construction of a 14-mile transmission pipeline that interconnects with Florida Gas Transmission Company's ("FGT") pipeline to provide additional capacity to serve current and planned growth of Florida gas distribution customers 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 by the end of September 2018. For the three months ended March 31, 2018, FPU generated incremental gross margin of approximately $352,000 from this project.
2017 Eastern Shore System Expansion Project
The Company expects to invest approximately $117.0 million in 2018 to increase Eastern Shore's capacity by 26 percent. The new transportation services contracted for this capacity will generate approximately $15.8 million of gross margin in the first full year of service. In December 2017, the first phase of the project was placed into service, and the remaining segments are expected to be placed into service over the remainder of 2018. For the three months ended March 31, 2018, Eastern Shore generated incremental gross margin, including margin from interim services, of approximately $1.0 million.
Northwest Florida Expansion Project
Peninsula Pipeline and the Company's Florida natural gas division are constructing a pipeline that will interconnect with the FGT interstate pipeline. The project consists of transmission lines that will be operated by Peninsula Pipeline and lateral distribution lines that will be operated by the Company's Florida natural gas division. The Company has signed agreements to serve two large customers and continues to market to other customers close to the facilities. The estimated annual gross margin from this project is $6.0 million, and the project is currently expected to be in service by the end of the second quarter of 2018.
(Palm Beach County) Belvedere, Florida Project
Peninsula Pipeline is constructing a pipeline that will interconnect with FGT's pipeline and bring gas directly to FPU’s distribution system in West Palm Beach, Florida. The project is expected to be in service by the end of the third quarter of 2018. The estimated annual gross margin associated with the project is approximately $1.1 million
Other major factors influencing gross margin
Weather and Consumption
Gross margin increased by $3.9 million in the first quarter of 2018, primarily as a result of colder temperatures, as compared to the extremely warm temperatures experienced during the first quarter of 2017. Despite being colder than the first quarter of 2017, the temperatures in the first quarter of 2018 were still warmer than normal. We estimate that an additional $1.7 million of gross margin would have been generated if the temperatures in the first quarter of 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 months ended March 31, 2018 and 2017.
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HDD and CDD Information
Three Months Ended | ||||||||
March 31, | ||||||||
2018 | 2017 | Variance | ||||||
Delmarva | ||||||||
Actual HDD | 2,295 | 1,958 | 337 | |||||
10-Year Average HDD ("Delmarva Normal") | 2,354 | 2,403 | (49 | ) | ||||
Variance from Delmarva Normal | (59 | ) | (445 | ) | ||||
Florida | ||||||||
Actual HDD | 490 | 285 | 205 | |||||
10-Year Average HDD ("Florida Normal") | 517 | 536 | (19 | ) | ||||
Variance from Florida Normal | (27 | ) | (251 | ) | ||||
Ohio | ||||||||
Actual HDD | 2,991 | 2,484 | 507 | |||||
10-Year Average HDD ("Ohio Normal") | 3,069 | 3,137 | (68 | ) | ||||
Variance from Ohio Normal | (78 | ) | (653 | ) | ||||
Florida | ||||||||
Actual CDD | 139 | 145 | (6 | ) | ||||
10-Year Average CDD ("Florida CDD Normal") | 89 | 82 | 7 | |||||
Variance from Florida CDD Normal | 50 | 63 | ||||||
Natural Gas Distribution Customer Growth
Customer growth for the Company's Delmarva Peninsula natural gas distribution operations generated $500,000 in additional gross margin for the quarter ended March 31, 2018, compared to the same period in 2017. The additional margin was generated from a 3.7 percent increase in the average number of residential customers as well as growth in commercial and industrial customers on the Delmarva Peninsula in the first quarter of 2018.
The Company's Florida natural gas distribution operations generated $302,000 in additional gross margin for the quarter ended March 31, 2018, compared to the same period in 2017, with approximately half of the margin growth generated from residential customers and the other half from commercial and industrial customers.
Propane Operations
The Company's Florida and Delmarva Peninsula propane distribution operations continue to pursue a multi-pronged growth plan, which includes: targeting retail and wholesale customer growth in existing markets, both organically as well as through acquisitions; incremental growth from recent and planned start-ups in new markets; targeting new community gas systems in high growth areas; further build-out of the Company's propane vehicular platform through AutoGas fueling stations; and optimization of its supply portfolio to generate incremental margin opportunities. As a member of AutoGas, the Company's Delmarva Peninsula propane distribution operations and AutoGas install and support propane vehicle conversion systems for vehicle fleets. The Company's Delmarva Peninsula propane distribution operations continues to convert fleets to bi-fuel propane-powered engines and provides on-site fueling infrastructure.
These operations generated $4.0 million in incremental margin for the three months ended March 31, 2018, compared to the same period in 2017. In addition to increased sales due to more normal weather conditions in the areas served, successful marketing initiatives led to increased volumes sold and revenues from service contracts. Supply management initiatives have increased retail propane margins as well as opportunities to generate incremental margin from wholesale sales.
PESCO
PESCO markets and sells natural gas to wholesale, industrial and commercial customers and manages natural gas storage and transportation assets in several market areas. PESCO also provides management of storage and transportation assets for natural gas producers and regulated utilities. These management transactions typically involve the release of storage and/or transportation capacity in combination with an obligation to purchase and/or deliver natural gas. In April 2017, PESCO entered into 3-year asset management agreements with the Company's Delmarva Peninsula natural gas distribution operations whereby PESCO manages a portion of their natural gas transportation and storage capacity.
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In conjunction with the active management of these contracts, PESCO generates financial margin by identifying market opportunities and simultaneously entering into natural gas purchase/sale, storage or transportation contracts and/or financial derivatives contracts. The financial derivatives contracts consist primarily of exchange-traded futures that are used to manage volatility in natural gas market prices. Volatility in PESCO’s recorded gross margin and operating income can occur over periods of time due to changes in the value of financial derivatives contracts prior to the time of the settlement of the financial derivatives and the purchase or sale of the underlying physical commodity. Derivatives accounting has no impact on economic gains or losses of the purchase or sale contracts. PESCO’s results may also fluctuate based on the actual demand of its customers relative to its initial estimates of their demand, and PESCO's ability to manage its supply portfolio, considering weather and other factors, including pipeline constraints.
For the three months ended March 31, 2018, PESCO's gross margin decreased by $2.3 million compared to the same period in 2017. Lower first quarter 2018 margin from PESCO resulted from the following:
(in thousands) | Margin Impact | ||
PESCO First Quarter 2017 Margin | $ | 3,467 | |
Reversal of fourth quarter 2017 unrealized MTM loss | 5,713 | ||
Margin from 2017 customer Supply Agreement that was not renewed | (2,124 | ) | |
Net impact for the Mid-Atlantic wholesale portfolio from extraordinary costs associated with the 2018 Bomb Cyclone | (3,284 | ) | |
Loss for the Mid-Atlantic retail portfolio caused by capacity constraints in January and warm weather in February | (2,261 | ) | |
Other | (336 | ) | |
PESCO First Quarter 2018 Margin | $ | 1,175 | |
• | Reversal of MTM loss recorded during the fourth quarter of 2017 as contracts settled, as well as $300,000 of unrealized gains at the end of March 31, 2018; |
• | Absence of revenues from a supplier agreement in the first quarter of 2017, which was not renewed; and |
• | Extraordinary costs of meeting demand requirements in the Mid-Atlantic region due to pipeline capacity constraints experienced due to the 2018 Bomb Cyclone, followed by unseasonably warm weather in February. |
The 2018 Bomb Cyclone refers to the early January high intensity winter storms that impacted the Company's Mid-Atlantic service territory and which had a residual impact on the Company's businesses through the month. The early days of January experienced higher levels of wintry precipitation (snow and wind) and an extended period of anomalously cold weather. The extraordinary weather conditions created by the 2018 Bomb Cyclone generated incremental margin for the Company’s natural gas transmission and natural gas and propane distribution businesses. However, the exceedingly high demand and associated pipeline capacity and gas supply in the Delmarva Peninsula region created significant, unusual costs for PESCO. While these circumstances will recur infrequently, the Company's management has taken various steps to mitigate PESCO’s exposure going forward. These mitigation steps resulted in improved results in February and March of 2018.
Xeron
Xeron's operations were wound down during the second quarter of 2017. Operating income for the quarter ended March 31, 2018, improved by $697,000 due to the absence of pre-tax losses generated by Xeron in the first quarter of 2017.
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Capital Investment Growth and Financing Plan
The Company's capital expenditures were $61.2 million for the three months ended March 31, 2018. For 2018, the Company has budgeted capital expenditures of $181.6 million. The following table shows the 2018 capital expenditures budget by segment and business line:
2018 | |||
(dollars in thousands) | |||
Regulated Energy: | |||
Natural gas distribution | $ | 53,899 | |
Natural gas transmission | 92,562 | ||
Electric distribution | 7,972 | ||
Total Regulated Energy | 154,433 | ||
Unregulated Energy: | |||
Propane distribution | 11,235 | ||
Other unregulated energy | 5,827 | ||
Total Unregulated Energy | 17,062 | ||
Other: | |||
Corporate and other businesses | 10,097 | ||
Total Other | 10,097 | ||
Total 2018 Budgeted Capital Expenditures | $ | 181,592 | |
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 first quarter's 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 will issue $100 million of unsecured senior notes in two tranches during 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.
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14-14-14-14
Chesapeake Utilities Corporation and Subsidiaries Condensed Consolidated Statements of Income (Unaudited) (in thousands, except shares and per share data) | |||||||
Three Months Ended | |||||||
March 31, | |||||||
2018 | 2017 | ||||||
Operating Revenues | |||||||
Regulated Energy | $ | 109,393 | $ | 97,654 | |||
Unregulated Energy and other | 129,963 | 87,506 | |||||
Total Operating Revenues | 239,356 | 185,160 | |||||
Operating Expenses | |||||||
Regulated Energy cost of sales | 48,231 | 40,244 | |||||
Unregulated Energy and other cost of sales | 99,826 | 60,754 | |||||
Operations | 32,702 | 32,490 | |||||
Maintenance | 3,593 | 3,231 | |||||
Depreciation and amortization | 9,704 | 8,812 | |||||
Other taxes | 4,894 | 4,530 | |||||
Total operating expenses | 198,950 | 150,061 | |||||
Operating Income | 40,406 | 35,099 | |||||
Other income (expense), net | 68 | (700 | ) | ||||
Interest charges | 3,664 | 2,739 | |||||
Income Before Income Taxes | 36,810 | 31,660 | |||||
Income taxes | 9,955 | 12,516 | |||||
Net Income | $ | 26,855 | $ | 19,144 | |||
Weighted Average Common Shares Outstanding: | |||||||
Basic | 16,351,338 | 16,317,224 | |||||
Diluted | 16,402,985 | 16,363,796 | |||||
Earnings Per Share of Common Stock: | |||||||
Basic | $ | 1.64 | $ | 1.17 | |||
Diluted | $ | 1.64 | $ | 1.17 | |||
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15-15-15-15
Chesapeake Utilities Corporation and Subsidiaries Condensed Consolidated Balance Sheets (Unaudited) | ||||||||
Assets | March 31, 2018 | December 31, 2017 | ||||||
(in thousands, except shares and per share data) | ||||||||
Property, Plant and Equipment | ||||||||
Regulated Energy | $ | 1,083,004 | $ | 1,073,736 | ||||
Unregulated Energy | 213,803 | 210,682 | ||||||
Other businesses and eliminations | 27,892 | 27,699 | ||||||
Total property, plant and equipment | 1,324,699 | 1,312,117 | ||||||
Less: Accumulated depreciation and amortization | (279,802 | ) | (270,599 | ) | ||||
Plus: Construction work in progress | 131,640 | 84,509 | ||||||
Net property, plant and equipment | 1,176,537 | 1,126,027 | ||||||
Current Assets | ||||||||
Cash and cash equivalents | 5,996 | 5,614 | ||||||
Trade and other receivables (less allowance for uncollectible accounts of $901 and $936, respectively) | 69,447 | 77,223 | ||||||
Accrued revenue | 18,907 | 22,279 | ||||||
Propane inventory, at average cost | 7,345 | 8,324 | ||||||
Other inventory, at average cost | 4,607 | 12,022 | ||||||
Regulatory assets | 10,833 | 10,930 | ||||||
Storage gas prepayments | 1,197 | 5,250 | ||||||
Income taxes receivable | 4,378 | 14,778 | ||||||
Prepaid expenses | 8,199 | 13,621 | ||||||
Mark-to-market energy assets | 208 | 1,286 | ||||||
Other current assets | 6,717 | 7,260 | ||||||
Total current assets | 137,834 | 178,587 | ||||||
Deferred Charges and Other Assets | ||||||||
Goodwill | 22,104 | 22,104 | ||||||
Other intangible assets, net | 4,482 | 4,686 | ||||||
Investments, at fair value | 6,641 | 6,756 | ||||||
Regulatory assets | 75,536 | 75,575 | ||||||
Other assets | 4,316 | 3,699 | ||||||
Total deferred charges and other assets | 113,079 | 112,820 | ||||||
Total Assets | $ | 1,427,450 | $ | 1,417,434 | ||||
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16-16-16-16
Chesapeake Utilities Corporation and Subsidiaries Condensed Consolidated Balance Sheets (Unaudited) | ||||||||
Capitalization and Liabilities | March 31, 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) | 7,964 | 7,955 | ||||||
Additional paid-in capital | 254,126 | 253,470 | ||||||
Retained earnings | 250,024 | 229,141 | ||||||
Accumulated other comprehensive loss | (6,873 | ) | (4,272 | ) | ||||
Deferred compensation obligation | 3,573 | 3,395 | ||||||
Treasury stock | (3,573 | ) | (3,395 | ) | ||||
Total stockholders' equity | 505,241 | 486,294 | ||||||
Long-term debt, net of current maturities | 222,014 | 197,395 | ||||||
Total capitalization | 727,255 | 683,689 | ||||||
Current Liabilities | ||||||||
Current portion of long-term debt | 9,389 | 9,421 | ||||||
Short-term borrowing | 229,108 | 250,969 | ||||||
Accounts payable | 57,457 | 74,688 | ||||||
Customer deposits and refunds | 34,795 | 34,751 | ||||||
Accrued interest | 3,256 | 1,742 | ||||||
Dividends payable | 5,318 | 5,312 | ||||||
Accrued compensation | 5,444 | 13,112 | ||||||
Regulatory liabilities | 18,503 | 6,485 | ||||||
Mark-to-market energy liabilities | 2,359 | 6,247 | ||||||
Other accrued liabilities | 8,694 | 10,273 | ||||||
Total current liabilities | 374,323 | 413,000 | ||||||
Deferred Credits and Other Liabilities | ||||||||
Deferred income taxes | 141,484 | 135,850 | ||||||
Regulatory liabilities | 141,346 | 140,978 | ||||||
Environmental liabilities | 8,215 | 8,263 | ||||||
Other pension and benefit costs | 28,981 | 29,699 | ||||||
Deferred investment tax credits and other liabilities | 5,846 | 5,955 | ||||||
Total deferred credits and other liabilities | 325,872 | 320,745 | ||||||
Total Capitalization and Liabilities | $ | 1,427,450 | $ | 1,417,434 | ||||
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17-17-17-17
Chesapeake Utilities Corporation and Subsidiaries Distribution Utility Statistical Data (Unaudited) | ||||||||||||||||||||||||||||||||
For the Three Months Ended March 31, 2018 | For the Three Months Ended March 31, 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 | $ | 35,314 | $ | 1,761 | $ | 11,182 | $ | 11,533 | $ | 25,710 | $ | 1,552 | $ | 10,768 | $ | 9,327 | ||||||||||||||||
Commercial | 15,830 | 1,722 | 8,331 | 9,157 | 11,412 | 1,523 | 9,594 | 9,414 | ||||||||||||||||||||||||
Industrial | 2,306 | 1,871 | 6,536 | 400 | 1,834 | 1,759 | 5,927 | 471 | ||||||||||||||||||||||||
Other (1) | (1,743 | ) | 510 | (2,836 | ) | (2,349 | ) | 1,458 | 900 | (2,785 | ) | (1,589 | ) | |||||||||||||||||||
Total Operating Revenues | $ | 51,707 | $ | 5,864 | $ | 23,213 | $ | 18,741 | $ | 40,414 | $ | 5,734 | $ | 23,504 | $ | 17,623 | ||||||||||||||||
Volume (in Dts for natural gas and MWHs for electric) | ||||||||||||||||||||||||||||||||
Residential | 2,240,555 | 140,759 | 523,062 | 78,528 | 1,807,900 | 123,275 | 470,811 | 61,326 | ||||||||||||||||||||||||
Commercial | 1,705,426 | 1,239,936 | 535,544 | 67,740 | 1,381,408 | 2,957,716 | 601,203 | 65,862 | ||||||||||||||||||||||||
Industrial | 1,509,039 | 2,334,243 | 1,304,530 | 4,520 | 1,373,798 | 1,767,430 | 1,189,263 | 3,160 | ||||||||||||||||||||||||
Other | 12,533 | — | 468,556 | 1,896 | 10,538 | — | 487,910 | 1,873 | ||||||||||||||||||||||||
Total | 5,467,553 | 3,714,938 | 2,831,692 | 152,684 | 4,573,644 | 4,848,421 | 2,749,187 | 132,221 | ||||||||||||||||||||||||
Average Customers | ||||||||||||||||||||||||||||||||
Residential | 71,233 | 16,223 | 55,280 | 24,644 | 68,701 | 15,664 | 54,041 | 24,437 | ||||||||||||||||||||||||
Commercial(2) | 7,024 | 1,460 | 3,927 | 7,481 | 6,910 | 1,409 | 4,892 | 7,446 | ||||||||||||||||||||||||
Industrial(2) | 153 | 73 | 2,251 | 2 | 142 | 75 | 1,109 | 2 | ||||||||||||||||||||||||
Other | 6 | — | 17 | — | 5 | — | — | — | ||||||||||||||||||||||||
Total | 78,416 | 17,756 | 61,475 | 32,127 | 75,758 | 17,148 | 60,042 | 31,885 | ||||||||||||||||||||||||
(1) | Operating Revenues from "Other" sources include unbilled revenue, under (over) recoveries of fuel cost, conservation revenue, other miscellaneous charges, fees for billing services provided to third parties, and adjustments for pass-through taxes. 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. |