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Rates and Other Regulatory Activities | 3 Months Ended
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Mar. 31, 2022
Regulated Operations [Abstract] |
Public Utilities Disclosure [Text Block] | Rates and Other Regulatory Activities Our natural gas and electric distribution operations in Delaware, Maryland and Florida are subject to regulation by their respective PSC; Eastern Shore, our natural gas transmission subsidiary, is subject to regulation by the FERC; and Peninsula Pipeline and Aspire Energy Express, our intrastate pipeline subsidiaries, are subject to regulation (excluding cost of service) by the Florida PSC and Public Utilities Commission of Ohio, respectively. Delaware See the discussion below under COVID-19 impact. Maryland Ocean City Maryland Reinforcement: In March 2022, we filed a Section 7(f) - Request for Service Area Determination with the FERC regarding plans to extend our natural gas facilities across the Delaware/Maryland state line from Sussex County, Delaware, to Worcester County, Maryland, to provide a secondary feed to Sandpiper Energy, Inc.'s (Sandpiper) system. We anticipate resolution of this filing in the second quarter of 2022. Strategic Infrastructure Development and Enhancement (“STRIDE”) Plan: In March 2021, Elkton Gas filed a strategic infrastructure development and enhancement plan with the Maryland PSC. The STRIDE plan accelerates Elkton Gas' Aldyl-A pipeline replacement program as costs of the plan are recovered through a fixed charge rider which is effective for five years. Under Elkton Gas’ STRIDE plan, the Aldyl-A pipelines will be fully replaced by 2023. In July 2021, Elkton Gas reached a settlement with the Maryland PSC Staff and the Maryland Office of Public Counsel that approved Elkton Gas’ STRIDE plan. The STRIDE plan allows for recovery of the associated revenue requirement through a monthly surcharge, which was implemented effective September 2021. Florida Winter Haven Expansion Project: In May 2021, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with CFG for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area. As part of this agreement, Peninsula Pipeline will construct a new interconnect with FGT and a new regulator station for CFG. CFG will use the additional firm service to support new incremental load due to growth, including providing service to a new can manufacturing facility, as well as provide reliability and operational benefits to CFG’s existing distribution system in the area. In connection with Peninsula Pipeline’s new regulator station, CFG is also extending its distribution system to connect to the new station. The Transportation Service Agreement was approved by the Florida PSC in September 2021. Construction commenced in February 2021 and the expected in-service date is the second quarter of 2022. Beachside Pipeline Extension: In June 2021, Peninsula Pipeline and Florida City Gas entered into a Transportation Service Agreement for an incremental 10,176 Dts/d of firm service in Indian River County, Florida, to support Florida City Gas’ growth along the Indian River's barrier island. As part of this agreement, Peninsula Pipeline will construct 11.3 miles of pipeline from its existing pipeline in the Sebastian, Florida area, which will travel east under the Intercoastal Waterway ("ICW") and southward on the barrier island. As required by Peninsula Pipeline’s tariff and Florida Statutes, Peninsula Pipeline filed the required company and customer affidavits with the Florida PSC in June 2021. Construction commenced in June 2021 and the expected in-service date is early 2023. Eastern Shore Southern Expansion Project: In January 2022, Eastern Shore submitted a prior notice filing with the FERC pursuant to blanket certificate procedures, regarding its proposal to install an additional compressor unit and related facilities at Eastern Shore's existing compressor station in Bridgeville, Sussex County, Delaware. The project will enable Eastern Shore to provide additional firm natural gas transportation service to an existing shipper on Eastern Shore's pipeline system, with a projected in-service date by November 2022. We are currently in the midst of the comment and protest phase of the filing of the application process. Capital Cost Surcharge: In June 2021, Eastern Shore submitted a filing with the FERC regarding a capital cost surcharge to recover capital costs associated with two mandated highway relocate projects that required the replacement of existing Eastern Shore facilities. The capital cost surcharge was an approved item in Eastern Shore’s last rate case. In conjunction with the filing of this surcharge, pursuant to the settlement agreement, a cumulative adjustment to the existing surcharge to reflect additional depreciation was included in this filing. The FERC issued an order approving the surcharge as filed on July 7, 2021. The combined revised surcharge became effective July 15, 2021. COVID-19 Impact In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and continued to impact economic conditions, to a lesser extent, through 2021. Chesapeake Utilities is considered an “essential business,” which allowed us to continue operational activities and construction projects with appropriate safety precautions and personal protective equipment, while being mindful of the social distancing restrictions that were in place. In response to the COVID-19 pandemic and related restrictions, we experienced reduced consumption of energy largely in the commercial and industrial sectors, higher bad debt expenses and incremental expenses associated with COVID-19, including expenditures associated with personal protective equipment and premium pay for field personnel. The additional operating expenses we incurred supported the ongoing delivery of our essential services during these unprecedented times. In April and May 2020, we were authorized by the Maryland and Delaware PSCs, respectively, to record regulatory assets for COVID-19 related costs which offers us the ability to seek recovery of those costs. In July 2021, the Florida PSC issued an order that approved incremental expenses we incurred due to COVID-19. The order allowed us to establish a regulatory asset in a total amount of $2.1 million as of June 30, 2021 for natural gas and electric distribution operations. The regulatory asset is amortized over two years and is recovered through the Purchased Gas Adjustment and Swing Service mechanisms for our natural gas distribution businesses and through the Fuel Purchased Power Cost Recovery clause for our electric division. As of March 31, 2022 and December 31, 2021, our total COVID-19 regulatory asset balance was $2.0 million and $2.3 million, respectively. In 2021 and 2022, restrictions were gradually lifted as vaccines became widely available in the United States. The various state of emergencies associated with the COVID-19 pandemic that were previously declared in our service territories have been terminated and we have adjusted our operating practices accordingly to ensure the safety of our operations and will take the necessary actions to comply with the CDC, and the Occupational Safety and Health Administration, as new developments occur. Summary TCJA Table Customer rates for our regulated businesses were adjusted as approved by the regulators, prior to 2020 with the exception of Elkton Gas, which implemented a one-time bill credit in May 2020. The following table summarizes the regulatory liabilities related to accumulated deferred taxes ("ADIT") associated with TCJA for our regulated businesses as of March 31, 2022 and December 31, 2021:
|  | Amount (in thousands) |  |
Operation and Regulatory Jurisdiction |  | March 31, 2022 | December 31, 2021 | Status |
Eastern Shore (FERC) |  | $34,190 | $34,190 | Will be addressed in Eastern Shore's next rate case filing. |
Delaware Division (Delaware PSC) |  | $12,551 | $12,591 | PSC approved amortization of ADIT in January 2019. |
Maryland Division (Maryland PSC) |  | $3,806 | $3,840 | PSC approved amortization of ADIT in May 2018. |
Sandpiper Energy (Maryland PSC) |  | $3,641 | $3,656 | PSC approved amortization of ADIT in May 2018. |
Chesapeake Florida Gas Division/Central Florida Gas (Florida PSC) |  | $7,986 | $8,032 | PSC issued order authorizing amortization and retention of net ADIT liability by the Company in February 2019. |
FPU Natural Gas (excludes Fort Meade and Indiantown) (Florida PSC) |  | $19,086 | $19,189 | Same treatment on a net basis as Chesapeake Florida Gas Division (above). |
FPU Fort Meade and Indiantown Divisions (Florida PSC) |  | $268 | $271 | Same treatment on a net basis as Chesapeake Florida Gas Division (above). |
FPU Electric (Florida PSC) |  | $5,176 | $5,237 | In January 2019, PSC issued order approving amortization of ADIT through purchased power cost recovery, storm reserve and rates. |
Elkton Gas (Maryland PSC) |  | $1,091 | $1,091 | PSC approved amortization of ADIT in March 2018. |

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