Utility Plant

12 Months Ended

Dec. 31, 2021

The following table presents electric, natural gas and common utility plant classified by account:


		Puget Energy				Puget Sound Energy
Utility Plant	Estimated Useful Life	December 31,				December 31,
(Dollars in Thousands)	(Years)	2021		2020		2021		2020
Distribution plant	20-65	$	7,488,629	$	7,028,731	$	9,026,042	$	8,592,720
Production plant	12-90	3,147,987		3,096,092		3,815,599		3,767,014
Transmission plant	43-75	1,556,666		1,494,781		1,663,559		1,601,731
General plant	5-75	746,758		697,501		773,662		726,327
Intangible plant (including capitalized software)1	3-50	797,691		779,767		788,240		770,317
Plant acquisition adjustment	N/A	242,826		242,826		282,792		282,792
Underground storage	25-60	43,391		39,498		56,820		52,927
Liquefied natural gas storage	25-60	12,628		12,628		14,498		14,498
Plant held for future use	N/A	46,020		45,929		46,172		46,081
Recoverable Cushion Gas	N/A	8,655		8,655		8,655		8,655
Plant not classified	N/A	316,933		384,794		316,933		384,794
Finance leases, net of accumulated amortization2	N/A	105,020		881		105,020		881
Less: accumulated provision for depreciation		(4,031,458)		(3,671,094)		(6,416,246)		(6,087,748)
Subtotal		$	10,481,746	$	10,160,989	$	10,481,746	$	10,160,989
Construction work in progress		870,204		712,204		870,204		712,204
Net utility plant		$	11,351,950	$	10,873,193	$	11,351,950	$	10,873,193

_______________________

1.Intangible assets include capitalized software and franchise agreements with useful lives ranging between 3-10 years and 10-50 years, respectively.

2.At December 31, 2021, and 2020, accumulated amortization of finance leases at Puget Energy and PSE was $2.6 million and $1.6 million, respectively.

Jointly owned generating plant service costs are included in utility plant service cost at the Company's ownership share. The Company provides financing for its ownership interest in the jointly owned utility plants. The following tables indicate the Company’s percentage ownership and the extent of the Company’s investment in jointly owned generating plants in service at December 31, 2021. These amounts are also included in the Utility Plant table above. The Company's share of fuel costs and operating expenses for plant in service are included in the corresponding accounts in the Consolidated Statements of Income.


Puget Energy
Jointly Owned Generating Plants (Dollars in Thousands)	Energy Source (Fuel)	Company’s Ownership Share	Plant in Service at Cost		Construction Work in Progress		Accumulated Depreciation

Colstrip Units 3 & 4	Coal	25.00%	$	339,073	$	—	$	(153,950)
Frederickson 1	Natural Gas	49.85	63,210		—		(18,215)
Jackson Prairie	Natural Gas	33.34	42,736		471		(10,867)
Tacoma LNG	Natural Gas	various	—		484,299		—


Puget Sound Energy
Jointly Owned Generating Plants (Dollars in Thousands)	Energy Source (Fuel)	Company’s Ownership Share	Plant in Service at Cost		Construction Work in Progress		Accumulated Depreciation

Colstrip Units 3 & 4	Coal	25.00 %	$	597,009	$	—	$	(411,887)
Frederickson 1	Natural Gas	49.85	69,278		—		(24,283)
Jackson Prairie	Natural Gas	33.34	56,820		471		(24,952)
Tacoma LNG	Natural Gas	various	—		239,566		—

In June 2019, Talen, the plant operator of Colstrip Units 1 and 2, announced a plan to shut down as of December 31, 2019. The Company retired Colstrip 1&2 from Utility Plant and transferred the unrecovered plant amount of $126.5 million to regulatory assets, offset by depreciation as included in base rates until the 2019 GRC became effective in October 2020. Consistent with the GRC settlement in 2017, monetization of the PTCs will fund the following: (i) Colstrip Community Transition Fund, (ii) unrecovered Colstrip plant and (iii) incurred decommissioning and remediation costs for Colstrip. At December 31, 2021, and December 31, 2020, the unrecovered plant for Colstrip 1&2 was fully offset with PTCs.

Asset Retirement Obligation

The Company has recorded liabilities for steam generation sites, combustion turbine generation sites, wind generation sites, distribution and transmission poles, natural gas mains, liquefied natural gas storage sites, and leased facilities where disposal is governed by ASC 410-20 “Asset Retirement and Environmental Obligations" (ARO). The Company records its ARO liabilities for its electric transmission and distribution poles as well as gas distribution mains aligned with its underlying asset data with future estimates of retirements.

On April 17, 2015, the EPA published a final rule, effective October 19, 2015, that regulates Coal Combustion Residuals (CCR) under the Resource Conservation and Recovery Act, Subtitle D. The CCR rule requires the Company to perform an extensive study on the effects of coal ash on the environment and public health. The rule addresses the risks from coal ash disposal, such as leaking of contaminants into ground water, blowing of contaminants into the air as dust, and the catastrophic failure of coal ash surface impoundments.

The CCR rule and two legal agreements which include a consent decree with the Sierra Club and a settlement agreement with the Sierra Club and the National Wildlife Federation in 2016 made changes to the Company’s Colstrip operations, which were reviewed by the Company and the plant operator in 2015 and 2016. PSE had previously recognized a legal obligation in 2003 under the EPA rules to dispose of coal ash material at Colstrip.

The actual ARO costs related to the CCR rule requirements may vary substantially from the estimates used to record the increased obligation due to uncertainty about the compliance strategies that will be used and the preliminary nature of available data used to estimate costs. We will continue to gather additional data and coordinate with the plant operator to make decisions about compliance strategies and the timing of closure activities. As additional information becomes available, the Company will update the ARO obligation for these changes, which could be material.

For the twelve months ended December 31, 2021, the Company reviewed the estimated remediation costs at Colstrip and decreased the Colstrip ARO liability by $1.5 million for Colstrip Units 1 and 2 and $3.1 million for Colstrip Units 3 and 4. The 2021 decrease to Colstrip 1 and 2 is primarily due to remediation plans approved by the Montana Department of Environmental Quality under a 2012 settlement between the plant operator and the state for the remaining sites at Colstrip. The plant operator previously contested the approved plan for Colstrip Units 1 and 2 under the defined process in the settlement with the state and reached a settlement agreement regarding the ability to still present another option under the settlement terms and conditions. The Company had previously recorded these incremental costs in 2020 for remediation work on the older ponds under ASC 410-20 “Asset Retirement and Environmental Obligations" and ASC 410-30 “Environmental Remediation". For the twelve months ended December 31, 2020, the Company reviewed the estimated remediation costs at Colstrip and increased the Colstrip ARO liability by $29.7 million for Colstrip Units 1 and 2, and $2.0 million for Colstrip Units 3 and 4. The environmental remediation liability for Colstrip Units 1 and 2 increased $39.0 million during the same period. The 2020 increase to these Colstrip related liabilities is primarily due to remediation plans approved by the Montana Department of Environmental Quality under a 2012 settlement between the plant operator and the state for the remaining sites at Colstrip. For the twelve months ended December 31, 2021 and 2020, the Company also recorded relief of ARO and environmental remediation liability of $13.1 million and $9.6 million, respectively.

In addition, the Company recorded Tacoma LNG facility ARO liability of $3.8 million and $3.3 million for PSE and $3.7 million and $7.4 million for Puget LNG as of December 31, 2021 and December 31, 2020, respectively. The 2021 and 2020 increases to the Tacoma LNG facility ARO liabilities are primarily due to continued construction of the plant. In 2021, the ARO liability associated with the Tacoma LNG facility was fully recorded as construction was essentially complete and commissioning activities are on-going.


Puget Energy and Puget Sound Energy	December 31,
(Dollars in Thousands)	2021		2020
Asset retirement obligation at beginning of the period	$	216,163	$	181,353

Relief of liability	(13,146)		(9,647)
Revisions in estimated cash flows	(46)		38,677
Accretion expense	6,070		5,780
Asset retirement obligation at end of period1	$	209,041	$	216,163

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1.Asset retirement obligations include $3.7 million and $7.4 million for Puget LNG held only at Puget Energy as of December 31, 2021, and 2020, respectively.

The Company has identified the following obligations, as defined by ASC 410, “ARO,” which were not recognized because the liability for these assets cannot be reasonably estimated at December 31, 2021:

•A legal obligation under Federal Dangerous Waste Regulations to dispose of asbestos-containing material in facilities that are not scheduled for remodeling, demolition or sales. The disposal cost related to these facilities could not be measured since the retirement date is indeterminable; therefore, the liability cannot be reasonably estimated;

•An obligation under Washington state law to decommission the wells at the Jackson Prairie natural gas storage facility upon termination of the project. Since the project is expected to continue as long as the Northwest pipeline continues to operate, the liability cannot be reasonably estimated;

•An obligation to pay its share of decommissioning costs at the end of the functional life of the major transmission lines. The major transmission lines are expected to be used indefinitely; therefore, the liability cannot be reasonably estimated;

•A legal obligation under Washington state environmental laws to remove and properly dispose of certain under and above ground fuel storage tanks. The disposal costs related to under and above ground storage tanks could not be measured since the retirement date is indeterminable; therefore, the liability cannot be reasonably estimated;

•An obligation to pay decommissioning costs at the end of utility service franchise agreements to restore the surface of the franchise area. The decommissioning costs related to facilities at the franchise area could not be measured since the decommissioning date is indeterminable; therefore, the liability cannot be reasonably estimated; and

•A potential legal obligation may arise upon the expiration of an existing FERC hydropower license if the FERC orders the project to be decommissioned, although PSE contends that the FERC does not have such authority. Given the value of ongoing generation, flood control and other benefits provided by these projects, PSE believes that the potential for decommissioning is remote and cannot be reasonably estimated.