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Note 1 - Summary of Significant Accounting Policies | 12 Months Ended
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Dec. 31, 2019
Notes to Financial Statements |
Significant Accounting Policies and New Accounting Pronouncements [Text Block] | 1. Summary of Significant Accounting Policies Principles of Consolidation The consolidated financial statements of Otter Tail Corporation and its wholly owned subsidiaries (the Company) include the accounts of the following segments: Electric, Manufacturing and Plastics. See note 2 to consolidated financial statements for further descriptions of the Company’s business segments. All intercompany balances and transactions have been eliminated in consolidation except profits on sales to the regulated electric utility company from nonregulated affiliates, which is in accordance with the requirements of Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980, Regulated Operations (ASC 980). Regulation and ASC 980 The Company’s regulated electric utility company, Otter Tail Power Company (OTP), accounts for the financial effects of regulation in accordance with ASC 980. This standard allows for the recording of a regulatory asset or liability for costs and revenues that will be collected or refunded through the ratemaking process in the future. In accordance with regulatory treatment, OTP defers utility debt redemption premiums and amortizes such costs over the original life of the reacquired bonds. See note 4 to consolidated financial statements for further discussion. OTP is subject to various state and federal agency regulations. The accounting policies followed by this business are subject to the Uniform System of Accounts of the Federal Energy Regulatory Commission (FERC). These accounting policies differ in some respects from those used by the Company’s nonelectric businesses. Plant, Retirements and Depreciation Utility plant is stated at original cost. The cost of additions includes contracted work, direct labor and materials, allocable overheads and allowance for funds used during construction. The amount of interest capitalized on electric utility plant was $1,728,000 in 2019, $1,206,000 in 2018 and $741,000 in 2017. The cost of depreciable units of property retired less salvage is charged to accumulated depreciation. Removal costs, when incurred, are charged against the accumulated reserve for estimated removal costs, a regulatory liability. Maintenance, repairs and replacement of minor items of property are charged to operating expenses. The provisions for utility depreciation for financial reporting purposes are made on the straight-line method based on the estimated remaining service lives of the properties (5 to 82 years). Such provisions as a percent of the average balance of depreciable electric utility property were 2.81% in 2019, 2.76% in 2018 and 2.74% in 2017. Gains or losses on group asset dispositions are taken to the accumulated provision for depreciation reserve and impact current and future depreciation rates. Property and equipment of nonelectric operations are carried at historical cost or at fair value if acquired in a business combination and are depreciated on a straight-line basis over the assets’ estimated useful lives (2 to 40 years). The cost of additions includes contracted work, direct labor and materials, allocable overheads and capitalized interest. No interest was capitalized on nonelectric plant in 2019, 2018 or 2017. Maintenance and repairs are expensed as incurred. Gains or losses on asset dispositions are included in the determination of operating income. Recoverability of Long-Lived Assets The Company reviews its long-lived assets whenever events or changes in circumstances indicate the carrying amount of the assets may not be recoverable. The Company determines potential impairment by comparing the carrying amount of the assets with net cash flows expected to be provided by operating activities of the business or related assets. If the sum of the expected future net cash flows is less than the carrying amount of the assets, the Company would recognize an impairment loss. Such an impairment loss would be measured as the amount by which the carrying amount exceeds the fair value of the asset, where fair value is based on the discounted cash flows expected to be generated by the asset. Jointly Owned Facilities OTP is a joint owner in two coal-fired steam-powered electric generation plants: Big Stone Plant near Big Stone City, South Dakota and Coyote Station near Beulah, North Dakota. OTP is also a joint owner, with other regional utilities, in five major transmission lines. The following table provides OTP’s ownership percentages and amounts included in the Company’s December 31, 2019 and 2018 consolidated balance sheets for OTP’s share of jointly owned assets in each of these jointly owned facilities:
Jointly Owned Facilities (dollars in thousands) |  | OTP Ownership Percentage |  |  | Electric Plant in Service |  |  | Construction Work in Progress |  |  | Accumulated Depreciation |  |  | Net Plant |
December 31, 2019 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Big Stone Plant |  |  | 53.9 | % |  | $ | 337,197 |  |  | $ | 384 |  |  | $ | (98,654 | ) |  | $ | 238,927 |
Coyote Station |  |  | 35.0 | % |  |  | 184,493 |  |  |  | 83 |  |  |  | (108,248 | ) |  |  | 76,328 |
Big Stone South–Ellendale 345 kV line1 |  |  | 50.0 | % |  |  | 106,343 |  |  |  | - |  |  |  | (819 | ) |  |  | 105,524 |
Fargo–Monticello 345 kV line |  |  | 14.2 | % |  |  | 78,184 |  |  |  | - |  |  |  | (7,011 | ) |  |  | 71,173 |
Big Stone South–Brookings 345 kV line |  |  | 50.0 | % |  |  | 53,036 |  |  |  | - |  |  |  | (2,016 | ) |  |  | 51,020 |
Brookings–Southeast Twin Cities 345 kV line |  |  | 4.8 | % |  |  | 26,286 |  |  |  | - |  |  |  | (2,086 | ) |  |  | 24,200 |
Bemidji–Grand Rapids 230 kV line |  |  | 14.8 | % |  |  | 16,331 |  |  |  | - |  |  |  | (233 | ) |  |  | 16,098 |
December 31, 2018 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Big Stone Plant |  |  | 53.9 | % |  | $ | 336,051 |  |  | $ | 361 |  |  | $ | (92,007 | ) |  | $ | 244,405 |
Coyote Station |  |  | 35.0 | % |  |  | 177,713 |  |  |  | 2,588 |  |  |  | (100,997 | ) |  |  | 79,304 |
Big Stone South–Ellendale 345 kV line1 |  |  | 50.0 | % |  |  | - |  |  |  | 106,490 |  |  |  | - |  |  |  | 106,490 |
Fargo–Monticello 345 kV line |  |  | 14.2 | % |  |  | 78,184 |  |  |  | - |  |  |  | (5,891 | ) |  |  | 72,293 |
Big Stone South–Brookings 345 kV line |  |  | 50.0 | % |  |  | 53,235 |  |  |  | (150 | ) |  |  | (1,264 | ) |  |  | 51,821 |
Brookings–Southeast Twin Cities 345 kV line |  |  | 4.8 | % |  |  | 26,281 |  |  |  | - |  |  |  | (1,713 | ) |  |  | 24,568 |
Bemidji–Grand Rapids 230 kV line |  |  | 14.8 | % |  |  | 16,331 |  |  |  | - |  |  |  | (2,091 | ) |  |  | 14,240 |
1Midcontinent Independent System Operator, Inc. (MISO) Multi-Value Project (MVP) designation provides for a return on invested funds while under construction under the MISO Open Access Transmission, Energy and Operating Reserve Markets Tariff (MISO Tariff). The Company’s share of direct revenue and expenses of the jointly owned facilities is included in operating revenue and expenses in the consolidated statements of income. Coyote Station Lignite Supply Agreement – Variable Interest Entity In October 2012 the Coyote Station owners, including OTP, entered into a lignite sales agreement (LSA) with Coyote Creek Mining Company, L.L.C. (CCMC), a subsidiary of The North American Coal Corporation, for the purchase of lignite coal to meet the coal supply requirements of Coyote Station for the period beginning in May 2016 and ending in December 2040. The price per ton paid by the Coyote Station owners under the LSA reflects the cost of production, along with an agreed profit and capital charge. CCMC was formed for the purpose of mining coal to meet the coal fuel supply requirements of Coyote Station from May 2016 through December 2040 and, based on the terms of the LSA, is considered a variable interest entity (VIE) due to the transfer of all operating and economic risk to the Coyote Station owners, as the agreement is structured so that the price of the coal would cover all costs of operations as well as future reclamation costs. The Coyote Station owners are required to buy certain assets of CCMC at book value should they terminate the contract prior to the end of the contract term and are providing a guarantee of the value of the equity of CCMC because the Coyote Station owners are required to buy the membership interests of CCMC at the end of the contract term at equity value. Under current accounting standards, the primary beneficiary of a VIE is required to include the assets, liabilities, results of operations and cash flows of the VIE in its consolidated financial statements. No single owner of Coyote Station owns a majority interest in Coyote Station and none, individually, has the power to direct the activities that most significantly impact CCMC. Therefore, none of the owners individually, including OTP, is considered a primary beneficiary of the VIE and the Company is not required to include CCMC in its consolidated financial statements. If the LSA terminates prior to the expiration of its term or the production period terminates prior to December 31, 2040 and the Coyote Station owners purchase all of the outstanding membership interests of CCMC, the owners will satisfy (or if permitted by CCMC’s applicable lenders assume) all of CCMC’s obligations owed to CCMC’s lenders under its loans and leases. The Coyote Station owners have limited rights to assign their rights and obligations under the LSA without the consent of CCMC’s lenders during any period in which CCMC’s obligations to its lenders remain outstanding. In the event the contract is terminated prior to the end of the term due to certain events, OTP’s maximum exposure to additional costs, as a result of its involvement with CCMC, and potential impairment loss if recovery of those costs is denied by regulatory authorities, could be as high as $50.4 million, OTP’s 35% share of CCMC’s unrecovered costs as of December 31, 2019. Income Taxes Comprehensive interperiod income tax allocation is used for substantially all book and tax temporary differences. Deferred income taxes arise for all temporary differences between the book and tax basis of assets and liabilities. Deferred taxes are recorded using the tax rates scheduled by tax law to be in effect in the periods when the temporary differences reverse. The Company amortizes investment tax credits over the estimated lives of related property. The Company records income taxes in accordance with ASC Topic 740, Income Taxes, and has recognized in its consolidated financial statements the tax effects of all tax positions that are “more-likely-than-not” to be sustained on audit based solely on the technical merits of those positions as of the balance sheet date. The term “more-likely-than-not” means a likelihood of more than 50%. The Company classifies interest and penalties on tax uncertainties as components of the provision for income taxes. See note 14 to consolidated financial statements regarding the Company’s accounting for uncertain tax positions. The Company also is required to assess the realizability of its deferred tax assets, taking into consideration the Company’s forecast of future taxable income, the reversal of other existing temporary differences, available net operating loss carryforwards and available tax planning strategies that could be implemented to realize the deferred tax assets. Based on this assessment, management must evaluate the need for, and amount of, valuation allowances against the Company’s deferred tax assets. To the extent facts and circumstances change in the future, adjustments to the valuation allowance may be required. Revenue Recognition In May 2014 the FASB issued a major update to the ASC, Accounting Standards Update (ASU) 2014-09, Revenue from Contracts with Customers (Topic 606) (ASC 606). The Company adopted the updates in ASC 606 effective January 1, 2018 on a modified retrospective basis but did not record a cumulative effect adjustment to retained earnings on application of the updates because the adoption of the updates in ASC 606 had no material impact on the timing of revenue recognition for the Company or its subsidiaries. ASC 606 is a comprehensive, principles-based accounting standard which amended previous revenue recognition guidance with the objective of improving revenue recognition requirements by providing a single comprehensive model to determine the measurement of revenue and the timing of revenue recognition. ASC 606 requires expanded disclosures to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. Due to the diverse business operations of the Company, recognition of revenue from contracts with customers depends on the product produced and sold or service performed. The Company recognizes revenue from contracts with customers, at prices that are fixed or determinable as evidenced by an agreement with the customer, when the Company has met its performance obligation under the contract and it is probable that the Company will collect the amount to which it is entitled in exchange for the goods or services transferred or to be transferred to the customer. Depending on the product produced and sold or service performed and the terms of the agreement with the customer, the Company recognizes revenue either over time, in the case of delivery or transmission of electricity or related services or the production and storage of certain custom-made products, or at a point in time for the delivery of standardized products and other products made to the customers specifications where the terms of the contract require transfer of the completed product. Provisions for sales returns, early payment terms discounts, volume-based variable pricing incentives and warranty costs are recorded as reductions to revenue at the time revenue is recognized based on customer history, historical information and current trends. In addition to recognizing revenue from contracts with customers under ASC 606, the Company also records adjustments to Electric segment revenues for amounts subject to future collection under alternative revenue programs (ARPs) as defined in ASC 980. The ARP revenue adjustments are recorded on the basis of recoverable costs incurred and returns earned under rate riders on a separate line on the face of the Company’s consolidated statements of income as they do not meet the criteria to be classified as revenue from contracts with customers. Electric Segment Revenues—In the Electric segment, the Company recognizes revenue in two categories: (1) revenues from contracts with customers and (2) adjustments to revenues for amounts collectible under ARPs. Most Electric segment revenues are earned from the generation, transmission and sale of electricity to retail customers at rates approved by regulatory commissions in the states where OTP provides service. OTP also earns revenue from the transmission of electricity for others over the transmission assets it owns separately, or jointly with other transmission service providers, under rate tariffs established by the independent transmission system operator and approved by the FERC. A third source of revenue for OTP comes from the generation and sale of electricity to wholesale customers at contract or market rates. Revenues from all these sources meet the criteria to be classified as revenue from contracts with customers and are recognized over time as energy is delivered or transmitted. Revenue is recognized based on the metered quantity of electricity delivered or transmitted at the applicable rates. For electricity delivered and consumed after a meter is read but prior to the end of the reporting period, OTP records revenue and an unbilled receivable based on estimates of the kilowatt-hours (kwh) of energy delivered to the customer. ARPs provide for adjustments to rates outside of a general rate case proceeding, usually as a surcharge applied to future billings typically through the use of rate riders subject to periodic adjustments, to encourage or incentivize investments in certain areas such as conservation, renewable energy, pollution reduction or control, improved infrastructure of the transmission grid or other programs that provide benefits to the general public under public policy, laws or regulations. ARP riders generally provide for the recovery of specified costs and investments and include an incentive component to provide the regulated utility with a return on amounts invested. OTP has recovered costs and earned incentives or returns on investments subject to recovery under several ARP rate riders, including:
| ● | In Minnesota: Transmission Cost Recovery (TCR), Environmental Cost Recovery (ECR), Renewable Resource Adjustment (RRA), Energy Intensive Trade Exposed and Conservation Improvement Program riders.
| ● | In North Dakota: TCR, ECR, RRA and Generation Cost Recovery (GCR) riders.
| ● | In South Dakota: TCR, ECR, Phase-in Rate Plan and Energy Efficiency Plan (conservation) riders.
OTP accrues ARP revenue on the basis of costs incurred, investments made and returns on those investments that qualify for recovery through established riders. Amounts billed under riders in effect at the time of the billing are included in revenues from contracts with customers net of amounts billed that are subject to refund through future rider adjustments. Amounts accrued and subject to recovery through future rider rate updates and adjustments are reported as changes in accrued revenues under ARPs on a separate line in the revenue section of the Company’s consolidated statement of income. See table in note 3 to consolidated financial statements for total revenues billed and accrued under ARP riders for the years ended December 31, 2019, 2018 and 2017. Manufacturing Segment Revenues—Companies in the Manufacturing segment, BTD Manufacturing, Inc. (BTD) and T.O. Plastics, Inc. (T.O. Plastics), earn revenue predominantly from the production and delivery of custom-made or standardized parts to customers across several industries. BTD also earns revenue from the production and sale of tools and dies to other manufacturers. For the production and delivery of standardized products and other products made to customer specifications where the terms of the contract require transfer of the completed product, the operating company has met its performance obligation and recognizes revenue at the point in time when the product is shipped. For revenue recognized on products when shipped, the operating companies have no further obligation to provide services related to such products. The shipping terms used in these instances are FOB shipping point. Plastics Segment Revenues—Companies in our Plastics segment earn revenue predominantly from the sale and delivery of standardized polyvinyl chloride (PVC) pipe products produced at their manufacturing facilities. Revenue from the sale of these products is recognized at the point in time when the product is shipped based on prices agreed to in a purchase order. For revenue recognized on shipped products, there is no further obligation to provide services related to such products. The shipping terms used in these instances are FOB shipping point. The Plastics segment has one customer for which it produces and stores a product made to the customer’s specifications and design under a build and hold agreement. For sales to this customer, the operating company recognizes revenue as the custom-made product is produced, adjusting the amount of revenue for volume rebate variable pricing considerations the operating company expects the customer will earn and applicable early payment discounts the company expects the customer will take. Ownership of the pipe transfers to the customer prior to delivery and the operating company is paid a negotiated fee for storage of the pipe. Revenue for storage of the pipe is also recognized over time as the pipe is stored. See operating revenue table in note 2 to consolidated financial statements for a disaggregation of the Company’s revenues by business segment for the years ended December 31, 2019, 2018 and 2017. Agreements Subject to Legally Enforceable Netting Arrangements OTP has certain derivative contracts that are designated as normal purchases. Individual counterparty exposures for these contracts can be offset according to legally enforceable netting arrangements. The Company does not offset assets and liabilities under legally enforceable netting arrangements on the face of its consolidated balance sheet. Warranty Reserves Certain products sold by the Company’s manufacturing and plastics companies carry product warranties for one year after the shipment date. These companies’ standard product warranty terms generally include post-sales support and repairs or replacement of a product at no additional charge for a specified period of time. While these companies engage in extensive product quality programs and processes, including actively monitoring and evaluating the quality of their component suppliers, they base their estimated warranty obligations on warranty terms, ongoing product failure rates, repair costs, product call rates, average cost per call, and current period product shipments. The Company’s manufacturing and plastics companies have not incurred any significant warranty costs over the last three fiscal years. Shipping and Handling Costs The Company includes revenues received for shipping and handling in operating revenues. Expenses paid for shipping and handling are recorded as part of cost of goods sold. Use of Estimates The Company uses estimates based on the best information available in recording transactions and balances resulting from business operations. As better information becomes available (or actual amounts are known), the recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates. Cash Equivalents The Company considers all highly liquid debt instruments purchased with maturity of 90 days or less to be cash equivalents. Investments The following table provides a breakdown of the Company’s investments at December 31:
(in thousands) |  | 2019 |  |  | 2018 |
Cost Method: |  |  |  |  |  |  |  |
Economic Development Loan Pools |  | $ | 24 |  |  | $ | 34 |
Other |  |  | 73 |  |  |  | 123 |
Equity Method Partnerships |  |  | 27 |  |  |  | 26 |
Marketable Debt Securities Classified as Available-for-Sale |  |  | 8,184 |  |  |  | 7,484 |
Marketable Equity Securities Classified as Available-for-Sale |  |  | 1,586 |  |  |  | 1,294 |
Total Investments |  | $ | 9,894 |  |  | $ | 8,961 |
The Company’s marketable securities classified as available-for-sale are held for insurance purposes and are reflected at their fair values on December 31, 2019. See further discussion below. Inventories Inventories, valued at the lower of cost or net realizable value, consist of the following:
|  | December 31, |  |  | December 31, |
(in thousands) |  | 2019 |  |  | 2018 |
Finished Goods |  | $ | 31,863 |  |  | $ | 37,130 |
Work in Process |  |  | 16,508 |  |  |  | 20,393 |
Raw Material, Fuel and Supplies |  |  | 49,480 |  |  |  | 48,747 |
Total Inventories |  | $ | 97,851 |  |  | $ | 106,270 |
Fair Value Measurements The Company follows ASC Topic 820, Fair Value Measurements and Disclosures (ASC 820), for recurring fair value measurements. ASC 820 provides a single definition of fair value, requires enhanced disclosures about assets and liabilities measured at fair value and establishes a hierarchal framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value. The three levels defined by the hierarchy and examples of each level are as follows: Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reported date. The types of assets and liabilities included in Level 1 are highly liquid and actively traded instruments with quoted prices, such as equities listed by the New York Stock Exchange and commodity derivative contracts listed on the New York Mercantile Exchange. Level 2 – Pricing inputs are other than quoted prices in active markets but are either directly or indirectly observable as of the reported date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, such as treasury securities with pricing interpolated from recent trades of similar securities, or priced with models using highly observable inputs, such as commodity options priced using observable forward prices and volatilities. Level 3 – Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 are those with inputs requiring significant management judgment or estimation and may include complex and subjective models and forecasts. The following tables present, for each of the hierarchy levels, the Company’s assets and liabilities that are measured at fair value on a recurring basis as of December 31, 2019 and December 31, 2018:
December 31, 2019 (in thousands) |  | Level 1 |  |  | Level 2 |  |  | Level 3 |
Assets: |  |  |  |  |  |  |  |  |  |  |  |
Investments: |  |  |  |  |  |  |  |  |  |  |  |
Equity Funds – Held by Captive Insurance Company |  | $ | 1,586 |  |  |  |  |  |  |  |  |
Corporate Debt Securities – Held by Captive Insurance Company |  |  |  |  |  | $ | 2,124 |  |  |  |  |
Government-Backed and Government-Sponsored Enterprises’ Debt Securities – Held by Captive Insurance Company |  |  |  |  |  |  | 6,060 |  |  |  |  |
Other Assets: |  |  |  |  |  |  |  |  |  |  |  |
Money Market and Mutual Funds – Retirement Plans |  |  | 2,363 |  |  |  |  |  |  |  |  |
Total Assets |  | $ | 3,949 |  |  | $ | 8,184 |  |  |  |  |
December 31, 2018 (in thousands) |  | Level 1 |  |  | Level 2 |  |  | Level 3 |
Assets: |  |  |  |  |  |  |  |  |  |  |  |
Investments: |  |  |  |  |  |  |  |  |  |  |  |
Equity Funds – Held by Captive Insurance Company |  | $ | 1,294 |  |  |  |  |  |  |  |  |
Corporate Debt Securities – Held by Captive Insurance Company |  |  |  |  |  | $ | 5,898 |  |  |  |  |
Government-Backed and Government-Sponsored Enterprises’ Debt Securities – Held by Captive Insurance Company |  |  |  |  |  |  | 1,586 |  |  |  |  |
Other Assets: |  |  |  |  |  |  |  |  |  |  |  |
Money Market and Mutual Funds – Nonqualified Retirement Savings Plan |  |  | 838 |  |  |  |  |  |  |  |  |
Total Assets |  | $ | 2,132 |  |  | $ | 7,484 |  |  |  |  |
The level 2 fair values for Government-Backed and Government-Sponsored Enterprises’ and Corporate Debt Securities Held by the Company’s Captive Insurance Company are determined on the basis of valuations provided by a third-party pricing service which utilizes industry accepted valuation models and observable market inputs to determine valuation. Some valuations or model inputs used by the pricing service may be based on broker quotes. Goodwill and Other Intangible Assets The Company accounts for goodwill and other intangible assets in accordance with the requirements of ASC Topic 350, Intangibles—Goodwill and Other, measuring its goodwill for impairment annually in the fourth quarter, and more often when events indicate the assets may be impaired. The Company does qualitative assessments of its reporting units with recorded goodwill to determine if it is more likely than not that the fair value of the reporting unit exceeds its book value. The Company also does quantitative assessments of its reporting units with recorded goodwill to determine the fair value of the reporting unit. The following tables summarize changes to goodwill by business segment during 2019 and 2018:
(in thousands) |  | Gross Balance December 31, 2018 |  |  | Accumulated Impairments |  |  | Balance (net of impairments) December 31, 2018 |  |  | Adjustments to Goodwill in 2019 |  |  | Balance (net of impairments) December 31, 2019 |
Manufacturing |  | $ | 18,270 |  |  | $ | - |  |  | $ | 18,270 |  |  | $ | - |  |  | $ | 18,270 |
Plastics |  |  | 19,302 |  |  |  | - |  |  |  | 19,302 |  |  |  | - |  |  |  | 19,302 |
Total |  | $ | 37,572 |  |  | $ | - |  |  | $ | 37,572 |  |  | $ | - |  |  | $ | 37,572 |
(in thousands) |  | Gross Balance December 31, 2017 |  |  | Accumulated Impairments |  |  | Balance (net of impairments) December 31, 2017 |  |  | Adjustments to Goodwill in 2018 |  |  | Balance (net of impairments) December 31, 2018 |
Manufacturing |  | $ | 18,270 |  |  | $ | - |  |  | $ | 18,270 |  |  | $ | - |  |  | $ | 18,270 |
Plastics |  |  | 19,302 |  |  |  | - |  |  |  | 19,302 |  |  |  | - |  |  |  | 19,302 |
Total |  | $ | 37,572 |  |  | $ | - |  |  | $ | 37,572 |  |  | $ | - |  |  | $ | 37,572 |
Intangible assets with finite lives are amortized over their estimated useful lives and reviewed for impairment in accordance with requirements under ASC Topic 360-10-35, Property, Plant, and Equipment—Overall—Subsequent Measurement. The following table summarizes the components of the Company’s intangible assets at December 31, 2019 and December 31, 2018:
December 31, 2019 (in thousands) |  | Gross Carrying Amount |  |  | Accumulated Amortization |  |  | Net Carrying Amount |  |  | Remaining Amortization Periods (months) |
Amortizable Intangible Assets: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Customer Relationships |  | $ | 22,491 |  |  | $ | 11,259 |  |  | $ | 11,232 |  |  |  | 88 - 188 |
Other |  |  | 179 |  |  |  | 121 |  |  |  | 58 |  |  |  | 8 - 45 |
Total |  | $ | 22,670 |  |  | $ | 11,380 |  |  | $ | 11,290 |  |  |  |  |
December 31, 2018 (in thousands) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Amortizable Intangible Assets: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Customer Relationships |  | $ | 22,491 |  |  | $ | 10,127 |  |  | $ | 12,364 |  |  |  | 12 - 200 |
Other |  |  | 154 |  |  |  | 68 |  |  |  | 86 |  |  |  | 20 |
Total |  | $ | 22,645 |  |  | $ | 10,195 |  |  | $ | 12,450 |  |  |  |  |
The amortization expense for these intangible assets was:
(in thousands) |  | 2019 |  |  | 2018 |  |  | 2017 |
Amortization Expense – Intangible Assets |  | $ | 1,186 |  |  | $ | 1,315 |  |  | $ | 1,347 |
The estimated annual amortization expense for these intangible assets for the next five years is:
(in thousands) |  | 2020 |  |  | 2021 |  |  | 2022 |  |  | 2023 |  |  | 2024 |
Estimated Amortization Expense – Intangible Assets |  | $ | 1,140 |  |  | $ | 1,105 |  |  | $ | 1,105 |  |  | $ | 1,104 |  |  | $ | 1,099 |
Supplemental Disclosures of Cash Flow Information
|  | As of December 31, |
(in thousands) |  | 2019 |  |  | 2018 |
Noncash Investing Activities: |  |  |  |  |  |  |  |
Transactions Related to Capital Additions not Settled in Cash |  | $ | 37,429 |  |  | $ | 13,757 |
(in thousands) |  | 2019 |  |  | 2018 |  |  | 2017 |
Cash Paid During the Year for: |  |  |  |  |  |  |  |  |  |  |  |
Interest (net of amount capitalized) |  | $ | 30,132 |  |  | $ | 28,109 |  |  | $ | 29,791 |
Income Taxes |  | $ | 4,797 |  |  | $ | 6,109 |  |  | $ | 5,064 |
New Accounting Standards Adopted ASU 2016-02—In February 2016 the FASB issued ASU No. 2016-02, Leases (Topic 842) (ASU 2016-02). ASU 2016-02 is a comprehensive amendment of the ASC, creating Topic 842, which supersedes the requirements under ASC Topic 840 on leases and requires the recognition of lease assets and lease liabilities on the balance sheet and the disclosure of key information about leasing arrangements. The amendments in ASU 2016-02 are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The main difference between previous Generally Accepted Accounting Principles in the United States (GAAP) and Topic 842 is the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. The Company adopted the amendments in ASU 2016-02 to its consolidated financial statements effective January 1, 2019. See note 8 to consolidated financial statements for further information on leases and the Company’s elections for applying the new standard. ASU 2017-04—In January 2017 the FASB issued ASU No. 2017-04, Intangibles—Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment (ASU 2017-04), which simplifies how an entity is required to test goodwill for impairment by eliminating Step 2 from the goodwill impairment test. Step 2 measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount of that goodwill. In computing the implied fair value of goodwill under Step 2, an entity must perform procedures to determine the fair value at the impairment testing date of its assets and liabilities (including unrecognized assets and liabilities) following the procedure that would be required in determining the fair value of assets acquired and liabilities assumed in a business combination. Under the amendments in ASU 2017-04, an entity will perform its annual, or interim, goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An entity will recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value; however, the loss recognized will not exceed the total amount of goodwill allocated to that reporting unit. Additionally, an entity will consider income tax effects from any tax-deductible goodwill on the carrying amount of the reporting unit when measuring the goodwill impairment loss, if applicable. The amendments in ASU 2017-04 modify the concept of impairment from the condition that exists when the carrying amount of goodwill exceeds its implied fair value to the condition that exists when the carrying amount of a reporting unit exceeds its fair value. An entity no longer will determine goodwill impairment by calculating the implied fair value of goodwill by assigning the fair value of a reporting unit to all of its assets and liabilities as if that reporting unit had been acquired in a business combination. Because these amendments eliminate Step 2 from the goodwill impairment test, they should reduce the cost and complexity of evaluating goodwill for impairment. The amendments in ASU 2017-04 are effective for annual or any interim goodwill impairment tests in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The Company early adopted the amendments in ASU 2017-04 in the first quarter of 2019. The Company had no indication that any of its goodwill was impaired, and therefore, the adoption of the updated standard had no impact on the Company’s consolidated financial statements. ASU 2018-02—In February 2018 the FASB issued ASU No. 2018-02, Income Statement—Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income (ASU 2018-02). The amendments in ASU 2018-02, which are narrow in scope, allow a reclassification from accumulated other comprehensive income/loss (AOCI/(L)) to retained earnings for stranded tax effects resulting from the 2017 Tax Cuts and Jobs Act (TCJA). Consequently, the amendments eliminate the stranded tax effects resulting from the TCJA and will improve the usefulness of information reported to financial statement users. The amendments in ASU 2018-02 also require certain disclosures about stranded tax effects and are effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. The amendments in ASU 2018-02 can be applied either in the period of adoption or retrospectively to each period (or periods) in which the effect of the change in the U.S. federal corporate income tax rate in the TCJA is recognized. The Company adopted the updates in ASU 2018-02 effective January 1, 2019, applying them in the period of adoption and not retrospectively. On adoption, the Company reclassified $784,000 of income tax effects of the TCJA on the gross deferred tax amounts reflected in AOCI/(L) at the date of enactment of the TCJA and AOCI/(L) to retained earnings so the remaining gross deferred tax amounts related to items in AOCI/(L) will reflect current effective tax rates. Support for the determination of the stranded tax effects resulting from the enactment of the TCJA in AOCI/(L) is provided in the table below.
(in thousands) |  | Unrealized Gains on Available-for- Sale Securities |  |  | Unamortized Actuarial Losses and Prior Service Costs on Pension and Other Postretirement Benefits |  |  | AOCI/(L) |
Balance on December 22, 2017 – Pre-tax |  | $ | 71 |  |  | $ | (5,672 | ) |  | $ | (5,601 | )
Effect of TCJA 14% Federal Tax Rate Reduction on Gross Deferred Tax Amounts |  | $ | 10 |  |  | $ | (794 | ) |  | $ | (784 | )
New Accounting Standards Pending Adoption ASU 2016-13—In June 2016 the FASB issued ASU No. 2016-13, Financial Instruments—Credit Losses (Topic 326) (ASC 326), which changes how entities account for credit losses on receivables and certain other assets. The guidance requires use of a current expected credit loss model, which may result in earlier recognition of credit losses than under previous accounting standards. ASC 326 is effective for interim and annual periods beginning on or after December 15, 2019. The Company has reviewed its outstanding investments and receivables that will be subject to evaluation for credit losses under the new standard and determined that application of the new expected loss model will not have a material impact on its current calculation of credit losses and allowance for doubtful accounts balance. The Company will apply ASC 326 to its consolidated financial statements in the first quarter of 2020. Adoption of the new standard will not have a material impact on the Company’s consolidated financial statements and the Company will not record a cumulative effect adjustment to retained earnings on adoption. ASU 2018-15—In August 2018 the FASB issued ASU No. 2018-15, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40), which amends ASC 350-40, Internal-Use Software, to address a customer's accounting for implementation costs incurred in a cloud computing arrangement that is a service contract. The amendments in ASU 2018-15 align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal-use software license). Accordingly, the amendments in ASU 2018-15 require an entity (customer) in a hosting arrangement that is a service contract to follow the guidance in ASC 350-40 to determine which implementation costs to capitalize as an asset related to the service contract and which costs to expense. The amendments in ASU 2018-15 also require the entity to present the expense related to the capitalized implementation costs in the same line item in the statement of income as the fees associated with the hosting element (service) of the arrangement and classify payments for capitalized implementation costs in the statement of cash flows in the same manner as payments made for fees associated with the hosting element. The entity is also required to present the capitalized implementation costs in the statement of financial position in the same line item that a prepayment for the fees of the associated hosting arrangement would be presented. The amendments in ASU 2018-15 are effective for interim and annual periods beginning on or after December 15, 2019 with early adoption permitted in any interim period. The Company will adopt the amendments in ASU 2018-15 in the first quarter of 2020 and expects there will be no impact to its consolidated financial statements on adoption but does expect to begin capitalizing implementation costs incurred in cloud computing arrangements post-adoption.

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