Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2018

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Note 2 — Summary of Significant Accounting Policies

Use of Estimates

The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.

Principles of Consolidation

The accompanying consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Reclassifications

Certain reclassifications have been made to the 2017 and 2016 financial statements to conform to the presentation used in the 2018 financial statements. These reclassifications had no effect on Cleco and Cleco Power’s net income, financial condition, or cash flows.

Cleco and Cleco Power’s Consolidated Statements of Income for the years ended December 31, 2017, and 2016, have been retrospectively adjusted by $0.4 million and $7.3 million, respectively, for the reclassification of deferred expenses from Depreciation and amortization to Other operations and maintenance.

Goodwill

Goodwill is the excess of the purchase price (consideration transferred and liabilities assumed) over the estimated fair value of net assets of the acquired business and is not subject to amortization. Goodwill is assessed annually or more often if an event occurs or circumstances change that would indicate the carrying amount may be impaired. For more information on goodwill, see Note 18 — “Intangible Assets and Goodwill.”

Intangible Assets

Intangible assets include Cleco Katrina/Rita’s right to bill and collect storm recovery charges, fair value adjustments for long-term wholesale power supply agreements, and a fair value adjustment for the valuation of the Cleco trade name. The intangible assets are being amortized over their estimated useful lives in a manner that best reflects the economic benefits derived from such assets. Impairment will be tested if there are events or circumstances that indicate that an impairment analysis should be performed. If such an event or circumstance occurs, intangible impairment testing will be performed prior to goodwill impairment testing. Impairment is calculated as the excess of the asset’s carrying amount over its fair value. For more information on intangible assets, see Note 18 — “Intangible Assets and Goodwill.”

Statements of Cash Flows

Cleco and Cleco Power’s Consolidated Statements of Cash Flows are prepared using the indirect method. This method requires adjusting net income to remove the effects of all deferrals and accruals of operating cash receipts and payments and to remove items whose cash effects are related to investing and financing cash flows. Derivatives meeting the definition of an accounting hedge are classified in the same category as the item being hedged.

Regulation

Cleco Power is subject to regulation by FERC and the LPSC. Cleco Power complies with the accounting policies and practices prescribed by its regulatory commissions. Cleco Power’s retail rates are regulated by the LPSC and its tariffs for transmission services are regulated by FERC. Rates for wholesale power sales are based on market-based rates, pending FERC review of Cleco Power’s generation market power analysis. Cleco Power capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process. Regulatory assets and liabilities are amortized consistent with the treatment of the related cost in the ratemaking process. Pursuant to this regulatory approval, Cleco has recorded regulatory assets and liabilities.

Any future plan adopted by the LPSC for purposes of transitioning utilities from LPSC regulation to retail competition may affect the regulatory assets and liabilities recorded by Cleco if the criteria for the application of the authoritative guidelines for industry regulated operations cannot continue to be met. At this time, Cleco cannot predict whether any legislation or regulation affecting Cleco will be enacted or adopted and, if enacted, what form such legislation or regulation may take.

For more information regarding the regulatory assets and liabilities recorded by Cleco Power, see Note 5 — “Regulatory Assets and Liabilities.”

AROs

Cleco Power recognizes an ARO when there is a legal obligation under existing or enacted law, statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel to incur costs to remove an asset when the asset is retired. These guidelines also require an ARO which is conditional on a future event to be recorded even if the event has not yet occurred.

Cleco Power recognizes AROs at the present value of the projected liability in the period in which it is incurred, if a reasonable estimate of fair value can be made. The liability is accreted to its present value each accounting period. Cleco Power defers this accretion as a regulatory asset based on its determination that these costs can be collected from customers. Concurrent with the recognition of the liability, these costs are capitalized to the related property, plant, and equipment asset. These capitalized costs are depreciated over the same period as the related property asset. Cleco Power also defers the current depreciation of the asset retirement cost as a regulatory asset.

In March 2018, Cleco Power recorded a $1.5 million decrease to its ARO related to the retirement of certain ash management areas. Cleco Power will continue to gather additional data in future periods and will make decisions about compliance strategies and the timing of closure activities. As this additional information becomes available, Cleco Power will update the ARO balance for these changes in estimates. At December 31, 2018, management’s analysis confirmed that no additional adjustments were needed to update Cleco Power’s ARO balance. For more information on Cleco Power’s current AROs, see Note 5 — “Regulatory Assets and Liabilities — AROs.”

Property, Plant, and Equipment

Property, plant, and equipment consists primarily of regulated utility generation and energy transmission and distribution assets. Regulated assets, utilized primarily for retail operations and electric transmission and distribution, are stated at the cost of construction, which includes certain materials, labor, payroll taxes and benefits, administrative and general costs, and the estimated cost of funds used during construction. Jointly owned assets are reflected in property, plant, and equipment at Cleco Power’s share of the cost to construct or purchase the assets. For information on jointly owned assets, see Note 6 — “Jointly Owned Generation Units.”

Most of the carrying values of Cleco’s assets were determined to be stated at fair value at the 2016 Merger date, considering that most of these assets are subject to regulation by the LPSC and FERC. A fair value adjustment was made to record the stepped-up basis for the Coughlin assets, because Cleco Power is able to earn a return on and recover these costs from customers. At the date of the 2016 Merger, the gross balance of fixed depreciable assets at Cleco was adjusted to be net of accumulated depreciation, as no accumulated depreciation existed on the date of the 2016 Merger. Since pushdown accounting was not elected at the Cleco Power level, Cleco Power retained its accumulated depreciation. For more information about 2016 Merger related adjustments to property, plant, and equipment, see Note 4 — “Business Combinations.”

Cleco’s cost of improvements to property, plant, and equipment is capitalized. Costs associated with repairs and major maintenance projects are expensed as incurred. Cleco capitalizes the cost to purchase or develop software for internal use. The amounts of unamortized computer software costs on Cleco’s Consolidated Balance Sheets at December 31, 2018, and 2017 were $7.2 million and $7.9 million, respectively. The amounts of unamortized computer software costs on Cleco Power’s Consolidated Balance Sheets at December 31, 2018, and 2017 were $5.8 million and $6.6 million, respectively. Amortization of capitalized computer software costs charged to expense in Cleco and Cleco Power’s Consolidated Statements of Income for the years ending December 31, 2018, 2017, and 2016 is shown in the following tables:

Cleco
	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE YEAR ENDED DEC. 31, 2018		FOR THE YEAR ENDED DEC. 31, 2017		APR. 13, 2016 - DEC. 31, 2016		JAN. 1, 2016 - APR. 12, 2016
Amortization	$	2,154	$	2,367	$	2,351	$	921

Cleco Power
	FOR THE YEAR ENDED DEC. 31,
(THOUSANDS)	2018		2017		2016
Amortization	$	1,607	$	1,887	$	2,405

Upon retirement or disposition, the cost of Cleco Power’s depreciable plant and the cost of removal, net of salvage value, are charged to accumulated depreciation. For Cleco’s other depreciable assets, upon disposition or retirement, the difference between the net book value of the property and any proceeds received for the property is recorded as a gain or loss on asset disposition on Cleco’s Consolidated Statements of Income. Any cost incurred to remove the asset is charged to expense. Annual depreciation provisions expressed as a percentage of average depreciable property for Cleco Power for 2018, 2017, and 2016 was 2.80%, 2.72%, and 2.68%, respectively.

Depreciation on property, plant, and equipment is calculated primarily on a straight-line basis over the useful lives of the assets, as follows:

CATEGORY	YEARS
Utility Plants
Generation	10	–	95
Distribution	15	–	50
Transmission	5	–	55
Other utility plant	5	–	45
Other property, plant, and equipment	5	–	45

At December 31, 2018, and 2017, Cleco and Cleco Power’s property, plant, and equipment consisted of the following:

Cleco
	AT DEC. 31,
(THOUSANDS)	2018			2017
Utility plants
Generation	$	1,949,042		$	1,908,344
Distribution	1,081,650			1,015,472
Transmission	519,269			512,428
Other utility plant	174,010			153,900
Other property, plant, and equipment	4,506			4,381
Total property, plant, and equipment	3,728,477			3,594,525
Accumulated depreciation	(303,727		)	(192,348		)
Net property, plant, and equipment	$	3,424,750		$	3,402,177

Cleco Power
	AT DEC. 31,
(THOUSANDS)	2018			2017
Regulated utility plants
Generation	$	2,476,733		$	2,442,987
Distribution	1,523,885			1,462,193
Transmission	731,432			725,199
Other utility plant	282,954			263,105
Total property, plant, and equipment	5,015,004			4,893,484
Accumulated depreciation	(1,804,563		)	(1,712,590		)
Net property, plant, and equipment	$	3,210,441		$	3,180,894

During 2018, Cleco Power’s regulated utility property, plant, and equipment increased primarily due to general installation and rehabilitation of transmission, distribution, and generation assets.

Deferred Project Costs

Cleco Power defers costs related to the initial stage of a construction project during which time the feasibility of the construction of property, plant, and equipment is being investigated. At December 31, 2018, and 2017, Cleco Power had deferred $1.4 millionand $3.2 million, respectively, for projects that are in the initial stages of development. These amounts are classified as Other deferred charges on Cleco Power’s Consolidated Balance Sheets.

Fuel Inventory and Materials and Supplies

Fuel inventory consists primarily of petroleum coke, coal, limestone, lignite, and natural gas used to generate electricity.

Materials and supplies consists of transmission and distribution line construction and repair materials. It also consists of generating station and transmission and distribution substation repair materials.

Both fuel inventory and materials and supplies are recorded at the lower of cost or market value using the average cost method and are issued from stock using the average cost of existing stock. Materials and supplies are recorded when purchased and subsequently charged to expense or capitalized to property, plant, and equipment when installed.

Accounts Receivable

Accounts receivable are recorded at the invoiced amount and do not bear interest. It is the policy of management to review the outstanding accounts receivable monthly, as well as the bad debt write-offs experienced in the past, and establish an allowance for doubtful accounts. Account balances are charged off against the allowance when management determines it is probable the receivable will not be recovered.

Reserves

Cleco maintains property insurance on generating stations, buildings and contents, and substations. Cleco is self-insured for any damage to transmission and distribution lines. To mitigate the exposure to potential financial loss for damage to lines, Cleco maintains an LPSC-approved funded storm reserve.

Cleco Power also maintains liability and workers’ compensation insurance to mitigate financial losses due to injuries and damages to the property of others. Cleco’s insurance covers claims that exceed certain self-insured limits. For claims that do not meet the limits to be covered by insurance, Cleco Power maintains reserves. At December 31, 2018, and 2017, the general liability and workers compensation reserves together were $4.8 million and $4.5 million, respectively.

Additionally, Cleco maintains directors and officers insurance to protect managers from claims which may arise from their decisions and actions taken within the scope of their regular duties.

Cash Equivalents

Cleco considers highly liquid, marketable securities, and other similar instruments with original maturity dates of three months or less to be cash equivalents.

Restricted Cash and Cash Equivalents

Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general company purposes.

Cleco and Cleco Power’s restricted cash and cash equivalents consisted of:

Cleco
	AT DEC. 31,
(THOUSANDS)	2018		2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	9,505	$	8,597
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	536		3,284
Total current	11,241		13,081
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	15,391		14,456
Cleco Power’s charitable contributions	2,753		3,575
Cleco Power’s rate credit escrow	505		2,029
Total non-current	18,670		20,081
Total restricted cash and cash equivalents	$	29,911	$	33,162

Cleco Power
	AT DEC. 31,
(THOUSANDS)	2018		2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	9,505	$	8,597
Charitable contributions	1,200		1,200
Rate credit escrow	536		3,284
Total current	11,241		13,081
Non-current
Future storm restoration costs	15,391		14,456
Charitable contributions	2,753		3,575
Rate credit escrow	505		2,029
Total non-current	18,649		20,060
Total restricted cash and cash equivalents	$	29,890	$	33,141

Cleco Katrina/Rita has the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash is collected, it is restricted for payment of administration fees, interest, and principal on storm recovery bonds. The change from December 31, 2017, to December 31, 2018, was due to Cleco Katrina/Rita collecting $22.7 million net of administration fees, partially offset by $19.2 million for scheduled storm recovery bond principal payments and $2.6 million for related interest payments.

Equity Investments

Cleco and Cleco Power account for investments in unconsolidated affiliated companies using the equity method of accounting. The amounts reported on Cleco and Cleco Power’s Consolidated Balance Sheets represent assets contributed by Cleco or Cleco Power, plus their share of the net income of the affiliate, less any distributions of earnings (dividends) received from the affiliate. The revenues and expenses (excluding income taxes) of these affiliates are netted and reported on one line item as equity income from investees on Cleco and Cleco Power’s Consolidated Statements of Income.

Cleco evaluates for impairments of equity method investments at each balance sheet date to determine if events and circumstances have occurred that indicate a possible other-than-temporary decline in the fair value of the investment and the possible inability to recover the carrying value through operations. Cleco uses estimates of the future cash flows from the investee and observable market transactions in order to calculate fair value and recoverability. An impairment is recognized when an other-than-temporary decline in market value occurs and recovery of the carrying value is not probable. There were no impairments recorded for 2018, 2017, or 2016. For more information on Cleco’s equity investments, see Note 14 — “Variable Interest Entities.”

Income Taxes

Cleco accounts for income taxes under the asset and liability method. Cleco provides for federal and state income taxes currently payable, as well as for those deferred due to timing differences between reporting income and expenses for financial statement purposes versus tax purposes. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using enacted income tax rates expected to be applied to taxable income in the years in which those temporary differences are expected to be recovered or settled. Deferred tax assets and liabilities are classified as non-current on Cleco and Cleco Power’s Consolidated Balance Sheets. Cleco’s income tax expense and related regulatory assets and liabilities could be affected by changes in its assumptions and estimates and by ultimate resolution of assumptions and estimates with taxing authorities. Cleco Group files a federal income tax return for all wholly owned subsidiaries. Cleco Power computes its federal and state income taxes as if it were a stand-alone taxpayer. The LPSC generally requires Cleco Power to flow the effects of state income taxes to customers immediately. The LPSC specifically requires that the state tax benefits associated with the deductions related to certain storm damages be normalized. For more information on income taxes, see Note 11 — “Income Taxes.”

Investment Tax Credits

Investment tax credits, which were deferred for financial statement purposes, are amortized as a reduction to income tax expense over the estimated service lives of the properties that gave rise to the credits.

NMTC Fund

In 2008, Cleco Holdings and the USBCDC formed the NMTC Fund. The purpose of the NMTC Fund was to invest in projects located in qualified active low-income communities that are underserved by typical debt capital markets. These investments were designed to generate NMTCs and Historical Rehabilitation tax credits. The NMTC Fund was later amended to include renewable energy investments. The majority of the energy investments qualified for grants under Section 1603 of the ARRA. By using the cost method for investments, the gross investment amortization expense of the NMTC Fund was recognized over a ten-year period, which ended in 2018. The grants received under Section 1603, which allowed certain projects to receive a federal grant in lieu of tax credits, and other cash reduced the basis of the investment. Periodic amortization of the investment and the deferred taxes generated by the basis reduction temporary difference were included as components of income tax expense.

For more information, see Note 16 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — NMTC Fund.”

Accounting for Renewable Energy Tax Credits and Grants Under the ARRA

Cleco and the NMTC Fund elected to receive cash grants under the ARRA for investments in various projects. Cleco elected to reduce the carrying value of the qualifying assets as cash grants were received, which reduced the amount of depreciation expense recognized after the underlying assets were placed in service. Certain cash grants also reduced the tax basis of the underlying assets. Grants received via the NMTC Fund reduced the carrying value of the investment for GAAP, but did not reduce the income tax basis of the investment.

Debt Issuance Costs, Premiums, and Discounts

Issuance costs, premiums, and discounts applicable to debt securities are amortized to interest expense ratably over the lives of the related issuances. Expenses and call premiums related to refinanced Cleco Power debt are deferred and amortized over the life of the new issuance. Debt issuance costs, premiums, and discounts are presented as a direct deduction from the carrying value of the related debt liability.

Revenue and Fuel Costs

Utility Revenue

Revenue from sales of electricity is recognized when the service is provided. The costs of fuel and purchased power used for retail customers currently are recovered from customers through the FAC. These costs are subject to audit and final determination by regulators. Excise taxes and pass-through fees collected on the sale of electricity are not recorded in utility revenue.

Unbilled Revenue

Cleco Power accrues estimated revenue monthly for energy used by customers but not yet billed. The monthly estimated unbilled revenue amounts are recorded as unbilled revenue and a receivable. Cleco Power uses actual customer energy consumption data available from AMI to calculate unbilled revenues.

Other Operations Revenue

Other operations revenue is recognized at the time products or services are provided to and accepted by customers, and collectability is reasonably assured.

Sales/Excise Taxes

Cleco Power collects a sales and use tax on the sale of electricity that subsequently is remitted to the state in accordance with state law. These amounts are not recorded as income or expense on Cleco’s Consolidated Statements of Income but are reflected at gross amounts on Cleco’s Consolidated Balance Sheets as a receivable until the tax is collected and as a payable until the liability is paid. Cleco currently does not have any excise taxes reflected on its income statement.

Franchise Fees

Cleco Power collects a consumer fee for one of its franchise agreements. This fee is not recorded on Cleco’s Consolidated Statements of Income as revenue and expense, but is reflected at gross amounts on Cleco’s Consolidated Balance Sheets as a receivable until it is collected and as a payable until the liability is paid.

AFUDC

The capitalization of AFUDC by Cleco Power is a utility accounting practice prescribed by FERC and the LPSC. AFUDC represents the estimated debt and equity costs of capital funds that are necessary to finance construction of new and existing facilities. While cash is not realized currently from such allowance, AFUDC increases the revenue requirement over the same life of the plant through a higher rate base and higher depreciation. Under regulatory practices, a return on and recovery of AFUDC is permitted in setting rates charged for utility services. The composite AFUDC rate, including borrowed and other funds, was 9.58% on a pretax basis (7.08% net of tax) for 2018, 11.07% on a pretax basis (6.81% net of tax) for 2017, and 11.94% on a pretax basis (7.39% net of tax) for 2016.

Fair Value Measurements and Disclosures

Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes. For more information about fair value levels, see Note 7 — “Fair Value Accounting.”

Risk Management

Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes in value arising from changes in interest rates and the commodity market prices of power, FTRs, and natural gas in the industry on different energy exchanges. Cleco’s Energy Market Risk Management Policy authorizes the use of various derivative instruments, including exchange traded futures and option contracts, forward purchase and sales contracts, and swap transactions to reduce exposure to fluctuations in the price of power, FTRs, and natural gas. Cleco evaluates derivatives and hedging activities to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market.

Cleco Power may also enter into risk mitigating positions that would not meet the requirements of a normal-purchase, normal-sale transaction in order to attempt to mitigate the volatility in customer fuel costs. These positions would be marked-to-market with the resulting gain or loss recorded on Cleco and Cleco Power’s Consolidated Balance Sheets as a component of energy risk management assets or liabilities. Such gain or loss would be deferred as a component of deferred fuel assets or liabilities in accordance with regulatory policy. When these positions close, actual gains or losses would be included in the FAC and reflected on customers’ bills as a component of the fuel charge. There were no open natural gas positions at December 31, 2018, or 2017.

In 2015, the LPSC approved a long-term natural gas hedging pilot program that required Cleco Power to establish a proposal for a program that is designed to provide gas price stability for a minimum of five years. This proposal was submitted to the LPSC in July 2017. An ALJ was assigned to the docket and a status conference was held in October 2017. In February 2018, Cleco Power responded to LPSC data requests for the gas hedging docket. Cleco Power is currently awaiting a new procedural schedule to be established for the gas hedging docket.

Cleco Power purchases FTRs in auctions facilitated by MISO. The majority of its FTRs are purchased in annual auctions during the second quarter, but Cleco Power may purchase additional FTRs in monthly auctions. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Cleco Power’s customer load. FTRs are not designated as hedging instruments for accounting purposes.

Cleco Power records FTRs at their estimated fair value when purchased. Each accounting period, Cleco Power adjusts the carrying value of FTRs to their estimated fair value based on the most recent MISO FTR auction prices.

Unrealized gains or losses on FTRs held by Cleco Power are included in Accumulated deferred fuel on Cleco Power’s Consolidated Balance Sheets. Realized gains or losses on settled FTRs are recorded in Fuel used for electric generation on Cleco Power’s Consolidated Statements of Income. For more information on FTRs, see Note 7 — “Fair Value Accounting — Commodity Contracts.”

Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, aggregate counterparty credit exposure, and aggregate counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Cleco Power has agreements in place with various counterparties that authorize the netting of financial buys and sells and contract payments to mitigate credit risk for transactions entered into for risk management purposes.

Cleco and Cleco Power may enter into contracts to mitigate the volatility in interest rate risk. These contracts include, but are not limited to, interest rate swaps and treasury rate locks. For the years ended December 31, 2018, and 2017, Cleco did not enter into any contracts to mitigate the volatility in interest rate risk.

Accounting for MISO Transactions

Cleco Power participates in MISO’s Energy and Operating Reserve market where sales and purchases are netted hourly. If the hourly activity nets to sales, the result is reported in Electric operations on Cleco and Cleco Power’s Consolidated Statements of Income. If the hourly activity nets to purchases, the result is reported in Power purchased for utility customers on Cleco and Cleco Power’s Consolidated Statements of Income.

Recent Authoritative Guidance

In February 2016, FASB amended the guidance to account for leases. This guidance is intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The adoption of this guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those years. Cleco adopted this new standard on January 1, 2019, using the optional transition method, which allows an entity to recognize a cumulative-effect adjustment to the opening balance of retained earnings at the date of adoption and apply the new disclosure requirements beginning in the period of adoption. The new standard provides a number of optional practical expedients. Cleco has elected the following:

• Transition Elections - Cleco elected the package of practical expedients that permits entities to not reassess prior conclusions about lease identification, lease classification, and initial direct costs under the new standard, as well as the practical expedient that permits entities to not assess existing land easements under the new standard;

• Lessee Accounting Policy Elections - Cleco elected the short-term lease recognition exemption whereby right-of-use (ROU) assets and lease liabilities will not be recognized for leasing arrangements with terms one year or less, and the practical expedient to not separate lease and non-lease components for all classes of underlying assets other than the marine transportation asset class, which includes barges and towboats; and

• Lessor Accounting Policy Election - Cleco elected the practical expedient to account for lease and non-lease components in a contract as a single lease component for all classes of underlying assets. Cleco does not currently have lessor marine transportation agreements, but if any are entered into in the future then the practical expedient to not separate lease and non-lease components will not be elected for this class of underlying asset.

Adoption of this standard resulted in the recognition of ROU assets and lease liabilities for operating leases of $16.6 million and $16.0 million, respectively, as of January 1, 2019. There was no impact to retained earnings as a result of adopting this standard. Adoption of this standard did not materially impact the results of operations, financial condition, or cash flows of the Registrants.

In August 2016, FASB amended the guidance for certain cash flow issues with the objective of reducing existing diversity in practice. This guidance affects the cash flow classification related to certain types of transactions including debt, contingent consideration, proceeds from the settlement of insurance claims, and distributions from equity method investees. The amended guidance was adopted by the Registrants at January 1, 2018. This amendment was applied using a retrospective transition method to each period presented. This guidance impacted the presentation of Cleco and Cleco Power’s cash flow statements for the year ended December 31, 2016, by moving make-whole payments of $18.6 million, which were made in connection with the redemption of $250.0 million of 6.65% senior notes in 2016, from Other deferred accounts to Payments for long-term debt prepayment costs. Also, this amount was removed from Interest paid, net of amount capitalized, in the supplementary cash flow information. This guidance did not impact the results of operations or financial condition of the Registrants.

In November 2016, FASB amended guidance for certain cash flow issues. The amended guidance requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash. Therefore, amounts generally described as restricted cash and cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The amended guidance was adopted by the Registrants at January 1, 2018, by moving the presentation of restricted cash and restricted cash equivalents in the statement of cash flows to net cash flows of total cash, cash equivalents, restricted cash, and restricted cash equivalents. This amendment was applied using a retrospective transition method to each period presented. This guidance impacted the presentation of the cash flows statement, as noted above, but did not have an impact on the results of operations or financial condition of the Registrants.

In January 2017, FASB amended the accounting guidance to simplify the measurement of a goodwill impairment loss. The amended guidance eliminates step two of the goodwill impairment test, which requires a hypothetical purchase price allocation to measure goodwill impairment. Under the new guidance, a goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Cleco elected to early adopt this guidance effective January 1, 2018. Adoption of this guidance did not impact the results of operations, financial condition, or cash flows of the Registrants.

In March 2017, FASB amended guidance related to defined benefit pension and other postretirement benefit plans. The new amendment requires an entity to present service cost in the same line item as other current employee compensation costs and to present the remaining components of net benefit cost in a separate line item outside of operating items. The amendment also allows only the service cost component of net benefit cost to be eligible for capitalization within property, plant, and equipment. The non-service costs capitalized for ratemaking purposes will be reflected as a regulatory asset or liability for GAAP. Cleco adopted this guidance as of January 1, 2018. This amendment was applied retrospectively for the presentation of the service cost in the income statement while the capitalization of the service cost was applied prospectively. This guidance did not have a significant impact on the results of operations, financial condition, or cash flows of the Registrants. The change in presentation for Cleco and Cleco Power was as follows:

Cleco
	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE YEAR ENDED DEC. 31, 2017			APR. 13, 2016 - DEC. 31, 2016			JAN. 1, 2016 - APR. 12, 2016
Other operations and maintenance	$	(11,071	)	$	(8,618	)	$	(3,447	)
Other expense	$	11,071		$	8,618		$	3,447

Cleco Power
	FOR THE YEAR ENDED DEC. 31,
(THOUSANDS)	2017			2016
Other operations and maintenance	$	(7,612	)	$	(8,529	)
Other expense	$	7,612		$	8,529

In February 2018, FASB amended guidance that permits, but does not require, companies to reclassify stranded tax effects from the TCJA from AOCI to retained earnings. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2018, including interim periods within those years. Management has elected to early adopt. On December 31, 2018, Cleco and Cleco Power reclassed $0.6 million and $2.5 million, respectively, of stranded tax effects associated with the TCJA from AOCI to retained earnings.

In March 2018, FASB issued clarifying guidance regarding a company’s ability to comply with the accounting requirements for the income tax effects of the TCJA in the period of enactment. The guidance clarifies accounting for income taxes if information is not yet available or complete. In December 2018, Cleco recorded its final adjustments related to the TCJA.

In August 2018, FASB issued guidance that allows for the deferral of certain implementation costs incurred in a cloud computing arrangement. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2019, including interim periods within those years. Early adoption is permitted. Management does not expect this guidance to have significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In August 2018, FASB issued guidance updating the disclosure framework for Defined Benefit Plans. Under the new guidance, entities will no longer be required to disclose the amount in other comprehensive income expected to be recognized as a component of net periodic benefit cost of the next fiscal year or the impact of a one-percentage point increase and a one-percentage point decrease in the assumed health care cost trend. The new framework will require additional disclosure including a narrative description of the reasons for significant gains/losses affecting the benefit obligation. The adoption of this guidance is effective for fiscal years ending after December 15, 2020. Early adoption is permitted. Management does not expect this guidance to have a significant impact on the result of operations, financial condition, or cash flows of Registrants.

In August 2018, FASB issued guidance updating the disclosure framework for Fair Value Measurement. Under the new guidance, entities will no longer be required to disclose the amount of and reasons for transfers between level 1 and level 2 of the fair value hierarchy, the policy of timing of transfers between levels, or the valuation policies and procedures for level 3 fair value measurements. The new framework will require additional disclosures around level 3 fair value measurements, including the range, weighted average, and time period used to develop significant unobservable inputs. The adoption of this guidance is effective for fiscal years beginning after December 15, 2019. Early adoption is permitted. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In October 2018, FASB issued guidance that requires indirect interest held through related parties under common control to be considered on a proportional basis when determining whether fees paid to decision makers and service providers are variable interest. The adoption of this guidance is effective for fiscal years beginning after December 15, 2019, including interim periods within those years. Early adoption is permitted. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In November 2018, FASB issued amendments clarifying that transactions in a collaborative arrangement should be accounted for using the Revenue Recognition standards when the counterparty is a customer for a direct good or service. The guidance precludes an entity from presenting consideration from a transaction in a collaborative arrangement as revenue from contracts with customers if the counterparty is not a customer for that transaction. The adoption of this guidance is effective for fiscal years beginning after December 15, 2019, including interim periods within those years. Early adoption is permitted. Management does not expect this guidance to have a significant impact on the results of operations, financials condition, or cash flows of the registrants.