Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2011

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America 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.

On January 1, 2010, Cleco implemented the amended authoritative guidance with respect to the consolidation of Perryville, Attala, and Evangeline. For more information on the consolidation of these entities, see Note 12 — “Variable Interest Entities.”

Reclassifications

Certain reclassifications have been made to the 2009 and 2010 financial statements to conform them to the presentation used in the 2011 financial statements. These reclassifications had no effect on Cleco Corporation’s net income applicable to common stock or total common shareholders’ equity or Cleco Power’s net income or total member’s equity.

The Registrants determined that an error existed in the statement of cash flow methodology for determining non-cash transactions related to property, plant, and equipment, specifically the dollar amount of property, plant, and equipment acquisitions included in accounts payable. This caused errors between the operating activities section and investing activities section for prior years, including 2009 and 2010.

Cleco Corporation and Cleco Power’s Consolidated Statements of Cash Flows for the years ended December 31, 2010, and 2009, have been adjusted to correct the presentation of cash flows related to accruals for property, plant, and equipment. These corrections had no impact on the Registrants’ financial condition or results of operations. Management believes that these corrections did not have a material effect on the Registrants’ Consolidated Statements of Cash Flows. The corrections to the December 31, 2010, and 2009 Consolidated Statements of Cash Flows are presented in the following tables.

Cleco
	FOR THE YEAR ENDED
				2009						2010
(THOUSANDS)	AS REPORTED			AS ADJUSTED			AS REPORTED			AS ADJUSTED
Accounts receivable	$	8,310		$	8,310		$	(35,156	)	$	(16,156	)
Accounts payable	$	11,231		$	18,593		$	3,459		$	8,167
Retainage payable	$	(11,921	)	$	(13,011	)	$	1,913		$	(27	)
Net cash provided by operating activities	$	135,179		$	141,452		$	193,405		$	215,173
Additions to property, plant, and equipment	$	(250,286	)	$	(256,558	)	$	(283,389	)	$	(305,157	)
Net cash used in investing activities	$	(177,176	)	$	(183,449	)	$	(285,137	)	$	(306,905	)
Net increase in cash and cash equivalents	$	47,710		$	47,710		$	45,935		$	45,935
Cash and cash equivalents at the beginning of the period	$	97,483		$	97,483		$	145,193		$	145,193
Cash and cash equivalents at the end of the period	$	145,193		$	145,193		$	191,128		$	191,128
Accrued additions to property, plant, and equipment	$	3,069		$	11,396		$	17,765		$	6,032

Cleco Power
	FOR THE YEAR ENDED
				2009						2010
(THOUSANDS)	AS REPORTED			AS ADJUSTED			AS REPORTED			AS ADJUSTED
Accounts receivable	$	9,646		$	9,646		$	(35,261	)	$	(16,261	)
Accounts payable	$	10,831		$	18,254		$	3,936		$	8,934
Retainage payable	$	(11,921	)	$	(13,011	)	$	1,913		$	(27	)
Net cash provided by operating activities	$	141,726		$	148,059		$	148,701		$	170,759
Additions to property, plant, and equipment	$	(249,252	)	$	(255,585	)	$	(127,153	)	$	(149,211	)
Net cash used in investing activities	$	(141,998	)	$	(148,331	)	$	(112,614	)	$	(134,672	)
Net increase in cash and cash equivalents	$	46,571		$	46,571		$	46,799		$	46,799
Cash and cash equivalents at the beginning of the period	$	91,542		$	91,542		$	138,113		$	138,113
Cash and cash equivalents at the end of the period	$	138,113		$	138,113		$	184,912		$	184,912
Accrued additions to property, plant, and equipment	$	3,069		$	11,335		$	17,765		$	5,697

Statements of Cash Flows

Cleco Corporation and Cleco Power’s Consolidated Statements of Cash Flows are prepared using the indirect method described in the authoritative guidance for the presentation of the statement of cash flows. This method requires that net income be adjusted to remove the effects of all deferrals and accruals of operating cash receipts and payments and the effects of all investing and financing cash flow items. Derivatives meeting the definition of an accounting hedge are classified in the same category as the item being hedged.

Regulation

Cleco Power maintains its accounts in accordance with the Uniform System of Accounts prescribed for electric utilities by FERC, as adopted by the LPSC. Cleco Power’s retail rates are regulated by the LPSC, and its rates for transmission services and wholesale power sales are regulated by FERC. Cleco Power follows the authoritative guidelines for industry regulated operations, which allows utilities to capitalize or defer certain costs based on regulatory approval, and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process.

Pursuant to this authoritative guidance, Cleco Power has recorded regulatory assets and liabilities primarily for the effects of income taxes, postretirement plan costs, AFUDC equity gross-up, mining costs, and construction carrying costs. For more information regarding the regulatory assets and liabilities recorded by Cleco Power, see Note 3 — “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 Power 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 Power will be enacted or adopted and, if enacted, what form such legislation or regulation may take.

Asset Retirement Obligation

Cleco has recorded asset retirement obligations (liabilities) in accordance with the authoritative guidance. This authoritative guidance requires an entity to record 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.

At the point the liability for asset retirement is incurred, the authoritative guidance requires capitalization of the costs to the related property, plant, and equipment asset. For AROs existing at the time of adoption, the statement requires capitalization of costs at the level that existed at the point of incurring the liability. 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.

Under the authoritative guidance, the initial ARO liability recorded 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. For more information on Cleco’s AROs, see Note 3 — “Regulatory Assets and Liabilities — Asset Removal Costs.”

Property, Plant, and Equipment

Property, plant, and equipment consist primarily of regulated utility generation and energy transmission 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 4 — “Jointly Owned Generation Units.”

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 at December 31, 2011, and 2010 were $3.3 million and $3.8 million, respectively. Amortization of capitalized computer software costs charged to expense for the years ending December 31, 2011, 2010, and 2009 was $1.5 million, $1.7 million, and $1.5 million, respectively.

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 Corporation’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 were 2.80% for 2011, 2.55% for 2010, and 3.22% for 2009. The 0.25% increase in the percentage of average depreciable property for Cleco Power from 2010 to 2011 was primarily due to Cleco Power’s new retail rate plan, the addition of Madison Unit 3, the acquisition of Acadia Unit 1, and the addition of Teche Unit 4.

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

	YEARS
Utility plant	5-58
Other	5-44

During 2011, Cleco’s investment in regulated utility plant increased primarily due to the Acadiana Load Pocket project and the completion of Teche Unit 4. Teche Unit 4 has a useful life of 23 years.

Property, plant, and equipment consist of:

	AT DECEMBER 31,
(THOUSANDS)	2011			2010
Regulated utility plants	$	3,759,541		$	3,552,054
Other	264,114			258,842
Total property, plant, and equipment	4,023,655			3,810,896
Accumulated depreciation	(1,230,783		)	(1,162,456		)
Net property, plant, and equipment	$	2,792,872		$	2,648,440

In 2010, Cleco Power’s acquisition of Acadia Unit 1 resulted in a plant acquisition adjustment. The plant acquisition adjustment represents the fair market value of the assets acquired in excess of their carrying value. In January 2010, the LPSC approved the full recovery of the $304.0 million purchase price for the acquisition of Acadia Unit 1, which includes a plant acquisition adjustment in the amount of $95.6 million. The plant acquisition adjustment in the amount of $5.4 million relates primarily to the 1997 acquisition of Teche. For more information on the Acadia Unit 1 transaction, see Note 18 — “Acadia Transactions — Acadia Unit 1.” The following table discloses the amounts of plant acquisition adjustments reported in Cleco Power’s property, plant, and equipment and the associated accumulated amortization reported in accumulated depreciation at December 31, 2011, and December 31, 2010.

(THOUSANDS)	AT DECEMBER 31, 2011		AT DECEMBER 31, 2010
Acadia Unit 1
Plant acquisition adjustment	$	95,578	$	95,578
Less:  accumulated amortization	5,836		2,653
Net plant acquisition adjustment	$	89,742	$	92,925
Teche
Plant acquisition adjustment	5,359		$	5,359
Less:  accumulated amortization	3,724		3,470
Net plant acquisition adjustment	$	1,635	$	1,889

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. Cleco Power had spent approximately $1.2 million and $0.2 million as of December 31, 2011, and December 31, 2010, respectively, for various resource planning projects. These projects are still in the initial stages of development and as a result are classified as other deferred charges on Cleco Power’s Consolidated Balance Sheets.

Inventories

Fuel inventories consist of petroleum coke, coal, lignite, and natural gas used to generate electricity.

Materials and supplies inventory consists of transmission and distribution line construction and repair material, and generating station and transmission and distribution substation repair materials.

Both fuel and materials and supplies inventories are stated at average cost and are issued from inventory using the average cost of existing inventory. The amount of storeroom operating expenses allocated to inventory for the years ended December 31, 2011, and 2010 was $4.7 million and $3.2 million, respectively. Deferred storeroom operating expenses remaining in materials and supplies inventory as of December 31, 2011, and 2010 were $5.0 million and $1.9 million, respectively.

During 2010 and 2011, no fuel oil was purchased or burned. During 2011, Cleco Power sold its entire fuel oil supply. Cleco Power does not anticipate a need to use fuel oil as a fuel source going forward.

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. As of December 31, 2011, and 2010, the allowance for doubtful accounts amounted to $1.1 million and $3.5 million, respectively. There is no off-balance sheet credit exposure related to Cleco’s customers.

Financing Receivables

Cleco, through Perryville and Attala, has a combined net investment in direct financing lease long-term asset of $13.6 million. Each subsidiary leases its respective transmission assets to a single counterparty. Both counterparties are considered credit worthy and are expected to pay their obligations when due, thus, no allowance for credit loss has been recognized. Management bases this assessment on the following common factors of each counterparty:

• both counterparties use the respective transmission facilities to move electricity from its power plants to the regional transmission grid,

• neither counterparty has another avenue to move electricity from its respective power plants to the regional transmission grid,

• the stream of payments was approved by the FERC through respective rate orders, and

• both counterparties serve retail and wholesale customers in their respective service territories under LPSC oversight that allows recovery of prudent costs, of which, the stream of payments under the direct financing leases appear to be prudent.

Management monitors both entities for indication of adverse actions by their respective public service commissions and market conditions which would indicate an inability to pay their obligations under the direct financing leases when due. Since the inception of the agreements, each counterparty has paid their respective obligations when due and at December 31, 2011, no amounts were past due.

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 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 maintains reserves. The general liability and workers compensation reserves are immaterial because the balance of these items as of December 31, 2011, together represented 0.2% of total liabilities.

Cash Equivalents

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

Restricted Cash

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 corporate purposes. Cleco’s restricted cash consisted of:

	AT DECEMBER 31,
(THOUSANDS)	2011		2010
Diversified Lands’ mitigation escrow	$	97	$	97
Cleco Katrina/Rita’s storm recovery bonds	8,761		8,822
Cleco Power’s future storm restoration costs	24,876		25,992
Cleco Power’s renewable energy grant	381		—
Cleco Power’s GO Zone bonds	—		6,137
Cleco Power’s NOx allowance escrow	1,713		—
Total restricted cash	$	35,828	$	41,048

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 operating expenses, interest, and principal on storm recovery bonds. During 2011, Cleco Katrina/Rita collected $19.7 million net of operating expenses. In March and September 2011, Cleco Katrina/Rita used $6.3 million and $6.0 million, respectively for scheduled storm recovery bond principal payments and $3.8 million and $3.7 million, respectively for related interest. In 2011, Cleco Power received a $0.6 million renewable energy grant from the Louisiana Department of Natural Resources.

Equity Investments

Cleco reports its investment in unconsolidated affiliated companies on the equity method of accounting, as defined in the authoritative guidance on investments. The amounts reported on Cleco Corporation and Cleco Power's Consolidated Balance Sheets represent assets contributed by Cleco Corporation 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 of these affiliates are netted and reported on one line item as equity income from investees on Cleco Corporation and Cleco Power's Consolidated Statements of Income. For more information, see Note 12 — “Variable Interest Entities.”

Cleco applies the provisions of the authoritative guidance on investments to account for equity method investment impairments. Under this standard, Cleco evaluates at each balance sheet date whether 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. No impairments were recorded for 2011, 2010, or 2009. For more information, see Note 12 — “Variable Interest Entities.”

Prior to April 30, 2011, Cleco reported its investment in Cajun on the equity method of accounting. In conjunction with the disposition of Acadia Unit 2 to Entergy Louisiana, APH received 100% ownership in Acadia in exchange for its 50% ownership interest in Cajun, and Acadia became a consolidated subsidiary of APH. Following the transaction, Acadia’s assets, liabilities, revenues, expenses, and cash flows are presented on the corresponding line items of Cleco Corporation’s consolidated financial statements, prospectively. For more information on the Acadia Unit 2 transaction, see Note 18 — “Acadia Transactions — Acadia Unit 2.”

Effective January 1, 2010, FASB amended the authoritative guidance on consolidation. Beginning January 1, 2010, the assets, liabilities, revenues, expenses, and cash flows for Evangeline, Perryville, and Attala are presented in the corresponding line items of the consolidated financial statements. For more information, see Note 12 — “Variable Interest Entities.”

Income Taxes

Cleco accounts for income taxes under the appropriate authoritative guidance. 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 files a federal consolidated income tax return for all wholly owned subsidiaries. Cleco computes its federal and state income taxes as if it were a standalone taxpayer. The LPSC generally requires Cleco Power to flow the state tax benefit of deductions immediately to customers. The LPSC specifically requires that the state tax benefits associated with the deductions related to storm damages be normalized. For more information on income taxes, see Note 9 — “Income Taxes.”

Investment Tax Credits

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

New Markets Tax Credits

In August 2008, Cleco Corporation acquired a membership interest in U.S. Bank New Markets Tax Credit Fund 2008-1 LLC which was formed by U.S. Bancorp Community Development Corporation which purpose is to invest in projects located in qualified active low-income communities that are underserved by typical debt capital markets. These investments are designed to generate new markets tax credits and historical rehabilitation tax credits. In July 2011, the operating agreement of the Fund was amended to include renewable energy investments qualifying for grants under Section 1603 of the American Recovery and Reinvestment Tax Act of 2009. For more information, see Note 14 — “Litigation, Other Commitments and Contingencies, and Disclosures About Guarantees — Other Commitments — New Markets Tax Credits.”

Debt Expenses, Premiums, and Discounts

Expenses, premiums, and discounts applicable to debt securities are amortized to income ratably over the lives of the related issues. Expenses and call premiums related to refinanced Cleco Power debt are deferred and amortized over the life of the new issue.

Revenue and Fuel Costs

Utility RevenueRevenue from sales of electricity is recognized based upon the amount of energy delivered. The costs of fuel and purchased power used for retail customers currently are recovered from customers through the fuel adjustment clause. 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 delivered since the latest billings. The monthly estimated unbilled revenue amounts are recorded as revenue and a receivable and are reversed the following month.

Other Revenue Other revenue is recognized at the time products or services are provided to and accepted by customers.

Evangeline Midstream owns 100% of Evangeline. On February 22, 2010, Evangeline and JPMVEC entered into the Evangeline Restructuring Agreement whereby the parties agreed to terminate the existing Evangeline Tolling Agreement and enter into the Evangeline 2010 Tolling Agreement, which was considered to be an executory contract, whereby Evangeline’s revenues were derived. Some provisions, such as penalties and bonuses, were considered to be contingent and were recognized when the contingencies were fulfilled. A significant portion of Evangeline’s revenue was derived from a capacity payment, which it received when the plant was available to produce electricity. Evangeline also recognized variable revenue from the Evangeline 2010 Tolling Agreement which depended on the dispatch of the unit and the electricity generated. The Evangeline 2010 Tolling Agreement expired on December 31, 2011. Beginning January 1, 2012, Coughlin’s capacity and energy became available to Midstream. Evangeline was one of the successful bidders in Cleco Power’s RFP for short-term 2012 resources beginning January 1, 2012, and is currently providing 250 MW of capacity and energy to Cleco Power under a tolling agreement through April 30, 2012. In addition to Cleco Power’s RFP referenced above, in December 2011, Evangeline was also notified that Cleco Power selected its proposal to fulfill Cleco Power’s capacity and energy needs as defined in the Cleco Power RFP for contractual resources to meet CSAPR beginning in May 2012. The proposal was for a 730-MW product beginning May 1, 2012, and ending April 30, 2015. The definitive agreement between Evangeline and Cleco Power was executed in January 2012 and has been submitted to the LPSC and FERC for approval. Currently, Midstream is marketing Coughlin’s capacity for periods beginning after April 30, 2015, and is evaluating various options to optimize Coughlin’s value.

For more information on Evangeline, see Note 17 — “Evangeline Transactions.”

Perryville and Attala Cleco Corporation owns 100% of Perryville and Attala. Both companies provide transmission to a single customer. The transmission tariffs charged by both companies are regulated by FERC.

Franchise Fees Cleco Power collects a consumer fee for one of its franchise agreements. This fee is not recorded on Cleco’s income statement as revenue and expense, but is reflected at gross amounts on Cleco’s balance sheet as a receivable until it is collected and as a payable until the liability is paid. Cleco currently does not have any excise taxes reflected on its income statement.

AFUDC

The capitalization of AFUDC by Cleco Power is a utility accounting practice prescribed by FERC and the LPSC. AFUDC represents the estimated cost of financing construction and is not a current source of cash. 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 12.0% on a pre-tax basis (7.5% net of tax) for 2011, 11.9% on a pre-tax basis (7.4% net of tax) for 2010, and 12.3% on a pre-tax basis (7.6% net of tax) for 2009.

Capitalized Interest

Cleco and its subsidiaries, except Cleco Power (see AFUDC above), capitalize interest costs related to longer-term construction projects. Other than AFUDC at Cleco Power, no interest was capitalized in 2011, 2010, or 2009.

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 are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP.  Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the consolidated balance sheets with their fair values disclosed without regard to the three levels. For more information about fair value levels, see Note 5 — “Fair Value Accounting.”

Risk Management

Market risk inherent in Cleco Power’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas 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 and natural gas. Cleco applies the authoritative guidance as it relates to derivatives and hedging to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Generally, Cleco Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting because Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements. Cleco Power entered into certain financial transactions it considered economic hedges to mitigate the risk associated with the fixed-price power provided to a wholesale customer through December 2010.

Cleco Power may enter into positions to mitigate the volatility in customer fuel costs. These positions are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of energy risk management assets or liabilities. Such gain or loss is deferred as a component of deferred fuel assets or liabilities. When these positions close, actual gains or losses will be included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment.

Cleco Power maintains margin accounts with commodity brokers used to partially fund the acquisition of natural gas futures, options and swap contracts. These contracts/positions are used to mitigate the risks associated with the volatility in customer fuel costs noted above. The current and long-term portions of collateral are reported as a component of energy risk management assets or liabilities and other deferred credits, respectively.

Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, counterparty credit exposure, and counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and by 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 has entered into various 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 these contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified as earnings in the periods in which earnings are affected by the variability of the cash flows of the hedged item. The ineffective portions of hedges will be recognized in current-period earnings unless management determines that it is probable that the costs will be recovered through the rate making process. If management determines that it is probable that the costs will be recovered, then they will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For those contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that do not qualify as cash flow hedges, the changes in the fair value of such derivative instruments will be recognized in current period earnings unless management determines that it is probable that the costs will be recovered through the rate-making process. If management determines that it is probable that the costs will be recovered, then they will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For more information on the interest rate risk contracts, see Note 5 — “Fair Value Accounting — Interest Rate Derivatives.”

Recent Authoritative Guidance

The Registrants adopted, or will adopt, the following recent authoritative guidance on their respective effective dates.

In July 2010, FASB amended the authoritative guidance on receivables, which required companies to improve their disclosures about the credit quality of their financing receivables and the credit reserves held against them. For public companies, the amendment was effective for interim and annual reporting periods ending on or after December 15, 2010, with specific items, such as allowance rollforward and modification disclosures, effective for periods beginning after December 15, 2010. The adoption of this amendment did not have any effect on the financial condition or results of operations of the Registrants.

In December 2010, FASB amended the authoritative guidance on business combinations to expand supplemental pro forma disclosures and to require comparative prior period financial statement disclosures as if the combination occurred as of the beginning of the prior annual period. The amendment was effective prospectively for business combination acquisition dates on or after the beginning of the first annual reporting period beginning on or after December 15, 2010. The adoption of this amendment did not have any effect on the financial condition or results of operations of the Registrants.

In April 2011, FASB issued additional guidance to creditors for evaluating whether a modification or restructuring of a receivable is a troubled debt restructuring. The implementation of this guidance was effective in the first interim or annual period beginning on or after June 15, 2011. The adoption of this guidance did not have an impact on the financial condition or results of operations of the Registrants.

In April 2011, FASB issued guidance to improve the accounting for repurchase agreements and other similar agreements. Specifically, this guidance modifies the criteria for determining when these transactions would be accounted for as financings as opposed to sales or purchases with commitments to repurchase or resale. The adoption of this guidance is effective in the first interim or annual period beginning on or after December 15, 2011. The adoption of this guidance is not expected to have an impact on the financial condition or results of operations of the Registrants.

In May 2011, FASB issued guidance on fair value measurements. This guidance results in a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and IFRS (International Financial Reporting Standards). The adoption of this guidance is effective prospectively for interim and annual periods beginning after December 15, 2011. The adoption of this guidance is not expected to have a material impact on the financial condition or results of operations of the Registrants.

In June 2011, FASB issued guidance on the presentation of comprehensive income. This guidance eliminates the current option to report other comprehensive income and its components in the statement of changes in equity. The adoption of this guidance is effective for interim and annual periods beginning after December 15, 2011. In December 2011, the FASB deferred the requirements relating to the presentation of reclassifications of items out of accumulated other comprehensive income until a later date to be determined by the FASB. The other provisions of the June 2011 guidance are not affected by this deferral. The adoption of this guidance will not have any impact on the financial condition or results of operations of the Registrants.

In September 2011, FASB revised the testing of goodwill for impairment. The revision provides entities the option to first use qualitative factors to determine whether it is necessary to perform the quantitative two-step test. The adoption of this guidance is effective for interim and annual goodwill impairment tests performed for fiscal years beginning after December 15, 2011, with some provisions for early adoption. The adoption of this guidance will not have any impact on the financial condition or results of operations of the Registrants.

In December 2011, FASB revised the accounting for a parent that ceases to have a controlling financial interest in a subsidiary due to a default on the subsidiary’s non-recourse debt when the subsidiary is in substance real estate by requiring the application of real estate sales guidance. This revision is effective for events occurring on or after June 15, 2012. The adoption of this guidance will not have any impact on the financial condition or results of operations of the Registrants.

In December 2011, FASB revised the disclosure requirements related to balance sheet offsetting. After the effective date, entities must disclose both the gross and net information about instruments and transactions eligible for offsetting on the balance sheet, including transactions under master netting agreements. The adoption of this revision is required for interim and annual periods beginning on or after January 1, 2013. The adoption of this revision will not have any effect on the financial condition or results of operations of the Registrants since it relates to disclosures.

Earnings per Average Common Share

The following table shows the calculation of basic and diluted earnings per share.

	FOR THE YEAR ENDED DECEMBER 31,
				2011					2010					2009
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Income from continuing operations	$	195,848				$	255,391				$	106,307
Deduct:  non-participating stock dividends (4.5% preferred stock)	26					46					46
Deduct:  non-participating stock redemption costs (4.5% preferred stock)	112					—					—
Basic net income applicable to common stock	$	195,710	60,488,740	$3.24		$	255,345	60,431,142	$	4.23	$	106,261	60,187,894	$	1.77
Effect of dilutive securities
Add:  stock option grants			20,647					32,080					32,050
Add:  restricted stock (LTICP)			324,177					291,367					278,261
Diluted net income applicable to common stock	$	195,710	60,833,564	$	3.22	$	255,345	60,754,589	$	4.20	$	106,261	60,498,205	$	1.76

Stock option grants excluded from the computation of 2009 diluted earnings per share are presented in the following table. These stock option grants were excluded from the computation of 2009 diluted earnings per share because they had exercise prices higher than the average market price. There were no stock option grants excluded from the computation of 2011 or 2010 diluted earnings per share.

	FOR THE YEAR ENDED DECEMBER 31, 2009
	STRIKE PRICE	AVERAGE MARKET  PRICE	SHARES
Stock option grants excluded	$ 23.31 - $ 24.25	$23.28	57,766

Preferred Stock Redemption

On June 24, 2011, Cleco Corporation redeemed all 10,288 outstanding shares of its 4.5% preferred stock. The redemption price was $101 per share plus accrued and unpaid dividends to the redemption date, or $101.296 per share. As of the redemption date, no shares of 4.5% preferred stock were outstanding. Holders are no longer entitled to dividends and all rights of such holders as shareholders of Cleco Corporation by reason of their ownership of such 4.5% preferred stock have ceased.

Stock-Based Compensation

For information on Cleco’s stock-based compensation, see Note 7 — “Common and Preferred Stock — Common Stock — Stock-Based Compensation.”