PowerSecure International 10-Q 6 May 16 2016 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	3 Months Ended
	Mar. 31, 2016	May. 02, 2016
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1
Entity Registrant Name	POWERSECURE INTERNATIONAL, INC.
Entity Central Index Key	882,154
Trading Symbol	powr
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		22,508,173

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Current Assets:
Cash and cash equivalents	$ 6,399	$ 18,433
Trade receivables, net of allowance for doubtful accounts of $464 and $502, respectively	115,864	137,899
Inventories	65,843	64,062
Income taxes receivable	389	361
Prepaid expenses and other current assets	2,419	3,413
Total current assets	190,914	224,168
Property, plant and equipment:
Equipment	73,882	69,484
Furniture and fixtures	766	766
Land, building and improvements	8,089	8,089
Total property, plant and equipment, at cost	82,737	78,339
Less accumulated depreciation and amortization	26,926	25,730
Property, plant and equipment, net	55,811	52,609
Other noncurrent assets:
Goodwill	41,582	41,582
Deferred tax asset, net	2,776
Restricted annuity contract	3,137	3,137
Intangible assets and capitalized software costs, net of accumulated amortization of $11,872 and $10,903, respectively	11,109	11,830
Other assets	2,443	2,489
Total other noncurrent assets	61,047	59,038
Total Assets	307,772	335,815
Current liabilities:
Accounts payable	57,460	88,370
Accrued and other liabilities	47,234	54,917
Accrued restructuring liabilities	38	585
Current portion of long-term debt	4,245	4,416
Total current liabilities	108,977	$ 148,288
Long-term liabilities:
Revolving line of credit	25,000
Long-term debt, net of current portion	13,261	$ 14,187
Deferred tax liability, net		2,911
Other long-term liabilities	4,298	4,941
Total long-term liabilities	$ 42,559	$ 22,039
Commitments and contingencies (Notes 9)
Stockholders' Equity:
Preferred stock
Common stock, $.01 par value; 50,000,000 shares authorized; 22,508,173 and 22,501,173 shares issued and outstanding, respectively	$ 225	$ 225
Additional paid-in-capital	165,142	164,429
Retained earnings (deficit)	(9,025)	898
Accumulated other comprehensive income (loss)	(106)	(64)
Total stockholders' equity	156,236	165,488
Total Liabilities and Stockholders' Equity	$ 307,772	$ 335,815
Series C Preferred Stock [Member]
Stockholders' Equity:
Preferred stock

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Trade receivables, allowance for doubtful accounts	$ 464	$ 502
Intangible rights and capitalized software costs, accumulated amortization	$ 11,872	$ 10,903
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	2,000,000	2,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	50,000,000	50,000,000
Common stock, shares issued	22,508,173	22,501,173
Common stock, shares outstanding	22,508,173	22,501,173
Series C Preferred Stock [Member]
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	500,000	500,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0

Condensed Consolidated Statemen

Condensed Consolidated Statements Of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Consolidated Statements Of Operations [Abstract]
Revenues	$ 105,151	$ 79,509
Cost of sales (excluding depreciation and amortization)	95,865	58,180
Gross profit	9,286	21,329
Operating expenses:
General and administrative	18,439	15,634
Selling, marketing and service	3,295	2,748
Depreciation and amortization	2,728	2,477
Total operating expenses	24,462	20,859
Operating income (loss)	(15,176)	470
Other income and (expenses):
Interest income and other income	1	1
Interest expense	(394)	(269)
Income (loss) before income taxes	(15,569)	202
Income tax expense (benefit)	(5,646)	81
Net income (loss)	$ (9,923)	$ 121
Earnings (loss) per share:
Basic	$ (0.44)	$ 0.01
Diluted	$ (0.44)	$ 0.01
Weighted average common shares outstanding during the period:
Basic	22,505	22,385
Diluted	22,505	22,489

Condensed Consolidated Stateme5

Condensed Consolidated Statements Of Comprehensive Income (Loss) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Consolidated Statements Of Comprehensive Income (Loss) [Abstract]
Net income (loss)	$ (9,923)	$ 121
Other comprehensive income (loss), net of tax:
Unrealized foreign currency translation adjustment, net of tax benefit of $0 and $0, respectively	20
Cash flow hedge:
Change in unrealized gain (loss)	(84)	(81)
Reclassification adjustment for net (gains) losses included in net income (loss)	22	36
Other comprehensive income (loss) from cash flow hedge, net of tax	(62)	(45)
Total other comprehensive income (loss), net of tax	(42)	(45)
Total comprehensive income (loss), net of tax	$ (9,965)	$ 76

Condensed Consolidated Stateme6

Condensed Consolidated Statements Of Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Consolidated Statements Of Comprehensive Income (Loss) [Abstract]
Unrealized foreign currency translation adjustment, tax	$ 0	$ 0

Condensed Consolidated Stateme7

Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities:
Net income (loss)	$ (9,923)	$ 121
Adjustments to reconcile net income (loss) to net cash used in operating activities:
Depreciation and amortization	2,728	2,477
Stock compensation expense	632	650
(Gain) loss on disposal of miscellaneous assets	91	(22)
Changes in operating assets and liabilities:
Trade receivables, net	22,035	(8,906)
Inventories	(1,781)	(2,047)
Deferred taxes	(5,646)
Other current assets and liabilities	973	1,348
Other noncurrent assets and liabilities	(701)	(9)
Accounts payable	(30,910)	(619)
Accrued and other liabilities	(7,683)	737
Accrued restructuring liabilities	(547)	(88)
Net cash used in operating activities	(30,732)	(6,358)
Cash flows from investing activities:
Purchases of property, plant and equipment	(5,060)	(2,012)
Additions to intangible rights and software development	(247)	(802)
Proceeds from sale of property, plant and equipment	8	146
Net cash used in investing activities	(5,299)	$ (2,668)
Cash flows from financing activities:
Borrowings (payments) on revolving line of credit	25,000
Principal payments on term loans	(1,104)	$ (933)
Principal payments on capital lease obligations		(241)
Proceeds from stock option exercises	81	271
Net cash provided by (used in) financing activities	23,977	(903)
Effects of currency exchange rate changes on cash and cash equivalents	20
Net decrease in cash and cash equivalents	(12,034)	(9,929)
Cash and cash equivalents at beginning of period	18,433	33,775
Cash and cash equivalents at end of period	$ 6,399	$ 23,846

Description Of Business And Bas

Description Of Business And Basis Of Presentation	3 Months Ended
	Mar. 31, 2016
Description Of Business And Basis Of Presentation [Abstract]
Description Of Business And Basis Of Presentation	1. Description of Business and Basis of Presentation Description of Business PowerSecure International, Inc., headquartered in Wake Forest, North Carolina, is a leading provider of products and services to electric utilities, and their large commercial, institutional and industrial customers. On February 24, 2016, we entered into an Agreement and Plan of Merger, which we refer to as the Merger Agreement, with The Southern Company, Inc., or Southern Company. See Note 2 for further information on this merger. We provide products and services through our four reportable segments: our Distributed Generation segment, our Solar Energy segment, our Utility Infrastructure segment, and our Energy Efficiency segment. These four reportable segments constitute our major product and service offerings, each of which are focused on serving the needs of utilities and their large commercial, institutional and industrial customers to help them generate, deliver, and utilize electricity more reliably and efficiently. Our strategy is focused on growing these four segments, which require unique knowledge and skills that utilize our core competencies, because they address large market opportunities due to their strong customer value propositions. The segments share common or complementary utility relationships and customer types, common sales and overhead resources, and facilities. However, we distinguish our operations among these segments due to their unique products and services, differing economic characteristics, market needs they are addressing, and the distinct technical disciplines and specific capabilities required for us to deliver their products and services, including personnel, technology, engineering, and intellectual capital. We currently operate primarily out of our Wake Forest, North Carolina headquarters office. Our operations also include several satellite offices and manufacturing facilities, the largest of which are in the Raleigh-Durham and Greensboro, North Carolina, Atlanta, Georgia, Bethlehem, Pennsylvania, and Stamford, Connecticut areas. The locations of our sales organization and field employees for our operations are generally in close proximity to the utilities and commercial, industrial, and institutional customers they serve. Our four operating segments are operated through our principal operating wholly-owned subsidiary, PowerSecure, Inc.  See Note 11 for more information concerning our reportable segments. Basis of Presentation Organization – The accompanying condensed consolidated financial statements include the accounts of PowerSecure International, Inc. and its subsidiaries, primarily PowerSecure, Inc. and its majority-owned and wholly-owned subsidiaries, UtilityEngineering, Inc., PowerServices, Inc., PowerSecure Lighting, LLC (“PowerSecure Lighting”), Solais Lighting, Inc. (“Solais”), EnergyLite, Inc.(“EnergyLite”), Reid’s Trailer, Inc. d/b/a PowerFab (“PowerFab”), Innovation Energies, LLC, and PowerSecure Solar, LLC (“PowerSecure Solar”) and PowerPackages, LLC which are collectively referred to as the “Company” or “PowerSecure” or “we” or “us” or “our”.  These condensed consolidated financial statements have been prepared pursuant to rules and regulations of the Securities and Exchange Commission. The accompanying condensed consolidated financial statements and notes thereto should be read in conjunction with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015. In management’s opinion, all adjustments (all of which are normal and recurring) have been made which are necessary for a fair presentation of the condensed consolidated financial position of us and our subsidiaries as of March 31, 2016 and the condensed consolidated results of our operations, comprehensive income (loss) and cash flows for the three months ended March 31, 2016 and 2015. Principles of Consolidation – The condensed consolidated financial statements include the accounts of PowerSecure International, Inc. and its subsidiaries after elimination of intercompany accounts and transactions. Foreign Currency Translation – The functional currency of PowerSecure’s subsidiary in Canada is the local currency. The financial statements of PowerSecure’s Canadian subsidiary is translated into the Company’s reporting currency, which is the U.S. dollar. The foreign currency translation adjustments are recorded as a separate component of accumulated other comprehensive income (loss). The Company does not have any other foreign subsidiaries.  Use of Estimates – The preparation of our consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires that our management make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates include, among others, percentage-of-completion estimates for revenue and cost of sales recognition, incentive compensation and commissions, allowance for doubtful accounts receivable, inventory valuation reserves, warranty reserves, deferred tax valuation allowance, purchase price allocations on business acquisitions, fair value estimates of interest rate swap contracts and any impairment charges on long-lived assets and goodwill. Reclassifications – Certain 2015 amounts have been reclassified to conform to current year presentation. Such reclassifications had no effect on net income (loss) or stockholders’ equity as previously reported. 

Proposed Merger With Southern C

Proposed Merger With Southern Company	3 Months Ended
	Mar. 31, 2016
Proposed Merger [Abstract]
Proposed Merger With Southern Company	1. Proposed Merger with Southern Company  On February 24, 2016, we entered into the Merger Agreement with Southern Company and a wholly-owned subsidiary of Southern Company, which we refer to as the Merger Sub, providing for the merger of the Merger Sub with and into PowerSecure, with PowerSecure surviving as a wholly-owned subsidiary of Southern Company (the “Merger”) . At the effective time of the M erger, subject to meeting specified customary closing conditions, each share of our common stock will be converted automatically into the right to receive $18.75 in cash, without interest, less any applicable withholding taxes. The Merger Agreement also provides that , at the effective time of the M erger, (i) all outstanding stock options will be deemed to be fully vested and converted into the right to receive a cash payment equal to the excess of the merger consideration over the exercise prices of such stock options, (ii) all outstanding restricted shares and restricted stock units will be deemed to be fully vested and converted into the right to receive the merger consideration, except for certain unvested restricted shares held by our Chief Executive Officer, which will be converted into a stock award relating to shares of Southern Company, and (iii) all performance share units payable in shares of Common Stock will be deemed vested at the target level of achievement and converted into the right to receive the merger consideration. In the Merger Agreement, we agreed to covenants affecting the conduct of our business between the date of the Merger Agreement and the effective date of the M erger.  Completion of the Merger is subject to various closing conditions, including, among others (i) the approval of the Merger Agreement by the affirmative vote of the holders of a majority of all outstanding shares of our common stock, which occurred at the special meeting of stockholders held on May 5, 2016, (ii) the receipt of all regulatory approvals required to consummate the Merger , including expiration of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act, as amended (the Hart-Scott-Rodino Act), which have been received, (iii) the a bsence of any law or injunction prohibiting the closing of the Merger , and (iv) other customary closing conditions, including (a) the accuracy of each party’s representations and warranties (subject to customary materiality qualifiers), (b) each party’s performance in all material respects with its obligations under the Merger Agreement, and (c) no material adverse effect (as defined in the Merger Agreement) on us having occurred. The Merger is not subject to any financing condition.  The Merger Agreement contains customary representations, warranties and covenants by us and Southern Company , including, among others, covenants by us not to solicit proposals relating to alternative business combinations or, subject to certain exceptions, enter into discussions concerning or provide information in connection with alternative business combination proposals or withdraw or adversely modify the recommendation of our Board in favor of the stockholder approval. In addition, the Merger Agreement contains (i) agreements by us to conduct our business in the ordinary course until the Merger is consummated, to not engage in certain kinds of transactions, and (ii) agreements by each of the parties to use their reasonable best efforts to obtain all required regulatory approvals.  The Merger Agreement contains certain termination rights, including the right by us to terminate the Merger Agreement if our Board has changed its recommendation in favor of the Merger in connection with a “Superior Proposal” or “Intervening Event” as such terms are defined in the Merger Agreement. The Merger Agreement also provides that, upon termination of the Merger Agreement in specified circumstances, we will be required to pay Southern Company a termination fee of $12.0 million. In addition, subject to certain exceptions and limitations, either party may terminate the Merger Agreement if the Merger is not consummated by November 30, 2016.  On February 23, 2016, the lenders under our credit facility provided a waiver of any event of default arising from the execution of the Merger Agreement (but not the consummation of the Merger) under the credit agreement with our lenders. On May 6, 2016, those lenders also provided a waiver of any event of default arising under the credit agreement from (i) the consummation of the Merger Agreement under th e credit agreement, and (ii) our failure to comply with the minimum fixed charge coverage ratio financial covenant under the credi t agreement at March 31, 2016.  On March 31, 2016, the U.S. Federal Trade Commission granted early termination of the waiting period under the Hart-Scott-Rodino Act with regard to the Merger, and on May 5, 2016, at a special meeting of shareholders of the Company, the holders of a majority of all outstanding shares of our common stock voted to approve the Merger, thus fulfilling two of the primary conditions to complete the transaction.  As of the date of this report, the Company expects to complete the Merger on or around May 9, 2016. 

Summary Of Significant Accounti

Summary Of Significant Accounting Policies And Recent Accounting Standards	3 Months Ended
	Mar. 31, 2016
Summary Of Significant Accounting Policies And Recent Accounting Standards [Abstract]
Summary Of Significant Accounting Policies And Recent Accounting Standards	3. Summary of Significant Accounting Policies and Recent Accounting Standards Revenue Recognition – For our turn-key project-based revenues, we recognize revenue and profit as work progresses using the percentage-of-completion method, which relies on various estimates. These turn-key Distributed Generation, Solar Energy, Utility Infrastructure, and Energy Efficiency Services projects are nearly always fixed-price contracts. In applying the percentage-of-completion method to our Distributed Generation and Solar Energy turn-key projects, we have identified the key output project phases that are standard components of these projects. We have further identified, based on past experience, an estimate of the value of each of these output phases based on a combination of the costs incurred and the value added to the overall project. While the order of these phases varies depending on the project, each of these output phases is necessary to complete each project and each phase is an integral part of the turn-key product solution we deliver to our customers. We use these output phases and percentages to measure our progress toward completion of our construction projects. For each reporting period, the status of each project, by phase, is determined by employees who are managers of or are otherwise directly involved with the project, and this determination is reviewed by our accounting personnel. Utilizing this information, we recognize project revenues and associated project costs and gross profit based on the percentage associated with output phases that are complete or in process on each of our projects. In applying the percentage-of-completion method to Distributed Generation projects that specifically involve data center infrastructure construction, Utility Infrastructure turn-key projects and our Energy Efficiency Services projects, revenues and gross profit are recognized as work is performed based on the relationship between actual costs incurred and total estimated costs at completion. In all cases where we utilize the percentage-of-completion method, revenues and gross profit are adjusted prospectively for revisions in estimated total contract costs and contract values. Estimated losses, if any, are recorded when identified. While a project is in process, amounts billed to customers in excess of revenues recognized to date are classified as current liabilities. Likewise, amounts recognized as revenue in excess of actual billings to date are recorded as unbilled accounts receivable. In the event adjustments are made to the contract price, including, for example, adjustments for additional scope, we adjust the purchase price and related costs for these items when they are identified. Because the percentage-of-completion method of accounting relies upon estimates as described above, recognized revenues and profits are subject to revision as a project progresses to completion. Revisions in profit estimates are recorded to income in the period in which the facts that give rise to the revision become known. In the event we are required to adjust any particular project’s estimated revenues or costs, the effect on the current period earnings may or may not be significant. If, however, conditions arise that require us to adjust our estimated revenues or costs for a series of similar construction projects, or on very large projects, the effect on current period earnings would more likely be significant. In addition, certain contracts contain cancellation provisions permitting the customer to cancel the contract prior to completion of a project. Such cancellation provisions generally require the customer to pay/reimburse us for costs we incurred on the project, but may result in an adjustment to profit already recognized in a prior period. Service revenue includes regulatory consulting and rate design services, power system engineering services, energy conservation services, compliance services, and monitoring and maintenance services. Revenues from these services are recognized when the service is performed and the customer has accepted the work. Additionally, our utility infrastructure business provides services to utilities involving construction, maintenance, and upgrades to their electrical transmission and distribution systems which is not fixed price turn-key project-based work. These services are delivered by us under contracts which are generally of two types. In the first type, we are paid a fee based on the number of units of work we complete, an example of which could be the number of utility transmission poles we replace. In the second type, we are paid for the time and materials utilized to complete the work, plus a profit margin. In both of these cases, we recognize revenue as these services are delivered. We recognize revenue on non-project-based equipment and product sales when persuasive evidence of a commercial arrangement exists, delivery has occurred and/or services have been rendered, the price is fixed or determinable, and collectability is reasonably assured. Equipment and product sales are generally made directly to end users of the product, who are responsible for payment for the product, although in some instances we can be a subcontractor, which occurs most frequently on larger jobs that involve more scope than our products and services, and in other instances we sell through distributors.  Revenues for our recurring revenue distributed generation projects are recognized over the term of the contract or when energy savings are realized by the customer at its site. Under these arrangements, we provide utilities and their customers with access to PowerSecure-owned and operated distributed generation systems, for standby power and to deliver peak shaving benefits. These contracts can involve multiple parties, with one party paying us for the value of backup power (usually, but not always, a commercial, industrial, or institutional customer), and one party paying us a fee or credit for the value of the electrical capacity provided by the system during peak power demand (either the customer or a utility). Sales of certain goods and services sometimes involve the provision of multiple deliverables. Revenues from contracts with multiple deliverables are recognized as each element is earned based on the selling price for each deliverable. The selling price for each deliverable is generally based on our selling price for that deliverable on a stand-alone basis, third-party evidence if we do not sell that deliverable on a stand-alone basis, or an estimated selling price if neither specific selling prices nor third-party evidence exists. Cash and Cash Equivalents – Cash and all highly liquid investments with a maturity of three months or less from the date of purchase, including money market mutual funds, short-term time deposits, and government agency and corporate obligations, are classified as cash and cash equivalents. Accounts Receivable – Accounts receivable includes both billed and unbilled receivables from our customers. The balance of unbilled receivables included in accounts receivable was $47.7 million and $63.9 million at March 31, 2016 and December 31, 2015, respectively. Our customers include a wide variety of mid-sized and large businesses, utilities and institutions. We perform ongoing credit evaluations of our customers’ financial condition and generally do not require collateral. We monitor collections and payments from our customers and adjust credit limits of customers based upon payment history and a customer’s current credit worthiness, as judged by us. In certain instances, from time to time, we may purchase credit insurance on our accounts receivable in order to minimize our exposure to potential credit loss. We maintain a provision for estimated credit losses. Concentration of Credit Risk – We are subject to concentrations of credit risk from our cash and cash equivalents and accounts receivable. We limit our exposure to credit risk associated with cash and cash equivalents by placing them with multiple domestic financial institutions. Nevertheless, our cash in bank deposit accounts at these financial institutions frequently exceeds federally insured limits. We have not experienced any losses in such accounts. From time to time, we have derived a material portion of our revenues from one or more significant customers. To date, nearly all our revenues have been derived from sales to customers within the United States, although we recently commenced deriving revenues from sales to customers in Canada and the Bahamas, and expect revenues from customers in such countries to increase in the future.  Inventories – Inventories are stated at the lower of cost (determined primarily on a specific-identification basis for the majority of our distributed generation inventory and secondarily on a first-in first-out basis for our LED-based lighting product inventory) or market. Our raw materials, equipment and supplies inventory consist primarily of equipment with long lead-times purchased for anticipated customer orders. Our work in progress inventory consists primarily of equipment and parts allocated to specific Distributed Generation and Solar project s accounted for on the percentage-of-completion basis. Our finished goods inventory consists primarily of LED-based lighting products stocked to meet customer order and delivery requirements. Inventory also includes shipping costs incurred on incoming product shipments. We provide a valuation reserve primarily for raw materials, equipment and supplies and certain work in process inventory items that may be in excess of our needs, obsolete or damaged and requiring repair or re-work.  Property, Plant and Equipment – Property, plant and equipment are stated at cost and are generally depreciated using the straight-line method over their estimated useful lives, which depending on asset class ranges from 3 to 30 years.  Goodwill and Other Intangible Assets – We amortize the cost of specifically identifiable intangible assets that do not have an indefinite life over their estimated useful lives. We do not amortize goodwill and intangible assets with indefinite lives. We perform reviews of goodwill and intangible assets with indefinite lives for impairment annually, as of October 1, or more frequently if impairment indicators arise. We capitalize software development costs integral to our products once technological feasibility of the products and software has been determined. Purchased software and software development costs are amortized over five years, using the straight-line method. Patents and license agreements are amortized using the straight-line method over the lesser of their estimated economic lives or their legal term of existence, currently 3 to 5 years.  Debt Issuance Costs – Debt issuance costs associated with our revolving line of credit are capitalized and included in other current and non-current assets in our condensed consolidated balance sheets. Debt issuance costs associated with our term loan debt are capitalized and included as a reduction of the balance of our long-term debt. In both cases, these costs are amortized over the term of the corresponding debt instrument using the straight-line method for debt issuance costs related to the revolving portion of our credit facility and the effective interest method for debt issuance costs on our term loan debt. Amortization of debt issuance costs is included in interest expense in our condensed consolidated statements of operations.  Warranty Reserve – We provide a standard one year warranty for our Distributed Generation, switchgear, Utility Infrastructure, and Energy Efficiency Services equipment and a 5 to 10 year warranty for our LED lighting-based products. In certain cases, we offer extended warranty terms for those product lines. In addition, we provide longer warranties for our Solar Energy products and services including a warranty period of generally 1 to 5 years for defects in material and workmanship, a warranty period that can extend to 10 to 20 years for declines in power performance, and a warranty period which can extend to 15 to 25 years on the functionality of solar panels which is generally backed by the panel manufacturer. We reserve for the estimated cost of product warranties when revenue is recognized, and we evaluate our reserve periodically by comparing our warranty repair experience by product. The balance of our warranty reserve was $1.7 million and $1.7 million at March 31, 2016 and December 31, 2015, respectively, and is included in accrued and other liabilities in the accompanying condensed consolidated balance sheet.  Share-Based Compensation – We measure compensation cost for all stock-based awards at their fair value on date of grant and recognize the compensation expense over the service period for awards expected to vest, net of estimated forfeitures. We measure the fair value of restricted stock awards based on the number of shares granted and the last sale price of our common stock on the date of the grant. We measure the fair value of restricted stock units based on the underlying number of shares included in the units that are granted and the last sale price of our common stock on the date of the grant. We measure the fair value of performance unit awards based on the underlying number of shares included in the performance units and the last sale price of our common stock on the date of the grant. We measure the fair value of stock options using the Black-Scholes valuation model. Pre-tax share-based compensation expense recognized during the three months ended March 31, 2016 and 2015 was $0.6 million and $0.7 million, respectively. All share-based compensation expense is included in general and administrative expense in the accompanying condensed consolidated statements of operations.  Impairment or Disposal of Long-Lived Assets –We evaluate our long-lived assets whenever significant events or changes in circumstances occur that indicate that the carrying amount of an asset may be impaired. Recoverability of these assets is determined by comparing the forecasted undiscounted future cash flows from the operations to which the assets relate, based on management’s best estimates using appropriate assumptions and projections at the time, to the carrying amount of the assets. If the carrying value is determined not to be recoverable from future operating cash flows, the asset is deemed impaired and an impairment loss is recognized equal to the amount by which the carrying amount exceeds the estimated fair value of the asset or assets. We did not record any long-lived asset impairment charges during the three months ended March 31, 2016 and 2015.  Income Taxes – We recognize deferred income tax assets and liabilities for the estimated future tax consequences attributable to temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. We have net operating loss carryforwards available in certain jurisdictions to reduce future taxable income. Future tax benefits for net operating loss carryforwards are recognized to the extent that realization of these benefits is considered more likely than not. To the extent that available evidence raises doubt about the realization of a deferred income tax asset, a valuation allowance is established. We recognize a liability and income tax expense, including potential penalties and interest, for uncertain income tax positions taken or expected to be taken. The liability is adjusted for positions taken when the applicable statute of limitations expires or when the uncertainty of a particular position is resolved.  Derivative Financial Instruments – Our derivative financial instruments consist solely of two interest rate swap contracts that are used to hedge our interest rate risk on a portion of our variable rate debt. These interest rate swap contracts are designated as cash flow hedges. It is our policy to execute such interest rate swaps with creditworthy banks and we do not enter into derivative financial instruments for speculative purposes.  Fair Value Measurement s – We measure our derivative instruments at fair value on a recurring basis. The fair value measurements standard establishes a framework for measuring fair value. The framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements), and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy under the standard are described below:  Level 1 – Inputs to the valuation methodology are unadjusted quoted prices for identical assets or liabilities in active markets.  Level 2 – Inputs to the valuation methodology include:  Quoted market prices for similar assets or liabilities in active markets;  Quoted prices for identical or similar assets or liabilities in inactive markets;  Inputs other than quoted prices that are observable for the asset or liability;  Inputs that are derived principally from or corroborated by observable market data by correlation or other means. If the asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability.  Level 3 – Inputs to the valuation methodology are unobservable and significant to the fair value measurement.  The asset’s or liability’s fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Valuation techniques used need to maximize the use of observable inputs and minimize the use of unobservable inputs.  See Note 7 for more information concerning the fair value of our derivative instruments. Subsequent Events —Subsequent events are events or transactions that occur after the balance sheet date but before the financial statements are issued or are available to be issued and are classified as either “recognized subsequent events” or “non-recognized subsequent events”. We recognize and include in our financial statements the effects of subsequent events that provide additional evidence about conditions that existed at the balance sheet date. We disclose non-recognized subsequent events that provide evidence about conditions that arise after the balance sheet date but are not yet reflected in our financial statements when such disclosure is required to prevent the financial statements from being misleading. Recent Accounting Pronouncements  Employee Share-Based Payments – In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-09, Improvements to Employee Share-Based Payment Accounting (Topic 718) (“ASU 2016-09”). ASU 2016-09 revises several aspects of the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures, and statutory tax withholding requirements, as well as classification in the statement of cash flows. The new standard is effective for annual reporting periods beginning after December 15, 2016, including interim periods therein. We are in the process of evaluating the impact the adoption of this standard will have on our consolidated financial statements and related disclosures.  Leases – In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (“ASU 2016-02”). ASU 2016-02 requires entities to recognize right-of-use assets and lease liabilities on the balance sheet for the rights and obligations created by all leases, including operating leases, with terms of more than 12 months. The new standard also requires additional disclosures on the amount, timing, and uncertainty of cash flows arising from leases. These disclosures include qualitative and quantitative information. The new standard will be effective for us on January 1, 2019. Early adoption is permitted. We are in the process of evaluating the impact the adoption of this standard will have on our consolidated financial statements and related disclosures.  Balance Sheet Classification of Deferred Taxes – In November 2015, the FASB issued ASU No. 2015-17, Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes (“ASU 2015-17”). ASU 2015-17 requires entities to present deferred tax assets and deferred tax liabilities as noncurrent in a classified balance sheet. The new standard is effective for public entities for annual periods beginning after December 15, 2016, with early adoption allowed on either a prospective or retrospective basis. We adopted ASU 2015-17, on a prospective basis, for our annual period ending December 31, 2015. Accordingly, the accompanying condensed consolidated balance sheet at March 31, 2016 and December 31, 2015 reflects the presentation of deferred tax assets and deferred tax liabilities in accordance with ASU 2015-17.  Business Combinations – In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments (“ASU 2015-16”). The new standard requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined and sets forth new disclosure requirements related to the adjustments. The new standard became effective for us on January 1, 2016. The adoption of this standard had no effect on our consolidated financial statements.  Inventory Measurement – In July 2015, the FASB issued ASU No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory (“ASU 2015-11”), which requires entities to measure inventory at the lower of cost and net realizable value (“NRV”). ASU 2015-11 defines NRV as the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The ASU will not apply to inventories that are measured by using either the last-in, first-out method or the retail inventory method. The guidance in ASU 2015-11 is effective prospectively for fiscal years beginning after December 15, 2016, and interim periods therein. Early adoption is permitted. Upon transition, entities must disclose the nature of and reason for the accounting change. We do not expect that the adoption of this standard will have a material effect on our consolidated financial statements.  Presentation of Debt Issuance Costs – In April 2015, the FASB issued ASU No. 2015-03: Simplifying the Presentation of Debt Issuance Costs (“ASU 2015-03”), and in August 2015, the FASB issued ASU 2015-15: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements (“ASU 2015-15”). These ASUs require debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the carrying amount of that debt consistent with debt discounts. The presentation and subsequent measurement of debt issuance costs associated with lines of credit, may be presented as an asset and amortized ratably over the term of the line of credit arrangement, regardless of whether there are outstanding borrowings on the arrangement. The recognition and measurement guidance for debt issuance costs are not affected by these ASUs. These ASUs are effective for financial statements issued for fiscal years beginning after December 15, 2015 and interim periods within those years. Early adoption is permitted for financial statements that have not been previously issued, and retrospective application is required for each balance sheet presented. We adopted the provisions of ASU 2015-03 and ASU 2015-15 on a retrospective basis for our annual period ended December 31, 2015. Accordingly, the accompanying condensed consolidated balance sheet at March 31, 2016 and December 31, 2015 reflects the presentation of debt issuance costs in accordance with ASU 2015-03 and ASU 2015-15.  Going Concern Disclosures – In August 2014, the FASB issued ASU No. 2014-15: Disclosure of Uncertainties About an Entity’s Ability to Continue as a Going Concern (“ASU 2014-15”). ASU 2014-15 requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued and provides guidance on determining when and how to disclose going concern uncertainties in the financial statements. Certain disclosures will be required if conditions give rise to substantial doubt about an entity’s ability to continue as a going concern. ASU 2014-15 is effective for annual and interim reporting periods ending after December 15, 2016, with early adoption permitted. We do not expect that the adoption of this standard will have a material effect on our consolidated financial statements.  Stock Compensation – In June 2014, the FASB issued ASU No. 2014-12, Compensation – Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (“ASU 2014-12”) . ASU 2014-12 requires that a performance target that affects vesting, and that could be achieved after the requisite service period, be treated as a performance condition. As such, the performance target should not be reflected in estimating the grant date fair value of the award. This standard further clarifies that compensation cost should be recognized in the period in which it becomes probable that the performance target will be achieved and should represent the compensation cost attributable to the periods for which the requisite service has already been rendered. The new standard became effective for us on January 1, 2016. The adoption of this standard had no effect on our consolidated financial statements.  Revenue Recognition – In May 2014, the FASB issued ASU No. 2014-09: Revenue from Contracts with Customers (“ASU 2014-09”). The new standard was originally effective for reporting periods beginning after December 15, 2016 and early adoption was not permitted. On August 12, 2015, the FASB approved a one year delay of the effective date to reporting periods beginning after December 15, 2017, while permitting companies to voluntarily adopt the new standard as of the original effective date. This standard replaces existing accounting literature relating to how and when a company recognizes revenue. Under ASU 2014-09, a company will recognize revenue when it transfers goods or services to customers in an amount equal to the amount that it expects to be entitled to receive in exchange for those goods and services. This standard also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts, including significant judgments and changes in judgments. ASU 2014-09 will be effective for us for our fiscal year that begins January 1, 2018, and permits the use of either the retrospective or cumulative effect transition method. We are in the process of determining the method of adoption and evaluating the impact, if any, the adoption of this standard will have on our consolidated financial statements and related disclosures.  

Earnings (Loss) Per Share

Earnings (Loss) Per Share	3 Months Ended
	Mar. 31, 2016
Earnings (Loss) Per Share [Abstract]
Earnings (Loss) Per Share	4. Earnings (Loss) per Share Basic earnings (loss) per share is computed by dividing net income (loss) by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per share is computed using the weighted average number of common shares outstanding and, when dilutive, potential common shares from stock options using the treasury stock method. Diluted earnings per share excludes the impact of potential common shares related to stock options in periods in which we reported a loss from continuing operations or in which the option exercise price is greater than the average market price of our common stock during the period because the effect would be antidilutive. A total of 415 thousand common shares issuable upon the potential exercise of outstanding stock options were excluded from the calculation of diluted weighted average number of shares outstanding for the three months ended March 31, 2016, because their effect was antidilutive to our net loss for that period. The following table sets forth the calculation of basic and diluted earnings (loss) per share:      Three Months Ended  March 31,  2016 2015   Net income (loss) $ (9,923) $ 121   Basic weighted-average common  shares outstanding in period 22,505 22,385  Dilutive effect of stock options - 104  Diluted weighted-average common  shares outstanding in period 22,505 22,489   Basic earnings (loss) per common share $ (0.44) $ 0.01   Diluted earnings (loss) per common share $ (0.44) $ 0.01  

Restructuring Charges

Restructuring Charges	3 Months Ended
	Mar. 31, 2016
Restructuring Charges [Abstract]
Restructuring Charges	5. Restructuring Charges From time to time and most recently in 2015, we have engaged in restructuring programs designed to reduce our cost structure and improve productivity. These initiatives typically consist of realigning operations, reducing employee counts, rationalizing facilities, changing manufacturing sourcing, eliminating certain products, inventory writedowns and long term asset disposals, and other actions designed to reduce our cost structure and improve productivity.  The following table summarizes our 2015 business realignment plan activities and the balance of our accrued restructuring liabilities at and for the three months ended March 31, 2016:      Employee  Termination Long Term Asset  Costs Writedowns Total  2015 Business Realignment Plan:   Accrued charges, December 31, 2015 $ 538 $ - $ 538  Costs paid or otherwise settled (500) - (500)   Accrued charges, March 31, 2016 $ 38 $ - $ 38   The following table summarizes our 2013 business realignment plan activities and the balance of our accrued restructuring liabilities at and for the three months ended March 31, 2016:      Inventory Leasehold  Employee Writedowns and Termination and  Termination Long Term Asset Other Facility  Costs Disposals Exit Costs Total  2013 Business Realignment Plan:   Accrued charges, December 31, 2015 $ 47 $ - $ - $ 47  Costs paid or otherwise settled (47) - - (47)   Accrued charges, March 31, 2016 $ - $ - $ - $ -   \ The balances of our accrued restructuring liabilities at March 31, 2016 and December 31, 2015 are included in current liabilities in our condensed consolidated balance sheet. We expect the majority of the balance of our accrued restructuring charges at March 31, 2016 will be paid or otherwise settled during the remainder of 2016.

Debt And Interest Rate Swap Con

Debt And Interest Rate Swap Contracts	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Debt And Interest Rate Swap Contracts	6. Debt and Interest Rate Swap Contracts  Long-Term Credit Facility - We have a long-term credit facility with Citibank, N.A. (“Citibank”), as administrative agent and lender, and other lenders under a credit agreement that we first entered into with our lenders in August 2007 and have amended and restated from time-to-time. At March 31, 2016 and December 31, 2015, our credit agreement with Citibank along with Branch Banking and Trust Company (“BB&T”) as additional lender, consisted of a $40.0 million senior, first-priority secured revolving line of credit maturing on June 30, 2020 , a $2.6 million term loan maturing on June 30, 2020 , and a $25.0 million, 7 year amortizing term loan maturing on June 30, 2020 . Our credit facility also contains an accordion provision permitting us to request an increase in the revolving loan by up to an additional $20 million, subject to lender’s participation  The credit facility contains three basic financial covenants. First, under the credit agreement, if cash on hand does not exceed funded indebtedness by at least $5.0 million, then our minimum fixed charge coverage ratio must be in excess of 1.25 , where the fixed charge coverage ratio is defined as the ratio of the aggregate of our consolidated Earnings before Interest, Taxes, Depreciation and Amortization (“EBITDA”) plus our lease expense minus our taxes based on income and payable in cash, divided by the sum of our consolidated interest charges plus our lease expenses plus our scheduled principal payments and dividends, computed over the previous period. The fixed charge coverage ratio is currently based on our financial results for the previous four fiscal quarters on a rolling basis. Second, we are required to maintain a minimum consolidated net worth, computed on a quarterly basis, of not less than the sum of $142.1 million, plus an amount equal to 50% of our net income each fiscal year commencing with the year ending December 31, 2014, with no reduction for any net loss in any fiscal year, plus 90% of any equity we raise through the sale of equity interests, less the amount of any non-cash charges or losses. Under our third financial covenant, the ratio of our funded indebtedness to our capitalization, computed as funded indebtedness divided by the sum of funded indebtedness plus stockholders equity, cannot exceed 25% .  On February 23, 2016, the lenders under our credit facility provided a waiver of any event of default arising from the execution of the Merger Agreement (but not the consummation of the Merger) under the credit agreement with our lenders. On May 6, 2016, those lenders also provided a waiver of any event of default arising under the credit agreement from (i) the consummation of the Merger Agreement under the credit agreement, and (ii) our failure to comply with the minimum fixed charge coverage ratio financial covenant under the credit agreement at March 31, 2016.  We have used, and intend to continue to use, the proceeds available under the credit facility to support our growth and future investments in working capital, additional UtilityServices equipment, Company-owned distributed generation projects, other capital expenditures, acquisitions and general corporate purposes.  Outstanding balances under the credit facility bear interest, at our discretion, at either the London Interbank Offered Rate ("LIBOR") for the corresponding deposits of U. S. Dollars plus an applicable margin, which is on a sliding scale ranging from 2.00% to 3.25% based upon our leverage ratio, or at Citibank's alternate base rate plus an applicable margin, on a sliding scale ranging from 0.25% to 1.50% based upon our leverage ratio. Our leverage ratio is the ratio of our funded indebtedness as of a given date, net of our cash on hand in excess of $5.0 million, to our consolidated EBITDA, as defined in the credit agreement, for the four consecutive fiscal quarters ending on such date. Citibank’s alternate base rate is equal to the higher of the Federal Funds Rate as published by the Federal Reserve of New York plus 0.50% , Citibank’s prime commercial lending rate and 30 day LIBOR plus 1.00% .  In July 2013, we entered into two forward-starting interest rate swap contracts based on three-month LIBOR that effectively converted 80% of the outstanding balance of our $25 million Term Loan to fixed rate debt. As discussed further in Note 7, we have designated the interest rate swaps as a cash flow hedge of the interest payments due on our floating rate debt. Accordingly, at March 31, 2016, $12.1 million of our outstanding credit facility debt bears interest at a fixed rate of 3.73% and $29.8 million of our outstanding credit facility debt, including amounts borrowed under the revolving portion of the credit facility, bears interest at floating rates as described above. The termination dates of the swap contracts and the maturity date of the $25 million Term Loan are both June 30, 2020.  The credit facility contains customary terms and conditions for credit facilities of this type, including restrictions or limits on our ability to incur additional indebtedness, create liens, enter into transactions with affiliates, pay dividends on our capital stock or consolidate or merge with other entities. In addition, the credit agreement contains customary events of default, including payment defaults, breach of representations and warranties, covenant defaults, cross-defaults, certain bankruptcy or insolvency events, judgment defaults and certain ERISA-related events. Our obligations under the credit facility are secured by guarantees and security agreements by each of our active subsidiaries, including PowerSecure, Inc. The guarantees guaranty all of our obligations under the credit facility, and the security agreements grant to the Lenders a first priority security interest in virtually all of the assets of each guarantor. At March 31, 2016, there was an aggregate balance of $16.9 million outstanding under the two term loans under our credit facility and there was $25.0 million outstanding under the revolving portion of the credit facility. At March 31, 2016 and December 31, 2015, we had $9.0 million and $36.0 million, respectively, of available and unused borrowing capacity from our revolving credit facility within the limits of our financial covenants. At May 6, 2016, an aggregate balance of $30.0 million was outstanding under our revolving credit facility, and there was approximately $4.0 million of available and unused borrowing capacity within the limits of our financial covenants. The availability of this capacity under our credit facility includes restrictions on the use of proceeds, and is dependent upon our ability to satisfy certain financial and operating covenants including financial ratios, as discussed above.  Acquisition Term Notes – We financed a portion of our 2015 acquisition of the assets and business of ESCO Energy Services Company with two unsecured promissory notes payable to the seller in the aggregate amount of $0.8 million. The first acquisition term note in the principal amount of $685 thousand is payable in four equal quarterly installments, plus interest at 5% , during 2016. The second acquisition term note in the principal amount of $150 thousand is payable on December 1, 2017.  The following table summarizes the balances outstanding on our long-term debt at March 31, 2016 and December 31, 2015:        March 31, December 31,  2016 2015  Revolving line of credit, maturing June 30, 2020 $ 25,000 $ -  Term loan, principal of $0.04 million plus interest payable  quarterly at variable rates, maturing June 30, 2020 1,720 1,760  Term loan, principal of $0.9 million plus interest payable  quarterly at variable rates, maturing June 30, 2020 15,178 16,072  Acquisition term notes payable 664 835  Total debt 42,562 18,667  Less: Unamortized debt issuance costs, term loans (56) (64)  Total debt, net of term loan debt issuance costs 42,506 18,603  Less: Current portion (4,245) (4,416)  Long-term debt, net of current portion $ 38,261 $ 14,187   Scheduled remaining principal payments on our outstanding debt obligations at March 31, 2016, are as follows:      Revolving Total  Scheduled Principal Payments for Line of $25.0 Million $2.6 Million Acquisition Principal  the Year Ending December 31: Credit Term Loan Term Loan Term Notes Payments  Remainder of 2016 $ - $ 2,677 $ 120 $ 514 $ 3,311  2017 - 3,571 160 150 3,881  2018 - 3,572 160 - 3,732  2019 - 3,572 160 - 3,732  2020 25,000 1,786 1,120 - 27,906   Total scheduled principal payments $ 25,000 $ 15,178 $ 1,720 $ 664 $ 42,562  

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income And Hedging Activities	3 Months Ended
	Mar. 31, 2016
Accumulated Other Comprehensive Income and Hedging Activities [Abstract]
Accumulated Other Comprehensive Income And Hedging Activities	7. Accumulated Other Comprehensive Income and Hedging Activities  Accumulated Other Comprehensive Income – Our Accumulated Other Comprehensive Income (“AOCI”) consists of unrealized foreign currency translation adjustments and activities associated with cash flow hedges related to our interest rate swaps described in greater detail below. The following is a summary of changes in AOCI by component for the three months ended March 31, 2016 (all amounts are net of tax):      Gains (losses) Foreign  on Cash Flow Currency  Hedge Items Total   Balance of AOCI, December 31, 2015 $ (55) $ (9) $ (64)  Other comprehensive income (loss) before reclassifications (84) 20 (64)  Reclassification adjustment for net (gains) losses  included in net income (loss) 22 - 22  Net other comprehensive income (loss) (62) 20 (42)   Balance of AOCI, March 31, 2016 $ (117) $ 11 $ (106)   The following is a summary of changes in AOCI by component for the three months ended March 31, 2015 (all amounts are net of tax):     Gains (losses) Foreign  on Cash Flow Currency  Hedge Items Total   Balance of AOCI, December 31, 2014 $ (77) $ - $ (77)  Other comprehensive income (loss) before reclassifications (81) - (81)  Reclassification adjustment for net (gains) losses  included in net income (loss) 36 - 36  Net other comprehensive income (loss) (45) - (45)   Balance of AOCI, March 31, 2015 $ (122) $ - $ (122)   Hedging Activities – In July 2013, we entered into two forward-starting interest rate swap contracts to manage interest rate risk associated with a portion of our $25 million Term Loan floating rate debt (see Note 6). The interest rate swaps effectively converted 80% of the outstanding balance of our $25.0 million floating rate term loan to a fixed rate term loan bearing interest at the rate of 3.73% . The notional amount of the interest rate swaps at March 31, 2016 was $12.1 million. The termination dates of the swap contracts and the maturity date of the $25 million Term Loan are both June 30, 2020 .  In accordance with ASC 815, Derivatives and Hedging , we have designated both of our interest rate swaps as cash flow hedges of the interest payments due on our floating rate debt. To qualify for designation as a cash flow hedge, specific criteria must be met and the appropriate documentation maintained. Hedging relationships are established pursuant to our risk management policies and are initially and regularly evaluated to determine whether they are expected to be, and have been, highly effective hedges. For our interest rate swap contracts designated as a cash flow hedge of interest on our floating rate debt, the effective portion of the change in fair value of the derivative is reported in other comprehensive income and reclassified into earnings in the period in which the hedged item affects earnings. Any amounts excluded from the effectiveness calculation and any ineffective portion of the change in fair value of the derivative are recognized currently in earnings.  The interest rate swaps are measured at Level 2 fair value on a recurring basis, using standard pricing models and market-based assumptions for all significant inputs, such as LIBOR yield curves. The fair value of the interest rate swap contracts included within our consolidated balance sheets as of March 31, 2016 and December 31, 2015, are as follows:       Derivative designated as Balance Sheet March 31, December 31, Balance Sheet March 31, December 31,  hedging instrument: Location 2016 2015 Location 2016 2015   Other long-term  Interest rate swaps Other assets $ - $ - liabilities $ 214 $ 109   The following tables present the effects of derivative instruments designated as cash flow hedges on our consolidated statements of operations and accumulated other comprehensive income (loss) (“AOCI”):      Amounts Reclassified from AOCI into income Affected Line Item in the  Three Months Ended March 31, Consolidated Statements  AOCI Component 2016 2015 of Operations  Gain (loss) on cash flow hedges:  Interest rate swaps $ 37 $ 58 Interest expense  (15) (22) Tax expense (benefit)  $ 22 $ 36 Net of tax          Amount of gain (loss) recognized in AOCI  Three Months Ended March 31,  AOCI Component 2016 2015  Gain (loss) on cash flow hedges:  Unrealized gain (loss) -  Interest rate swaps $ (140) $ (130)  Tax effect 56 49  Gain (loss) - net of tax $ (84) $ (81)   We did not realize any ineffectiveness related to our cash flow hedges during the three months ended March 31, 2016 and 2015.

Share-Based Compensation

Share-Based Compensation	3 Months Ended
	Mar. 31, 2016
Share-Based Compensation [Abstract]
Share-Based Compensation	8. Share-Based Compensation We recognize compensation expense for all share-based awards made to employees and directors based on estimated fair values on the date of grant. Stock Plans – Historically, we have granted stock options, restricted stock awards, restricted stock units and performance unit awards to employees and directors under various stock plans. We currently maintain two stock plans. Under our 1998 Stock Incentive Plan, as amended (the “1998 Stock Plan”), we granted incentive stock options, non-qualified stock options, restricted stock, performance awards and other stock-based awards to our officers, directors, employees, consultants and advisors for shares of our common stock. Stock options granted under the 1998 Stock Plan contained exercise prices not less than the fair market value of our common stock on the date of grant, and had a term of 10 years from the date of grant. Nonqualified stock option grants to our directors under the 1998 Stock Plan generally vested over periods up to two years. Qualified stock option grants to our employees under the 1998 Stock Plan generally vested over periods up to five years. The 1998 Stock Plan expired on June 12, 2008 , and no additional awards may be made under the 1998 Stock Plan, although awards granted prior to such date will remain outstanding and subject to the terms and conditions of those awards. In March 2008, our board of directors adopted the PowerSecure International, Inc. 2008 Stock Incentive Plan (the “2008 Stock Plan”), which was approved by our stockholders at the Annual Meeting of Stockholders held on June 9, 2008. The 2008 Stock Plan authorizes our board of directors to grant incentive stock options, non-qualified stock options, stock appreciation rights, restricted stock, performance awards and other stock-based awards to our officers, directors, employees, consultants and advisors for up to an aggregate of 0.6 million shares of our common stock. Stock options granted under the 2008 Stock Plan must contain exercise prices not less than the fair market value of our common stock on the date of grant, and must contain a term not in excess of 10 years from the date of grant. On June 19, 2012, at our 2012 Annual Meeting of Stockholders, our stockholders adopted and approved an amendment and restatement of the 2008 Stock Incentive Plan, including an amendment to increase the number of shares of our common stock authorized thereunder by 1.4 million shares to a total of 2.0 million shares. The 2008 Stock Plan replaced our 1998 Stock Plan. Stock Options – Net income (loss) for the three months ended March 31, 2016 and 2015 includes $52 thousand and $86 thousand, respectively, of pre-tax compensation costs related to outstanding stock options. All of the stock option compensation expense is included in general and administrative expenses in the accompanying condensed consolidated statements of operations. A summary of option activity for the three months ended March 31, 2016 is as follows:    Weighted  Average  Weighted Remaining Aggregate  Average Contractual Intrinsic  Shares Exercise Price Term (years) Value  Balance, December 31, 2015 422 $ 10.16  Granted - -  Exercised (7) 11.57  Expired - -  Forfeited - -  Balance, March 31, 2016 415 $ 10.14 5.84 $ 3,598   Exercisable, March 31, 2016 235 $ 9.32 4.09 $ 2,214  A summary of option activity for the three months ended March 31, 2015 is as follows:    Weighted  Average  Weighted Remaining Aggregate  Average Contractual Intrinsic  Shares Exercise Price Term (years) Value  Balance, December 31, 2014 519 $ 9.12  Granted 15 11.24  Exercised (50) 5.44  Expired - -  Forfeited (5) 8.91  Balance, March 31, 2015 479 $ 9.57 5.75 $ 2,018   Exercisable, March 31, 2015 269 $ 8.66 3.54 $ 1,290   There were no stock options granted during the three months ended March 31, 2016. The weighted average grant date fair value of stock options granted during the three months ended March 31, 2015 was $4.73 . The fair value of the stock options granted during the three months ended March 31, 2015 was measured using the Black-Scholes valuation model with the following assumptions:     Three Months Ended March 31,  2016 (1) 2015  Expected stock price volatility n/m 46.5 %  Risk free interest rate n/m 1.6 %  Annual dividends n/m $ -  Expected life (years) n/m 5   (1) 2016 amounts are not meaningful as there were no stock options granted during the period.   The fair value of stock option grants is amortized to expense over the respective service periods using the straight-line method and assuming a forfeiture rate of 5% . As of March 31, 2016 and December 31, 2015, there was $0.7 million and $0.8 million, respectively, of total unrecognized compensation costs related to stock options. These costs at March 31, 2016 are expected to be recognized over a weighted average period of approximately 3.9 years. During the three months ended March 31, 2016 and 2015, the total intrinsic value of stock options exercised was $36 thousand and $0.3 million, respectively. Cash received from stock option exercises during the three months ended March 31, 2016 and 2015 was $81 thousand and $0.3 million, respectively. The total grant date fair value of stock options vested during the three months ended March 31, 2016 and 2015 was $14 thousand and $28 thousand, respectively.  Restricted Stock Awards and Restricted Stock Units – Net income (loss) for the three months ended March 31, 2016 and 2015 includes $0.5 million and $0.5 million, respectively, of pre-tax compensation costs related to the vesting of outstanding restricted stock awards and restricted stock units granted to directors and employees. All of the restricted stock award compensation expense during the three months ended March 31, 2016 and 2015 is included in general and administrative expenses in the accompanying condensed consolidated statements of operations. A summary of restricted stock award activity for the three months ended March 31, 2016 is as follows:   Weighted  Unvested Average  Restricted Grant Date  Shares Fair Value  Balance, December 31, 2015 547 $ 17.44  Granted - -  Vested (1) 15.49  Forfeited - -  Balance, March 31, 2016 546 $ 17.44  A summary of restricted stock award activity for the three months ended March 31, 2015 is as follows:    Weighted  Unvested Average  Restricted Grant Date  Shares Fair Value  Balance, December 31, 2014 579 $ 17.20  Granted 28 12.30  Vested (6) 7.88  Forfeited - -  Balance, March 31, 2015 601 $ 17.06   A summary of restricted stock unit activity for the three months ended March 31, 2016 is as follows:       Weighted  Unvested Average  Restricted Grant Date  Stock Units Fair Value  Balance, December 31, 2015 5 $ 15.49  Granted - -  Vested (2) 15.49  Forfeited - -  Balance, March 31, 2016 3 $ 15.49   There were no restricted stock units issued or outstanding at or during the three months ended March 31, 2015.  Restricted shares and restricted stock units are subject to forfeiture and cannot be sold or otherwise transferred until they vest. If the holder of the restricted shares or stock units leaves us before they vest, other than due to termination by us without cause, then any unvested restricted shares will be forfeited and returned to us. The restricted shares and restricted stock units granted to directors vest in equal amounts over a period of one or three years, depending on the nature of the grant. The restricted shares granted to employees generally vest over five or ten years. All restricted and unvested shares or units automatically vest upon a change in control. The fair value of the restricted shares and restricted stock units is amortized on a straight-line basis over the respective vesting period. At March 31, 2016, the balance of unrecognized compensation cost related to unvested restricted shares was $6.0 million, which is expected to be recognized over a weighted average period of approximately 4.1 years. At March 31, 2016, the balance of unrecognized compensation cost related to unvested restricted stock units was $4 4 thousand , which is expected to be recognized over a weighted average period of approximately 0.3 years.  Performance Units – Net income (loss) for the three months ended March 31, 2016 and 2015 includes $67 thousand and $35 thousand, respectively, of pre-tax compensation costs related to outstanding performance units based on the number of awards that we expect will vest over the requisite service period and the probable outcome of the associated performance condition. All of the performance unit compensation expense during the three months ended March 31, 2016 and 2015 is included in general and administrative expenses in the accompanying condensed consolidated statements of operations.  A summary of performance unit award activity for the three months ended March 31, 2016 is as follows:      Weighted  Unvested Average  Performance Grant Date  Units Fair Value  Balance, December 31, 2015 45 $ 15.39  Granted - -  Vested - -  Incremental performance shares vested - -  Forfeited - -  Balance, March 31, 2016 45 $ 15.39   A summary of performance unit award activity for the three months ended March 31, 2015 is as follows:     Weighted  Unvested Average  Performance Grant Date  Units Fair Value  Balance, December 31, 2014 17 $ 20.57  Granted 28 12.30  Vested - -  Incremental performance shares vested - -  Forfeited - -  Balance, March 31, 2015 45 $ 15.39   The performance units outstanding at March 31, 2016 obligate the Company to issue a variable number of shares of its common stock in the event certain cumulative earnings per share performance thresholds are met. At March 31, 2016, the number of shares issuable upon attainment of performance thresholds ranges from 23 thousand to 68 thousand shares. The fair value of the performance units are being amortized on a straight-line basis over the requisite service period. At March 31, 2016, the balance of unrecognized compensation costs related to outstanding performance units was $0.3 million, which is expected to be recognized over a weighted average period of approximately 1.4 years.  At the effective time of the Merger (see Note 2), (i) all outstanding stock options will be deemed to be fully vested and converted into the right to receive a cash payment equal to the excess of the merger consideration over the exercise prices of such stock options, (ii) all outstanding restricted shares and restricted stock units will be deemed to be fully vested and converted into the right to receive the merger consideration, except for certain unvested restricted shares held by our Chief Executive Officer, which will be converted into a stock award relating to shares of Southern Company, and (iii) all performance share units payable in shares of Common Stock will be deemed vested at the target level of achievement and converted into the right to receive the merger consideration.

Commitments And Contingencies

Commitments And Contingencies	3 Months Ended
	Mar. 31, 2016
Commitments And Contingencies [Abstract]
Commitments And Contingencies	9. Commitments and Contingencies  Litigation Relating to the Merger – On March 17, 2016, a putative class action lawsuit challenging the Merger (Note 2) was filed by a purported PowerSecure stockholder on behalf of all PowerSecure stockholders in the General Court of Justice of the Superior Court Division of Wake County, North Carolina. The lawsuit names as defendants PowerSecure, its directors, Southern Company and Merger Sub. The lawsuit alleges that the PowerSecure directors breached their fiduciary duties to PowerSecure stockholders by engaging in a flawed process to sell PowerSecure, by agreeing to sell PowerSecure for inadequate consideration and by agreeing to imprope r deal protection terms in the Merger A greement. In addition, the lawsuit alleges that the entity defendants aided and abetted these breaches of fiduciary duty. The lawsuit seeks, among other thi ngs, an injunction barring the M erger, an accounting for damages and attorneys’ fees. The defendants believe that the lawsuit is without merit. The ultimate outcome of this lawsuit cannot be predicted due to the inherent uncertainty of litigation and the litigation is at a very early stage. Other than an imm aterial amount for litigation cost s, we have not recognized any expense for this matter as we do not believe, based upon current informatio n, that a loss relating to this matter is probable, or that an estimate of a range of p otential loss relating to this matter , can reasonably be made.  Securities Class Action and Related Litigation – On May 22, 2014, a putative securities class action lawsuit was filed against us and certain of our executive officers in the United States District Court for the Eastern District of North Carolina. Subsequently, in May and in July 2014, two additional purported securities class action lawsuits were filed against the same defendants in the United States District Courts, one in the Eastern District of North Carolina and the other in the Western District of North Carolina. On October 10, 2014, these lawsuits were consolidated in the United States District Court for the Eastern District of North Carolina, and a lead plaintiff was appointed. As consolidated, the lawsuit was filed on behalf of all persons or entities that purchased our common stock during a purported class period from August 8, 2013 through May 7, 2014, which is the longer of the two different purported class periods used in the pre-consolidation lawsuits. A consolidated amended complaint was filed on December 29, 2014. The action alleges that certain statements made by the defendants during the class period violated federal securities laws and seeks damages in an unspecified amount.  We filed a motion to dismiss the amended complaint on February 26, 2015, which the court granted on September 15, 2015, with leave for the plaintiff to file an amended complaint. On October 16, 2015, the plaintiff filed a second amended consolidated class action complaint, with similar allegations over the same class period. On November 23, 2015, we filed a motion to dismiss the second amended complaint, and the briefing on that motion concluded on February 5, 2016. We cannot provide any assurance as to when the court will rule on our motion to dismiss the second amended complaint or whether our motion will be granted, and even if granted whether the complaint will be dismissed with prejudice or appealed. On August 15, 2014, a shareholder derivative complaint was filed against certain of our executive officers and each of our directors during the class period in the United States District Court for the Eastern District of North Carolina. The complaint alleges breach of fiduciary duty, waste of corporate assets and unjust enrichment by the named officers and directors in connection with substantially the same events as set forth in the class action lawsuit, seeking damages in an unspecified amount. On November 26, 2014, based on mutual agreement of the parties to the lawsuit, the court ordered that proceedings under the complaint be stayed until resolution of the securities class action litigation.  While we believe that we have substantial legal and factual defenses to the claims in the class action and we are pursuing these defenses vigorously the outcome of this litigation is difficult to predict and quantify, and the defense against such claims could be costly. In addition, we have various insurance policies related to the risk associated with our business, including directors’ and officers’ liability insurance policies. However, there is no assurance that we will be successful in our defense of the securities class action, and there is no assurance that our insurance coverage will be sufficient or that our insurance carriers will cover all claims in that litigation. If we are not successful in our defense of the claims asserted in the securities class action and the claims are not covered by insurance or exceed our insurance coverage, we may have to pay damage awards, indemnify our officers and directors from damage awards that may be entered against them and pay the costs and expenses incurred in defense of, or in any settlement of, such claims.  While the company is only a nominal defendant in the shareholder derivative litigation, it could be obligated to indemnify and/or to pay an advancement of fees and costs incurred by our officers and directors in their defense of the litigation.  Any such payments or settlement arrangements in these current lawsuits or related litigation or proceedings could be significant and have a material adverse effect on our business, financial condition, results of operations, or cash flows if the claims are not covered by our insurance carriers or if damages exceed the limits of our insurance coverage. Furthermore, regardless of the outcome of these claims, defending the litigation itself could result in substantial costs and divert management’s attention and resources, which could have a material adverse effect on our business, operating results, financial condition and ability to finance our operations.  The ultimate outcome of these proceedings cannot be accurately predicted due to the inherent uncertainty of litigation and the litigation is at a very early stage. Other than an immaterial amount for legal expenses, we have not recognized any costs for the securities class action as we do not believe, based upon current information, that a loss relating to these matters is probable, or that an estimate of a range of potential loss relating to these matters, can reasonably be made.  SEC Informal Inquiry – The SEC is conducting an informal inquiry that appears to be focused on our interpretation and application of the FASB’s Accounting Standards Codification (“ASC”) Topic 280, Segment Reporting (“ASC 280”), in regards to our identification of operating and reportable segments since 2012, but may be broader in scope. We are cooperating with the SEC in this matter, including consultation with the Office of Chief Accountant of the SEC. There is no assurance that the scope of this inquiry is currently limited to segment reporting or that it will not be expanded in the future. In addition, the outcome of this inquiry could be unfavorable to us and adversely affect our business, financial condition or operating results.  P erformance Bonds and Letters of Credit – In the ordinary course of business, we are required by certain customers to post surety or performance bonds or letters of credit in connection with services that we provide to them. These bonds and letters of credit provide a guarantee to the customer that we will perform under the terms of a contract and that we will pay subcontractors and vendors. If we fail to perform under a contract or to pay subcontractors and vendors, the customer may demand that the surety, in the case of a performance bond, or our lenders, in the case of a letter of credit, make payments or provide services under the bond. We must reimburse the surety or our lenders for any expenses or outlays they incur. We have not been required to make any reimbursements to our sureties for bond-related costs, and we do not currently expect that we will have to fund significant claims under our surety arrangements in the foreseeable future. As of March 31, 2016, we had approximately $325.4 million in surety bonds outstanding. Based upon the current status of the completion of our contracts and projects, we estimate our exposure on these surety bonds was approximately $169.8 million at March 31 , 2016. Employee Matters – From time to time, we hire employees that are subject to restrictive covenants, such as non-competition agreements with their former employers. We comply, and require our employees to comply, with the terms of all known restrictive covenants. However, we have in the past and may in the future receive claims and demands by some former employers alleging actual or potential violations of these restrictive covenants. These claims are inherently difficult to predict, and therefore we generally cannot provide any assurance of the outcome of claims. We do not have any specific claims outstanding at this time. Product Performance and Component Parts Matters – From time to time, in the ordinary course of business we encounter issues with component parts that affect the performance of our distributed generation systems, switchgear systems, utility infrastructure products, engines, generators, alternators, breakers, fuel systems, boilers, chillers, LED and other lighting products, electrical circuit boards, power drivers, photovoltaic energy systems, inverters, and other complex electrical products. While we strive to utilize high quality component parts from reputable suppliers, and to back-up their quality and performance with manufacturers’ warranties, even the best parts and components have performance issues from time to time, and these performance issues create significant financial and operating risks to our business, operations and financial results. In addition, because we regularly develop new products and technical designs, we often incorporate component parts into these new products in configurations, for uses, and in environments, for which limited experience exists and which exposes us to performance risks that may not be covered by warranties, or may invalidate warranties or performance certifications. As we strive to bring solutions to customers with unique capabilities that provide performance and cost advantages, from time to time we use new suppliers and new products for applications where track record of performance does not exist, or is difficult to ascertain. As a result, we can encounter situations in which the responsibility for the performance issues is unclear, or difficult to ascertain. Because of our strong focus on customer satisfaction, we often take on the cost of repairs in excess of our contractual obligations. Additionally, the outcome of any performance disputes or warranty claims is inherently difficult to predict due to the uncertainty of technical solutions, cost, customer requirements, and the uncertainty inherent in litigation and disputes generally. As a result, there is no assurance we will not be adversely affected by these, or other performance issues with key parts and components. Moreover, performance issues may not be covered by manufacturer’s warranties, certain suppliers may not be financially able to fulfill their warranty obligations, and customers may also claim damages as a result of those performance issues. Also, the mere existence of performance issues, even if finally resolved with our suppliers and customers, can have an adverse effect on our reputation for quality, which could adversely affect our business. We estimate that from time to time we have performance issues related to component parts which have a cost basis of approximately 5 - 10% of our estimated annual revenues, although not necessarily limited to this amount, which are installed in equipment we own and have sold to various customers across our business lines, and additional performance issues could arise in the future. In addition, the failure or inadequate performance of these components pose potential material and adverse effects on our business, operations, reputation and financial results, including reduced revenues for projects in process or future projects, reduced revenues for recurring revenue contracts which are dependent on the performance of the affected equipment, additional expenses and capital cost to repair or replace the affected equipment, inventory write-offs for defective components held in inventory, asset write-offs for company-owned systems which have been deployed, the cancellation or deferral of contracts by our customers, or claims made by our customers for damages as a result of performance issues. We have experienced performance issues with two types of component parts, in particular, which we have made progress in correcting or mitigating, but which continue to represent operational and financial risks to our business: 1) a component we incorporated into a distributed generation system configuration installed in many of the systems deployed for our customers has been deemed to invalidate the generator manufacturer’s warranty and may cause other customer issues and costs, and 2) generators we purchased from a certain supplier have had performance issues in a system we own, and for which we have a performance-based recurring revenue contract that is dependent on the system’s successful operation. In both of these matters, we have actively worked to correct and resolve the performance issues and have made progress in mitigating certain elements of their risk, but the risk is not eliminated. Given that we continue to have risk related to these matters, and the inherent uncertainty in assessing and quantifying the costs and certainty regarding their resolution, we are unable to estimate the potential negative impacts from these two particular items, if any, in addition to other component part performance issues discussed above. In addition, we have not recorded any specific adjustment to our warranty reserve for these particular performance issues, other than our regular reserves for minor repairs, as the estimated cost, if any, of fulfilling our obligations for these matters within a possible range of outcomes is not determinable as of this date.  Utility-Scale Solar Project Contract Matters – In July 2014, we entered into two Engineering, Procurement and Construction Agreements (“EPC Contracts”) with Georgia Power Company, a large investor-owned utility customer (the “Utility”) and in July 2015, we entered into a third EPC Contract with the Utility. The July 2015 EPC Contract was subsequently terminated, by mutual agreement, on March 23, 2016. In connection with the termination agreement, we transferred to the Utility all of our rights, duties and obligations under our solar panel supply agreement, and the Utility agreed to pay us approximately $3.2 million, which is equal to the sum of the deposit paid by us to the solar panel supplier and the amount owed by us for certain engineering work product. In addition, the Utility fully released and discharged the underlying payment and performance bond. We did not incur any termination fees or penalties as a result of the termination of the July 2015 EPC Contract.  Each of July 2014 EPC Contracts relates to a similarly sized utility-scale solar distributed generation project that is being performed for the Utility for the benefit of the Utility’s customers. The two July 2014 EPC Contracts are currently expected to generate a total of approximately $120 million in revenues, of which we have already recognized $83.2 million through March 31, 2016. Prior to March 31, 2016, we expected that these projects, which are large in scale and carry significantly lower gross profit margins as a percentage of revenues compared to traditional projects of this type, would carry single digit gross margins as a percentage of revenues. During April 2016, we determined that our costs to complete these projects would be substantially in excess of our prior estimates and that a loss would be incurred to complete the contracts . Accordingly, in accordance with our revenue recognition policy described in Note 3, we recorded an aggregate cost adjustment on the two contracts during the three months ended March 31, 2016 in the amount of $6.5 million, which is included in cost of sales in the accompanying statement of operations. We do not currently anticipate recording any additional losses to complete these two contracts, but additional losses may be incurred if future events are different from our assumptions, and those losses may be significant. The scheduled substantial completion and placed in service dates of the two July 2014 EPC Contracts range from August 1, 2016 to October 1, 2016.  The two July 2014 EPC Contracts, which are virtually identical in rights and obligations and differ primarily in project descriptions, provide for customary covenants, representations, warranties and indemnities to the Utility. The EPC Contracts also include terms requiring us to provide performance guarantees and indemnification to the Utility under certain circumstances, as well as provisions requiring us to pay the Utility liquidated damages upon the occurrence of certain events, including certain delays in substantial completion and when the system is placed in service. The aggregate limit on our liability to the Utility for liquidated damages related to delays under the EPC Contracts is approximately $24 million per contract, and is $48 million in total. We could have additional liabilities to the Utility for any breaches of our covenants, representations or warranties in addition to these potential liquidated damages. The EPC Contracts also contain typical events of default, including material breaches of the EPC Contracts after notice and cure periods and defaults relating to bonding and surety failures. The EPC Contracts may be terminated by us upon an event of default by the Utility, in which case we would be entitled to the payment for work performed and for actual costs incurred. We also provide a warranty on each project for three years after substantial completion of the project.  In addition, the solar projects covered by the EPC Contracts are subject to bonding requirements. In connection with these requirements, we have obtained, for the benefit of the Utility, bonding arrangements in the aggregate amount of approximately $120 million at March 31, 2016 for the two EPC Contracts. Our solar panel manufacturer has provided a supply bond to us in the amount of approximately $62.0 million that backstops the on-time delivery of quality panels. Other Matters – From time to time, we are involved in other disputes, claims, proceedings and legal actions arising in the ordinary course of business. We intend to vigorously defend all claims against us, and pursue our full legal rights in cases where we have been harmed. Although the ultimate outcome of these proceedings cannot be accurately predicted due to the inherent uncertainty of litigation, in the opinion of management, based upon current information, no other currently pending or overtly threatened proceeding is expected to have a material adverse effect on our business, financial condition or results of operations.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2016
Income Taxes [Abstract]
Income Taxes	10. Income Taxes The income tax expense (benefit) for the three months ended March 31, 2016 and 2015 represents our income (loss) before income taxes multiplied by our best estimate of our expected annual effective tax rate taking into consideration our expectation of future earnings, federal income tax, state income tax for state jurisdictions in which we expect taxable income, potential effects of adverse outcomes on tax positions we have taken, true-up effects of prior tax provision estimates compared to actual tax returns, and our net operating loss carryforwards.

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2016
Segment Information [Abstract]
Segment Information	11. Segment Information Our reportable segments are currently organized around the following products and services that we offer as part of our core business strategy:   Distributed Generation solutions;  Solar Energy solutions;  Utility Infrastructure solutions; and  Energy Efficiency solutions.  Our Chief Operating Decision Maker (“CODM”) reviews revenues including intersegment revenues, gross profit and operating income (loss) before income taxes when evaluating segment performance and allocating resources to each segment. Accordingly, intersegment revenue is included in the segment revenues presented in the tables below and is eliminated from revenues and cost of sales in the “Eliminations and Other” column. The “Eliminations and Other” column also includes various expense items that we do not allocate to our reportable segments. These expenses include corporate overhead and corporate-wide items such as legal and professional fees as well as expense items for which we have not identified a reasonable basis for allocation. The acco unting policies of the reportable segments are the same as those described in Note 3 of the notes to condensed consolidated financial statements.  Distributed Generation Our Distributed Generation segment manufactures, installs and operates electric generation equipment “on site” at facilities where the power is used, including commercial, institutional and industrial operations. Our Distributed Generation systems typically utilize our proprietary PowerBlock units or, alternatively, generators sourced from major global generator manufacturers as the power plants for our systems. Our Distributed Generation systems provide a highly dependable backup power supply during power outages, and provide a more efficient and environmentally friendly source of power during high cost periods of peak power demand. These two sources of value benefit both utilities and their large customers.  Solar Energy  Our Solar Energy segment engineers, procures, constructs and maintains solar power generation equipment for utilities, independent power producers, developers who sell power to utilities and industrial, commercial and institutional customers for “on site” power requirements. Our Solar Energy systems use photovoltaic solar panels (which we do not manufacture) to provide utilities and their customers with environmentally friendly power to augment their core power requirements. Utility Infrastructure Our Utility Infrastructure segment is focused on helping electric utilities design, build, upgrade and maintain infrastructure that enhances the efficiency of their grid systems.  Our largest source of revenue within our Utility Infrastructure area is our UtilityServices products and services. We have significantly expanded our UtilityServices’ scope of utility relationships, customers and geography over the last few years. Our UtilityServices team provides utilities with transmission and distribution system construction and maintenance, including substation construction and maintenance, advanced metering and lighting installations, and storm restoration. In addition to providing these services directly to utilities, we also perform this work on behalf of utilities for their large industrial and institutional customers, and directly to large oil and gas companies.  Through our Encari, UtilityEngineering and PowerServices teams, we serve the engineering and consulting needs of our utility clients, broadening our offerings to our utility partners. The scope of services that we offer through UtilityEngineering includes technical engineering services for our utility partners and their customers, including design and engineering relating to virtually every element of their transmission and distribution systems, substations and renewable energy facilities. Through PowerServices, we provide management consulting services to utilities and commercial and industrial customers, including planning and quality improvement, technical studies involving reliability analysis and rate analysis, acquisition studies, accident investigations and power supply contracts and negotiations. Our Encari business, which we acquired in October 2013, provides cybersecurity consulting and regulatory compliance services to the utility industry.  Energy Efficiency We deliver Energy Efficiency products and services to assist our customers in the achievement of their energy efficiency goals. We have two primary product and service offerings in our Energy Efficiency segment: LED lighting fixtures and lamps, and energy efficiency upgrades for our Energy Efficiency Services customers. Our LED lighting products are primarily focused on the utility, commercial and industrial, and retail markets, while our Energy Efficiency Services solutions are focused on serving large energy services companies, referred to as ESCOs. In the future, we plan to bring our LED lighting products to our Energy Efficiency Services customer base. In both of our Energy Efficiency segment product and service lines we deliver highly engineered product solutions and upgrades with strong value propositions that are designed to reduce energy costs, improve operations and benefit the environment.  Summarized financial informatio n concerning our reportable segments is shown in the following tables.     Three Months Ended March 31, 2016  Distributed Solar Utility Energy Eliminations  Generation Energy Infrastructure Efficiency and Other Total  Revenues $ 30,223 $ 24,243 $ 37,634 $ 13,837 $ (786) $ 105,151  Cost of Sales (excluding depreciation  and amortization) 23,723 30,723 33,024 9,181 (786) 95,865  Gross Profit 6,500 (6,480) 4,610 4,656 - 9,286  Operating expenses:  General and administrative 4,550 814 2,484 3,288 7,303 18,439  Selling, marketing and service 1,299 79 526 753 638 3,295  Depreciation and amortization 1,147 48 742 474 317 2,728  Total operating expenses 6,996 941 3,752 4,515 8,258 24,462  Operating income (loss) (496) (7,421) 858 141 (8,258) (15,176)  Other income and (expenses):  Interest income and other income - - - - 1 1  Interest expense - - - - (394) (394)  Income (loss) before income taxes $ (496) $ (7,421) $ 858 $ 141 $ (8,651) $ (15,569)   Total capital expenditures YTD 2016 $ 4,296 $ 21 $ 617 $ 118 $ 255 $ 5,307  Total goodwill at March 31, 2016 $ 11,403 $ 4,914 $ 2,325 $ 22,940 $ - $ 41,582  Total assets at March 31, 2016 $ 141,276 $ 47,157 $ 44,404 $ 52,848 $ 22,087 $ 307,772      Three Months Ended March 31, 2015  Distributed Solar Utility Energy Eliminations  Generation Energy Infrastructure Efficiency and Other Total  Revenues $ 30,731 $ 6,348 $ 28,883 $ 13,562 $ (15) $ 79,509  Cost of Sales (excluding depreciation  and amortization) 18,881 5,733 25,033 8,548 (15) 58,180  Gross Profit 11,850 615 3,850 5,014 - 21,329  Operating expenses:  General and administrative 4,360 780 2,873 3,255 4,366 15,634  Selling, marketing and service 1,213 97 336 591 511 2,748  Depreciation and amortization 1,070 32 776 392 207 2,477  Total operating expenses 6,643 909 3,985 4,238 5,084 20,859  Operating income (loss) 5,207 (294) (135) 776 (5,084) 470  Other income and (expenses):  Interest income and other income - - - - 1 1  Interest expense - - - - (269) (269)  Income (loss) before income taxes $ 5,207 $ (294) $ (135) $ 776 $ (5,352) $ 202   Total capital expenditures YTD 2015 $ 1,158 $ 34 $ 993 $ 67 $ 562 $ 2,814  Total goodwill at March 31, 2015 $ 11,403 $ 4,914 $ 2,325 $ 21,568 $ - $ 40,210  Total assets at March 31, 2015 $ 105,984 $ 21,935 $ 56,172 $ 41,686 $ 39,393 $ 265,170 

Description Of Business And B19

Description Of Business And Basis Of Presentation (Policy)	3 Months Ended
	Mar. 31, 2016
Description Of Business And Basis Of Presentation [Abstract]
Organization	Organization – The accompanying condensed consolidated financial statements include the accounts of PowerSecure International, Inc. and its subsidiaries, primarily PowerSecure, Inc. and its majority-owned and wholly-owned subsidiaries, UtilityEngineering, Inc., PowerServices, Inc., PowerSecure Lighting, LLC (“PowerSecure Lighting”), Solais Lighting, Inc. (“Solais”), EnergyLite, Inc.(“EnergyLite”), Reid’s Trailer, Inc. d/b/a PowerFab (“PowerFab”), Innovation Energies, LLC, and PowerSecure Solar, LLC (“PowerSecure Solar”) and PowerPackages, LLC which are collectively referred to as the “Company” or “PowerSecure” or “we” or “us” or “our”.  These condensed consolidated financial statements have been prepared pursuant to rules and regulations of the Securities and Exchange Commission. The accompanying condensed consolidated financial statements and notes thereto should be read in conjunction with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015. In management’s opinion, all adjustments (all of which are normal and recurring) have been made which are necessary for a fair presentation of the condensed consolidated financial position of us and our subsidiaries as of March 31, 2016 and the condensed consolidated results of our operations, comprehensive income (loss) and cash flows for the three months ended March 31, 2016 and 2015.
Principles Of Consolidation	Principles of Consolidation – The condensed consolidated financial statements include the accounts of PowerSecure International, Inc. and its subsidiaries after elimination of intercompany accounts and transactions.
Foreign Currency Translation	Foreign Currency Translation – The functional currency of PowerSecure’s subsidiary in Canada is the local currency. The financial statements of PowerSecure’s Canadian subsidiary is translated into the Company’s reporting currency, which is the U.S. dollar. The foreign currency translation adjustments are recorded as a separate component of accumulated other comprehensive income (loss). The Company does not have any other foreign subsidiaries.
Use Of Estimates	Use of Estimates – The preparation of our consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires that our management make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates include, among others, percentage-of-completion estimates for revenue and cost of sales recognition, incentive compensation and commissions, allowance for doubtful accounts receivable, inventory valuation reserves, warranty reserves, deferred tax valuation allowance, purchase price allocations on business acquisitions, fair value estimates of interest rate swap contracts and any impairment charges on long-lived assets and goodwill.
Reclassifications	Reclassifications – Certain 2015 amounts have been reclassified to conform to current year presentation. Such reclassifications had no effect on net income (loss) or stockholders’ equity as previously reported.

Summary Of Significant Accoun20

Summary Of Significant Accounting Policies And Recent Accounting Standards (Policy)	3 Months Ended
	Mar. 31, 2016
Summary Of Significant Accounting Policies And Recent Accounting Standards [Abstract]
Revenue Recognition	 Revenue Recognition – For our turn-key project-based revenues, we recognize revenue and profit as work progresses using the percentage-of-completion method, which relies on various estimates. These turn-key Distributed Generation, Solar Energy, Utility Infrastructure, and Energy Efficiency Services projects are nearly always fixed-price contracts. In applying the percentage-of-completion method to our Distributed Generation and Solar Energy turn-key projects, we have identified the key output project phases that are standard components of these projects. We have further identified, based on past experience, an estimate of the value of each of these output phases based on a combination of the costs incurred and the value added to the overall project. While the order of these phases varies depending on the project, each of these output phases is necessary to complete each project and each phase is an integral part of the turn-key product solution we deliver to our customers. We use these output phases and percentages to measure our progress toward completion of our construction projects. For each reporting period, the status of each project, by phase, is determined by employees who are managers of or are otherwise directly involved with the project, and this determination is reviewed by our accounting personnel. Utilizing this information, we recognize project revenues and associated project costs and gross profit based on the percentage associated with output phases that are complete or in process on each of our projects. In applying the percentage-of-completion method to Distributed Generation projects that specifically involve data center infrastructure construction, Utility Infrastructure turn-key projects and our Energy Efficiency Services projects, revenues and gross profit are recognized as work is performed based on the relationship between actual costs incurred and total estimated costs at completion. In all cases where we utilize the percentage-of-completion method, revenues and gross profit are adjusted prospectively for revisions in estimated total contract costs and contract values. Estimated losses, if any, are recorded when identified. While a project is in process, amounts billed to customers in excess of revenues recognized to date are classified as current liabilities. Likewise, amounts recognized as revenue in excess of actual billings to date are recorded as unbilled accounts receivable. In the event adjustments are made to the contract price, including, for example, adjustments for additional scope, we adjust the purchase price and related costs for these items when they are identified. Because the percentage-of-completion method of accounting relies upon estimates as described above, recognized revenues and profits are subject to revision as a project progresses to completion. Revisions in profit estimates are recorded to income in the period in which the facts that give rise to the revision become known. In the event we are required to adjust any particular project’s estimated revenues or costs, the effect on the current period earnings may or may not be significant. If, however, conditions arise that require us to adjust our estimated revenues or costs for a series of similar construction projects, or on very large projects, the effect on current period earnings would more likely be significant. In addition, certain contracts contain cancellation provisions permitting the customer to cancel the contract prior to completion of a project. Such cancellation provisions generally require the customer to pay/reimburse us for costs we incurred on the project, but may result in an adjustment to profit already recognized in a prior period. Service revenue includes regulatory consulting and rate design services, power system engineering services, energy conservation services, compliance services, and monitoring and maintenance services. Revenues from these services are recognized when the service is performed and the customer has accepted the work. Additionally, our utility infrastructure business provides services to utilities involving construction, maintenance, and upgrades to their electrical transmission and distribution systems which is not fixed price turn-key project-based work. These services are delivered by us under contracts which are generally of two types. In the first type, we are paid a fee based on the number of units of work we complete, an example of which could be the number of utility transmission poles we replace. In the second type, we are paid for the time and materials utilized to complete the work, plus a profit margin. In both of these cases, we recognize revenue as these services are delivered. We recognize revenue on non-project-based equipment and product sales when persuasive evidence of a commercial arrangement exists, delivery has occurred and/or services have been rendered, the price is fixed or determinable, and collectability is reasonably assured. Equipment and product sales are generally made directly to end users of the product, who are responsible for payment for the product, although in some instances we can be a subcontractor, which occurs most frequently on larger jobs that involve more scope than our products and services, and in other instances we sell through distributors.  Revenues for our recurring revenue distributed generation projects are recognized over the term of the contract or when energy savings are realized by the customer at its site. Under these arrangements, we provide utilities and their customers with access to PowerSecure-owned and operated distributed generation systems, for standby power and to deliver peak shaving benefits. These contracts can involve multiple parties, with one party paying us for the value of backup power (usually, but not always, a commercial, industrial, or institutional customer), and one party paying us a fee or credit for the value of the electrical capacity provided by the system during peak power demand (either the customer or a utility). Sales of certain goods and services sometimes involve the provision of multiple deliverables. Revenues from contracts with multiple deliverables are recognized as each element is earned based on the selling price for each deliverable. The selling price for each deliverable is generally based on our selling price for that deliverable on a stand-alone basis, third-party evidence if we do not sell that deliverable on a stand-alone basis, or an estimated selling price if neither specific selling prices nor third-party evidence exists.
Cash And Cash Equivalents	Cash and Cash Equivalents – Cash and all highly liquid investments with a maturity of three months or less from the date of purchase, including money market mutual funds, short-term time deposits, and government agency and corporate obligations, are classified as cash and cash equivalents.
Accounts Receivable	Accounts Receivable – Accounts receivable includes both billed and unbilled receivables from our customers. The balance of unbilled receivables included in accounts receivable was $47.7 million and $63.9 million at March 31, 2016 and December 31, 2015, respectively. Our customers include a wide variety of mid-sized and large businesses, utilities and institutions. We perform ongoing credit evaluations of our customers’ financial condition and generally do not require collateral. We monitor collections and payments from our customers and adjust credit limits of customers based upon payment history and a customer’s current credit worthiness, as judged by us. In certain instances, from time to time, we may purchase credit insurance on our accounts receivable in order to minimize our exposure to potential credit loss. We maintain a provision for estimated credit losses.
Concentration Of Credit Risk	Concentration of Credit Risk – We are subject to concentrations of credit risk from our cash and cash equivalents and accounts receivable. We limit our exposure to credit risk associated with cash and cash equivalents by placing them with multiple domestic financial institutions. Nevertheless, our cash in bank deposit accounts at these financial institutions frequently exceeds federally insured limits. We have not experienced any losses in such accounts. From time to time, we have derived a material portion of our revenues from one or more significant customers. To date, nearly all our revenues have been derived from sales to customers within the United States, although we recently commenced deriving revenues from sales to customers in Canada and the Bahamas, and expect revenues from customers in such countries to increase in the future.
Inventories	Inventories – Inventories are stated at the lower of cost (determined primarily on a specific-identification basis for the majority of our distributed generation inventory and secondarily on a first-in first-out basis for our LED-based lighting product inventory) or market. Our raw materials, equipment and supplies inventory consist primarily of equipment with long lead-times purchased for anticipated customer orders. Our work in progress inventory consists primarily of equipment and parts allocated to specific Distributed Generation and Solar project s accounted for on the percentage-of-completion basis. Our finished goods inventory consists primarily of LED-based lighting products stocked to meet customer order and delivery requirements. Inventory also includes shipping costs incurred on incoming product shipments. We provide a valuation reserve primarily for raw materials, equipment and supplies and certain work in process inventory items that may be in excess of our needs, obsolete or damaged and requiring repair or re-work.
Property, Plant And Equipment	Property, Plant and Equipment – Property, plant and equipment are stated at cost and are generally depreciated using the straight-line method over their estimated useful lives, which depending on asset class ranges from 3 to 30 years.
Goodwill And Other Intangible Assets	Goodwill and Other Intangible Assets – We amortize the cost of specifically identifiable intangible assets that do not have an indefinite life over their estimated useful lives. We do not amortize goodwill and intangible assets with indefinite lives. We perform reviews of goodwill and intangible assets with indefinite lives for impairment annually, as of October 1, or more frequently if impairment indicators arise. We capitalize software development costs integral to our products once technological feasibility of the products and software has been determined. Purchased software and software development costs are amortized over five years, using the straight-line method. Patents and license agreements are amortized using the straight-line method over the lesser of their estimated economic lives or their legal term of existence, currently 3 to 5 years. 
Debt Issuance Costs	Debt Issuance Costs – Debt issuance costs associated with our revolving line of credit are capitalized and included in other current and non-current assets in our condensed consolidated balance sheets. Debt issuance costs associated with our term loan debt are capitalized and included as a reduction of the balance of our long-term debt. In both cases, these costs are amortized over the term of the corresponding debt instrument using the straight-line method for debt issuance costs related to the revolving portion of our credit facility and the effective interest method for debt issuance costs on our term loan debt. Amortization of debt issuance costs is included in interest expense in our condensed consolidated statements of operations.
Warranty Reserve	Warranty Reserve – We provide a standard one year warranty for our Distributed Generation, switchgear, Utility Infrastructure, and Energy Efficiency Services equipment and a 5 to 10 year warranty for our LED lighting-based products. In certain cases, we offer extended warranty terms for those product lines. In addition, we provide longer warranties for our Solar Energy products and services including a warranty period of generally 1 to 5 years for defects in material and workmanship, a warranty period that can extend to 10 to 20 years for declines in power performance, and a warranty period which can extend to 15 to 25 years on the functionality of solar panels which is generally backed by the panel manufacturer. We reserve for the estimated cost of product warranties when revenue is recognized, and we evaluate our reserve periodically by comparing our warranty repair experience by product. The balance of our warranty reserve was $1.7 million and $1.7 million at March 31, 2016 and December 31, 2015, respectively, and is included in accrued and other liabilities in the accompanying condensed consolidated balance sheet. 
Share-Based Compensation	Share-Based Compensation – We measure compensation cost for all stock-based awards at their fair value on date of grant and recognize the compensation expense over the service period for awards expected to vest, net of estimated forfeitures. We measure the fair value of restricted stock awards based on the number of shares granted and the last sale price of our common stock on the date of the grant. We measure the fair value of restricted stock units based on the underlying number of shares included in the units that are granted and the last sale price of our common stock on the date of the grant. We measure the fair value of performance unit awards based on the underlying number of shares included in the performance units and the last sale price of our common stock on the date of the grant. We measure the fair value of stock options using the Black-Scholes valuation model. Pre-tax share-based compensation expense recognized during the three months ended March 31, 2016 and 2015 was $0.6 million and $0.7 million, respectively. All share-based compensation expense is included in general and administrative expense in the accompanying condensed consolidated statements of operations.
Impairment Or Disposal Of Long-Lived Assets	Impairment or Disposal of Long-Lived Assets –We evaluate our long-lived assets whenever significant events or changes in circumstances occur that indicate that the carrying amount of an asset may be impaired. Recoverability of these assets is determined by comparing the forecasted undiscounted future cash flows from the operations to which the assets relate, based on management’s best estimates using appropriate assumptions and projections at the time, to the carrying amount of the assets. If the carrying value is determined not to be recoverable from future operating cash flows, the asset is deemed impaired and an impairment loss is recognized equal to the amount by which the carrying amount exceeds the estimated fair value of the asset or assets. We did not record any long-lived asset impairment charges during the three months ended March 31, 2016 and 2015.
Income Taxes	Income Taxes – We recognize deferred income tax assets and liabilities for the estimated future tax consequences attributable to temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. We have net operating loss carryforwards available in certain jurisdictions to reduce future taxable income. Future tax benefits for net operating loss carryforwards are recognized to the extent that realization of these benefits is considered more likely than not. To the extent that available evidence raises doubt about the realization of a deferred income tax asset, a valuation allowance is established. We recognize a liability and income tax expense, including potential penalties and interest, for uncertain income tax positions taken or expected to be taken. The liability is adjusted for positions taken when the applicable statute of limitations expires or when the uncertainty of a particular position is resolved.
Derivative Instruments	Derivative Financial Instruments – Our derivative financial instruments consist solely of two interest rate swap contracts that are used to hedge our interest rate risk on a portion of our variable rate debt. These interest rate swap contracts are designated as cash flow hedges. It is our policy to execute such interest rate swaps with creditworthy banks and we do not enter into derivative financial instruments for speculative purposes.
Fair Value Measurements	Fair Value Measurement s – We measure our derivative instruments at fair value on a recurring basis. The fair value measurements standard establishes a framework for measuring fair value. The framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements), and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy under the standard are described below:  Level 1 – Inputs to the valuation methodology are unadjusted quoted prices for identical assets or liabilities in active markets.  Level 2 – Inputs to the valuation methodology include:  Quoted market prices for similar assets or liabilities in active markets;  Quoted prices for identical or similar assets or liabilities in inactive markets;  Inputs other than quoted prices that are observable for the asset or liability;  Inputs that are derived principally from or corroborated by observable market data by correlation or other means. If the asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability.  Level 3 – Inputs to the valuation methodology are unobservable and significant to the fair value measurement.  The asset’s or liability’s fair value measurement level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement. Valuation techniques used need to maximize the use of observable inputs and minimize the use of unobservable inputs.  See Note 7 for more information concerning the fair value of our derivative instruments.
Subsequent Events	Subsequent Events —Subsequent events are events or transactions that occur after the balance sheet date but before the financial statements are issued or are available to be issued and are classified as either “recognized subsequent events” or “non-recognized subsequent events”. We recognize and include in our financial statements the effects of subsequent events that provide additional evidence about conditions that existed at the balance sheet date. We disclose non-recognized subsequent events that provide evidence about conditions that arise after the balance sheet date but are not yet reflected in our financial statements when such disclosure is required to prevent the financial statements from being misleading.
Recent Accounting Pronouncements	Recent Accounting Pronouncements  Employee Share-Based Payments – In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-09, Improvements to Employee Share-Based Payment Accounting (Topic 718) (“ASU 2016-09”). ASU 2016-09 revises several aspects of the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures, and statutory tax withholding requirements, as well as classification in the statement of cash flows. The new standard is effective for annual reporting periods beginning after December 15, 2016, including interim periods therein. We are in the process of evaluating the impact the adoption of this standard will have on our consolidated financial statements and related disclosures.  Leases – In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (“ASU 2016-02”). ASU 2016-02 requires entities to recognize right-of-use assets and lease liabilities on the balance sheet for the rights and obligations created by all leases, including operating leases, with terms of more than 12 months. The new standard also requires additional disclosures on the amount, timing, and uncertainty of cash flows arising from leases. These disclosures include qualitative and quantitative information. The new standard will be effective for us on January 1, 2019. Early adoption is permitted. We are in the process of evaluating the impact the adoption of this standard will have on our consolidated financial statements and related disclosures.  Balance Sheet Classification of Deferred Taxes – In November 2015, the FASB issued ASU No. 2015-17, Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes (“ASU 2015-17”). ASU 2015-17 requires entities to present deferred tax assets and deferred tax liabilities as noncurrent in a classified balance sheet. The new standard is effective for public entities for annual periods beginning after December 15, 2016, with early adoption allowed on either a prospective or retrospective basis. We adopted ASU 2015-17, on a prospective basis, for our annual period ending December 31, 2015. Accordingly, the accompanying condensed consolidated balance sheet at March 31, 2016 and December 31, 2015 reflects the presentation of deferred tax assets and deferred tax liabilities in accordance with ASU 2015-17.  Business Combinations – In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments (“ASU 2015-16”). The new standard requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined and sets forth new disclosure requirements related to the adjustments. The new standard became effective for us on January 1, 2016. The adoption of this standard had no effect on our consolidated financial statements.  Inventory Measurement – In July 2015, the FASB issued ASU No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory (“ASU 2015-11”), which requires entities to measure inventory at the lower of cost and net realizable value (“NRV”). ASU 2015-11 defines NRV as the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The ASU will not apply to inventories that are measured by using either the last-in, first-out method or the retail inventory method. The guidance in ASU 2015-11 is effective prospectively for fiscal years beginning after December 15, 2016, and interim periods therein. Early adoption is permitted. Upon transition, entities must disclose the nature of and reason for the accounting change. We do not expect that the adoption of this standard will have a material effect on our consolidated financial statements.  Presentation of Debt Issuance Costs – In April 2015, the FASB issued ASU No. 2015-03: Simplifying the Presentation of Debt Issuance Costs (“ASU 2015-03”), and in August 2015, the FASB issued ASU 2015-15: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements (“ASU 2015-15”). These ASUs require debt issuance costs related to a recognized debt liability to be presented in the balance sheet as a direct deduction from the carrying amount of that debt consistent with debt discounts. The presentation and subsequent measurement of debt issuance costs associated with lines of credit, may be presented as an asset and amortized ratably over the term of the line of credit arrangement, regardless of whether there are outstanding borrowings on the arrangement. The recognition and measurement guidance for debt issuance costs are not affected by these ASUs. These ASUs are effective for financial statements issued for fiscal years beginning after December 15, 2015 and interim periods within those years. Early adoption is permitted for financial statements that have not been previously issued, and retrospective application is required for each balance sheet presented. We adopted the provisions of ASU 2015-03 and ASU 2015-15 on a retrospective basis for our annual period ended December 31, 2015. Accordingly, the accompanying condensed consolidated balance sheet at March 31, 2016 and December 31, 2015 reflects the presentation of debt issuance costs in accordance with ASU 2015-03 and ASU 2015-15.  Going Concern Disclosures – In August 2014, the FASB issued ASU No. 2014-15: Disclosure of Uncertainties About an Entity’s Ability to Continue as a Going Concern (“ASU 2014-15”). ASU 2014-15 requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued and provides guidance on determining when and how to disclose going concern uncertainties in the financial statements. Certain disclosures will be required if conditions give rise to substantial doubt about an entity’s ability to continue as a going concern. ASU 2014-15 is effective for annual and interim reporting periods ending after December 15, 2016, with early adoption permitted. We do not expect that the adoption of this standard will have a material effect on our consolidated financial statements.  Stock Compensation – In June 2014, the FASB issued ASU No. 2014-12, Compensation – Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (“ASU 2014-12”) . ASU 2014-12 requires that a performance target that affects vesting, and that could be achieved after the requisite service period, be treated as a performance condition. As such, the performance target should not be reflected in estimating the grant date fair value of the award. This standard further clarifies that compensation cost should be recognized in the period in which it becomes probable that the performance target will be achieved and should represent the compensation cost attributable to the periods for which the requisite service has already been rendered. The new standard became effective for us on January 1, 2016. The adoption of this standard had no effect on our consolidated financial statements.  Revenue Recognition – In May 2014, the FASB issued ASU No. 2014-09: Revenue from Contracts with Customers (“ASU 2014-09”). The new standard was originally effective for reporting periods beginning after December 15, 2016 and early adoption was not permitted. On August 12, 2015, the FASB approved a one year delay of the effective date to reporting periods beginning after December 15, 2017, while permitting companies to voluntarily adopt the new standard as of the original effective date. This standard replaces existing accounting literature relating to how and when a company recognizes revenue. Under ASU 2014-09, a company will recognize revenue when it transfers goods or services to customers in an amount equal to the amount that it expects to be entitled to receive in exchange for those goods and services. This standard also requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts, including significant judgments and changes in judgments. ASU 2014-09 will be effective for us for our fiscal year that begins January 1, 2018, and permits the use of either the retrospective or cumulative effect transition method. We are in the process of determining the method of adoption and evaluating the impact, if any, the adoption of this standard will have on our consolidated financial statements and related disclosures. 

Earnings (Loss) Per Share (Tabl

Earnings (Loss) Per Share (Tables)	3 Months Ended
	Mar. 31, 2016
Earnings (Loss) Per Share [Abstract]
Calculation Of Basic And Diluted Earnings (Loss) Per Share	   Three Months Ended  March 31,  2016 2015   Net income (loss) $ (9,923) $ 121   Basic weighted-average common  shares outstanding in period 22,505 22,385  Dilutive effect of stock options - 104  Diluted weighted-average common  shares outstanding in period 22,505 22,489   Basic earnings (loss) per common share $ (0.44) $ 0.01   Diluted earnings (loss) per common share $ (0.44) $ 0.01  

Restructuring Charges (Tables)

Restructuring Charges (Tables)	3 Months Ended
	Mar. 31, 2016
2015 Business Realignment Charges [Member]
Restructuring Cost and Reserve [Line Items]
Schedule Of Restructuring Activities	   Employee  Termination Long Term Asset  Costs Writedowns Total  2015 Business Realignment Plan:   Accrued charges, December 31, 2015 $ 538 $ - $ 538  Costs paid or otherwise settled (500) - (500)   Accrued charges, March 31, 2016 $ 38 $ - $ 38  
2013 Business Realignment Charges [Member]
Restructuring Cost and Reserve [Line Items]
Schedule Of Restructuring Activities	  Inventory Leasehold  Employee Writedowns and Termination and  Termination Long Term Asset Other Facility  Costs Disposals Exit Costs Total  2013 Business Realignment Plan:   Accrued charges, December 31, 2015 $ 47 $ - $ - $ 47  Costs paid or otherwise settled (47) - - (47)   Accrued charges, March 31, 2016 $ - $ - $ - $ -  

Debt And Interest Rate Swap C23

Debt And Interest Rate Swap Contracts (Tables)	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Schedule Of Long-Term Debt Outstanding	  March 31, December 31,  2016 2015  Revolving line of credit, maturing June 30, 2020 $ 25,000 $ -  Term loan, principal of $0.04 million plus interest payable  quarterly at variable rates, maturing June 30, 2020 1,720 1,760  Term loan, principal of $0.9 million plus interest payable  quarterly at variable rates, maturing June 30, 2020 15,178 16,072  Acquisition term notes payable 664 835  Total debt 42,562 18,667  Less: Unamortized debt issuance costs, term loans (56) (64)  Total debt, net of term loan debt issuance costs 42,506 18,603  Less: Current portion (4,245) (4,416)  Long-term debt, net of current portion $ 38,261 $ 14,187  
Schedule Of Annual Principal Payments	   Revolving Total  Scheduled Principal Payments for Line of $25.0 Million $2.6 Million Acquisition Principal  the Year Ending December 31: Credit Term Loan Term Loan Term Notes Payments  Remainder of 2016 $ - $ 2,677 $ 120 $ 514 $ 3,311  2017 - 3,571 160 150 3,881  2018 - 3,572 160 - 3,732  2019 - 3,572 160 - 3,732  2020 25,000 1,786 1,120 - 27,906   Total scheduled principal payments $ 25,000 $ 15,178 $ 1,720 $ 664 $ 42,562   

Accumulated Other Comprehensi24

Accumulated Other Comprehensive Income And Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2016
Accumulated Other Comprehensive Income and Hedging Activities [Abstract]
Summary Of Changes in Accumulated Other Comprehensive Income	The following is a summary of changes in AOCI by component for the three months ended March 31, 2016 (all amounts are net of tax):      Gains (losses) Foreign  on Cash Flow Currency  Hedge Items Total   Balance of AOCI, December 31, 2015 $ (55) $ (9) $ (64)  Other comprehensive income (loss) before reclassifications (84) 20 (64)  Reclassification adjustment for net (gains) losses  included in net income (loss) 22 - 22  Net other comprehensive income (loss) (62) 20 (42)   Balance of AOCI, March 31, 2016 $ (117) $ 11 $ (106)   The following is a summary of changes in AOCI by component for the three months ended March 31, 2015 (all amounts are net of tax):     Gains (losses) Foreign  on Cash Flow Currency  Hedge Items Total   Balance of AOCI, December 31, 2014 $ (77) $ - $ (77)  Other comprehensive income (loss) before reclassifications (81) - (81)  Reclassification adjustment for net (gains) losses  included in net income (loss) 36 - 36  Net other comprehensive income (loss) (45) - (45)   Balance of AOCI, March 31, 2015 $ (122) $ - $ (122)  
Schedule Of Fair Value Of Interest Rate Swaps	   Derivative designated as Balance Sheet March 31, December 31, Balance Sheet March 31, December 31,  hedging instrument: Location 2016 2015 Location 2016 2015   Other long-term  Interest rate swaps Other assets $ - $ - liabilities $ 214 $ 109  
Schedule Of Effects Of Cash Flow Hedges On Income Statement And AOCI	   Amounts Reclassified from AOCI into income Affected Line Item in the  Three Months Ended March 31, Consolidated Statements  AOCI Component 2016 2015 of Operations  Gain (loss) on cash flow hedges:  Interest rate swaps $ 37 $ 58 Interest expense  (15) (22) Tax expense (benefit)  $ 22 $ 36 Net of tax          Amount of gain (loss) recognized in AOCI  Three Months Ended March 31,  AOCI Component 2016 2015  Gain (loss) on cash flow hedges:  Unrealized gain (loss) -  Interest rate swaps $ (140) $ (130)  Tax effect 56 49  Gain (loss) - net of tax $ (84) $ (81)  

Share-Based Compensation (Table

Share-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2016
Summary Of Stock Option Activity	A summary of option activity for the three months ended March 31, 2016 is as follows:    Weighted  Average  Weighted Remaining Aggregate  Average Contractual Intrinsic  Shares Exercise Price Term (years) Value  Balance, December 31, 2015 422 $ 10.16  Granted - -  Exercised (7) 11.57  Expired - -  Forfeited - -  Balance, March 31, 2016 415 $ 10.14 5.84 $ 3,598   Exercisable, March 31, 2016 235 $ 9.32 4.09 $ 2,214  A summary of option activity for the three months ended March 31, 2015 is as follows:    Weighted  Average  Weighted Remaining Aggregate  Average Contractual Intrinsic  Shares Exercise Price Term (years) Value  Balance, December 31, 2014 519 $ 9.12  Granted 15 11.24  Exercised (50) 5.44  Expired - -  Forfeited (5) 8.91  Balance, March 31, 2015 479 $ 9.57 5.75 $ 2,018   Exercisable, March 31, 2015 269 $ 8.66 3.54 $ 1,290  
Summary Of Stock Options Valuation Assumptions	   Three Months Ended March 31,  2016 (1) 2015  Expected stock price volatility n/m 46.5 %  Risk free interest rate n/m 1.6 %  Annual dividends n/m $ -  Expected life (years) n/m 5   (1) 2016 amounts are not meaningful as there were no stock options granted during the period.  
Summary Of Performance Unit Award Activity	A summary of performance unit award activity for the three months ended March 31, 2016 is as follows:      Weighted  Unvested Average  Performance Grant Date  Units Fair Value  Balance, December 31, 2015 45 $ 15.39  Granted - -  Vested - -  Incremental performance shares vested - -  Forfeited - -  Balance, March 31, 2016 45 $ 15.39   A summary of performance unit award activity for the three months ended March 31, 2015 is as follows:     Weighted  Unvested Average  Performance Grant Date  Units Fair Value  Balance, December 31, 2014 17 $ 20.57  Granted 28 12.30  Vested - -  Incremental performance shares vested - -  Forfeited - -  Balance, March 31, 2015 45 $ 15.39  
Restricted Stock [Member]
Summary Of Restricted Stock Award Activity	A summary of restricted stock award activity for the three months ended March 31, 2016 is as follows:   Weighted  Unvested Average  Restricted Grant Date  Shares Fair Value  Balance, December 31, 2015 547 $ 17.44  Granted - -  Vested (1) 15.49  Forfeited - -  Balance, March 31, 2016 546 $ 17.44  A summary of restricted stock award activity for the three months ended March 31, 2015 is as follows:    Weighted  Unvested Average  Restricted Grant Date  Shares Fair Value  Balance, December 31, 2014 579 $ 17.20  Granted 28 12.30  Vested (6) 7.88  Forfeited - -  Balance, March 31, 2015 601 $ 17.06  
Restricted Stock Units [Member]
Summary Of Restricted Stock Unit Activity	  Weighted  Unvested Average  Restricted Grant Date  Stock Units Fair Value  Balance, December 31, 2015 5 $ 15.49  Granted - -  Vested (2) 15.49  Forfeited - -  Balance, March 31, 2016 3 $ 15.49  

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2016
Segment Information [Abstract]
Summary Of Financial Information In Reportable Segments	 Three Months Ended March 31, 2016  Distributed Solar Utility Energy Eliminations  Generation Energy Infrastructure Efficiency and Other Total  Revenues $ 30,223 $ 24,243 $ 37,634 $ 13,837 $ (786) $ 105,151  Cost of Sales (excluding depreciation  and amortization) 23,723 30,723 33,024 9,181 (786) 95,865  Gross Profit 6,500 (6,480) 4,610 4,656 - 9,286  Operating expenses:  General and administrative 4,550 814 2,484 3,288 7,303 18,439  Selling, marketing and service 1,299 79 526 753 638 3,295  Depreciation and amortization 1,147 48 742 474 317 2,728  Total operating expenses 6,996 941 3,752 4,515 8,258 24,462  Operating income (loss) (496) (7,421) 858 141 (8,258) (15,176)  Other income and (expenses):  Interest income and other income - - - - 1 1  Interest expense - - - - (394) (394)  Income (loss) before income taxes $ (496) $ (7,421) $ 858 $ 141 $ (8,651) $ (15,569)   Total capital expenditures YTD 2016 $ 4,296 $ 21 $ 617 $ 118 $ 255 $ 5,307  Total goodwill at March 31, 2016 $ 11,403 $ 4,914 $ 2,325 $ 22,940 $ - $ 41,582  Total assets at March 31, 2016 $ 141,276 $ 47,157 $ 44,404 $ 52,848 $ 22,087 $ 307,772      Three Months Ended March 31, 2015  Distributed Solar Utility Energy Eliminations  Generation Energy Infrastructure Efficiency and Other Total  Revenues $ 30,731 $ 6,348 $ 28,883 $ 13,562 $ (15) $ 79,509  Cost of Sales (excluding depreciation  and amortization) 18,881 5,733 25,033 8,548 (15) 58,180  Gross Profit 11,850 615 3,850 5,014 - 21,329  Operating expenses:  General and administrative 4,360 780 2,873 3,255 4,366 15,634  Selling, marketing and service 1,213 97 336 591 511 2,748  Depreciation and amortization 1,070 32 776 392 207 2,477  Total operating expenses 6,643 909 3,985 4,238 5,084 20,859  Operating income (loss) 5,207 (294) (135) 776 (5,084) 470  Other income and (expenses):  Interest income and other income - - - - 1 1  Interest expense - - - - (269) (269)  Income (loss) before income taxes $ 5,207 $ (294) $ (135) $ 776 $ (5,352) $ 202   Total capital expenditures YTD 2015 $ 1,158 $ 34 $ 993 $ 67 $ 562 $ 2,814  Total goodwill at March 31, 2015 $ 11,403 $ 4,914 $ 2,325 $ 21,568 $ - $ 40,210  Total assets at March 31, 2015 $ 105,984 $ 21,935 $ 56,172 $ 41,686 $ 39,393 $ 265,170  

Description Of Business And B27

Description Of Business And Basis Of Presentation (Narrative) (Details)	3 Months Ended
	Mar. 31, 2016segment
Description Of Business And Basis Of Presentation [Abstract]
Number of reportable segments	4
Number of operating segments	4

Proposed Merger With Southern28

Proposed Merger With Southern Company (Details) $ / shares in Units, $ in Millions	Feb. 24, 2016USD ($)$ / shares
Proposed Merger [Abstract]
Common stock shares cancelled with right to receive | $ / shares	$ 18.75
Termination fee | $	$ 12

Summary Of Significant Accoun29

Summary Of Significant Accounting Policies And Recent Accounting Standards (Narrative) (Details)	1 Months Ended	3 Months Ended
	Jul. 31, 2013contract	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2015USD ($)
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Unbilled receivables		$ 47,700,000		$ 63,900,000
Warranty reserve		1,700,000		$ 1,700,000
Pre-tax share-based compensation expense		600,000	$ 700,000
Asset impairment charges		$ 0	$ 0
Number of interest rate swap contracts | contract	2
Purchased Software And Software Development Costs [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Finite-lived intangible assets, useful life		5 years
Maximum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Estimated useful lives		30 years
Maximum [Member] | Patents And Licensing Agreements [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Finite-lived intangible assets, useful life		5 years
Minimum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Estimated useful lives		3 years
Minimum [Member] | Patents And Licensing Agreements [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Finite-lived intangible assets, useful life		3 years
Distributed Generation, Switchgear And Utility Infrastructure Equipment [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		1 year
LED Lighting-Based Products [Member] | Maximum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		10 years
LED Lighting-Based Products [Member] | Minimum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		5 years
Defects In Material And Workmanship [Member] | Maximum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		5 years
Defects In Material And Workmanship [Member] | Minimum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		1 year
Declines In Power Performance [Member] | Maximum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		20 years
Declines In Power Performance [Member] | Minimum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		10 years
Functionality Of Solar Panels [Member] | Maximum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		25 years
Functionality Of Solar Panels [Member] | Minimum [Member]
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty period		15 years

Earnings (Loss) Per Share (Deta

Earnings (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Earnings (Loss) Per Share [Abstract]
Net income (loss)	$ (9,923)	$ 121
Basic weighted-average common shares outstanding in period	22,505	22,385
Dilutive effect of stock options		104
Diluted weighted-average common shares outstanding in period	22,505	22,489
Basic earnings (loss) per common share	$ (0.44)	$ 0.01
Diluted earnings (loss) per common share	$ (0.44)	$ 0.01
Shares excluded from the diluted weighted average number of shares outstanding	415

Restructuring Charges (Schedule

Restructuring Charges (Schedule Of Restructuring Activities) (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)
2015 Business Realignment Charges [Member]
Restructuring Cost and Reserve [Line Items]
Accrued charges, beginning balance	$ 538
Costs paid or otherwise settled	(500)
Accrued charges, ending balance	38
2015 Business Realignment Charges [Member] | Employee Termination Costs [Member]
Restructuring Cost and Reserve [Line Items]
Accrued charges, beginning balance	538
Costs paid or otherwise settled	(500)
Accrued charges, ending balance	38
2013 Business Realignment Charges [Member]
Restructuring Cost and Reserve [Line Items]
Accrued charges, beginning balance	47
Costs paid or otherwise settled	(47)
2013 Business Realignment Charges [Member] | Employee Termination Costs [Member]
Restructuring Cost and Reserve [Line Items]
Accrued charges, beginning balance	47
Costs paid or otherwise settled	$ (47)

Debt And Interest Rate Swap C32

Debt And Interest Rate Swap Contracts (Narrative) (Details) $ in Thousands	Dec. 01, 2017USD ($)	Jul. 31, 2013USD ($)contract	Mar. 31, 2016USD ($)item	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	May. 06, 2016USD ($)
Debt Instrument [Line Items]
Term loan debt			$ 13,261	$ 14,187
Sum used to compute minimum required consolidated net worth					$ 142,100
Percentage of fiscal year net income to be maintained					50.00%
Percentage of equity raise through sale of equity interests to be maintained					90.00%
Number of interest rate swap contracts | contract		2
Notional amount of interest rate swap			$ 12,100
Swap option, termination date			Jun. 30, 2020
Subsequent Event [Member]
Debt Instrument [Line Items]
Remaining borrowing capacity						$ 4,000
Outstanding balance						$ 30,000
ESCO Energy Services Company, Inc [Member]
Debt Instrument [Line Items]
Number of unsecured promissory notes payable | item			2
Annual principal amount			$ 685
Number of installments payable | item			4
Interest rate			5.00%
Promissory notes			$ 800
ESCO Energy Services Company, Inc [Member] | Scenario, Forecast [Member]
Debt Instrument [Line Items]
Annual principal amount	$ 150
Federal Funds Rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate			0.50%
Citibank Prime Commercial Lending Rate And 30 Day LIBOR [Member]
Debt Instrument [Line Items]
Basis spread on variable rate			1.00%
Maximum [Member]
Debt Instrument [Line Items]
Maximum funded indebtness ratio percentage					25.00%
Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Basis spread on variable rate			3.25%
Maximum [Member] | Citibank Alternate Bank Rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate			1.50%
Minimum [Member]
Debt Instrument [Line Items]
Cash on hand			$ 5,000
Coverage ratio			1.25
Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Basis spread on variable rate			2.00%
Minimum [Member] | Citibank Alternate Bank Rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate			0.25%
$25 Million Term Loan [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 25,000
Term loan, maturity date			Jun. 30, 2020
Percentage of debt converted to fixed-rate debt		80.00%
Outstanding balance			$ 29,800
Fixed interest rate		3.73%
$25 Million Term Loan With 3.73% Fixed Interest Rate [Member]
Debt Instrument [Line Items]
Outstanding balance			$ 12,100
Fixed interest rate			3.73%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Remaining borrowing capacity			$ 9,000	36,000
Outstanding balance			25,000
Citibank I [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 20,000
Term loan, maturity date			Jun. 30, 2020
Citibank I [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 40,000	40,000
Citibank II [Member]
Debt Instrument [Line Items]
Term loan debt			$ 2,600	$ 2,600
Term loan, maturity date			Jun. 30, 2020	Jun. 30, 2020
Citibank III [Member]
Debt Instrument [Line Items]
Term loan debt			$ 25,000
Term loan, maturity date			Jun. 30, 2020
Credit facility, length of term			7 years
Citibank I And II [Member]
Debt Instrument [Line Items]
Outstanding balance			$ 16,900

Debt And Interest Rate Swap C33

Debt And Interest Rate Swap Contracts (Schedule Of Long-Term Debt Outstanding) (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term debt	$ 42,562	$ 18,667
Less: Unamortized debt issuance costs, term loans	(56)	(64)
Total scheduled principal payments	42,506	18,603
Less: Current portion	(4,245)	(4,416)
Long-term debt, net of current portion	38,261	14,187
Revolving Line Of Credit, Maturing June 30, 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	$ 25,000
Term loan, maturity date	Jun. 30, 2020
Term Loan 1, Due June 30, 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	$ 1,720	1,760
Quarterly principal amount	$ 40	40
Term loan, maturity date	Jun. 30, 2020
Term Loan 2, Due June 30, 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	$ 15,178	16,072
Quarterly principal amount	$ 900	900
Term loan, maturity date	Jun. 30, 2020
Acquisition Term Notes Payable [Member]
Debt Instrument [Line Items]
Long-term debt	$ 664	$ 835

Debt And Interest Rate Swap C34

Debt And Interest Rate Swap Contracts (Schedule Of Annual Principal Payments) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Remainder of 2016	$ 3,311
2,017	3,881
2,018	3,732
2,019	3,732
2,020	27,906
Total scheduled principal payments	42,562	$ 18,667
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
2,020	25,000
Total scheduled principal payments	25,000
$25 Million Term Loan [Member]
Debt Instrument [Line Items]
Remainder of 2016	2,677
2,017	3,571
2,018	3,572
2,019	3,572
2,020	1,786
Total scheduled principal payments	15,178
$2.6 Million Term Loan [Member] | Citibank II [Member]
Debt Instrument [Line Items]
Remainder of 2016	120
2,017	160
2,018	160
2,019	160
2,020	1,120
Total scheduled principal payments	1,720
Acquisition Term Notes [Member]
Debt Instrument [Line Items]
Remainder of 2016	514
2,017	150
Total scheduled principal payments	$ 664

Accumulated Other Comprehensi35

Accumulated Other Comprehensive Income And Hedging Activities (Narrative) (Details) $ in Thousands	1 Months Ended	3 Months Ended
	Jul. 31, 2013USD ($)contract	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)
Line of Credit Facility [Line Items]
Number of interest rate swap contracts | contract	2
Notional amount of interest rate swap		$ 12,100
Swap option, termination date		Jun. 30, 2020
Gain (loss) on cash flow hedge ineffectiveness		$ 0	$ 0
$25 Million Term Loan [Member]
Line of Credit Facility [Line Items]
Percentage of debt converted to fixed-rate debt	80.00%
Maximum borrowing capacity	$ 25,000
Fixed interest rate	3.73%
$25 Million Term Loan With 3.73% Fixed Interest Rate [Member]
Line of Credit Facility [Line Items]
Fixed interest rate		3.73%

Accumulated Other Comprehensi36

Accumulated Other Comprehensive Income And Hedging Activities (Summary Of Changes in Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance of AOCI, Beginning	$ (64)	$ (77)
Other comprehensive income (loss) before reclassifications	(64)	(81)
Reclassification adjustment for net (gains) losses included in net income (loss)	22	36
Net other comprehensive income (loss)	(42)	(45)
Balance of AOCI, Ending	(106)	(122)
Gain (Losses) On Cash Flow Hedge [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance of AOCI, Beginning	(55)	(77)
Other comprehensive income (loss) before reclassifications	(84)	(81)
Reclassification adjustment for net (gains) losses included in net income (loss)	22	36
Net other comprehensive income (loss)	(62)	(45)
Balance of AOCI, Ending	(117)	$ (122)
Foreign Currency Items [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance of AOCI, Beginning	(9)
Other comprehensive income (loss) before reclassifications	20
Net other comprehensive income (loss)	20
Balance of AOCI, Ending	$ 11

Accumulated Other Comprehensi37

Accumulated Other Comprehensive Income And Hedging Activities (Schedule Of Fair Value Of Interest Rate Swaps) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2014
Other Long-Term Liabilities [Member] | Interest Rate Swaps [Member]
Derivatives, Fair Value [Line Items]
Fair value of interest rate swaps, Liabilities	$ 214	$ 109

Accumulated Other Comprehensi38

Accumulated Other Comprehensive Income And Hedging Activities (Schedule Of Effects Of Cash Flow Hedges On Income Statement) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Interest expense	$ 394	$ 269
Tax expense (benefit)	(5,646)	81
Net of tax	9,923	(121)
Gain (Losses) On Cash Flow Hedge [Member] | Amounts Reclassified From AOCI Into Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest expense	37	58
Tax expense (benefit)	(15)	(22)
Net of tax	$ 22	$ 36

Accumulated Other Comprehensi39

Accumulated Other Comprehensive Income And Hedging Activities (Schedule Of Effects Of Cash Flow Hedges On AOCI) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Accumulated Other Comprehensive Income and Hedging Activities [Abstract]
Unrealized gain (loss) - Interest rate swaps	$ (140)	$ (130)
Tax effect	56	49
Gain (loss) - Net of tax	$ (84)	$ (81)

Share-Based Compensation (Narra

Share-Based Compensation (Narrative) (Details) $ / shares in Units, $ in Thousands	Jun. 19, 2012shares	Mar. 31, 2016USD ($)itemshares	Mar. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2015USD ($)shares	Dec. 31, 2014shares	Mar. 31, 2008shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of stock option plans | item		2
Pre-tax compensation costs		$ 600	$ 700
1998 Stock Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option term		10 years
Stock Plan expiration date		June 12, 2008
Number of additional shares authorized | shares		0
1998 Stock Plan [Member] | Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonqualified stock options, vesting period		2 years
1998 Stock Plan [Member] | Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Qualified stock options, vesting period		5 years
2008 Stock Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option term		10 years
Shares authorized under the plan | shares	2,000,000					600,000
Number of additional shares authorized | shares	1,400,000
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre-tax compensation costs		$ 52	$ 86
Weighted average grant date fair value of the options granted | $ / shares			$ 4.73
Forfeiture rate of stock options granted		5.00%
Total unrecognized compensation costs		$ 700		$ 800
Weighted average period for compensation costs to be recognized		3 years 10 months 24 days
Total intrinsic value of stock options exercised		$ 36	$ 300
Cash received from stock option exercised		81	300
Stock options vested, fair value		14	28
Restricted Stock And Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre-tax compensation costs		$ 500	$ 500
Restricted Stock And Restricted Stock Units [Member] | Minimum [Member] | Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock, vesting period		1 year
Restricted Stock And Restricted Stock Units [Member] | Maximum [Member] | Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock, vesting period		3 years
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units outstanding | shares		546,000	601,000	547,000	579,000
Total unrecognized compensation costs		$ 6,000
Weighted average period for compensation costs to be recognized		4 years 1 month 6 days
Restricted Stock [Member] | Minimum [Member] | Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock, vesting period		5 years
Restricted Stock [Member] | Maximum [Member] | Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock, vesting period		10 years
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units outstanding | shares		3,000	0	5,000
Total unrecognized compensation costs		$ 44
Weighted average period for compensation costs to be recognized		3 months 18 days
Restricted stock units issued | shares			0
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre-tax compensation costs		$ 67	$ 35
Units outstanding | shares		45,000	45,000	45,000	17,000
Total unrecognized compensation costs		$ 300
Weighted average period for compensation costs to be recognized		1 year 4 months 24 days
Performance Units [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares authorized under the plan | shares		23,000
Performance Units [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares authorized under the plan | shares		68,000

Share-Based Compensation (Summa

Share-Based Compensation (Summary Of Stock Option Activity) (Details) - USD ($) $ / shares in Units, shares in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Share-Based Compensation [Abstract]
Stock options, Shares, Beginning balance	422	519
Stock options, Weighted Average Exercise Price, Beginning balance	$ 10.16	$ 9.12
Granted, Shares		15
Granted, Weighted Average Exercise Price		$ 11.24
Exercised, Shares	(7)	(50)
Exercised, Weighted Average Exercise Price	$ 11.57	$ 5.44
Forfeited, Shares		(5)
Forfeited, Weighted Average Exercise Price		$ 8.91
Stock options, Shares, Ending balance	415	479
Stock options, Weighted Average Exercise Price, Ending balance	$ 10.14	$ 9.57
Stock options, Weighted Average Remaining Contractual Term	5 years 10 months 2 days	5 years 9 months
Stock options, Aggregate Intrinsic Value	$ 3,598,000	$ 2,018
Stock options, Exercisable, Shares	235	269
Stock options, Exercisable, Weighted Average Exercise Price	$ 9.32	$ 8.66
Stock Options, Exercisable, Weighted Average Remaining Contractual Term (years)	4 years 1 month 2 days	3 years 6 months 15 days
Stock options, Exercisable, Aggregate Intrinsic Value	$ 2,214,000	$ 1,290,000

Share-Based Compensation (Sum42

Share-Based Compensation (Summary Of Stock Options Valuation Assumptions) (Details)	3 Months Ended
	Mar. 31, 2015
Share-Based Compensation [Abstract]
Expected stock price volatility	46.50%
Risk free interest rate	1.60%
Expected life (years)	5 years

Share-Based Compensation (Sum43

Share-Based Compensation (Summary Of Restricted Stock Award and Unit Activity) (Details) - $ / shares	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance, Unvested Restricted Shares	547,000	579,000
Beginning balance, Weighted Average Grant Date Fair Value	$ 17.44	$ 17.20
Granted, Unvested Restricted Shares		28,000
Granted, Weighted Average Grant Date Fair Value		$ 12.30
Vested, Unvested Restricted Shares	(1,000)	(6,000)
Vested, Weighted Average Grant Date Fair Value	$ 15.49	$ 7.88
Ending balance, Unvested Restricted Shares	546,000	601,000
Ending balance, Weighted Average Grant Date Fair Value	$ 17.44	$ 17.06
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance, Unvested Restricted Shares	5,000
Beginning balance, Weighted Average Grant Date Fair Value	$ 15.49
Vested, Unvested Restricted Shares	(2,000)
Vested, Weighted Average Grant Date Fair Value	$ 15.49
Ending balance, Unvested Restricted Shares	3,000	0
Ending balance, Weighted Average Grant Date Fair Value	$ 15.49

Share-Based Compensation (Sum44

Share-Based Compensation (Summary Of Performance Unit Award Activity) (Details) - Performance Units [Member] - $ / shares shares in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance, Unvested Restricted Shares	45	17
Beginning balance, Weighted Average Grant Date Fair Value	$ 15.39	$ 20.57
Granted, Unvested Restricted Shares		28
Granted, Weighted Average Grant Date Fair Value		$ 12.30
Ending balance, Unvested Restricted Shares	45	45
Ending balance, Weighted Average Grant Date Fair Value	$ 15.39	$ 15.39

Commitments And Contingencies (

Commitments And Contingencies (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Commitments And Contingencies [Line Items]
Surety bond issued	$ 62,000
Revenues	105,151	$ 79,509
Surety Bond [Member]
Commitments And Contingencies [Line Items]
Values associated with surety arrangements	325,400
Amount exposed to bond	169,800
2014 EPC Contract [Member]
Commitments And Contingencies [Line Items]
Surety bond issued	120,000
Expected revenue	120,000
Revenues	83,200
Maximum liability for damages	48,000
Aggregate cost adjustment	$ 6,500
Minimum [Member]
Commitments And Contingencies [Line Items]
Cost basis of component parts as a percentage of revenues	5.00%
Maximum [Member]
Commitments And Contingencies [Line Items]
Cost basis of component parts as a percentage of revenues	10.00%
Maximum liability for damages	$ 24,000
Utility-Scale Solar Project [Member]
Commitments And Contingencies [Line Items]
Warranty period	3 years
Damages paid	$ 3,200

Segment Information (Narrative)

Segment Information (Narrative) (Details)	3 Months Ended
	Mar. 31, 2016item
Segment Information [Abstract]
Number of product and service offerings	2

Segment Information (Summary Of

Segment Information (Summary Of Financial Information In Reportable Segments) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Revenues	$ 105,151	$ 79,509
Cost of sales (excluding depreciation and amortization)	95,865	58,180
Gross Profit	9,286	21,329
General and administrative	18,439	15,634
Selling, marketing and service	3,295	2,748
Depreciation and amortization	2,728	2,477
Total operating expenses	24,462	20,859
Operating income (loss)	(15,176)	470
Interest income and other income	1	1
Interest expense	(394)	(269)
Income (loss) before income taxes	(15,569)	202
Total capital expenditures		2,814
Total goodwill	41,582	40,210	$ 41,582
Total assets	307,772	265,170	$ 335,815
Eliminations And Other [Member]
Segment Reporting Information [Line Items]
Revenues	(786)	(15)
Cost of sales (excluding depreciation and amortization)	(786)	(15)
General and administrative	7,303	4,366
Selling, marketing and service	638	511
Depreciation and amortization	317	207
Total operating expenses	8,258	5,084
Operating income (loss)	(8,258)	(5,084)
Interest income and other income	1	1
Interest expense	(394)	(269)
Income (loss) before income taxes	(8,651)	(5,352)
Total capital expenditures		562
Total assets	22,087	39,393
Distributed Generation [Member]
Segment Reporting Information [Line Items]
Revenues	30,223	30,731
Cost of sales (excluding depreciation and amortization)	23,723	18,881
Gross Profit	6,500	11,850
General and administrative	4,550	4,360
Selling, marketing and service	1,299	1,213
Depreciation and amortization	1,147	1,070
Total operating expenses	6,996	6,643
Operating income (loss)	(496)	5,207
Income (loss) before income taxes	(496)	5,207
Total capital expenditures		1,158
Total goodwill	11,403	11,403
Total assets	141,276	105,984
Solar Energy [Member]
Segment Reporting Information [Line Items]
Revenues	24,243	6,348
Cost of sales (excluding depreciation and amortization)	30,723	5,733
Gross Profit	(6,480)	615
General and administrative	814	780
Selling, marketing and service	79	97
Depreciation and amortization	48	32
Total operating expenses	941	909
Operating income (loss)	(7,421)	(294)
Income (loss) before income taxes	(7,421)	(294)
Total capital expenditures		34
Total goodwill	4,914	4,914
Total assets	47,157	21,935
Utility Infrastructure [Member]
Segment Reporting Information [Line Items]
Revenues	37,634	28,883
Cost of sales (excluding depreciation and amortization)	33,024	25,033
Gross Profit	4,610	3,850
General and administrative	2,484	2,873
Selling, marketing and service	526	336
Depreciation and amortization	742	776
Total operating expenses	3,752	3,985
Operating income (loss)	858	(135)
Income (loss) before income taxes	858	(135)
Total capital expenditures		993
Total goodwill	2,325	2,325
Total assets	44,404	56,172
Energy Efficiency [Member]
Segment Reporting Information [Line Items]
Revenues	13,837	13,562
Cost of sales (excluding depreciation and amortization)	9,181	8,548
Gross Profit	4,656	5,014
General and administrative	3,288	3,255
Selling, marketing and service	753	591
Depreciation and amortization	474	392
Total operating expenses	4,515	4,238
Operating income (loss)	141	776
Income (loss) before income taxes	141	776
Total capital expenditures		67
Total goodwill	22,940	21,568
Total assets	$ 52,848	$ 41,686