PowerSecure International 10-Q 5 Aug 15 2015 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Jul. 31, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
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		22,455,731

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Current Assets:
Cash and cash equivalents	$ 20,516	$ 33,775
Trade receivables, net of allowance for doubtful accounts of $609 and $470, respectively	102,761	81,381
Inventories	29,967	35,144
Income taxes receivable		382
Deferred tax asset, net	2,320	2,320
Prepaid expenses and other current assets	3,458	3,478
Total current assets	159,022	156,480
Property, plant and equipment:
Equipment	67,023	62,231
Furniture and fixtures	685	617
Land, building and improvements	7,836	7,413
Total property, plant and equipment, at cost	75,544	70,261
Less accumulated depreciation and amortization	23,569	20,392
Property, plant and equipment, net	51,975	49,869
Other assets:
Goodwill	40,210	40,210
Restricted annuity contract	3,137	3,137
Intangible assets and capitalized software costs, net of accumulated amortization of $9,209 and $7,374, respectively	12,890	13,642
Other assets	2,446	1,879
Total other assets	58,683	58,868
Total Assets	269,680	265,217
Current liabilities:
Accounts payable	39,963	39,699
Accrued and other liabilities	44,840	41,113
Accrued restructuring liabilities	60	114
Income taxes payable	199
Current portion of long-term debt	3,731	3,731
Current portion of capital lease obligation	500	986
Total current liabilities	$ 89,293	$ 85,643
Long-term liabilities:
Revolving line of credit
Long-term debt, net of current portion	$ 15,966	$ 17,832
Capital lease obligation, net of current portion
Deferred tax liability, net	$ 1,457	$ 1,460
Other long-term liabilities	4,031	3,913
Total long-term liabilities	$ 21,454	$ 23,205
Commitments and contingencies (Notes 8 and 10)
Stockholders' Equity:
Preferred stock
Common stock, $.01 par value; 50,000,000 shares authorized; 22,455,731 and 22,369,487 shares issued and outstanding, respectively	$ 225	$ 224
Additional paid-in-capital	162,739	161,163
Accumulated deficit	(3,949)	(4,941)
Accumulated other comprehensive income (loss)	(82)	(77)
Total stockholders' equity	158,933	156,369
Total Liabilities and Stockholders' Equity	$ 269,680	$ 265,217
Series C Preferred Stock [Member]
Stockholders' Equity:
Preferred stock

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Trade receivables, allowance for doubtful accounts	$ 609	$ 470
Intangible rights and capitalized software costs, accumulated amortization	$ 9,209	$ 7,374
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	22,455,731	22,369,487
Common stock, shares outstanding	22,455,731	22,369,487
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		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Condensed Consolidated Statements Of Operations [Abstract]
Revenues	$ 107,182	$ 57,069	$ 186,691	$ 109,866
Cost of sales (excluding depreciation and amortization)	83,111	42,738	141,291	84,494
Gross profit	24,071	14,331	45,400	25,372
Operating expenses:
General and administrative	16,705	13,670	32,339	26,714
Selling, marketing and service	2,973	2,466	5,721	4,475
Depreciation and amortization	$ 2,612	2,137	5,089	4,315
Restructuring charges				427
Total operating expenses	$ 22,290	18,273	43,149	35,931
Operating income (loss)	1,781	(3,942)	2,251	(10,559)
Other income and (expenses):
Interest income and other income	2	5	3	9
Interest expense	(287)	(292)	(556)	(592)
Income (loss) before income taxes	1,496	(4,229)	1,698	(11,142)
Income tax expense (benefit)	625	(1,481)	706	(4,135)
Net income (loss)	$ 871	$ (2,748)	$ 992	$ (7,007)
Earnings (loss) per share:
Basic	$ 0.04	$ (0.12)	$ 0.04	$ (0.32)
Diluted	$ 0.04	$ (0.12)	$ 0.04	$ (0.32)
Weighted average common shares outstanding during the period:
Basic	22,450	22,346	22,418	22,164
Diluted	22,592	22,346	22,544	22,164

Condensed Consolidated Stateme5

Condensed Consolidated Statements Of Comprehensive Income (Loss) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Condensed Consolidated Statements Of Comprehensive Income (Loss) [Abstract]
Net income (loss)	$ 871	$ (2,748)	$ 992	$ (7,007)
Cash flow hedge:
Change in unrealized gain (loss)	8	(74)	(73)	(119)
Reclassification adjustment for net (gains) losses included in net income (loss)	32	46	68	87
Total comprehensive income (loss), net of tax	$ 911	$ (2,776)	$ 987	$ (7,039)

Condensed Consolidated Stateme6

Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flows from operating activities:
Net income (loss)	$ 992	$ (7,007)
Adjustments to reconcile net income (loss) to net cash used in operating activities:
Depreciation and amortization	5,089	4,315
Stock compensation expense	1,326	893
(Gain) loss on disposal of miscellaneous assets	(34)	(92)
Changes in operating assets and liabilities
Trade receivables, net	(21,380)	7,888
Inventories	5,177	(3,796)
Other current assets and liabilities	600	(5,336)
Other noncurrent assets and liabilities	(456)	(704)
Accounts payable	264	3,740
Accrued and other liabilities	3,727	(3,894)
Accrued restructuring liabilities	(54)	(604)
Net cash used in operating activities	(4,749)	(4,597)
Cash flows from investing activities:
Purchases of property, plant and equipment	(5,486)	(4,501)
Additions to intangible rights and software development	(1,083)	(318)
Proceeds from sale of property, plant and equipment	159	460
Net cash used in investing activities	$ (6,410)	$ (4,359)
Cash flows from financing activities:
Borrowings (payments) on revolving line of credit
Principal payments on long-term borrowings	$ (1,866)	$ (1,866)
Payments on capital lease obligations	(486)	(460)
Repurchases of common stock	(48)	(366)
Proceeds from stock option exercises	300	2,045
Net cash provided by (used in) financing activities	(2,100)	(647)
NET DECREASE IN CASH AND CASH EQUIVALENTS	(13,259)	(9,603)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	33,775	50,915
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$ 20,516	$ 41,312

Description Of Business And Bas

Description Of Business And Basis Of Presentation	6 Months Ended
	Jun. 30, 2015
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. We provide products and services through four operating segments: our Distributed Generation segment, our Solar Energy segment, our Utility Infrastructure segment, and our Energy Efficiency segment. These four operating segments constitute our major product and services 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 cost structures, 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 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. Each of our four operating segments also represents a reporting segment. See Note 12 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”), EfficientLights, LLC (“EfficientLights”), Innovative Electronic Solutions Lighting, LLC (“IES”), 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”. On June 30, 2014, EfficientLights and IES were dissolved and merged into EnergyLite. 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, 2014. 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 June 30, 2015 and the condensed consolidated results of our operations and cash flows for the three and six months ended June 30, 2015 and 2014. 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. Comprehensive Income or Loss – Comprehensive income or loss represents the changes in stockholders’ equity during a period resulting from transactions and other events and circumstances from non-owner sources. At June 30, 2015 and December 31, 2014, the balance of Accumulated other comprehensive income (loss) (“Accumulated OCI”) consisted solely of changes in the fair value of our interest rate cash flow hedge contracts, net of taxes. 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 2014 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 Accounti

Summary Of Significant Accounting Policies And Recent Accounting Standards	6 Months Ended
	Jun. 30, 2015
Summary Of Significant Accounting Policies And Recent Accounting Standards [Abstract]
Summary Of Significant Accounting Policies And Recent Accounting Standards	2. 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. Revenues from turn-key Mission Critical Data Center Energy Services (formerly referred to as “Mission Critical Energy Services”) projects, which are integrated in our Distributed Generation segment since our acquisition of those operations in October 2014, are also recognized using the percentage-of-completion method. 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 our Mission Critical Data Center Energy Services , 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. We recognize equipment and product revenue 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. 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. 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 – 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. 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, Mission Critical Data Center Energy Services and Solar Energy turn-key projects and our Utility Infrastructure and Energy Efficiency Services project costs 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 are capitalized and included in other current and non-current assets in our condensed consolidated balance sheets. 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 purchase price for extended warranties or for extended warranties included in the contract terms are deferred as a component of our warranty reserve. The balance of our warranty reserve was $1.6 million and $1.7 million at June 30, 2015 and December 31, 2014, 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 June 30, 2015 and 2014 was $0.7 million and $0.6 million, respectively. Pre-tax share-based compensation expense during the six months ended June 30, 2015 and 2014 was $1.3 million and $0.9 million, respectively. All share-based compensation expense is included in general and administrative expense in the accompanying condensed consolidated statements o f 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 no t record any long-lived asset impairment charges during the three and six months ended June 30, 2015 and 2014. 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 Inventory Measurement – In July 201 5, the Financial Accounting Standards Board (“FASB”) issued Accounti ng Standards Update (“ASU”) No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory (“ASU 2015-11”), which requires enti ties 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”). ASU 2015-03 specifies that debt issuance costs shall be reported in the balance sheet as a direct deduction from the related debt liability rather than as an asset. Amortization of the costs shall be reported as interest expense. The guidance in ASU 2015-03 is effective for fiscal years beginning after December 15, 2015. Early adoption is allowed. Application of the guidance in ASU 2015-03 is applicable retrospectively to all periods presented. We do not expect that the adoption of this standard will have a material effect on our consolidated financial statements. 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 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015 and can be applied either prospectively or retrospectively to all awards outstanding as of the beginning of the earliest annual period presented as an adjustment to opening retained earnings. Early adoption is permitted. We are evaluating the impact, if any, this new standard will have 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”). 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 annual and interim periods beginning after December 15, 201 7 , and will be effective for us for our fiscal year that begins January 1, 201 8 , and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. 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. Reporting Discontinued Operations – In April 2014, the FASB issued ASU No. 2014-08: Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (“ASU 2014-08”). ASU 2014-08 changes the definition of a discontinued operation to include only those disposals of components of an entity that represent a strategic shift that has (or will have) a major effect on an entity’s operations and financial results, and changes the criteria and enhances disclosures for reporting discontinued operations. This standard is to be applied prospectively, and is effective for our fiscal year that begins January 1, 2015. The adoption of this standard had no effect on our consolidated financial statements.

Earnings (Loss) Per Share

Earnings (Loss) Per Share	6 Months Ended
	Jun. 30, 2015
Earnings (Loss) Per Share [Abstract]
Earnings (Loss) Per Share	3. 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 449 thousand common shares issuable upon the potential exercise of outstanding stock options were ex cluded from the calculation of diluted weighted average number of shares outstanding for the three and six months ended June 30, 2014, 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 Six Months Ended June 30, June 30, 2015 2014 2015 2014 Net income (loss) $ $ $ $ Basic weighted-average common shares outstanding in period Dilutive effect of stock options - - Diluted weighted-average common shares outstanding in period Basic earnings (loss) per common share $ $ $ $ Diluted earnings (loss) per common share $ $ $ $

Contingent Consideration Paymen

Contingent Consideration Payment On 2014 Acquisition	6 Months Ended
	Jun. 30, 2015
Contingent Consideration Payment On 2014 Acquisition [Abstract]
Contingent Consideration Payment On 2014 Acquisition	4. Contingent Consideration Payment on 2014 Acquisition On October 14, 2014 , we acquired the mission critical data center energy services business and certain related assets of Power Design, Inc., a Florida corporation (“PDI”), pursuant to an Asset Purchase and Sale Agreement (the “Purchase Agreement”), between PDI, as seller, and PowerSecure, Inc., as purchaser. We refer to the acquired operations as our Mission Critical Data Center Energy Services operations and have integrated these operations within our Distributed Generation segment. The purchase price paid for the Mission Critical Data Center Energy Services operations was $13.0 million in cash and $0.1 million cash for a working capital adjustment plus a potential additional contingent cash payment in the amount of $1.0 million if PowerSecure, Inc. obtains firm backlog after the closing in the amount of at least $5.0 million from the acquired business, or in the amount of $2.0 million if the firm backlog amount obtained after closing is at least $15.0 million. We paid $1.0 million of contingent cash consideration to PDI on April 3, 2015. We expect to pay an additional $1.0 million in full settlement of the contingent consideration during the remainder of 2015 as the result of additional backlog that the acquired business is expected to generate. The balance of our contingent consideration liability at June 30, 2015 and December 31, 2014 was $1.0 million and $1.9 million, respectively.

Restructuring Charges

Restructuring Charges	6 Months Ended
	Jun. 30, 2015
Restructuring Charges [Abstract]
Restructuring Charges	5 . Restructuring Charges From time to time and most recently in 2013, we have engaged in restructuring programs designed to reduce our cost structure and improve producti vity. 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 the balance of our accrued restructuring liabilities at and for the six months ended June 30, 2015 : Inventory Leasehold Employee Writedowns and Termination and Termination Long Term Asset Other Facility Costs Disposals Exit Costs Total Accrued restructuring liabilities, December 31, 2014 $ $ - $ - $ Costs paid or otherwise settled - - Accrued restructuring liabilities, June 30, 2015 $ $ - $ - $ \ The balances of our accrued restructuring liabilities at June 30, 2015 and December 31, 2014 are included in current liabilities in our condensed consolidated balance sheet. We expect the majority of the balance of our accrued restructuring charges at June 30, 2015 will be paid or otherwise sett led during the remainder of 2015 .

Debt And Interest Rate Swap Con

Debt And Interest Rate Swap Contracts	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Debt And Interest Rate Swap Contracts	6 . Debt and Interest Rate Swap Contracts 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 June 30, 2015 and December 31, 2014 , our credit agreement with Citibank along with Branch Banking and Trust Company (“BB&T”) as additional lender, consisted of a $20.0 million senior, first-priority secured revolving line of credit maturing on November 12, 201 6, a $2.6 million term loan maturing on November 12, 2016 , and a $25.0 million, 7 year amortizing term loan maturing on June 30, 2020 . The credit agreement is guaranteed by all our active subsidiaries and is secured by the assets of us and those subsidiaries. The credit facility contains three basic financial covenants. First, u nder 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. Prior to the fiscal quarter ended June 30 , 2015, the fixed charge coverage ratio was based on our financial results for the third quarter 2014 and subsequent fiscal quarters. Commencing with the most recent fiscal quarter ended June 30, 2015 and continuing thereafter, the fixed charge coverage ratio is now 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 2014 fiscal year, 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 30% . As of June 30, 2015 , we were in compliance with these financial covenants. The following table summarizes the balances outstanding on our long-term debt , including our revolving line of credit, with Citibank and BB&T at June 30, 2015 and December 31, 2014 : June 30, December 31, 2015 2014 Revolving line of credit, maturing November 12, 2016 $ - $ - Term loan, principal of $0.04 million plus interest payable quarterly at variable rates, maturing November 12, 2016 Term loan, principal of $0.9 million plus interest payable quarterly at variable rates, maturing June 30, 2020 Total debt Less: Current portion Long-term debt, net of current portion $ $ 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 Utility Infrastructure 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 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% . Scheduled remaining principal payments on our outstanding debt obligations at June 30, 2015, are as follows: Revolving Total Scheduled Principal Payments for Line of $25.0 Million $2.6 Million Principal the Year Ending December 31: Credit Term Loan Term Loan Payments Remainder of 2015 $ - $ $ $ 2016 - 2017 - - 2018 - - 2019 and thereafter - - Total scheduled principal payments $ - $ $ $ In July 201 3 , 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 June 30, 2015, $14.3 million of our outstanding debt bears interest at a fixed rate of 3.73% and $5.4 million of our outstanding debt 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 , repurchase stock, and 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 a nd 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 g uarantees guaranty all of our obligations under the credit facility, and the s e curity agreements grant to the l enders a first priority security interest in virtually all of the assets of each guarantor . There was an aggregate balance of $19.7 million outstanding under the two term loans under our credit facility as of June 30, 2015. There were no balances outstanding on the revolving portion of the credit facility at, or during the three months ended, June 30, 2015 or at December 31, 2014 or at August 5, 2015 . In addition, there were no outstanding letters of credit reducing the amount available to borrow under the revolving portion of the credit facility at June 30 or August 5, 2015. Accordingly, we currently have $20.0 million available to borrow under the revolving portion of the credit facility. The availability this capital under our credit facility includes restrictions on the use of proceeds, and is dependent upon our ability to satisfy certain financial and operating covenants, as described above.

Derivative Instruments And Hedg

Derivative Instruments And Hedging Activities	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities [Abstract]
Derivative Instruments And Hedging Activities	7 . Derivative Instruments and 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 June 30 , 2015 was $14.3 million . The termination dates of the swap contracts and the maturity date of the $25 million Term Loan are b oth June 30, 2020 . In accordance with ASC 815, Derivatives and Hedging , w e have designated both of our interest rate swaps as cash flow hedges of the interest payment s 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 June 30, 2015 and December 31, 2014, are as follows: Derivative designated as Balance Sheet June 30, December 31, Balance Sheet June 30, December 31, hedging instrument: Location 2015 2014 Location 2015 2014 Other long-term Interest rate swaps Other assets $ - $ - liabilities $ $ 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 June 30, Six Months Ended June 30, Consolidated Statements AOCI Component 2015 2014 2015 2014 of Operations Gain (loss) on cash flow hedges: Interest rate swaps $ $ $ $ Interest expense Tax expense (benefit) $ $ $ $ Net of tax Amount of gain (loss) recognized in AOCI Three Months Ended June 30, Six Months Ended June 30, AOCI Component 2015 2014 2015 2014 Gain (loss) on cash flow hedges: Unrealized gain (loss) - Interest rate swaps $ $ $ $ Tax effect Gain (loss) - net of tax $ $ $ $ We did not realize any ineffectiveness related to our cash flow hedges during the three or six months ended June 30, 2015 and 2014.

Capital Lease Obligations

Capital Lease Obligations	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Capital Lease Obligations	8 . Capital Lease Obligations We have a capital lease with SunTrust Equipment Finance and Leasing (as Lessor) from the sale and leaseback of distributed generation equipment placed in service at customer locations. We received $5.9 million from the sale of the equipment in December 2008 which we are repaying under the terms of the lease with monthly principal and interest payments of $0.1 million over a period of 84 months. At the expiration of the term of the lease in December 2015 , we have the option to purchase the equipment for $1 dollar, assuming no default under the lease by us has occurred and is then continuing. The lease is guaranteed by us under an equipment lease guaranty. The lease and the lease guaranty constitute permitted indebtedness under our current credit agreement. Proceeds of the lease financing were used to finance capital investments in equipment for our recurring revenue distributed generation projects. We account for the lease financing as a capital lease in our condensed consolidated financial statements. The lease provides us with limited rights, subject to the lessor's approval which will not be unreasonably withheld, to relocate and substitute equipment during its term. The lease contains representations and warranties and covenants relating to the use and maintenance of the equipment, indemnification and events of default customary for leases of this nature. The lease also grants to the lessor certain remedies upon a default, including the right to cancel the lease, to accelerate all rent payments for the remainder of the term of the lease, to recover liquidated damages, or to repossess and re-lease, sell or otherwise dispose of the equipment. The balance s of our capital lease obligations shown in the accompanying condensed consolidated balance sheet at June 30, 2015 and December 31, 2014 consist s entirely of our obligations under the equipment lease described above.

Share-Based Compensation

Share-Based Compensation	6 Months Ended
	Jun. 30, 2015
Share-Based Compensation [Abstract]
Share-Based Compensation	9 . 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, w e have granted stock options, restricted stock awards , restricted stock units and performance unit awards to employees and direct ors 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 June 30, 2015 and 2014 includes $59 thousand and $43 thousand, respectively, of pre-tax compensation costs related to outstanding stock options. Net income (loss) for the six months ended June 30, 2015 and 2014 includes $145 thousand and $87 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 six months ended June 30, 2015 is as follows: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Shares Exercise Price Term (years) Value Balance, December 31, 2014 $ Granted Exercised Expired - - Forfeited Balance, June 30, 2015 $ $ 4.97 Exercisable, June 30, 2015 $ $ 5.73 A summary of option activity for the six months ended June 30, 2014 is as follows: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Shares Exercise Price Term (years) Value Balance, December 31, 2013 $ Granted Exercised Expired - - Forfeited Balance, June 30, 2014 $ $ 0.87 Exercisable, June 30, 2014 $ $ 2.03 The weighted aver age grant date fair value of stock options granted during the six months ended June 30, 2015 and 2014 was $4.99 and $6.49 , respectively . The fair value of the stock options granted during the six months ended June 30, 2015 and 2014 was measured using the Black-Scholes valuation model with the following assumptions: Six Months Ended June 30, 2015 2014 Expected stock price volatility % % Risk free interest rate % % Annual dividends $ - - Expected life (years) 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 June 30, 2015 and December 31, 2014, there was $0.7 million and $0.8 million, respectively, of total unrecognized compensation costs related to stock options. These costs at June 30, 2015 are expected to be recognized over a weighted average period of approximately 4.3 years. During the three months ended June 30, 2015 and 2014, the total intrinsic value of stock options exercised was $0.1 million and $0 , respectively. Cash received from stock option exercises during the three months ended June 30, 2015 and 2014 was $0 and $0 , respectively. The total grant date fair value of stock options vested during the three months ended June 30, 2015 and 2014 was $78 thousand and $60 thousand, respectively. During the six months ended June 30, 2015 and 2014, the total intrinsic value of stock options exercised was $0.4 million and $3.3 million, respectively. Cash received from stock option exercises during the six months ended June 30, 2015 and 2014 was $0.3 million and $2.0 million, respectively. The total grant date fair value of stock options vested during the six months ended June 30, 2015 and 2014 was $106 thousand and $65 thousand , respectively Restricted Stock Awards and Restricted Stock Units – Net income (loss) for the three months ended June 30, 2015 and 2014 includes $0.6 million and $0.6 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. Net income (loss) for the six months ended June 30, 2015 and 2014 includes $1.1 million and $0.8 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 and six months ended June 30, 2015 and 2014 is included in general and administrative expenses in the accompanying condensed consolidated statements of operations . A summary of restricted stock award activity for the six months ended June 30, 2015 is as follows: Weighted Unvested Average Restricted Grant Date Shares Fair Value Balance, December 31, 2014 $ Granted Vested Forfeited - - Balance, June 30, 2015 $ A summary of restricted stock award activity for the six months ended June 30, 2014 is as follows: Weighted Unvested Average Restricted Grant Date Shares Fair Value Balance, December 31, 2013 $ Granted Vested Forfeited Balance, June 30, 2014 $ A summary of restricted stock unit activity for the six months ended June 30, 2015 is as follows: Weighted Unvested Average Restricted Grant Date Stock Units Fair Value Balance, December 31, 2014 - $ - Granted Vested - - Forfeited - - Balance, June 30, 2015 $ There were no restricted stock units issued or outstanding at or during the three or six months ended June 30, 2014. 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 June 30, 2015 , the balance of unrecognized compensation cost related to unvested restricted shares was $7.7 million, which is expected to be recognized over a weighted average period of approximately 4.7 years. At June 30, 2015 , the balance of unrecognized compensation cost related to unvested restricted stock units was $0.2 million, which is expected to be recognized over a weighted average period of approximately 1.0 year. Performance Units – Net income (loss) for the three months ended June 30, 2015 includes $66 thousand 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 . Net income (loss) for the six months ended June 30, 2015 includes $101 thousand 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 and six months ended June 30, 2015 is included in general and administrative expenses in the accompanying condensed consolidated statements of operations . There were no performance units issued or outstanding during the three or six months ended June 30, 2014. A summary of performance unit award activity for the six months ended June 30, 2015 is as follows: Weighted Unvested Average Performance Grant Date Units Fair Value Balance, December 31, 2014 $ Granted Vested - - Incremental performance shares vested - - Forfeited - - Balance, June 30, 2015 $ The performance units outstanding at June 30, 2015 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 June 30, 2015 , 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 June 30, 2015, the balance of unrecognized compensation costs related to outstanding performance units was $0.5 million, which is expected to be recognized over a weighted average period of approximately 2.0 years.

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2015
Commitments And Contingencies [Abstract]
Commitments And Contingencies	10 . Commitments and Contingencies 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, to which plaintiffs responded on April 30, 2015. We file d our reply brief on June 4, 2015 . We cannot provide any assurance as to when or how the court will rule on our motion to dismiss. We believe that the claims asserted in this class action litigation are without merit, and we intend to vigorously defend against all such allegations. 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. Further action on the derivative complaint has been stayed by order of the court upon the mutual agreement of the parties, pending final resolution of the securities class action. 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 our insurance coverage will be sufficient or that our insurance carriers will cover all claims. 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 expected legal expenses, we have not recognized any costs for the securities class actions 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. 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 June 30, 2015, we had approximately $304.2 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 $81.8 million at June 30, 2015. In July 2015, we obtained additional bonding in the amount of approximately $85.0 million in connection with a July 2015 utility-scale solar project discussed in greater detail below. 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 Energy 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 subject to the issuance by the Utility of a notice to proceed, which we received on July 21, 2015. Each of these EPC Contracts relates to a similarly sized utility-scale solar distributed generation project that will be performed for the Utility for the benefit of the Utility’s customers. We expect these solar projects to generate a total of $205 million in revenues, and expect these projects to be completed and the associated revenues recognized over the course of 2015 and 2016. We also expect 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, will carry single digit gross margins as a percentage of revenues. Thus, we expect the impact of these contracts to be dilutive to our consolidated gross margins as a percentage of revenues, while being accretive to our net income and earnings per share. The scheduled substantial completion and placed in service dates of the three EPC Contracts range from August 1, 2016 to December 31, 2016. The 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 ranges from approximately $24 million to approximately $34 million per contract, and is $82 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 amount of approximately $120 million at June 30, 2015 for the two July 2014 EPC Contracts, and have obtained, for the benefit of the Utility, additional bonding arrangements in the amount of approximately $85 million in July 2015 for the third EPC Contract . The solar panel manufacturer has provided a supply bond to us in the amount of approximately $60 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	6 Months Ended
	Jun. 30, 2015
Income Taxes [Abstract]
Income Taxes	11 . Income Taxes The income tax expense (benefit) for the three and six months ended June 30, 2015 and 2014 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	6 Months Ended
	Jun. 30, 2015
Segment Information [Abstract]
Segment Information	12 . Segment Information Our operating and 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. The Distributed Generation and Solar Energy reporting segments, described in greater detail below, had previously been reported on a combined basis under our Distributed Generation segment as they both utilized distributed generation technology solutions in their products and services, and they shared overhead costs. As a result of the utility-scale solar projects awarded to us in July 2014, we expect the Solar Energy operations will be a material portion of our consolidated revenues and operations in 2015 and for the foreseeable future, and it is now being supported by separate overhead costs. In addition, the cost and margin structure of the Solar Energy segment differs from our traditional Distributed Generation segment. For these reasons, we determined it was appropriate to report our Distributed Generation and Solar Energy operations as separate reporting segments commencing in 2015. Our segment information for the three and six month periods ended June 30, 2014 have been reclassified to conform to our current presentation. 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 operating 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 accounting policies of the reportable segments are the same as those described in Note 2 of the n otes to condensed consolidated financial s tatements. 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 information concerning our reportable segments is shown in t he following tables. Three Months Ended June 30, 2015 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest income and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $ Total goodwill at June 30, 2015 $ $ $ $ $ - $ Total assets at June 30, 2015 $ $ $ $ $ $ Three Months Ended June 30, 2014 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest income and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $ Six Months Ended June 30, 2015 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $ Total capital expenditures YTD 2015 $ $ $ $ $ $ Six Months Ended June 30, 2014 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $

Description Of Business And B19

Description Of Business And Basis Of Presentation (Policy)	6 Months Ended
	Jun. 30, 2015
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”), EfficientLights, LLC (“EfficientLights”), Innovative Electronic Solutions Lighting, LLC (“IES”), 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”. On June 30, 2014, EfficientLights and IES were dissolved and merged into EnergyLite. 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, 2014. 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 June 30, 2015 and the condensed consolidated results of our operations and cash flows for the three and six months ended June 30, 2015 and 2014.
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.
Comprehensive Income Or Loss	Comprehensive Income or Loss – Comprehensive income or loss represents the changes in stockholders’ equity during a period resulting from transactions and other events and circumstances from non-owner sources. At June 30, 2015 and December 31, 2014, the balance of Accumulated other comprehensive income (loss) (“Accumulated OCI”) consisted solely of changes in the fair value of our interest rate cash flow hedge contracts, net of taxes.
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 2014 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)	6 Months Ended
	Jun. 30, 2015
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. Revenues from turn-key Mission Critical Data Center Energy Services (formerly referred to as “Mission Critical Energy Services”) projects, which are integrated in our Distributed Generation segment since our acquisition of those operations in October 2014, are also recognized using the percentage-of-completion method. 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 our Mission Critical Data Center Energy Services , 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. We recognize equipment and product revenue 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. 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. 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 – 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.
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, Mission Critical Data Center Energy Services and Solar Energy turn-key projects and our Utility Infrastructure and Energy Efficiency Services project costs 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 are capitalized and included in other current and non-current assets in our condensed consolidated balance sheets. 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 purchase price for extended warranties or for extended warranties included in the contract terms are deferred as a component of our warranty reserve. The balance of our warranty reserve was $1.6 million and $1.7 million at June 30, 2015 and December 31, 2014, 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 June 30, 2015 and 2014 was $0.7 million and $0.6 million, respectively. Pre-tax share-based compensation expense during the six months ended June 30, 2015 and 2014 was $1.3 million and $0.9 million, respectively. All share-based compensation expense is included in general and administrative expense in the accompanying condensed consolidated statements o f 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 no t record any long-lived asset impairment charges during the three and six months ended June 30, 2015 and 2014.
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 Inventory Measurement – In July 201 5, the Financial Accounting Standards Board (“FASB”) issued Accounti ng Standards Update (“ASU”) No. 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory (“ASU 2015-11”), which requires enti ties 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”). ASU 2015-03 specifies that debt issuance costs shall be reported in the balance sheet as a direct deduction from the related debt liability rather than as an asset. Amortization of the costs shall be reported as interest expense. The guidance in ASU 2015-03 is effective for fiscal years beginning after December 15, 2015. Early adoption is allowed. Application of the guidance in ASU 2015-03 is applicable retrospectively to all periods presented. We do not expect that the adoption of this standard will have a material effect on our consolidated financial statements. 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 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015 and can be applied either prospectively or retrospectively to all awards outstanding as of the beginning of the earliest annual period presented as an adjustment to opening retained earnings. Early adoption is permitted. We are evaluating the impact, if any, this new standard will have 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”). 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 annual and interim periods beginning after December 15, 201 7 , and will be effective for us for our fiscal year that begins January 1, 201 8 , and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. 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. Reporting Discontinued Operations – In April 2014, the FASB issued ASU No. 2014-08: Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (“ASU 2014-08”). ASU 2014-08 changes the definition of a discontinued operation to include only those disposals of components of an entity that represent a strategic shift that has (or will have) a major effect on an entity’s operations and financial results, and changes the criteria and enhances disclosures for reporting discontinued operations. This standard is to be applied prospectively, and is effective for our fiscal year that begins January 1, 2015. The adoption of this standard had no effect on our consolidated financial statements.

Earnings (Loss) Per Share (Tabl

Earnings (Loss) Per Share (Tables)	6 Months Ended
	Jun. 30, 2015
Earnings (Loss) Per Share [Abstract]
Calculation Of Basic And Diluted Earnings (Loss) Per Share	Three Months Ended Six Months Ended June 30, June 30, 2015 2014 2015 2014 Net income (loss) $ $ $ $ Basic weighted-average common shares outstanding in period Dilutive effect of stock options - - Diluted weighted-average common shares outstanding in period Basic earnings (loss) per common share $ $ $ $ Diluted earnings (loss) per common share $ $ $ $

Restructuring Charges (Tables)

Restructuring Charges (Tables)	6 Months Ended
	Jun. 30, 2015
Restructuring Charges [Abstract]
Schedule Of Restructuring Activities	Inventory Leasehold Employee Writedowns and Termination and Termination Long Term Asset Other Facility Costs Disposals Exit Costs Total Accrued restructuring liabilities, December 31, 2014 $ $ - $ - $ Costs paid or otherwise settled - - Accrued restructuring liabilities, June 30, 2015 $ $ - $ - $

Debt And Interest Rate Swap C23

Debt And Interest Rate Swap Contracts (Tables)	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Schedule Of Long-Term Debt Outstanding	June 30, December 31, 2015 2014 Revolving line of credit, maturing November 12, 2016 $ - $ - Term loan, principal of $0.04 million plus interest payable quarterly at variable rates, maturing November 12, 2016 Term loan, principal of $0.9 million plus interest payable quarterly at variable rates, maturing June 30, 2020 Total debt Less: Current portion Long-term debt, net of current portion $ $
Schedule Of Annual Principal Payments	Revolving Total Scheduled Principal Payments for Line of $25.0 Million $2.6 Million Principal the Year Ending December 31: Credit Term Loan Term Loan Payments Remainder of 2015 $ - $ $ $ 2016 - 2017 - - 2018 - - 2019 and thereafter - - Total scheduled principal payments $ - $ $ $

Derivative Instruments And He24

Derivative Instruments And Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities [Abstract]
Schedule Of Fair Value Of Interest Rate Swaps	Derivative designated as Balance Sheet June 30, December 31, Balance Sheet June 30, December 31, hedging instrument: Location 2015 2014 Location 2015 2014 Other long-term Interest rate swaps Other assets $ - $ - liabilities $ $
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 June 30, Six Months Ended June 30, Consolidated Statements AOCI Component 2015 2014 2015 2014 of Operations Gain (loss) on cash flow hedges: Interest rate swaps $ $ $ $ Interest expense Tax expense (benefit) $ $ $ $ Net of tax Amount of gain (loss) recognized in AOCI Three Months Ended June 30, Six Months Ended June 30, AOCI Component 2015 2014 2015 2014 Gain (loss) on cash flow hedges: Unrealized gain (loss) - Interest rate swaps $ $ $ $ Tax effect Gain (loss) - net of tax $ $ $ $

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2015
Share-Based Compensation [Abstract]
Summary Of Stock Option Activity	A summary of option activity for the six months ended June 30, 2015 is as follows: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Shares Exercise Price Term (years) Value Balance, December 31, 2014 $ Granted Exercised Expired - - Forfeited Balance, June 30, 2015 $ $ 4.97 Exercisable, June 30, 2015 $ $ 5.73 A summary of option activity for the six months ended June 30, 2014 is as follows: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Shares Exercise Price Term (years) Value Balance, December 31, 2013 $ Granted Exercised Expired - - Forfeited Balance, June 30, 2014 $ $ 0.87 Exercisable, June 30, 2014 $ $ 2.03
Summary Of Stock Options Valuation Assumptions	Six Months Ended June 30, 2015 2014 Expected stock price volatility % % Risk free interest rate % % Annual dividends $ - - Expected life (years)
Summary Of Restricted Stock Activity	A summary of restricted stock award activity for the six months ended June 30, 2015 is as follows: Weighted Unvested Average Restricted Grant Date Shares Fair Value Balance, December 31, 2014 $ Granted Vested Forfeited - - Balance, June 30, 2015 $ A summary of restricted stock award activity for the six months ended June 30, 2014 is as follows: Weighted Unvested Average Restricted Grant Date Shares Fair Value Balance, December 31, 2013 $ Granted Vested Forfeited Balance, June 30, 2014 $ A summary of restricted stock unit activity for the six months ended June 30, 2015 is as follows: Weighted Unvested Average Restricted Grant Date Stock Units Fair Value Balance, December 31, 2014 - $ - Granted Vested - - Forfeited - - Balance, June 30, 2015 $
Summary Of Performance Unit Award Activity	Weighted Unvested Average Performance Grant Date Units Fair Value Balance, December 31, 2014 $ Granted Vested - - Incremental performance shares vested - - Forfeited - - Balance, June 30, 2015 $

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2015
Segment Information [Abstract]
Summary Of Financial Information In Reportable Segments	Three Months Ended June 30, 2015 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest income and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $ Total goodwill at June 30, 2015 $ $ $ $ $ - $ Total assets at June 30, 2015 $ $ $ $ $ $ Three Months Ended June 30, 2014 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest income and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $ Six Months Ended June 30, 2015 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $ Total capital expenditures YTD 2015 $ $ $ $ $ $ Six Months Ended June 30, 2014 Distributed Solar Utility Energy Eliminations Generation Energy Infrastructure Efficiency and Other Total Revenues $ $ $ $ $ $ Cost of Sales (excluding depreciation and amortization) Gross Profit - Operating expenses: General and administrative Selling, marketing and service Depreciation and amortization Restructuring charges - - - - Total operating expenses Operating income (loss) Other income and (expenses): Interest and other income - - - - Interest expense - - - - Income (loss) before income taxes $ $ $ $ $ $

Summary Of Significant Accoun27

Summary Of Significant Accounting Policies And Recent Accounting Standards (Narrative) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Summary Of Significant Accounting Policies And Recent Accounting Standards [Line Items]
Warranty reserve	$ 1,600,000		$ 1,600,000		$ 1,700,000
Pre-tax share-based compensation expense	700,000	$ 600,000	1,300,000	$ 900,000
Asset impairment charges	$ 0	$ 0	$ 0	$ 0
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 (Calc

Earnings (Loss) Per Share (Calculation Of Basic And Diluted Earnings (Loss) Per Share) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Earnings (Loss) Per Share [Abstract]
Net income (loss)	$ 871	$ (2,748)	$ 992	$ (7,007)
Basic weighted-average common shares outstanding in period	22,450	22,346	22,418	22,164
Dilutive effect of stock options	142		126
Diluted weighted-average common shares outstanding in period	22,592	22,346	22,544	22,164
Basic earnings (loss) per common share	$ 0.04	$ (0.12)	$ 0.04	$ (0.32)
Diluted earnings (loss) per common share	$ 0.04	$ (0.12)	$ 0.04	$ (0.32)
Shares excluded from the diluted weighted average number of shares outstanding		449		449

Contingent Consideration Paym29

Contingent Consideration Payment On 2014 Acquisition (Narrative) (Details) - USD ($) $ in Millions	Oct. 14, 2014	Jun. 30, 2015	Dec. 31, 2014	Apr. 03, 2015
Business Acquisition [Line Items]
Contingent consideration		$ 1	$ 1.9
Contingent consideration paid				$ 1
Expected contingent consideration payment amount		$ 1
PDI [Member]
Business Acquisition [Line Items]
Date of acquisition		Oct. 14, 2014
Cash paid	$ 13
Working capital adjustment	0.1
PDI [Member] | Backlog In The Amount Of At Least $5 Million [Member]
Business Acquisition [Line Items]
Contingent consideration	1
PDI [Member] | Backlog In The Amount Of At Least $15 Million [Member]
Business Acquisition [Line Items]
Contingent consideration	2
Minimum [Member] | PDI [Member] | Backlog In The Amount Of At Least $5 Million [Member]
Business Acquisition [Line Items]
Intangible asset amount	5
Minimum [Member] | PDI [Member] | Backlog In The Amount Of At Least $15 Million [Member]
Business Acquisition [Line Items]
Intangible asset amount	$ 15

Restructuring Charges (Schedule

Restructuring Charges (Schedule Of Restructuring Activities) (Details) - 2013 Business Realignment Charges [Member] $ in Thousands	6 Months Ended
	Jun. 30, 2015USD ($)
Restructuring Cost and Reserve [Line Items]
Accrued charges, beginning balance	$ 114
Costs paid or otherwise settled	(54)
Accrued charges, ending balance	60
Employee Termination Costs [Member]
Restructuring Cost and Reserve [Line Items]
Accrued charges, beginning balance	114
Costs paid or otherwise settled	(54)
Accrued charges, ending balance	$ 60

Debt And Interest Rate Swap C31

Debt And Interest Rate Swap Contracts (Narrative) (Details)	1 Months Ended	6 Months Ended	12 Months Ended
	Jul. 31, 2013USD ($)contract	Jun. 30, 2015USD ($)	Dec. 31, 2014USD ($)	Aug. 05, 2015USD ($)
Debt Instrument [Line Items]
Term loan debt		$ 15,966,000	$ 17,832,000
Sum used to compute minimum required consolidated net worth		$ 142,100,000
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
Borrowing amount		$ 20,000,000
Swap option, termination date		Jun. 30, 2020
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		30.00%
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		$ 5,000,000
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	$ 25,000,000	$ 25,000,000	$ 25,000,000
Term loan, maturity date		Jun. 30, 2020
Credit facility, length of term		7 years	7 years
Percentage of debt converted to fixed-rate debt	80.00%
Variable rate portion of debt outstanding		$ 5,400,000
Fixed interest rate	3.73%
$25 Million Term Loan With 3.73% Fixed Interest Rate [Member]
Debt Instrument [Line Items]
Fixed interest rate		3.73%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Outstanding balance		$ 0	$ 0	$ 0
Letter of Credit [Member]
Debt Instrument [Line Items]
Outstanding balance		0		$ 0
Citibank I [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		20,000,000	20,000,000
Citibank II [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		2,600,000	$ 2,600,000
Citibank I And II [Member]
Debt Instrument [Line Items]
Outstanding balance		$ 19,700,000

Debt And Interest Rate Swap C32

Debt And Interest Rate Swap Contracts (Schedule Of Long-Term Debt Outstanding) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term debt	$ 19,697	$ 21,563
Less: Current portion	(3,731)	(3,731)
Long-term debt, net of current portion	$ 15,966	17,832
Revolving Line Of Credit, Maturing November 12, 2016 [Member]
Debt Instrument [Line Items]
Term loan, maturity date	Nov. 12, 2016
Term Loan, Maturing November 12, 2016 [Member]
Debt Instrument [Line Items]
Long-term debt	$ 1,840	1,920
Quarterly principal amount	$ 40	40
Term loan, maturity date	Nov. 12, 2016
Term Loan, Maturing June 30, 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	$ 17,857	19,643
Quarterly principal amount	$ 900	$ 900
Term loan, maturity date	Jun. 30, 2020

Debt And Interest Rate Swap C33

Debt And Interest Rate Swap Contracts (Schedule Of Annual Principal Payments) (Details) $ in Thousands	Jun. 30, 2015USD ($)
Debt Instrument [Line Items]
Remainder of 2015	$ 1,865
2,016	5,331
2,017	3,572
2,018	3,572
2019 and thereafter	5,357
Total scheduled principal payments	19,697
Citibank II [Member]
Debt Instrument [Line Items]
Remainder of 2015	80
2,016	1,760
Total scheduled principal payments	1,840
$25 Million Term Loan [Member]
Debt Instrument [Line Items]
Remainder of 2015	1,785
2,016	3,571
2,017	3,572
2,018	3,572
2019 and thereafter	5,357
Total scheduled principal payments	$ 17,857

Derivative Instruments And He34

Derivative Instruments And Hedging Activities (Details) $ in Millions	1 Months Ended	6 Months Ended
	Jul. 31, 2013USD ($)contract	Jun. 30, 2015USD ($)	Dec. 31, 2014USD ($)
Line of Credit Facility [Line Items]
Number of interest rate swap contracts | contract	2
Notional amount of interest rate swap		$ 14.3
Swap option, termination date		Jun. 30, 2020
$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	$ 25	$ 25
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%

Derivative Instruments And He35

Derivative Instruments And Hedging Activities (Schedule Of Fair Value Of Interest Rate Swaps) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Other Noncurrent Liabilities [Member] | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Fair value of interest rate swaps, Liabilities	$ 154	$ 146

Derivative Instruments And He36

Derivative Instruments And Hedging Activities (Schedule Of Effects Of Cash Flow Hedges On Income Statement And AOCI) (Details) - Interest Rate Swap [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Reclassified from AOCI into income	$ 55	$ 68	$ 113	$ 137
Income Tax Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Reclassified from AOCI into income	(23)	(22)	(45)	(50)
Gain (Loss) - Net Of Tax [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount Reclassified from AOCI into income	$ 32	$ 46	$ 68	$ 87

Derivative Instruments And He37

Derivative Instruments And Hedging Activities (Amount Of Gain (Loss) In AOCI) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Derivative Instruments and Hedging Activities [Abstract]
Unrealized gain (loss) - Interest rate swaps	$ 9	$ (112)	$ (121)	$ (187)
Tax effect	(1)	38	48	68
Gain (loss) - Net of tax	$ 8	$ (74)	$ (73)	$ (119)

Capital Lease Obligations (Narr

Capital Lease Obligations (Narrative) (Details) - USD ($)	1 Months Ended	6 Months Ended
	Dec. 31, 2008	Jun. 30, 2015
Debt Disclosure [Abstract]
Sale leaseback transaction, gross proceeds	$ 5,900,000
Repayment of lease terms with monthly principal and interest payments		$ 100,000
Term of lease, months		84 months
Expiration term of the lease		Dec. 1, 2015
Option purchase price on equipment		$ 1

Share-Based Compensation (Narra

Share-Based Compensation (Narrative) (Details) $ / shares in Units, $ in Thousands	Jun. 19, 2012shares	Jun. 30, 2015USD ($)itemshares	Jun. 30, 2014USD ($)shares	Jun. 30, 2015USD ($)item$ / sharesshares	Jun. 30, 2014USD ($)$ / sharesshares	Dec. 31, 2014USD ($)shares	Dec. 31, 2013shares	Mar. 31, 2008shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of stock option plans | item		2		2
Pre-tax compensation costs		$ 700	$ 600	$ 1,300	$ 900
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		59	43	$ 145	$ 87
Weighted average grant date fair value of the options granted | $ / shares				$ 4.99	$ 6.49
Forfeiture rate of stock options granted				5.00%
Total unrecognized compensation costs		700		$ 700		$ 800
Weighted average period for compensation costs to be recognized				4 years 3 months 18 days
Total intrinsic value of stock options exercised		100	0	$ 400	$ 3,300
Cash received from stock option exercised		0	0	300	2,000
Stock options vested, fair value		78	60	106	65
Restricted Stock And Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre-tax compensation costs		600	$ 600	$ 1,100	$ 800
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]
Total unrecognized compensation costs		$ 7,700		$ 7,700
Weighted average period for compensation costs to be recognized				4 years 8 months 12 days
Units outstanding | shares		583,000	597,000	583,000	597,000	579,000	387,000
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]
Total unrecognized compensation costs		$ 200		$ 200
Weighted average period for compensation costs to be recognized				1 year
Restricted stock units issued | shares			0		0
Units outstanding | shares		11,000	0	11,000	0
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre-tax compensation costs		$ 66		$ 101
Total unrecognized compensation costs		$ 500		$ 500
Weighted average period for compensation costs to be recognized				2 years
Units outstanding | shares		45,000	0	45,000	0	17,000
Performance units issued | shares			0		0
Performance Units [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares authorized under the plan | shares		23,000		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		68,000

Share-Based Compensation (Summa

Share-Based Compensation (Summary Of Stock Option Activity) (Details) - USD ($) $ / shares in Units, shares in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Share-Based Compensation [Abstract]
Stock options, Shares, Beginning balance	519	669
Stock options, Weighted Average Exercise Price, Beginning balance	$ 9.12	$ 8.59
Granted, Shares	21	20
Granted, Weighted Average Exercise Price	$ 11.88	$ 15.77
Exercised, Shares	(60)	(232)
Exercised, Weighted Average Exercise Price	$ 5.03	$ 8.80
Forfeited, Shares	(8)	(8)
Forfeited, Weighted Average Exercise Price	$ 7.32	$ 4.58
Stock options, Shares, Ending balance	472	449
Stock options, Weighted Average Exercise Price, Ending balance	$ 9.79	$ 8.87
Stock options, Weighted Average Remaining Contractual Term	5 years 7 months 6 days	4 years 11 months 27 days
Stock options, Aggregate Intrinsic Value	$ 4.97	$ 0.87
Stock options, Exercisable, Shares	275	298
Stock options, Exercisable, Weighted Average Exercise Price	$ 9.03	$ 7.71
SharebasedCompensationArrangementBySharebasedPaymentAwardOptionsExercisableWeightedAverageRemainingContractualTerm1	3 years 6 months	3 years 2 months 16 days
Stock options, Exercisable, Aggregate Intrinsic Value	$ 5.73	$ 2.03

Share-Based Compensation (Sum41

Share-Based Compensation (Summary Of Stock Options Valuation Assumptions) (Details)	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Share-Based Compensation [Abstract]
Expected stock price volatility	46.40%	45.50%
Risk free interest rate	1.50%	1.60%
Expected life (years)	5 years	5 years

Share-Based Compensation (Sum42

Share-Based Compensation (Summary Of Restricted Stock Activity) (Details) - $ / shares	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance	579,000	387,000
Beginning balance, Weighted Average Grant Date Fair Value	$ 17.20	$ 14.37
Granted	30,000	226,000
Granted, Weighted Average Grant Date Fair Value	$ 12.47	$ 21.39
Vested	(26,000)	(11,000)
Vested, Weighted Average Grant Date Fair Value	$ 12.86	$ 14.95
Forfeited		(5,000)
Forfeited, Weighted Average Grant Date Fair Value		$ 23.44
Ending balance	583,000	597,000
Ending balance, Weighted Average Grant Date Fair Value	$ 17.15	$ 16.95
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted	11,000
Granted, Weighted Average Grant Date Fair Value	$ 15.49
Ending balance	11,000	0
Ending balance, Weighted Average Grant Date Fair Value	$ 15.49

Share-Based Compensation (Sum43

Share-Based Compensation (Summary Of Performance Unit Award Activity) (Details) - Performance Units [Member] - $ / shares	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance	17,000
Beginning balance, Weighted Average Grant Date Fair Value	$ 20.57
Granted	28,000
Granted, Weighted Average Grant Date Fair Value	$ 12.30
Ending balance	45,000	0
Ending balance, Weighted Average Grant Date Fair Value	$ 15.39

Commitments And Contingencies (

Commitments And Contingencies (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Jul. 31, 2015	Jun. 30, 2015
Commitments And Contingencies [Line Items]
Expected revenue		$ 205
Maximum liability for damages		82
Performance bond issued		60
Surety Bond [Member]
Commitments And Contingencies [Line Items]
Values associated with surety arrangements		304.2
Amount exposed to bond		$ 81.8
Minimum [Member]
Commitments And Contingencies [Line Items]
Cost basis of component parts as a percentage of revenues		5.00%
Maximum liability for damages		$ 24
Maximum [Member]
Commitments And Contingencies [Line Items]
Cost basis of component parts as a percentage of revenues		10.00%
Maximum liability for damages		$ 34
Subsequent Event [Member]
Commitments And Contingencies [Line Items]
Additional bond amount	$ 85
Utility-Scale Solar Project [Member]
Commitments And Contingencies [Line Items]
Surety bond issued		$ 120
Warranty period		3 years

Segment Information (Summary Of

Segment Information (Summary Of Financial Information In Reportable Segments) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Revenues	$ 107,182	$ 57,069	$ 186,691	$ 109,866
Cost of Sales (excluding depreciation and amortization)	83,111	42,738	141,291	84,494
Gross Profit	24,071	14,331	45,400	25,372
General and administrative	16,705	13,670	32,339	26,714
Selling, marketing and service	2,973	2,466	5,721	4,475
Depreciation and amortization	$ 2,612	2,137	5,089	4,315
Restructuring charges				427
Total operating expenses	$ 22,290	18,273	43,149	35,931
Operating income (loss)	1,781	(3,942)	2,251	(10,559)
Interest and other income	2	5	3	9
Interest expense	(287)	(292)	(556)	(592)
Income (loss) before income taxes	1,496	(4,229)	1,698	(11,142)
Total capital expenditures YTD 2015			6,569
Total goodwill	40,210		40,210		$ 40,210
Total assets	269,680		269,680		$ 265,217
Eliminations And Other [Member]
Segment Reporting Information [Line Items]
Revenues	(190)	(421)	(205)	(421)
Cost of Sales (excluding depreciation and amortization)	(190)	(421)	(205)	(421)
General and administrative	4,896	5,048	9,263	9,561
Selling, marketing and service	290	351	800	421
Depreciation and amortization	306	160	513	317
Total operating expenses	5,492	5,559	10,576	10,299
Operating income (loss)	(5,492)	(5,559)	(10,576)	(10,299)
Interest and other income	2	5	3	9
Interest expense	(287)	(292)	(556)	(592)
Income (loss) before income taxes	(5,777)	(5,846)	(11,129)	(10,882)
Total capital expenditures YTD 2015			780
Total assets	37,224		37,224
Distributed Generation [Member]
Segment Reporting Information [Line Items]
Revenues	34,263	20,205	64,994	37,195
Cost of Sales (excluding depreciation and amortization)	22,530	13,195	41,411	23,822
Gross Profit	11,733	7,010	23,583	13,373
General and administrative	4,723	2,886	9,083	5,916
Selling, marketing and service	1,423	985	2,637	2,036
Depreciation and amortization	1,079	781	2,149	1,559
Total operating expenses	7,225	4,652	13,869	9,511
Operating income (loss)	4,508	2,358	9,714	3,862
Income (loss) before income taxes	4,508	2,358	9,714	3,862
Total capital expenditures YTD 2015			3,223
Total goodwill	11,403		11,403
Total assets	115,325		115,325
Solar Energy [Member]
Segment Reporting Information [Line Items]
Revenues	24,985	2,108	31,333	2,613
Cost of Sales (excluding depreciation and amortization)	22,695	1,885	28,428	2,424
Gross Profit	2,290	223	2,905	189
General and administrative	940	470	1,719	977
Selling, marketing and service	196	112	293	225
Depreciation and amortization	32	24	64	48
Total operating expenses	1,168	606	2,076	1,250
Operating income (loss)	1,122	(383)	829	(1,061)
Income (loss) before income taxes	1,122	(383)	829	(1,061)
Total capital expenditures YTD 2015			268
Total goodwill	4,914		4,914
Total assets	16,408		16,408
Utility Infrastructure [Member]
Segment Reporting Information [Line Items]
Revenues	33,264	23,770	62,147	50,598
Cost of Sales (excluding depreciation and amortization)	28,229	20,257	53,262	44,424
Gross Profit	5,035	3,513	8,885	6,174
General and administrative	3,347	2,626	6,220	5,549
Selling, marketing and service	361	318	697	622
Depreciation and amortization	830	867	1,606	1,726
Total operating expenses	4,538	3,811	8,523	7,897
Operating income (loss)	497	(298)	362	(1,723)
Income (loss) before income taxes	497	(298)	362	(1,723)
Total capital expenditures YTD 2015			1,918
Total goodwill	2,325		2,325
Total assets	54,979		54,979
Energy Efficiency [Member]
Segment Reporting Information [Line Items]
Revenues	14,860	11,407	28,422	19,881
Cost of Sales (excluding depreciation and amortization)	9,847	7,822	18,395	14,245
Gross Profit	5,013	3,585	10,027	5,636
General and administrative	2,799	2,640	6,054	4,711
Selling, marketing and service	703	700	1,294	1,171
Depreciation and amortization	365	305	757	665
Restructuring charges				427
Total operating expenses	3,867	3,645	8,105	6,974
Operating income (loss)	1,146	(60)	1,922	(1,338)
Income (loss) before income taxes	1,146	$ (60)	1,922	$ (1,338)
Total capital expenditures YTD 2015			380
Total goodwill	21,568		21,568
Total assets	$ 45,744		$ 45,744