Enernoc (ENOC) 10-Q 9 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2014	5-May-14
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	31-Mar-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'
Trading Symbol	'ENOC	'
Entity Registrant Name	'ENERNOC INC	'
Entity Central Index Key	'0001244937	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	30,346,946

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$103,698	$149,189
Restricted cash	1,197	1,834
Trade accounts receivable, net of allowance for doubtful accounts of $462 and $454 at March 31, 2014 and December 31, 2013, respectively	46,528	35,933
Unbilled revenue	27,507	66,675
Capitalized incremental direct customer contract costs	16,267	9,509
Deposits	263	252
Prepaid expenses, deposits and other current assets	9,920	6,610
Assets held for sale	681	681
Total current assets	206,061	270,683
Property and equipment, net of accumulated depreciation of $80,238 and $75,810 at March 31, 2014 and December 31, 2013, respectively	48,425	47,419
Goodwill	94,969	77,104
Customer relationship intangible assets, net	19,482	14,247
Other definite-lived intangible assets, net	5,702	2,939
Capitalized incremental direct customer contract costs, long-term	1,910	1,995
Deposits and other assets	2,794	1,568
Total assets	379,343	415,955
Current liabilities	'	'
Accounts payable	1,532	2,031
Accrued capacity payments	58,497	76,676
Accrued payroll and related expenses	10,978	13,370
Accrued expenses and other current liabilities	13,871	10,145
Accrued performance adjustments	539	1,720
Deferred revenue	29,281	20,625
Liabilities held for sale	521	521
Total current liabilities	115,219	125,088
Deferred acquisition consideration	572	566
Accrued acquisition contingent consideration	399	'
Deferred tax liability	6,938	6,211
Deferred revenue	7,997	6,819
Other liabilities	7,431	7,776
Commitments and contingencies (Note 10)	'	'
Stockholders' equity	'	'
Undesignated preferred stock, $0.001 par value; 5,000,000 shares authorized; no shares issued	'	'
Common stock, $0.001 par value; 50,000,000 shares authorized, 30,249,264 and 29,920,807 shares issued and outstanding at March 31, 2014 and December 31, 2013, respectively	30	30
Additional paid-in capital	354,140	353,354
Accumulated other comprehensive loss	-1,987	-2,535
Accumulated deficit	-111,767	-81,354
Total EnerNOC, Inc. stockholders' equity	240,416	269,495
Noncontrolling interest	371	'
Total stockholders' equity	240,787	269,495
Total liabilities and stockholders' equity	$379,343	$415,955

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
Statement Of Financial Position [Abstract]	'	'
Accounts receivable	$462	$454
Accumulated depreciation	$80,238	$75,810
Undesignated preferred stock, par value	$0.00	$0.00
Undesignated preferred stock, shares authorized	5,000,000	5,000,000
Undesignated preferred stock, shares issued	0	0
Common stock, par value	$0.00	$0.00
Common stock, shares authorized	50,000,000	50,000,000
Common stock, shares issued	30,249,264	29,920,807
Common stock, shares outstanding	30,249,264	29,920,807

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Revenues:	'	'
Grid operator	$35,770	$15,063
Utility	10,309	11,769
Enterprise	6,429	6,018
Total revenues	52,508	32,850
Cost of revenues	36,139	22,197
Gross profit	16,369	10,653
Operating expenses:	'	'
Selling and marketing	18,499	15,653
General and administrative	23,677	20,121
Research and development	5,175	4,820
Total operating expenses	47,351	40,594
Loss from operations	-30,982	-29,941
Other income, net	574	67
Interest expense	-450	-313
Loss before income tax	-30,858	-30,187
Benefit from (provision for) income tax	425	-350
Net loss	-30,433	-30,537
Net loss attributable to noncontrolling interest	-20	'
Net loss attributable to EnerNOC, Inc.	($30,413)	($30,537)
Net loss per common share attributable to EnerNOC, Inc. (basic and diluted)	($1.09)	($1.12)
Weighted average number of common shares used in computing basic and diluted net loss per common share	27,923,861	27,366,612

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Loss (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Statement Of Income And Comprehensive Income [Abstract]	'	'
Net loss	($30,433)	($30,537)
Foreign currency translation adjustments	547	-24
Comprehensive loss	-29,886	-30,561
Comprehensive loss attributable to noncontrolling interest	-21	'
Comprehensive loss attributable to EnerNOC, Inc.	($29,865)	($30,561)

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Cash flows from operating activities	'	'
Net loss	($30,433)	($30,537)
Adjustments to reconcile net loss to net cash (used in) provided by operating activities:	'	'
Depreciation	5,482	4,936
Amortization of acquired intangible assets	1,883	1,794
Stock-based compensation expense	4,227	4,704
Impairment of equipment	95	142
Impairment of definite lived assets	163	'
Unrealized foreign exchange transaction gain	-404	-32
Deferred taxes	208	372
Non-cash interest expense	116	71
Accretion of fair value of deferred purchase price and accrued contingent purchase price consideration related to acquisitions	6	30
Other, net	-174	77
Changes in operating assets and liabilities, net of effects of acquisitions:	'	'
Accounts receivable, trade	-10,332	8,123
Unbilled revenue	39,198	26,578
Prepaid expenses and other current assets	-3,126	-2,153
Capitalized incremental direct customer contract costs	-6,254	-5,033
Other assets	328	82
Other noncurrent liabilities	-345	3,357
Deferred revenue	9,341	11,004
Accrued capacity payments	-18,338	-17,073
Accrued payroll and related expenses	-3,426	-1,086
Accounts payable, accrued performance adjustments and accrued expenses and other current liabilities	219	1,424
Net cash (used in) provided by operating activities	-11,566	6,780
Cash flows from investing activities	'	'
Purchases of property and equipment	-6,113	-8,938
Payments made for acquisitions, net of cash acquired	-24,085	'
Payments made for cost method investment	-1,000	'
Change in restricted cash and deposits	651	1,564
Payments made for acquisition of customer contract	-403	'
Net cash used in investing activities	-30,950	-7,374
Cash flows from financing activities	'	'
Proceeds from exercises of stock options	525	489
Payments related to employee restricted stock minimum tax withholdings	-3,644	'
Net cash (used in) provided by financing activities	-3,119	489
Effects of exchange rate changes on cash and cash equivalents	144	-109
Net change in cash and cash equivalents	-45,491	-214
Cash and cash equivalents at beginning of period	149,189	115,041
Cash and cash equivalents at end of period	103,698	114,827
Non-cash financing and investing activities	'	'
Issuance of common stock in satisfaction of bonuses	$145	$154

Description_of_Business_and_Ba

Description of Business and Basis of Presentation	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Description of Business and Basis of Presentation	'
	1	Description of Business and Basis of Presentation
	Description of Business
	EnerNOC, Inc. (the Company) is a leading provider of energy intelligence software (EIS) and related solutions. The Company unlocks the full value of energy management for commercial, institutional and industrial end-users of energy, which it refers to as its C&I or enterprise customers, and its electric power grid operator and utility customers by delivering a comprehensive suite of demand-side management solutions. These solutions allow customers to make better and more strategic decisions about how and when they use electricity.
	The Company believes that it is the world’s leading provider of demand response applications and solutions. Demand response is an alternative to traditional electric power generation and transmission infrastructure projects that enables electric power grid operators and utilities to reduce the likelihood of service disruptions, such as brownouts and blackouts, during periods of peak electricity demand, and otherwise manage the electric power grid during short-term imbalances of supply and demand or during periods when energy prices are high.
	The Company provides its utility and grid operator customers with two demand response solutions: EnerNOC Demand Resource and EnerNOC Demand Manager, which it collectively refers to as EnerNOC DemandSMART.
	When the Company enters into an EnerNOC Demand Resource contract, it matches obligation, in the form of megawatts (MWs) that it agrees to deliver to its utility and electric power grid operator customers, with supply, in the form of MW that it is able to curtail from the electric power grid through its arrangements with C&I customers. The Company deploys a sales team to contract with its C&I customers and installs its advanced metering equipment at these customers’ sites to connect them to its network, resulting in an increased ability to curtail demand from the electric power grid. When the Company is called upon by its utility or electric power grid operator customers to deliver its contracted capacity, the Company uses its Network Operations Center (NOC) to remotely manage and reduce electricity consumption across its growing network of C&I customer sites, making demand response capacity available to electric power grid operators and utilities on demand while helping C&I customers achieve energy savings, improved financial results and environmental benefits. The Company receives recurring payments from electric power grid operators and utilities for providing its EnerNOC Demand Resource solution and it shares these recurring payments with its C&I customers in exchange for those C&I customers reducing their power consumption when called upon by the Company to do so. The Company occasionally reallocates and realigns its capacity supply and obligation through open market bidding programs, supplemental demand response programs, auctions or other similar capacity arrangements and bilateral contracts to account for changes in supply and demand forecasts, as well as changes in programs and market rules in order to achieve more favorable pricing opportunities. The Company refers to the above activities as managing its portfolio of demand response capacity.
	EnerNOC’s Demand Manager solution consists of long-term contracts with a utility customer for a Software-as-a-Service solution that allows utilities to manage demand response capacity in utility-sponsored demand response programs. The Company’s EnerNOC Demand Manager solution provides its utility customers with real-time load monitoring, dispatching applications, customizable reports, measurement and verification, and other professional services.
	The Company builds on its position as a leading demand response provider by using its NOC and energy intelligence software (EIS) platform to deliver a portfolio of additional EIS and solutions to new and existing C&I, electric power grid operator and utility customers. These additional EIS and solutions include the Company’s EfficiencySMART and SupplySMART applications and solutions, and certain wireless energy management products. EfficiencySMART is the Company’s data-driven energy efficiency suite that includes energy efficiency planning, audits, assessments, commissioning and retro-commissioning authority services, and a cloud-based energy analytics application used for managing energy across a C&I customer’s portfolio of sites. The cloud-based energy analytics application also includes the ability to integrate with a C&I customer’s existing energy management system, provide utility bill management and tools for measurement, tracking, analysis, reporting and management of greenhouse gas emissions. SupplySMART is the Company’s energy price and risk management application and solution that provides its C&I customers located in restructured or deregulated markets throughout the United States with the ability to more effectively manage the energy supplier selection process, including energy supply product procurement and implementation, budget forecasting, and utility bill management. The Company’s wireless energy management products are designed to ensure that its C&I customers can connect their equipment remotely and access meter data securely, and include both cellular modems and an agricultural specific wireless technology solution.
	Reclassifications
	The Company has reclassified certain amounts in its unaudited condensed consolidated statements of operations for the three month period ended March 31, 2013, to conform to the 2014 presentation. The reclassifications made related to the presentation of the Company’s revenues from DemandSMART revenues and EfficiencySMART, SupplySMART and other revenues to revenues from grid operators, revenues from utilities, and revenues from enterprise customers and was done in order to provide the users of its consolidated financial statements with additional insight into how the Company and its management views and evaluates its revenues and related growth. This reclassification within the unaudited condensed consolidated statements of operations for the three month period ended March 31, 2013 had no impact on previously reported total consolidated revenues or consolidated results of operations.
	Basis of Consolidation
	The unaudited condensed consolidated financial statements of the Company include the accounts of its wholly-owned subsidiaries and have been prepared in conformity with accounting principles generally accepted in the United States (GAAP) and variable interest entities (VIE) in which the Company has variable interests are consolidated where the Company is the primary beneficiary and thus controls the VIE. Intercompany transactions and balances are eliminated upon consolidation.
	On February 13, 2014, the Company acquired all of the outstanding capital stock of Entelios AG (Entelios) and all of the outstanding capital stock of Activation Energy DSU Limited (Activation) in separate purchase business combinations. Accordingly, the results of operations of Entelios and Activation subsequent to that date are included in the Company’s unaudited condensed consolidated statements of operations.
	Subsequent Events Consideration
	The Company considers events or transactions that occur after the balance sheet date but prior to the issuance of the financial statements to provide additional evidence relative to certain estimates or to identify matters that require additional disclosure. Subsequent events have been evaluated as required.
	Liquidity Changes
	In May 2014, the Company was required to provide incremental financial assurance in connection with its capacity bid in a certain open market bidding program. The Company has provided this financial assurance utilizing a $22,000 letter of credit issued under its $70,000 senior secured revolving credit facility with the several lenders from time to time party thereto and Silicon Valley Bank (SVB), as administrative agent, swingline lender, issuing lender, lead arranger and book manager (SVB and together with the other lenders, and referred to herein as the lenders), which was subsequently amended in August 2013, December 2013 and January 2014 (2013 credit facility) and additionally, utilized $4,500 of its available unrestricted cash on hand. Based on the Company’s prior experience with this certain open market bidding program, the Company currently expects that it will recover a portion of this letter of credit and cash during the three month period ending June 30, 2014.
	Acquisition of Entech Utility Service Bureau, Inc. and Entech Utility Service Bureau Ltd.
	On April 17, 2014, the Company and two of its subsidiaries completed acquisitions of all of the outstanding stock of Entech Utility Service Bureau, Inc. (Entech US) and Entech Utility Service Bureau Ltd. (Entech UK) (collectively, Entech), privately-held companies headquartered in the United States and the United Kingdom, respectively, that are leading providers of global utility bill management (UBM) software, which is currently deployed in over 100 countries, including many of the world’s fastest growing economies, such as China, India, and Brazil. The Company concluded that these acquisitions represented business combinations and, therefore, will account for them as such. The Company believes that the combination of Entech’s software and technology, including real-time energy data, tariffs, and monthly utility bill data on the Company’s EIS platform will now enable real-time visibility and forecasting of energy costs and empower better energy management across global enterprises.
	The Company concluded that these acquisitions represented business combinations under ASC 805, but has concluded that they did not represent material business combinations and therefore, no pro forma financial information will be required.
	Entech US and Entech UK were not entities under common control and the Company separately negotiated the acquisitions, including purchase price, with each of the entity’s stockholders. The Company acquired Entech US for an aggregate purchase price of $6,796 all of which was cash paid at closing with $60 paid to the stockholders’ consultants to settle transactional fees due to these consultants. There are no earn-out or other additional contingent purchase price arrangements related to the acquisition of Entech US. The Company acquired Entech UK for an aggregate purchase price of $3,154 all of which was cash paid at closing with $18 paid to the stockholders’ consultants to settle the stockholders’ fees due to these consultants. There are no earn-out or other additional contingent purchase price arrangements related to the acquisition of Entech UK.
	Transaction costs related to this business combination have been expensed as incurred and are included in general and administrative expenses in the accompanying condensed consolidated statements of operations. The Company’s consolidated financial statements will reflect Entech’s results of operations from April 17, 2014 forward.
	The Company is in the process of gathering information to complete its preliminary valuation of certain assets and liabilities in order to complete a preliminary purchase price allocation.
	There were no other material recognizable subsequent events recorded or requiring disclosure in the March 31, 2014 unaudited condensed consolidated financial statements.
	Use of Estimates in Preparation of Financial Statements
	The accompanying unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to SEC rules and regulations. In the opinion of the Company’s management, the unaudited condensed consolidated financial statements and notes thereto have been prepared on the same basis as the audited consolidated financial statements contained in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2013, and include all adjustments (consisting of normal, recurring adjustments) necessary for the fair presentation of the Company’s financial position at March 31, 2014 and statements of operations, statements of comprehensive loss and statements of cash flows for the three month periods ended March 31, 2014 and 2013. Operating results for the three month period ended March 31, 2014 are not necessarily indicative of the results to be expected for any other interim period or the entire fiscal year ending December 31, 2014 (fiscal 2014).
	The preparation of these unaudited condensed consolidated financial statements requires the Company to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. On an on-going basis, the Company evaluates its estimates, including those related to revenue recognition, allowance for doubtful accounts, valuations and purchase price allocations related to business combinations, fair value of deferred acquisition consideration, fair value of accrued acquisition contingent consideration, expected future cash flows including growth rates, discount rates, terminal values and other assumptions and estimates used to evaluate the recoverability of long-lived assets and goodwill, estimated fair values of intangible assets and goodwill, amortization methods and periods, certain accrued expenses and other related charges, stock-based compensation, contingent liabilities, fair value of asset retirement obligations, tax reserves and recoverability of the Company’s net deferred tax assets and related valuation allowance.
	Although the Company regularly assesses these estimates, actual results could differ materially. Changes in estimates are recorded in the period in which they become known. The Company bases its estimates on historical experience and various other assumptions that it believes to be reasonable under the circumstances. Actual results may differ from management’s estimates if these results differ from historical experience or other assumptions prove not to be substantially accurate, even if such assumptions are reasonable when made.
	The Company is subject to a number of risks similar to those of other companies of similar and different sizes both inside and outside of its industry, including, but not limited to, rapid technological changes, competition from similar energy management applications, services and products provided by larger companies, customer concentration, government regulations, market or program rule changes, protection of proprietary rights and dependence on key individuals.
	Revenue Recognition
	The Company recognizes revenues in accordance with ASC 605, Revenue Recognition (ASC 605). In all of the Company’s arrangements, it does not recognize any revenues until it can determine that persuasive evidence of an arrangement exists, delivery has occurred, the fee is fixed or determinable, and it deems collection to be reasonably assured. In making these judgments, the Company evaluates the following criteria:
		•		Evidence of an arrangement. The Company considers a definitive agreement signed by the customer and the Company or an arrangement enforceable under the rules of an open market bidding program to be representative of persuasive evidence of an arrangement.
		•		Delivery has occurred. The Company considers delivery to have occurred when service has been delivered to the customer and no significant post-delivery obligations exist. In instances where customer acceptance is required, delivery is deemed to have occurred when customer acceptance has been achieved.
		•		Fees are fixed or determinable. The Company considers fees to be fixed or determinable unless the fees are subject to refund or adjustment or are not payable within normal payment terms. If the fee is subject to refund or adjustment and the Company cannot reliably estimate this amount, the Company recognizes revenues when the right to a refund or adjustment lapses. If the Company offers payment terms significantly in excess of its normal terms, it recognizes revenues as the amounts become due and payable or upon the receipt of cash.
		•		Collection is reasonably assured. The Company conducts a credit review at the inception of an arrangement to determine the creditworthiness of the customer. Collection is reasonably assured if, based upon evaluation, the Company expects that the customer will be able to pay amounts under the arrangement as payments become due. If the Company determines that collection is not reasonably assured, revenues are deferred and recognized upon the receipt of cash.
	The Company maintains a reserve for customer adjustments and allowances as a reduction in revenues. In determining the Company’s revenue reserve estimate, and in accordance with company policy, the Company relies on historical data and known performance adjustments. These factors, and unanticipated changes in the economic and industry environment, could cause the Company’s reserve estimates to differ from actual results. The Company records a provision for estimated customer adjustments and allowances in the same period as the related revenues are recorded. These estimates are based on the specific facts and circumstances of a particular program, analysis of credit memo data, historical customer adjustments, and other known factors. If the data the Company uses to calculate these estimates does not properly reflect reserve requirements, then a change in the allowances would be made in the period in which such a determination is made and revenues in that period could be affected. As of March 31, 2014 and December 31, 2013, the Company’s revenue reserves were $475. During the three month period ended March 31, 2013, the Company recorded an increase to the revenue reserve of $50. There was no change to the revenue reserve for the three month period ended March 31, 2014.
	Revenues from grid operators and revenues from utilities principally represent demand response revenues. During the three month period ended March 31, 2014, revenues from grid operators and revenues from utilities were comprised of $44,100 of demand response revenues and $1,979 of enterprise EIS and solutions revenues. During the three month periods ended March 31, 2013, revenues from grid operators and revenues from utilities were comprised of $24,482 of demand response revenues and $2,350 of enterprise EIS and solutions revenues.
	All revenues from enterprise customers for the three month periods ended March 31, 2014 and 2013 were derived from enterprise EIS and solutions.
	Demand Response Revenues
	The Company enters into contracts and open market bidding programs with utilities and electric power grid operators to provide demand response applications and services. Currently the Company has two principal service offerings under which it provides demand response applications and services: (1) full-service turnkey offering to utilities under which it manages all aspects of demand response program delivery to deliver a firm capacity resource (Demand Resource) and (2) utility partnership offering under which utilities can utilize software through a software as a service offering, integrated metering hardware, and professional services to support their tariff-based C&I demand response programs on a service-level agreement basis (Demand Manager).
	The Company has evaluated the factors within ASC 605 regarding gross versus net revenue reporting for its demand response revenues and its payments to C&I customers. Based on the evaluation of the factors within ASC 605, the Company has determined that all of the applicable indicators of gross revenue reporting were met. The applicable indicators of gross revenue reporting included, but were not limited to, the following:
		•		The Company is the primary obligor in its arrangements with electric power grid operators and utility customers because the Company provides its demand response services directly to electric power grid operators and utilities under long-term contracts or pursuant to open market programs and contracts separately with C&I customers to deliver such services. The Company manages all interactions with the electric power grid operators and utilities, while C&I customers do not interact with the electric power grid operators and utilities. In addition, the Company assumes the entire performance risk under its arrangements with electric power grid operators and utility customers, including the posting of financial assurance to assure timely delivery of committed capacity with no corresponding financial assurance received from its C&I customers. In the event of a shortfall in delivered committed capacity, the Company is responsible for all penalties assessed by the electric power grid operators and utilities without regard for any recourse the Company may have with its C&I customers.
		•		The Company has latitude in establishing pricing, as the pricing under its arrangements with electric power grid operators and utilities is negotiated through a contract proposal and contracting process or determined through a capacity auction. The Company then separately negotiates payment to C&I customers and has complete discretion in the contracting process with the C&I customers.
		•		The Company has complete discretion in determining which suppliers (C&I customers) will provide the demand response services, provided that the C&I customer is located in the same region as the applicable electric power grid operator or utility.
		•		The Company is involved in both the determination of service specifications and performs part of the services, including the installation of metering and other equipment for the monitoring, data gathering and measurement of performance, as well as, in certain circumstances, the remote control of C&I customer loads.
	As a result, the Company determined that it earns revenue (as a principal) from the delivery of demand response services to electric power grid operators and utility customers and records the amounts billed to the electric power grid operators and utility customers as gross demand response revenues and the amounts paid to C&I customers as cost of revenues.
	EnerNOC Demand Resource Solution
	The majority of the Company’s demand response revenues are generated from the EnerNOC Demand Resource solution. Demand response revenues consist of two elements: revenue earned from the Company’s ability to deliver committed capacity to its electric power grid operator and utility customers, which the Company refers to as capacity revenue; and revenue earned from additional payments made to the Company for the amount of energy usage actually curtailed from the grid during a demand response event, which the Company refers to as energy event revenue.
	The Company recognizes demand response revenue when it has provided verification to the electric power grid operator or utility of its ability to deliver the committed capacity which entitles the Company to payments under the contract or open market program. Committed capacity is generally verified through the results of an actual demand response event or a measurement and verification test. Once the capacity amount has been verified, the revenue is recognized and future revenue becomes fixed or determinable and is recognized monthly until the next demand response event or test. In subsequent verification events, if the Company’s verified capacity is below the previously verified amount, the electric power grid operator or utility customer will reduce future payments based on the adjusted verified capacity amounts. Ongoing demand response revenue recognized between demand response events or tests that are not subject to penalty or customer refund are recognized in revenue. If the revenue is subject to refund and the amount of refund cannot be reliably estimated, the revenue is deferred until the right of refund lapses.
	Commencing in fiscal 2012, all demand response capacity revenues related to the Company’s participation in the PJM open market program are being recognized at the end of the four-month delivery period of June through September, or during the three month period ended September 30th of each year. Because the period during which the Company is required to perform (June through September) is shorter than the period over which payments are received under the program (June through May), a portion of the revenues that have been earned are recorded and accrued as unbilled revenue. Substantially all revenues related to the PJM open market program for the year ended September 30, 2013 were recognized during the three month period ended September 30, 2013 and as a result of the billing period not coinciding with the revenue recognition period, the Company had $26,465, and $64,643 in unbilled revenues from PJM at March 31, 2014 and December 31, 2013, respectively.
	Energy event revenues are recognized when earned. Energy event revenue is deemed to be substantive and represents the culmination of a separate earnings process and is recognized when the energy event is initiated by the electric power grid operator or utility customer and the Company has responded under the terms of the contract or open market program. During the three month periods ended March 31, 2014 and 2013, the Company recognized $20,570 and $1,935, respectively, of energy event revenues.
	The Company has evaluated the forward capacity programs in which the Company participates and has determined that its contractual obligations in these programs do not currently meet the definition of derivative contracts under ASC 815, Derivatives and Hedging (ASC 815).
	EnerNOC Demand Manager Solution
	Under the Company’s EnerNOC Demand Manager solution, the Company generally receives an ongoing fee for overall management of the utility demand response program based on enrolled capacity or enrolled C&I customers, which is not subject to adjustment based on performance during a demand response dispatch. The Company recognizes revenues from these fees ratably over the applicable service delivery period commencing upon when the C&I customers have been enrolled and the contracted services have been delivered. In addition, under this offering, the Company may receive additional fees for program start-up, as well as, for C&I customer installations. The Company has determined that these fees do not have stand-alone value due to that such services do not have value without the ongoing services related to the overall management of the utility demand response program and therefore, the Company recognizes these fees over the estimated customer relationship period, which is generally the greater of 3 years or the contract period, commencing upon the enrollment of the C&I customers and delivery of the contracted services. Through March 31, 2014, revenues from EnerNOC Demand Manager have not been material to the Company’s consolidated results of operations.
	Enterprise EIS and Solutions
	With respect to the Company’s enterprise EIS and solutions revenues, which represent the Company’s EfficiencySMART, SupplySMART and other revenues, these generally represent ongoing service arrangements where the revenues are recognized ratably over the service period commencing upon delivery of the contracted service with the customer. Under certain of the Company’s arrangements, in particular certain EfficiencySMART arrangements with utilities, a portion of the fees received may be subject to adjustment or refund based on the validation of the energy savings delivered after the implementation is complete. As a result, the Company defers the portion of the fees that are subject to adjustment or refund until such time as the right of adjustment or refund lapses, which is generally upon completion and validation of the implementation. In addition, under certain other of the Company’s arrangements, the Company sells proprietary equipment to C&I customers that is utilized to provide the ongoing services that the Company delivers. Currently, this equipment has been determined to not have stand-alone value. As a result, the Company defers revenues associated with the equipment and the Company begins recognizing such revenue ratably over the expected C&I customer relationship period (generally 3 years), once the C&I customer is receiving the ongoing services from the Company. In addition, the Company capitalizes the associated direct and incremental costs, which primarily represent the equipment and third-party installation costs, and recognizes such costs over the expected C&I customer relationship period.
	The Company follows the provisions of ASC Update No. 2009-13, Multiple-Deliverable Revenue Arrangements (ASU 2009-13). The Company typically determines the selling price of its services based on vendor specific objective evidence (VSOE). Consistent with its methodology under previous accounting guidance, the Company determines VSOE based on its normal pricing and discounting practices for the specific service when sold on a stand-alone basis. In determining VSOE, the Company’s policy is to require a substantial majority of selling prices for a product or service to be within a reasonably narrow range. The Company also considers the class of customer, method of distribution, and the geographies into which its products and services are sold when determining VSOE. The Company typically has had VSOE for its products and services.
	In certain circumstances, the Company is not able to establish VSOE for all deliverables in a multiple element arrangement. This may be due to the infrequent occurrence of stand-alone sales for an element, a limited sales history for new services or pricing within a broader range than permissible by the Company’s policy to establish VSOE. In those circumstances, the Company proceeds to the alternative levels in the hierarchy of determining selling price. Third Party Evidence (TPE) of selling price is established by evaluating largely similar and interchangeable competitor products or services in stand-alone sales to similarly situated customers. The Company is typically not able to determine TPE and has not used this measure since the Company has been unable to reliably verify standalone prices of competitive solutions. Management’s best estimate of selling price (ESP) is established in those instances where neither VSOE nor TPE are available, by considering internal factors such as margin objectives, pricing practices and controls, customer segment pricing strategies and the product life cycle. Consideration is also given to market conditions such as competitor pricing information gathered from experience in customer negotiations, market research and information, recent technological trends, competitive landscape and geographies. Use of ESP is limited to a very small portion of the Company’s services, principally certain EfficiencySMART services.
	Foreign Currency Translation
	Foreign currency translation adjustments are recorded as a component of other comprehensive loss and included in accumulated other comprehensive loss within stockholders’ equity. Gains arising from transactions denominated in foreign currencies and the re-measurement of certain intercompany receivables and payables are included in other income, net in the unaudited condensed consolidated statements of operations and were $387 and $16 for the three month periods ended March 31, 2014 and 2013, respectively. Foreign currency exchange gains (losses) resulted primarily from foreign denominated intercompany receivables held by the Company from one of its Australian subsidiaries which mainly resulted from funding provided to complete the acquisition of Energy Response Holdings Pty Ltd (Energy Response) and fluctuations in the Australian dollar exchange rate and U.S. dollar denominated intercompany payables from one of the Company’s German subsidiaries to the Company which mainly resulted from funding provided to complete the acquisition of Entelios.
	During the three month period ended March 31, 2014, there were no material settlements of foreign denominated receivables or payables and therefore, there were no material realized gains (losses) during the three month period ended March 31, 2014. During the three month period ended March 31, 2013, $10,266 ($9,921 Australian) of the intercompany receivable from the Company’s Australian subsidiary was settled resulting in a realized loss of $280. As of March 31, 2014, the Company had an intercompany receivable from its Australian subsidiary that is denominated in Australian dollars and not deemed to be of a “long-term investment” nature totaling $10,951 at March 31, 2014 exchange rates ($11,844 Australian) and two of its German subsidiaries had an intercompany payable to the Company that is denominated in U.S. dollars and not deemed to be of a “long-term investment” nature totaling $18,059 at March 31, 2014. The increase in the Australian intercompany receivable from December 31, 2013 was primarily due to royalties and other support charges due to the U.S. parent for services and technology provided by the U.S. parent during the three month period ended March 31, 2014. Subsequent to March 31, 2014, the Company settled $5,627 ($5,977 Australian) of the intercompany receivable from the Company’s Australian subsidiary resulting in a realized loss of $387.
	In addition, a portion of the funding provided by the Company to one of its Australian subsidiaries to complete the acquisition of Energy Response was deemed to be of a “long-term investment nature” and therefore, the resulting translation adjustments are being recorded as a component of stockholders’ equity within accumulated other comprehensive loss. As of March 31, 2014, the intercompany funding that is denominated in Australian dollars and deemed to be of a “long-term investment” nature totaled $18,829 at March 31, 2014 exchange rates ($20,364 Australian) and during the three month period ended March 31, 2014, the Company recorded translation adjustments of $654 related to this intercompany funding within accumulated other comprehensive loss.
	Comprehensive (Loss) Income
Comprehensive (loss) income is defined as the change in equity of a business enterprise during a period resulting from transactions and other events and circumstances from non-owner sources. As of March 31, 2014 and December 31, 2013, accumulated other comprehensive loss was comprised solely of cumulative foreign currency translation adjustments. The Company presents its components of other comprehensive loss, net of related tax effects, which have not been material to date.
Software Development Costs
Software development costs, including license fees and external consulting costs, of $1,398 and $2,631 for the three month periods ended March 31, 2014 and 2013, respectively, have been capitalized in accordance with Accounting Standard Codification (ASC) 350-40, Internal-Use Software (ASC 350-40). The capitalized amount was included as software in property and equipment at March 31, 2014 and December 31, 2013. Amortization of capitalized internal use software costs was $1,530 and $1,308 for the three month periods ended March 31, 2014 and 2013, respectively. Accumulated amortization of capitalized internal use software costs was $22,971 and $21,441 as of March 31, 2014 and December 31, 2013, respectively.
Impairment of Property and Equipment
During the three month period ended March 31, 2014, as a result of the removal of certain demand response equipment from service, the Company concluded that there were no expected future direct cash flows associated with this demand response equipment and therefore, an impairment indicator existed. The Company determined that the residual value of this demand response equipment was nominal and as a result, recorded an impairment charge during the three month period ended March 31, 2014 of $95, to reduce the carrying value of such equipment to zero. During the three month period ended March 31, 2013, the Company recognized impairment charges of $142.
Industry Segment Information
The Company operates in the following major geographic areas as noted in the below chart. The “All other” designation includes Australia, Germany, Japan, Ireland, New Zealand and the United Kingdom. Revenues are based upon customer location and internationally totaled $9,180 and $8,087 for the three month periods ended March 31, 2014 and 2013, respectively.
Revenues by geography as a percentage of total revenues are as follows:
		Three Months Ended March 31,
		2014			2013
United States			83	%		75	%
Canada			11			15
All other			6			10
Total			100	%		100	%
As of March 31, 2014 and December 31, 2013, the long-lived assets related to the Company’s international subsidiaries were not material to the accompanying unaudited condensed consolidated financial statements taken as a whole.

Acquisitions

Acquisitions	3 Months Ended
	Mar. 31, 2014
Business Combinations [Abstract]	'
Acquisitions	'
	2. Acquisitions
	Entelios AG
	On February 13, 2014, the Company and one of its subsidiaries completed an acquisition of all of the outstanding stock of Entelios, a privately-held company headquartered in Germany that is a leading provider of demand response in Europe. This acquisition accelerates the Company’s entry into continental Europe with Entelios’ strong team and existing relationships with leading grid operators, utilities, retailers, and commercial, institutional, and industrial customers.
	The Company concluded that this acquisition represented a business combination under ASC 805 and has also concluded that it did not represent a material business combination and therefore, no pro forma financial information is required to be presented. Subsequent to the acquisition date, the Company’s results of operations include the results of operations of Entelios.
	The Company acquired Entelios for an aggregate purchase price, exclusive of potential contingent consideration, of $21,784 (16,000 Euros translated based on the exchange rate on the closing date of the acquisition), all of which was paid in cash. Of the consideration paid at closing, $6,884 (5,056 Euros) was paid as consideration to allow Entelios to settle its outstanding debt and related tax obligations. In addition to the amounts paid at closing, the Company may be obligated to pay additional contingent purchase price consideration related to an earn-out amount up to a maximum of $2,042 (1,500 Euros). The earn-out payment, if any, will be based on the achievement of certain minimum defined profit metrics for the years ending December 31, 2014 and 2015, respectively. Of the $2,042 (1,500 Euros) maximum earn-out payment, up to $817 (600 Euros) and $1,225 (900 Euros) relate to the achievement of the defined profit metrics for the years ending December 31, 2014 and 2015, respectively. If the minimum defined profit metrics are not achieved, there will be no partial payment, however, the amount of the earn-out payment can vary based on the amount that profits exceed the minimum defined profit metrics. The Company determined that the initial fair value of the earn-out payment as of the acquisition date was $95. This fair value was included as a component of the purchase price resulting in an aggregate purchase price of $21,879. Any changes in fair value will be recorded in the Company’s consolidated statements of operations. The Company recorded its estimate of the fair value of the contingent consideration based on the evaluation of the likelihood of the achievement of the contractual conditions that would result in the payment of the contingent consideration and weighted probability assumptions of these outcomes. This fair value measurement was determined utilizing a Monte Carlo simulation and was based on significant inputs not observable in the market and therefore, represented a Level 3 measurement as defined in ASC 820, Fair Value Measurements and Disclosures (ASC 820). As of March 31, 2014, there were no changes in the probability of the earn-out payment. This liability has been discounted to reflect the time value of money and therefore, as the milestone date approaches, the fair value of this liability will increase. This increase in fair value will be recorded to cost of revenues in the Company’s consolidated statements of operations. During the three months ended March 31, 2014, the change in fair value due to the accretion of the time value of money discount was not material. At March 31, 2014, the liability was recorded at $96 after adjusting for changes in exchange rates.
	Transaction costs related to this business combination have been expensed as incurred and are included in general and administrative expenses in the Company’s unaudited condensed consolidated statements of operations. Transaction costs incurred related to this transaction were approximately $511.
	The components and preliminary allocation of the purchase price consist of the following approximate amounts:
	Net tangible liabilities assumed as of February 13, 2014	$	(50	)
	Customer relationships		4,084
	Non-compete agreements		204
	Developed technology		1,770
	Trade name		218
	Deferred income tax asset		2,070
	Deferred income tax liability		(2,070	)
	Goodwill		15,653
	Total	$	21,879
	The deferred income tax liability recorded in connection with the preliminary allocation of purchase price relates to the book and tax basis difference related to the acquired definite-lived intangible assets for which the book amortization expense for such assets will not be deductible for tax purposes. Due to the fact that this deferred income tax liability represents a potential source of income as defined in ASC 740, Income Taxes (ASC 740), the Company determined that it was more likely than not that a portion of the deferred tax assets acquired in the business combination, which relate to tax net operating loss carry forwards, were realizable. As a result, the Company recorded a corresponding deferred income tax asset that would be utilized to offset this potential source of taxable income. As the deferred income tax liability and deferred income tax asset are both long-term and relate to the same jurisdiction, these amounts are netted in the Company’s unaudited condensed consolidated balance sheet.
	Net tangible liabilities assumed in the acquisition of Entelios primarily related to the following:
	Cash	$	1,564
	Accounts receivable		19
	Capitalized incremental direct customer contract costs		36
	Prepaid expenses and other current assets		148
	Property and equipment		377
	Other assets		72
	Accounts payable		(178	)
	Accrued payroll and related expenses		(970	)
	Accrued expenses and other liabilities		(1,098	)
	Deferred revenues		(20	)
	Total	$	(50	)
	Identifiable Intangible Assets
	As part of the preliminary purchase price allocation, the Company determined that Entelios’s separately identifiable intangible assets were its customer relationships, non-compete agreements, developed technology, and trade name. Developed technology represented internally developed software that supports the management of demand response dispatches, including fast-response dispatches, as well as, assists with the performance calculations and related settlements. As of the date of acquisition, the Company determined that there was no in-process research and development as the ongoing research and development efforts were nominal and related to routine, on-going maintenance efforts.
	The Company used the income approach to value the acquired customer relationships, non-compete agreements, and trade name definite-lived intangible assets. This approach calculates fair value by discounting the after-tax cash flows back to a present value. The baseline data for this analysis was the cash flow estimates used to price the transaction. Cash flows were forecasted for each intangible asset then discounted based on an appropriate discount rate. The discount rates applied, which ranged between 12% and 17%, were benchmarked with reference to the implied rate of return from the transaction model, as well as an estimate of a market-participant’s weighted average cost of capital based on the capital asset pricing model.
	The Company used the cost approach to value the acquired developed technology definite-lived intangible asset, as the Company determined that a market participant would be expected to have similar offerings and capabilities to build a replacement version of the software. Furthermore, it is expected that the software will be migrated over time or potentially replaced by the Company’s existing software platform and this expectation is consistent with that of a market participant. The cost approach calculates fair value by calculating the reproduction cost of an exact replica of the subject intangible asset. The Company calculated the replacement cost based on the estimated hours and costs incurred to develop.
	In estimating the useful life of the acquired assets, the Company considered ASC 350-30-35, General Intangibles Other Than Goodwill (ASC 350-30-35), which lists the pertinent factors to be considered when estimating the useful life of an intangible asset. These factors include a review of the expected use by the combined Company of the assets acquired, the expected useful life of another asset (or group of assets) related to the acquired assets, legal, regulatory or other contractual provisions that may limit the useful life of an acquired asset or may enable the extension of the useful life of an acquired asset without substantial cost, the effects of obsolescence, demand, competition and other economic factors, and the level of maintenance expenditures required to obtain the expected future cash flows from the asset. The Company amortizes its intangible assets over their estimated useful lives using a method that is based on estimated future cash flows, as the Company believes this will approximate the pattern in which the economic benefits of the assets will be utilized, or where the Company has concluded that the cash flows were not reliably determinable, on a straight-line basis.
	The factors contributing to the recognition of goodwill were based upon the Company’s determination that several strategic and synergistic benefits are expected to be realized from the combination. None of the goodwill is expected to be currently deductible for tax purposes.
	Activation Energy DSU Limited
	On February13, 2014, the Company and one of its subsidiaries completed an acquisition of all of the outstanding stock of Activation, a privately-held company headquartered in Ireland that is the leading provider of demand response software and services in Ireland. This acquisition gives the Company an immediate presence in the Irish capacity market and further strengthens the Company’s ability to deliver its full suite of EIS and solutions throughout Europe.
	The Company concluded that this acquisition represented a business combination under ASC 805 and has also concluded that it did not represent a material business combination and therefore, no pro forma financial information will be required to be presented. Subsequent to the acquisition date, the Company’s results of operations include the results of operations of Activation.
	The Company acquired Activation for an aggregate purchase price of $3,844 (2,823 Euros translated based on the exchange rate on the date of the acquisition close), plus an additional $732 (538 Euros) paid as working capital and other adjustments, all of which was paid in cash. In addition to the amounts paid at closing, the Company may be obligated to pay additional contingent purchase price consideration related to an earn-out amount up to a maximum of $1,398 (1,027 Euros). The earn-out payment, if any, will be based on the achievement of certain minimum defined MW enrollment, as well as, profit metrics for the years ending December 31, 2014 and 2015, respectively. Of the $1,398 (1,027 Euros) maximum earn-out payment, up to $350 (257 Euros) and $1,048 (770 Euros) relate to the achievement of the defined profit metrics for the years ending December 31, 2014 and 2015, respectively. If the minimum defined profit metrics are not achieved, there will be no partial payment, however, the amount of the earn-out payment can vary based on the amount that profits exceed the minimum defined profit metrics. The Company determined that the initial fair value of the earn-out payment as of the acquisition date was $300. This fair value was included as a component of the purchase price resulting in an aggregate purchase price of $4,876. Any changes in fair value will be recorded in the Company’s consolidated statements of operations. The Company recorded its estimate of the fair value of the contingent consideration based on the evaluation of the likelihood of the achievement of the contractual conditions that would result in the payment of the contingent consideration and weighted probability assumptions of these outcomes. This fair value measurement was determined utilizing a Monte Carlo simulation and was based on significant inputs not observable in the market and therefore, represented a Level 3 measurement as defined in ASC 820. As of March 31, 2014, there were no changes in the probability of the earn-out payment. This liability has been discounted to reflect the time value of money and therefore, as the milestone date approaches, the fair value of this liability will increase. This increase in fair value will be recorded to cost of revenues in the Company’s consolidated statements of operations. During the three month period ended March 31, 2014, the change in fair value due to the accretion of the time value of money discount was not material. At March 31, 2014, the liability was recorded at $303 after adjusting for changes in exchange rates.
	Transaction costs related to this business combination have been expensed as incurred and are included in general and administrative expenses in the Company’s unaudited condensed consolidated statements of operations. Transaction costs incurred related to this transaction were approximately $159.
	The components and preliminary allocation of the purchase price consist of the following approximate amounts:
	Net tangible assets acquired as of February 13, 2014	$	752
	Customer relationships		2,042
	Non-compete agreements		220
	Developed technology		545
	Trade name		82
	Deferred income tax liability		(361	)
	Goodwill		1,596
	Total	$	4,876
	The deferred income tax liability recorded in connection with the preliminary allocation of purchase price relates to the book and tax basis difference related to the acquired definite-lived intangible assets where the book amortization expense for such assets will not be deductible for tax purposes.
	Net tangible assets acquired in the acquisition of Activation primarily related to the following:
	Cash	$	711
	Accounts receivable		472
	Prepaid expenses and other current assets		27
	Property and equipment		92
	Accounts payable		(45	)
	Accrued expenses and other current liabilities		(55	)
	Accrued capacity payments		(450	)
	Total	$	752
	Identifiable Intangible Assets
	As part of the preliminary purchase price allocation, the Company determined that Activation’s separately identifiable intangible assets were its customer relationships, non-compete agreements, developed technology, and trade name. Developed technology represented internally developed software that facilitates customer transactions and provides analytical capabilities. As of the date of acquisition, the Company determined that there was no in-process research and development as the ongoing research and development efforts were nominal and related to routine, on-going maintenance efforts.
	The Company used the income approach to value the acquired customer relationships, non-compete agreements, and trade name definite-lived intangible assets. This approach calculates fair value by discounting the after-tax cash flows back to a present value. The baseline data for this analysis was the cash flow estimates used to price the transaction. Cash flows were forecasted for each intangible asset then discounted based on an appropriate discount rate. The discount rates applied, which ranged between 17% and 20%, were benchmarked with reference to the implied rate of return from the transaction model, as well as an estimate of a market-participant’s weighted average cost of capital based on the capital asset pricing model.
	The Company used the cost approach to value the acquired developed technology definite-lived intangible asset, as the Company determined that a market participant would be expected to have similar offerings and capabilities to build a replacement version of the software. Furthermore, it is expected that the software will be migrated over time or potentially replaced by the Company’s existing software platform and this expectation is consistent with that of a market participant. The cost approach calculates fair value by calculating the reproduction cost of an exact replica of the subject intangible asset. The Company calculated the replacement cost based on the estimated hours and costs incurred to develop.
In estimating the useful life of the acquired assets, the Company considered ASC 350-30-35, which lists the pertinent factors to be considered when estimating the useful life of an intangible asset. These factors include a review of the expected use by the combined Company of the assets acquired, the expected useful life of another asset (or group of assets) related to the acquired assets, legal, regulatory or other contractual provisions that may limit the useful life of an acquired asset or may enable the extension of the useful life of an acquired asset without substantial cost, the effects of obsolescence, demand, competition and other economic factors, and the level of maintenance expenditures required to obtain the expected future cash flows from the asset. The Company amortizes its intangible assets over their estimated useful lives using a method that is based on estimated future cash flows, as the Company believes this will approximate the pattern in which the economic benefits of the assets will be utilized, or where the Company has concluded that the cash flows were not reliably determinable, on a straight-line basis.
The factors contributing to the recognition of goodwill were based upon the Company’s determination that several strategic and synergistic benefits are expected to be realized from the combination. None of the goodwill is expected to be currently deductible for tax purposes.

Japan_Joint_Venture

Japan Joint Venture	3 Months Ended
	Mar. 31, 2014
Text Block [Abstract]	'
Japan Joint Venture	'
	3	Japan Joint Venture
	On December 10, 2013, the Company entered into a joint venture with Marubeni Corporation to provide demand response applications and solutions in Japan. The new company was formed in January 2014 and named EnerNOC Japan K.K., which will have an exclusive license to market DemandSMART throughout Japan. The Company and Marubeni Corporation contributed initial capital funding in the form of common stock totaling $580 and $392, respectively. The Company is the majority-owner and owns 60% of EnerNOC Japan K.K. The Company has evaluated its accounting for its ownership interest in EnerNOC Japan K.K. in accordance with ASC 810, Consolidation (ASC 810) and has concluded that it is required to consolidate this entity. As a result, the Company will consolidate the results of this entity, which commenced during the three month period ended March 31, 2014, in accordance with ASC 810. During the three month period ended March 31, 2014, the revenues and pre-tax loss derived from EnerNOC Japan K.K. were not material to the Company’s consolidated results of operations.

Equity_Investment_and_License

Equity Investment and License	3 Months Ended
	Mar. 31, 2014
Text Block [Abstract]	'
Equity Investment and License	'
	4	Equity Investment and License
	In February 2014, the Company purchased Series A Preferred Stock (preferred stock) in a privately-held company that licenses its developed software technology for managing electricity tariff rates and related subject matters to allow third parties a central repository to obtain this information and to convert energy usage data into financial costs and savings for a purchase price of $1,000. Based on other recent financings completed by this privately-held company, the Company concluded that the $1,000 represented the fair value of its investment. The Company notes that its preferred stock investment has a substantive liquidation preference and therefore, does not represent in-substance common stock. As a result, the Company concluded that such investment should be accounted for as a cost method investment under ASC 325-20, Cost Method Investments (ASC 325-20). Under ASC 325-20, cost method investments are recorded as long-term assets initially at historical cost and are assessed for other-than-temporary impairments under the provisions of ASC 320 and are adjusted accordingly. Based on the Company’s assessment as of March 31, 2014, the Company did not identify any other-than-temporary impairment indicators. Since the inputs utilized for the Company’s periodic impairment assessment are not based on observable market data, this cost method investment is classified within Level 3 of the fair value hierarchy. To determine the fair value of this investment, the Company utilized available financial information related to the entity, including information based on recent or pending third-party equity investments in this entity. A cost method investment’s fair value is not estimated as there are no identified events or changes in circumstances that may have a significant adverse effect on the fair value of the investment and to do so would be impractical.
	In addition to the above equity investment, the Company also entered into a license agreement to obtain a perpetual license to the developed software technology and other rights for $2,000. In accordance with the terms of the license agreement, the Company has a perpetual license to the developed software technology, including any future updates and enhancements, as well as, in certain instances has the right to acquire ownership of the technology. The Company concluded that the $2,000 represents the fair value of the license obtained and has capitalized this amount as a component of property and equipment in its unaudited condensed consolidated balance sheets. The Company is depreciating this asset over its estimated useful life of three years with depreciation expense being recorded as a component of cost of revenues. For the three month period ended March 31, 2014, the Company recorded depreciation expense of $111. The Company also has the ability to earn a royalty of certain future revenues that may be generated from the licensing of the developed software technology up to a maximum of $2,000. The Company concluded that these potential royalties represent a potential contingent income stream and will record such royalties, if any, as a component of other income in its consolidated statements of operations upon cash receipt. Through March 31, 2014, the Company had not received any such royalty payments.

Intangible_Assets_and_Goodwill

Intangible Assets and Goodwill	3 Months Ended
	Mar. 31, 2014
Goodwill And Intangible Assets Disclosure [Abstract]	'
Intangible Assets and Goodwill	'
	5. Intangible Assets and Goodwill
	Definite-Lived Intangible Assets
	The following table provides the gross carrying amount and related accumulated amortization of intangible assets as of March 31, 2014 and December 31, 2013:
				As of March 31, 2014					As of December 31, 2013
		Weighted Average		Gross		Accumulated			Gross		Accumulated
		Amortization		Carrying		Amortization			Carrying		Amortization
		Period (in years)		Amount					Amount
	Customer relationships		3.63	$	35,573	$	(16,091	)	$	29,663	$	(15,416	)
	Customer contracts		2.81		5,152		(3,074	)		4,887		(2,900	)
	Employment agreements and non-compete agreements		1.09		1,988		(1,422	)		1,676		(1,475	)
	Software				120		(120	)		120		(120	)
	Developed technology		1.24		4,623		(2,048	)		2,277		(1,758	)
	Trade name		1.03		878		(503	)		575		(455	)
	Patents		5.9		180		(72	)		180		(68	)
	Total other definite-lived intangible assets				12,941		(7,239	)		9,715		(6,776	)
	Total			$	48,514	$	(23,330	)	$	39,378	$	(22,192	)
	The increase in the gross carrying amount of definite-lived intangible assets from December 31, 2013 to March 31, 2014 was primarily due to definite-lived intangible assets acquired in connection with the Company’s acquisitions of Entelios and Activation. Refer to Note 2 for further discussion. In addition, the increase to the gross carrying amount of the definite-lived customer contract intangible assets was due to the acquisition of certain C&I contractual arrangements acquired during the three month period ended March 31, 2014 for a purchase price of $403 to help fulfill its contractual obligations and overall performance requirements in connection with one of its bilateral demand response arrangements with an utility. The acquisition of this intangible asset did not meet the definition of a business, as defined in ASC 805, due to the fact that neither processes nor the additional inputs required to combine with this intangible asset in order to be capable of producing outputs were acquired. Therefore, the acquisition of this intangible asset was accounted for as an asset acquisition based on the principles described in ASC 850-50, and as there was only a single asset acquired, the entire purchase price was allocated to this single intangible asset. Based on the evaluation of the expected direct cash flows to be received from this acquired intangible asset, the Company determined that the cost exceeded the fair value of the acquired intangible asset and as a result, recorded an impairment charge of $163. The remaining value of this intangible asset of $240 is being amortized to cost of revenues over the contractual term of the acquired arrangements which expires on December 31, 2014.
	Amortization expense related to intangible assets amounted to $1,883 and $1,794 for the three month periods ended March 31, 2014 and 2013, respectively. Amortization expense for developed technology, which was $351 and $139 for the three months ended March 31, 2014 and 2013, respectively, is included in cost of revenues in the accompanying unaudited condensed consolidated statements of operations. Amortization expense for all other intangible assets is included as a component of operating expenses in the accompanying unaudited condensed consolidated statements of operations. The intangible asset lives range from one to ten years and the weighted average remaining life was 3.2 years at March 31, 2014. Estimated amortization is expected to be $6,879, $6,793, $5,023, $3,405, $996 and $2,088 for the nine month period ending December 31, 2014, and years ending 2015, 2016, 2017, 2018 and thereafter, respectively.
	Goodwill
	In accordance with ASC 350, Intangibles - Goodwill and Other (ASC 350), the Company tests goodwill at the reporting unit level for impairment on an annual basis and between annual tests if events and circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying value. The Company’s annual impairment test date is November 30 (Impairment Test Date). During the three months ended March 31, 2014, there were no potential impairment indicators identified that required an interim impairment test of goodwill. The Company’s market capitalization as of March 31, 2014 exceeded the book value of its consolidated net assets by more than 100%. In addition, as of November 30, 2013 (last Impairment Test Date), the fair value of both the Company’s consolidated Australian reporting unit and the Company’s all other operations reporting unit exceeded each of their respective carrying values by more than 50%.
	The following table shows the change of the carrying amount of goodwill from December 31, 2013 to March 31, 2014:
	Balance at December 31, 2013	$	77,104
	Acquisitions (Note 2)		17,249
	Foreign currency translation		616
	Balance at March 31, 2014	$	94,969

Net_Loss_Per_Share

Net Loss Per Share	3 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
Net Loss Per Share	'
	6. Net Loss Per Share
	A reconciliation of basic and diluted share amounts for the three month periods ended March 31, 2014 and 2013 are as follows (in thousands):
		Three Months Ended March 31,
		2014		2013
	Basic weighted average common shares outstanding		27,924		27,367
	Weighted average common stock equivalents		—		—
	Diluted weighted average common shares outstanding		27,924		27,367
	Weighted average anti-dilutive shares related to:
	Stock options		895		1,250
	Nonvested restricted shares		2,138		2,189
	Restricted stock units		18		81
	Escrow shares		—		64
	In reporting periods in which the Company reports a net loss, anti-dilutive shares consist of the impact of those number of shares that would have been dilutive had the Company had net income plus the number of common stock equivalents that would have been anti-dilutive had the Company had net income. In those reporting periods in which the Company reports net income, anti-dilutive shares consist of those common stock equivalents that have either an exercise price above the average stock price for the period or the common stock equivalents’ related average unrecognized stock compensation expense is sufficient to “buy back” the entire amount of shares.
	The Company excludes the shares issued in connection with restricted stock awards from the calculation of basic weighted average common shares outstanding until such time as those shares vest. In addition, with respect to restricted stock awards that vest based on achievement of performance conditions, because performance conditions are considered contingencies under ASC 260, Earnings per Share (ASC 260) the criteria for contingent shares must first be applied before determining the dilutive effect of these types of share-based payments. Prior to the end of the contingency period (i.e., before the performance conditions have been satisfied), the number of contingently issuable common shares to be included in diluted weighted average common shares outstanding should be based on the number of common shares, if any, that would be issuable under the terms of the arrangement if the end of the reporting period were the end of the contingency period (e.g., the number of shares that would be issuable based on current performance criteria) assuming the result would be dilutive.
	In connection with certain of the Company’s business combinations, the Company issued common shares that were held in escrow upon closing of the applicable business combination. The Company excludes shares held in escrow from the calculation of basic weighted average common shares outstanding where the release of such shares is contingent upon an event and not solely subject to the passage of time. As of March 31, 2014, the Company had no shares of common stock held in escrow.
	The 254,654 shares related to a component of the deferred purchase price consideration from the acquisition of M2M Communications Corporation (M2M), which are not subject to adjustment as the issuance of such shares is not subject to any contingency, are included in both the basic and diluted weighted average common shares outstanding amounts.

Disclosure_of_Fair_Value_of_Fi

Disclosure of Fair Value of Financial Instruments	3 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
Disclosure of Fair Value of Financial Instruments	'
	7. Disclosure of Fair Value of Financial Instruments
	The Company’s financial instruments mainly consist of cash and cash equivalents, restricted cash, cost-method investment, accounts receivable and accounts payable. The carrying amounts of the Company’s cash equivalents, restricted cash, accounts receivable and accounts payable approximate their fair value due to the short-term nature of these instruments. Refer to Note 4 for discussion of cost-method investment.

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	8. Fair Value Measurements
	The table below presents the balances of assets and liabilities measured at fair value on a recurring basis at March 31, 2014:
			Fair Value Measurement at March 31, 2014 Using
			Totals		Quoted Prices in		Significant		Unobservable
					Active Markets		Other		Inputs (Level 3)
					for Identical		Observable
					Assets (Level 1)		Inputs (Level 2)
	Assets:
	Money market funds (1)		$	88,611	$	88,611	$	—	$	—
	Liabilities:
	Accrued contingent purchase price consideration (2)		$	399	$	—	$	—	$	399
	Deferred acquisition consideration (2)		$	572	$	—	$	—	$	572
	-1	Total of $88,431 included in cash and cash equivalents and $180 included in restricted cash in the accompanying unaudited condensed consolidated balance sheets and represents the only asset that the Company measures and records at fair value on a recurring basis. These money market funds represent excess operating cash that is invested daily into an overnight investment account. The decrease from December 31, 2013 was primarily due to cash used in operations and cash utilized for the Company’s acquisitions of Entelios and Activation during the three month period ended March 31, 2014.
	-2	Accrued contingent purchase price consideration, which resulted from the Company’s acquisitions of Energy Response, Entelios and Activation, and deferred acquisition consideration, which is a result of the Company’s acquisition of M2M, represent the only assets or liabilities that the Company measures and records at fair value on a recurring basis using significant unobservable inputs (Level 3). The aggregate increase in fair value of liabilities for the three month period ended March 31, 2014 of $10 was due to the increase in the liabilities as a result of the amortization of the applicable discounts related to the time value of money of $6 and changes in exchange rates. There were no changes to the probability or timing of payment during the three month period ended March 31, 2014.
	With respect to assets measured at fair value on a non-recurring basis, these represent impaired long-lived assets (refer to Note 1 for discussion of the determination of fair value of these assets), impaired definite-lived intangible assets (refer to Note 2 for discussion of the determination of fair value of these assets) and cost method investments (refer to Note 4 for discussion of the determination of fair value of these assets).
	The table below presents the balances of assets and liabilities measured at fair value on a recurring basis at December 31, 2013:
			Fair Value Measurement at December 31, 2013 Using
			Totals		Quoted Prices in		Significant		Unobservable
					Active Markets		Other		Inputs (Level 3)
					for Identical		Observable
					Assets (Level 1)		Inputs (Level 2)
	Assets:
	Money market funds (1)		$	146,626	$	146,626	$	—	$	—
	Liabilities:
	Deferred acquisition consideration (2)		$	566	$	—	$	—	$	566
	-1	Total of $145,076 included in cash and cash equivalents and $1,550 included in restricted cash in the accompanying unaudited condensed consolidated balance sheets and represents the only assets that the Company measures and records at fair value on a recurring basis. These money market funds represent excess operating cash that is invested daily into an overnight investment account.
	-2	Deferred acquisition consideration which is a liability and was the result of the Company’s acquisition of M2M represents the only liability that the Company measures and records at fair value on a recurring basis using significant unobservable inputs (Level 3). The aggregate increase in fair value of this liability for the year ended December 31, 2013 of $33 was due to the increase in the liability as a result of the amortization of the discount related to the time value of money. There were no changes with respect to the timing of payment subsequent to December 31, 2013.

Financing_Arrangements

Financing Arrangements	3 Months Ended
	Mar. 31, 2014
Debt Disclosure [Abstract]	'
Financing Arrangements	'
	9. Financing Arrangements
	In March 2012, the Company and one of its subsidiaries entered into a $50,000 credit facility with Silicon Valley Bank (SVB), which was subsequently amended in June 2012 and April 2013 (the 2012 credit facility). On April 12, 2013, the Company, one its subsidiaries and SVB entered into an amendment to the 2012 credit facility to extend the termination date from April 15, 2013 to April 30, 2013. On April 18, 2013, the Company, one of its subsidiaries and SVB terminated the 2012 credit facility.
	On April 18, 2013, the Company entered into the 2013 credit facility. The 2013 credit facility replaced the 2012 credit facility
	The 2013 credit facility provides for a two year revolving line of credit in the aggregate amount of $70,000, subject to increase from time to time up to an aggregate amount of $100,000 with an additional commitment from the lenders or new commitments from new financial institutions.
	Subject to continued compliance with the covenants contained in the 2013 credit facility, the full amount of the 2013 credit facility may be available for issuances of letters of credit and up to $5,000 may be available for swing line loans. The interest on revolving loans under the 2013 credit facility will accrue, at the Company’s election, at either (i) the Eurodollar Rate with respect to the relevant interest period plus 2.00% per annum or (ii) the ABR (defined as the highest of (x) the “prime rate” as quoted in the Wall Street Journal, and (y) the Federal Funds Effective Rate plus 0.50%) plus 1.00% per annum. The letter of credit fee charged under the 2013 credit facility is 2.00% per annum. The Company expenses the interest and letter of credit fees under the 2013 credit facility, as applicable, in the period incurred. The obligations under the 2013 credit facility are secured by all domestic assets of the Company and several of its domestic subsidiaries. The 2013 credit facility terminates on April 18, 2015 and all amounts outstanding thereunder will become due and payable in full and the Company would be required to collateralize with cash any outstanding letters of credit under the 2013 credit facility up to 105% of the amounts outstanding. In connection with the 2013 credit facility and related amendments, the Company incurred financing costs of approximately $859 which have been deferred and are being amortized to interest expense over the term of the 2013 credit facility, or through April 18, 2015.
	The 2013 credit facility contains customary terms and conditions for credit facilities of this type, including, among other things, restrictions on the ability of the Company and its subsidiaries to incur additional indebtedness, create liens, enter into transactions with affiliates, transfer assets, make certain acquisitions, pay dividends or make distributions on, or repurchase, the Company’s common stock, consolidate or merge with other entities, or undergo a change in control. In addition and as described above, the Company is required to meet certain monthly and quarterly financial covenants customary for this type of credit facility, including maintaining a minimum specified level of free cash flow, a minimum specified unrestricted cash balance and a minimum specified ratio of current assets to current liabilities.
	The 2013 credit facility contains customary events of default, including payment defaults, breaches of representations, breaches of affirmative or negative covenants, cross defaults to other material indebtedness, bankruptcy and failure to discharge certain judgments. If a default occurs and is not cured within any applicable cure period or is not waived, SVB may accelerate the Company’s obligations under the 2013 credit facility. If the Company is determined to be in default then any amounts outstanding under the 2013 credit facility would become immediately due and payable and the Company would be required to collateralize with cash any outstanding letters of credit up to 105% of the amounts outstanding.
	As of March 31, 2014, the Company was in compliance with all of its covenants under the 2013 credit facility. The Company believes that it is reasonably assured that it will comply with the covenants of the 2013 credit facility for the foreseeable future.
	As of March 31, 2014, the Company had no borrowings, but had outstanding letters of credit totaling $46,213, under the 2013 credit facility. The decrease in the amount of outstanding letters of credit from December 31, 2013 to March 31, 2014 is primarily the result of fewer outstanding letters of credit as collateral for demand response arrangements and obligations. As of March 31, 2014, the Company had $23,787 available under the 2013 credit facility for future borrowings or issuances of additional letters of credit.
	In May 2014, the Company was required to provide incremental financial assurance in connection with its capacity bid in a certain open market bidding program. The Company has provided this financial assurance utilizing a $22,000 letter of credit issued under the 2013 credit facility and additionally, utilized $4,500 of its available unrestricted cash on hand. Based on the Company’s prior experience with this certain open market bidding program, the Company currently expects that it will recover a portion of this letter of credit and cash during the three month period ending June 30, 2014.

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	10. Commitments and Contingencies
	In July 2012, the Company entered into a lease for its new principal executive offices at One Marina Park Drive, Floors 4-6, Boston, Massachusetts. The lease term is through July 2020 and the lease contains both a rent holiday period and escalating rental payments over the lease term. The lease requires payments for additional expenses such as taxes, maintenance, and utilities and contains a fair value renewal option. The Company began occupying the space during the second quarter of fiscal 2013. In accordance with the terms of the lease, the landlord provided certain lease incentives with respect to the leasehold improvements. In accordance with ASC 840, Leases (ASC 840), the Company recorded the incentives as deferred rent and will reflect these amounts as reductions of lease expense over the lease term. Although lease payments under this arrangement did not commence until August 2013, as the Company had the right to use and controlled physical access to the space, it determined that the lease term commenced in July 2012 and, as a result, began recording rent expense on this lease arrangement at that time on a straight-line basis. The lease also contains certain provisions requiring the Company to restore certain aspects of the leased space to its initial condition. The Company has determined that these provisions represent asset retirement obligations and recorded the estimated fair value of these obligations as the related leasehold improvements were incurred. The Company will accrete the liability to fair value over the life of the lease as a component of operating expenses. As of March 31, 2014, the Company recorded an asset retirement obligation of $410.
	In March 2014, the Company entered into a lease for its California operations. The lease term runs through September 2019 and the lease contains both a rent holiday period and escalating rental payments over the lease term. The lease requires payments for additional expenses such as taxes, maintenance, and utilities and contains a fair value renewal option. The lease commences on April 1, 2014.
	As of March 31, 2014, future minimum lease payments for operating leases with non-cancelable terms of more than one year were as follows:
		Operating Leases
	Remainder of 2014	$	4,205
	2015		5,622
	2016		5,445
	2017		5,437
	2018		5,569
	Thereafter		7,517
	Total minimum lease payments (not reduced by sublease rentals of $191)	$	33,795
	As of March 31, 2014 and December 31, 2013, the Company had a deferred rent liability representing rent expense recorded on a straight-line basis in excess of contractual lease payments of $6,343 and $6,729, respectively, which is included in other liabilities in the accompanying unaudited condensed consolidated balance sheets.
	As of March 31, 2014, the Company was contingently liable under outstanding letters of credit for $46,213. As of March 31, 2014 and December 31, 2013, the Company had restricted cash balances of $1,197 and $1,834, respectively. The restricted cash balances as of March 31, 2014 and December 31, 2013 primarily relate to cash utilized to collateralize certain demand response programs.
	The Company is subject to performance guarantee requirements under certain utility and electric power grid operator customer contracts and open market bidding program participation rules, which may be secured by cash or letters of credit. Performance guarantees as of March 31, 2014 were $46,512 and included deposits held by certain customers of $119 and certain restricted cash utilized to collateralize certain demand response programs of $180 at March 31, 2014. These amounts primarily represent up-front payments required by utility and electric power grid operator customers as a condition of participation in certain demand response programs and to ensure that the Company will deliver its committed capacity amounts in those programs. If the Company fails to meet its minimum committed capacity requirements, a portion or all of the deposits may be forfeited. The Company assessed the probability of default under these customer contracts and open market bidding programs and has determined the likelihood of default and loss of deposits to be remote. In addition, under certain utility and electric power grid operator customer contracts, if the Company does not achieve the required performance guarantee requirements, the customer can terminate the arrangement and the Company would potentially be subject to termination penalties. Under these arrangements, the Company defers all fees received up to the amount of the potential termination penalty until the Company has concluded that it can reliably determine that the potential termination penalty will not be incurred or the termination penalty lapses. As of March 31, 2014, the Company had $2,593 in deferred fees for these arrangements which were included in deferred revenues as of March 31, 2014. As of March 31, 2014, the maximum termination penalty to which the Company could be subject under these arrangements, which the Company has deemed not probable of being incurred, was approximately $7,967.
	As of March 31, 2014 and December 31, 2013, the Company accrued in the accompanying unaudited condensed consolidated balance sheets $539 and $1,720, respectively, of performance adjustments related to fees received for its participation in a certain demand response program. The decrease in the accrual from December 31, 2013 was a result of the Company repaying $1,370 to the electric power grid operator during the three month period ended March 31, 2014 since the Company did not deliver all of its MW obligations under this demand response program offset by an increase in additional performance adjustments.
	The Company believes that it is probable that these performance adjustments will need to be re-paid to the electric power grid operator and since the electric power grid operator has the right to require repayment at any point at its discretion, the amounts have been classified as a current liability.
	In 2012, the Company decided to net settle a portion of its future contractual delivery obligations in a certain open market bidding program. As of March 31, 2014, the Company entered into transactions to net settle a significant portion of its future delivery obligations and these transactions have been approved by the customer. As a result, as long as the other criteria for revenue recognition are met, the Company will recognize these fees from the net settlement transactions as revenues as they become due and payable with such fees being recorded as a component of DemandSMART revenues. During the three month period ended March 31, 2014, the Company recognized revenues of $3,771 related to these net settlement transactions.
	The Company typically grants customers a limited warranty that guarantees that its hardware will substantially conform to current specifications for one year from the delivery date. Based on the Company’s operating history, the liability associated with product warranties has been determined to be nominal.
	In connection with the Company’s agreement for its employee health insurance plan, the Company could be subject to an additional payment if the agreement is terminated. The Company has not elected to terminate this agreement nor does the Company believe that termination is probable for the foreseeable future. As a result, the Company has determined that it is not probable that a loss is likely to occur and no amounts have been accrued related to this potential payment upon termination. As of March 31, 2014, the payment due upon termination would be $1,026.

Stockholders_Equity

Stockholders' Equity	3 Months Ended
	Mar. 31, 2014
Text Block [Abstract]	'
Stockholders' Equity	'
	11. Stockholders’ Equity
	Share Repurchase Program
	On August 6, 2013, the Company’s Board of Directors authorized the repurchase of up to $30,000 of the Company’s common stock during the period from August 6, 2013 through August 6, 2014, unless earlier terminated by the Board of Directors. During the three month period ended March 31, 2014, there were no repurchases of the Company’s common stock pursuant to its publicly announced share repurchase program, and as of March 31, 2014, $20,545 was available for repurchase under the Plan. The Company repurchased 169,176 shares of its common stock during the three month period ended March 31, 2014 to cover employee minimum statutory income tax withholding obligations in connection with the vesting of restricted stock under its equity incentive plans, which the Company pays in cash to the appropriate taxing authorities on behalf of its employees. All shares were retired upon repurchase.
	Stock-Based Compensation
	During the three month periods ended March 31, 2014 and 2013, the Company issued 6,632 shares and 8,920 shares of its common stock, respectively, to certain executives to satisfy a portion of the Company’s bonus obligation to these individuals. Historically, the Company’s Amended and Restated 2007 Employee, Director and Consultant Stock Plan (the 2007 Plan) contained an “evergreen” provision, which provided for an annual increase to the shares issuable under the 2007 Plan by an amount equal to the lesser of 520,000 shares or an amount determined by the Company’s board of directors. The last annual increase to the 2007 Plan of 520,000 shares occurred during the three month period ended March 31, 2013. On May 28, 2013, the Company’s shareholders approved an amendment and restatement of the 2007 Plan to, among other things, increase the number of shares of common stock authorized for issuance under the 2007 Plan by 2,500,000 shares and eliminate the evergreen provision. As of March 31, 2014, 2,329,080 shares were available for future grant under the 2007 Plan, as amended and restated.
	The fair value of stock options granted was estimated at the date of grant using the following weighted average assumptions:
			Three Months Ended March 31,
			2014			2013
	Risk-free interest rate			2.67	%		1.9	%
	Vesting term, in years			2.22			2.22
	Expected annual volatility			72	%		75	%
	Expected dividend yield			—	%		—	%
	Exit rate pre-vesting			7.8	%		7.7	%
	Exit rate post-vesting			14.06	%		14.06	%
	The risk-free interest rate is the rate available as of the option date on zero-coupon United States government issues with a term equal to the expected life of the option. Volatility measures the amount that a stock price has fluctuated or is expected to fluctuate during a period. The Company calculates volatility using a component of implied volatility and historical volatility to determine the value of share-based payments. The Company has not paid dividends on its common stock in the past and does not plan to pay any dividends in the foreseeable future. In addition, the terms of the 2013 credit facility preclude the Company from paying dividends. During the three month period ended March 31, 2014, the Company updated its estimated pre-vesting and post-vesting exit rates applied to options, restricted stock and restricted stock units based on an evaluation of demographics of its employee groups and historical forfeitures for these groups in order to determine its option valuations as well as its stock-based compensation expense noting no change in the exit-rate post vesting and no material changes in the expected annual volatility or exit rate pre-vesting. The changes in estimates of the volatility and exit rate pre-vesting did not have a material impact on the Company’s stock-based compensation expense recorded in the accompanying unaudited condensed consolidated statements of operations for the three month period ended March 31, 2014.
	The components of stock-based compensation expense are disclosed below:
			Three Months Ended March 31,
			2014			2013
	Stock options		$	186		$	399
	Restricted stock and restricted stock units			4,041	(1)		4,305
	Total		$	4,227		$	4,704
	-1	Due to the fact that the Company’s chief executive officer is required to receive his 2014 performance based bonus, if achieved, in shares of common stock of the Company determined based on the cash value of such bonus divided by the fair market value of the Company’s common stock on the date that the Company’s Compensation Committee validates the achievement of the performance bonus metrics, in accordance with the Company’s policy, the Company is recording this amount as stock-based compensation expense ratably over the applicable performance and service period in accordance with ASC 718, Stock Compensation (ASC 718). During the three month period ended March 31, 2014, the Company recorded $125 of stock-based compensation expense.
	Stock-based compensation is recorded in the accompanying unaudited condensed consolidated statements of operations, as follows:
			Three Months Ended March 31,
			2014			2013
	Selling and marketing expenses		$	1,193		$	1,390
	General and administrative expenses			2,696			2,952
	Research and development expenses			338			362
	Total		$	4,227		$	4,704
	The Company recognized no material income tax benefit from share-based compensation arrangements during the three month periods ended March 31, 2014 and 2013, respectively. No material compensation cost was capitalized during the three month periods ended March 31, 2014 and 2013.
	The following is a summary of the Company’s stock option activity during the three month period ended March 31, 2014:
			Three Months Ended March 31, 2014
			Number of			Exercise		Weighted-		Aggregate
			Shares			Price Per		Average		Intrinsic
			Underlying			Share		Exercise Price		Value
			Options					Per Share
	Outstanding at December 31, 2013			960,742		$0.17 - $48.06		$	17.87	$	4,691	(2)
	Granted			1,809					21.09
	Exercised			(51,237	)				10.26	$	592	(3)
	Cancelled			(74,309	)				29.47
	Outstanding at March 31, 2014			837,005		$0.35 - $48.06			17.32	$	6,817	(4)
	Weighted average remaining contractual life in years: 3.1
	Exercisable at end of period			814,852		$0.35 - $48.06		$	17.28	$	6,695	(4)
	Weighted average remaining contractual life in years: 3.0
	Vested or expected to vest at March 31, 2014 (1)			835,658		$0.35 - $48.06		$	17.32	$	6,807	(4)
	-1	This represents the number of vested options as of March 31, 2014 plus the number of unvested options expected to vest as of March 31, 2014 based on the unvested options outstanding at March 31, 2014, adjusted for the estimated forfeiture rate of 7.8%.
	-2	The aggregate intrinsic value was calculated based on the positive difference between the estimated fair value of the Company’s common stock on December 31, 2013 of $17.21 and the exercise price of the underlying options.
	-3	The aggregate intrinsic value was calculated based on the positive difference between the fair value of the Company’s common stock on the applicable exercise dates and the exercise price of the underlying options.
	-4	The aggregate intrinsic value was calculated based on the positive difference between the estimated fair value of the Company’s common stock on March 31, 2014 of $22.28 and the exercise price of the underlying options.
	Additional Information About Stock Options
			Three Months Ended March 31,
			2014			2013
	Total number of options granted during the period			1,809			1,000
	Weighted-average fair value per share of options granted		$	11.69		$	10.08
	Total intrinsic value of options exercised (1)		$	592		$	553
	-1	Represents the difference between the market price at exercise and the price paid to exercise the options.
	Of the stock options outstanding as of March 31, 2014, 828,512 options were held by employees and directors of the Company and 8,493 options were held by non-employees. For outstanding unvested stock options related to employees and directors of the Company as of March 31, 2014, the Company had $195 of unrecognized stock-based compensation expense, which is expected to be recognized over a weighted average period of 1.3 years. There were no unvested non-employee stock options as of March 31, 2014.
	Restricted Stock and Restricted Stock Units
	For non-vested restricted stock and restricted stock units subject to service-based vesting conditions outstanding as of March 31, 2014, the Company had $15,266 of unrecognized stock-based compensation expense, which is expected to be recognized over a weighted average period of 2.8 years. For non-vested restricted stock subject to performance-based vesting conditions outstanding that were probable of vesting as of March 31, 2014, the Company had $10,773 of unrecognized stock-based compensation expense, which is expected to be recognized over a weighted average period of 2.0 years. There were no non-vested restricted stock awards outstanding subject to performance-based vesting conditions that were not probable of vesting as of March 31, 2014.
	Restricted Stock
	The following table summarizes the Company’s restricted stock activity during the three month period ended March 31, 2014:
			Number of			Weighted Average
			Shares			Grant Date Fair
			Value Per Share
Nonvested at December 31, 2013			2,395,322		$	13.48
Granted			491,899			20.94
Vested			(694,401	)		13.64
Cancelled			(86,385	)		10.01
Nonvested at March 31, 2014			2,106,435		$	15.84
All shares underlying awards of restricted stock are restricted in that they are not transferable until they vest. Restricted stock typically vests ratably over a four-year period from the date of issuance, with 25% cliff vesting after one year and the remaining 75% vesting ratably quarterly thereafter, with certain exceptions. Included in the above table are 4,500 shares of restricted stock granted to certain non-executive employees and 31,365 shares of restricted stock granted to members of the Company’s board of directors during the three month period ended March 31, 2014 that immediately vested. Also included in the table above are shares of restricted stock granted to non-employee advisory board members. In fiscal 2013, the Company granted 33,000 shares of restricted stock to non-employee advisory board members. Of the 33,000 shares of restricted stock granted, 22,000 shares vest ratably on a quarterly basis over four years and 11,000 shares of restricted stock vest in equal annual tranches on July 1, 2014 and July 1, 2015, as long as the individuals continue to serve as advisory board members through the date of the applicable vesting. The Company will account for these share-based awards in accordance with ASC 505-50, Equity Based Payments to Non-Employees (ASC 505-50), which will result in the Company continuing to re-measure the fair value of the share-based awards until such time as the awards vest. During the three month period ended March 31, 2014, the Company recorded stock-based compensation expense related to these awards of $88. As of March 31, 2014, 28,875 shares were unvested and had a fair value of $643.
The fair value of restricted stock upon which vesting is solely service-based is expensed ratably over the vesting period. With respect to restricted stock where vesting contains certain performance-based vesting conditions, the fair value is expensed based on the accelerated attribution method as prescribed by ASC 718, over the vesting period. With the exception of certain executives whose employment agreements provide for continued vesting in certain circumstances upon departure, if the employee who received the restricted stock leaves the Company prior to the vesting date for any reason, the shares of restricted stock will be forfeited and returned to the Company. During the three month period ended March 31, 2014, the Company granted 388,034 shares of nonvested restricted stock to certain executives that contain performance-based vesting conditions. Of these shares, 25% vest in 2015 if the performance criteria related to certain 2014 operating results are achieved and the executive is still employed as of the vesting date and the remaining 75% of the shares vest quarterly over a three year period thereafter as long as the executive is still employed as of the vesting date. If the performance criteria related to certain 2014 operating results are not achieved, 100% of the shares are forfeited.
During the three month period ended March 31, 2014, there were no changes to probabilities of vesting of performance-based stock awards which had a material impact on stock-based compensation expense or amounts expected to be recognized.
Additional Information About Restricted Stock
		Three Months Ended March 31,
		2014			2013
		In thousands, except share and per
		share amounts
Total number of shares of restricted stock granted during the period			491,899			981,841
Weighted average fair value per share of restricted stock granted		$	20.94		$	16.71
Total number of shares of restricted stock vested during the period			694,401			577,293
Total fair value of shares of restricted stock vested during the period		$	15,103		$	5,706
Restricted Stock Units
The following table summarizes the Company’s restricted stock unit activity during the three month period ended March 31, 2014:
		Number of			Weighted Average
		Shares			Grant Date Fair
					Value Per Share
Nonvested at December 31, 2013			34,250		$	28.59
Granted			—			—
Vested			(34,250	)		28.59
Cancelled			—			—
Nonvested at March 31, 2014			—		$	—
Additional Information About Restricted Stock Units
		Three Months Ended March 31,
		2014			2013
		In thousands, except share amounts
Total number of shares of restricted stock units vested during the period			34,250			53,478
Total fair value of shares of restricted stock units vested during the period		$	772		$	911

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	12. Income Taxes
	The Company accounts for income taxes in accordance with the liability method of ASC 740, Income Taxes (ASC 740). Deferred tax assets and liabilities are recognized based on the differences between the financial reporting and income tax bases of assets and liabilities using statutory rates. A valuation allowance must be provided against deferred tax assets if, based upon the available evidence, it is more likely than not that some or all of the deferred tax assets will not be realized.
	ASC 740 also provides criteria for the recognition, measurement, presentation and disclosures of uncertain tax positions. A tax benefit from an uncertain tax position may be recognized if it is “more likely than not” that the position is sustainable based solely on its technical merits. During the three month period ended March 31, 2014, there were no material changes in the Company’s uncertain tax positions.
	Each interim period is considered an integral part of the annual period and tax expense is measured using an estimated annual effective tax rate. An enterprise is required, at the end of each interim reporting period, to make its best estimate of the effective tax rate for the full fiscal year and use that rate to provide for income taxes on a current year-to-date basis. However, if an enterprise is unable to make a reliable estimate of its annual effective tax rate, the actual effective tax rate for the year-to-date period may be the best estimate of the annual effective tax rate. The Company is able to reliably estimate the annual effective tax rate on its foreign earnings, but is unable to reliably estimate the annual effective tax rate on U.S. earnings due to the potential volatility related to forecasted U.S. earnings and the fact that the majority of the U.S. tax provision is fixed due to the deferred tax expense related to tax deductible goodwill. As a result, the Company has provided a $425 worldwide tax benefit for the three month period ended March 31, 2014. The provision is comprised of a tax benefit on its foreign loss for the three month period ended where the Company expects to realize such benefit during fiscal 2014 plus a U.S. tax expense related to tax deductible goodwill that generates a deferred tax liability that cannot be used as a source of income against which deferred tax assets may be realized.
	If the Company is able to make a reliable estimate of its worldwide annual effective tax rate as of June 30, 2014, the Company will utilize that rate to provide for income taxes on a current year-to-date basis which could result in a significant benefit from income taxes being recorded during the three month period ending June 30, 2014 since the majority of the year-to-date loss will be related to the U.S. If the Company continues to be unable to make a reliable estimate of its annual effective tax rate as of June 30, 2014, the Company expects to follow a consistent methodology as was applied for the three month period ended March 31, 2014 and record a provision for income taxes in the U.S. for the three month period ending June 30, 2014 consistent with the three month period ending March 31, 2014 resulting in an overall income tax benefit for the three month period ending June 30, 2014 consistent with the three month period ended March 31, 2014, excluding the discrete tax provision that would be recorded upon the completion of a sale of the Company’s service line as further discussed in Note 14.
	The Company reviews all available evidence to evaluate the recovery of deferred tax assets, including the recent history of losses in all tax jurisdictions, as well as its ability to generate income in future periods. As of March 31, 2014, due to the uncertainty related to the ultimate use of the Company’s deferred income tax assets, the Company has provided a valuation allowance on all of its U.S., Germany, Japan, and U.K deferred tax assets and a partial valuation on its Australia deferred tax assets.

Concentrations_of_Credit_Risk

Concentrations of Credit Risk

3 Months Ended

Mar. 31, 2014

Risks And Uncertainties [Abstract]

'

Concentrations of Credit Risk

'

13. Concentrations of Credit Risk

The following table presents the Company’s significant customers. PJM Interconnection (PJM), ISO-New England, Inc. (ISO-NE) and Tennessee Valley Authority (TVA) are regional electric power grid operator customers in the mid-Atlantic, New England and Southeast regions, respectively, that are comprised of multiple utilities and were formed to control the operation of the regional power system, coordinate the supply of electricity, and establish fair and efficient markets. No other customers comprised more than 10% of consolidated revenues during the three month periods ended March 31, 2014 and 2013.

Three Months Ended March 31,

2014

2013

Revenues

% of Total

Revenues

% of Total

Revenues

Revenues

PJM

18,218

35

%

*

*%

ISO-NE

*

*%

4,761

14

%

TVA

*

*%

3,416

10

%

*

Represented less than 10% of consolidated revenues.

PJM was the only customer that comprised 10% or more of the Company’s accounts receivable balance at March 31, 2014, representing 51% of the balance. PJM and Southern California Edison Company were the only customers that each comprised 10% or more of the Company’s accounts receivable balance at December 31, 2013, representing 39% and 18%, respectively, of such balance.

Unbilled revenue related to PJM was $26,465 and $64,643 at March 31, 2014 and December 31, 2013, respectively. There was no significant unbilled revenue for any other customers at March 31, 2014 and December 31, 2013.

Deposits and restricted cash include funds to secure performance under certain contracts and open market bidding programs with electric power grid operator and utility customers. Deposits held by these customers were $119 and $128 at March 31, 2014 and December 31, 2013, respectively.

Legal_Proceedings

Legal Proceedings	3 Months Ended
	Mar. 31, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Legal Proceedings	'
	14. Legal Proceedings
	The Company is subject to legal proceedings, claims and litigation arising in the ordinary course of business. The Company does not expect the ultimate costs to resolve these matters to have a material adverse effect on its consolidated financial condition, results of operations or cash flows.
	On May 3, 2013, a purported shareholder of the Company (the Plaintiff) filed a derivative and class action complaint in the United States District Court for the District of Delaware (the Court) against certain officers and directors of the Company as well as the Company as a nominal defendant (the Defendants). The complaint asserts derivative claims, purportedly brought on behalf of the Company, for breach of fiduciary duty, waste of corporate assets, and unjust enrichment in connection with certain equity grants (awarded in 2010, 2012, and 2013) that allegedly exceeded an annual limit on per-employee equity grants purported to be contained in the 2007 Plan. The complaint also asserts a direct claim, brought on behalf of the plaintiff and a proposed class of the Company’s shareholders, alleging the Company’s proxy statement filed on April 26, 2013 was false and misleading because it failed to disclose that the equity grants were improper. The plaintiff seeks, among other relief, rescission of the equity grants, unspecified damages, injunctive relief, disgorgement, attorneys’ fees, and such other relief as the Court may deem proper.
	Defendants filed a motion to dismiss on August 30, 2013. Plaintiff responded to the motion on October 18, 2013 and Defendants replied on November 22, 2013. No hearing date has been set.
	The Company continues to believe that the Company and the other defendants have substantial legal and factual defenses to the claims and allegations contained in the complaint, and continues to pursue these defenses vigorously. The Company continues to believe that it is neither remote nor probable that the Company will incur a loss related to this matter. There can be no assurance, however, that the Company’s defense of this matter will be successful. The Company carries insurance for these types of claims and currently believes that a resolution to this claim, in excess of the deductible, would be covered by its insurance. Therefore, the Company does not currently believe that it is reasonably possible that the potential magnitude of the range of any loss would be material to the Company’s consolidated financial conditions, results of operations or cash flows. However, there is no guarantee that this claim will be covered by the Company’s insurer. A denial of the claim by the insurance provider or a judgment significantly in excess of the Company’s insurance coverage could materially and adversely affect its consolidated financial condition, results of operations and cash flows. In addition, regardless of the outcome of this matter, the matter may divert financial and management resources and result in general business disruption, including that the Company may suffer from adverse publicity that could harm its reputation and negatively impact its stock price.
	Indemnification Provisions
	The Company includes indemnification provisions in certain of its contracts. These indemnification provisions include provisions indemnifying the customer against losses, expenses, and liabilities from damages that could be awarded against the customer in the event that the Company’s services and related enterprise software platforms are found to infringe upon a patent or copyright of a third party. The Company believes that its internal business practices and policies and the ownership of information limits the Company’s risk in paying out any claims under these indemnification provisions.

Assets_and_Liabilities_Held_fo

Assets and Liabilities Held for Sale	3 Months Ended
	Mar. 31, 2014
Text Block [Abstract]	'
Assets and Liabilities Held for Sale	'
	15. Assets and Liabilities Held for Sale
	During the three month period ended December 31, 2013, the Company committed to a plan to sell a component of the business that the Company acquired in connection with its acquisition of Global Energy Partners, Inc. (Global Energy) in January 2011 related to consulting and engineering support services to the global electric utility industry, with a particular focus on providing consulting services to utilities (Utility Solutions Consulting). The Company engaged a third party consultant to assist the Company in actively marketing this service line for sale and identify a buyer. Based on the Company’s evaluation of the assets held for sale criteria under ASC 360-10, Impairment and Disposal of Long-Lived Assets, it concluded all of the criteria were met and that the assets and liabilities of Utility Solutions Consulting that are expected to be sold should be classified as held for sale. The assets held for sale relate to separately identifiable intangible assets, including customer relationships and certain non-compete agreements that were acquired in connection with the Global Energy acquisition and specifically relate to Utility Solutions Consulting. Due to the fact that the Company has concluded that Utility Solutions Consulting meets the definition of a business in accordance with ASC 805, also included in assets held for sale is the goodwill of the Company’s All Other reporting unit which has been allocated to Utility Solutions Consulting, which is a component of this reporting unit. The amount of goodwill allocated to Utility Solutions Consulting was based on the relative fair values of this business and the portion of the reporting unit that will be retained. The liabilities held for sale relate to the portion of the Company’s deferred tax liability related to the goodwill that has been allocated to Utility Solutions Consulting. The following table summarizes the assets and liabilities held for sale as of March 31, 2014:
		March 31, 2014
	Customer relationship intangible assets, net	$	153
	Other definite-lived intangible assets, net		39
	Goodwill		489
	Total Assets Held for Sale		681
	Deferred tax liability		521
	Total Liabilities Held for Sale	$	521
	The Company has concluded that the Utility Solutions Consulting disposal group meets the criteria of discontinued operations under ASC 205-20, Discontinued Operations (ASC 205-20). However, the Company has determined that the operations of Utility Solutions Consulting are neither quantitatively or qualitatively material to the Company’s consolidated operations for the three month periods ended March 31, 2014 or 2013, respectively, and therefore, the results of operations of Utility Solutions Consulting have not been presented as discontinued operations in the Company’s accompanying consolidated statements of operations for the three month periods ended March 31, 2014 and 2013.
	On April 16, 2014, the Company entered into an agreement with a third party to sell the Utility Solutions Consulting services line for up to $4,750 subject to satisfaction of certain conditions and representations. The Company anticipates this transaction will close during the three month period ending June 30, 2014 and result in a potential gain upon sale of up to $2,275, net of tax effects and other costs and expenses related to the sale. Up to $500 of this potential gain may be either reduced or deferred depending on the timing of the Company’s fulfillment of certain obligations under the agreement.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	3 Months Ended
	Mar. 31, 2014
Accounting Changes And Error Corrections [Abstract]	'
Recent Accounting Pronouncements	'
	16. Recent Accounting Pronouncements
	In April 2014, the Financial Accounting Standards Board (FASB) issued ASU No. 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (ASU 2014-08). ASU 2014-08 amends the definition of discontinued operations under ASC 205-20 to 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 will be reported as discontinued operations in the financial statements. This guidance is effective for all disposals (or classifications as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. The Company has early adopted this guidance as of January 1, 2014. The adoption of this guidance had no impact on the Company’s consolidated financial statements.

Description_of_Business_and_Ba1

Description of Business and Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Description of Business	'
	Description of Business
	EnerNOC, Inc. (the Company) is a leading provider of energy intelligence software (EIS) and related solutions. The Company unlocks the full value of energy management for commercial, institutional and industrial end-users of energy, which it refers to as its C&I or enterprise customers, and its electric power grid operator and utility customers by delivering a comprehensive suite of demand-side management solutions. These solutions allow customers to make better and more strategic decisions about how and when they use electricity.
	The Company believes that it is the world’s leading provider of demand response applications and solutions. Demand response is an alternative to traditional electric power generation and transmission infrastructure projects that enables electric power grid operators and utilities to reduce the likelihood of service disruptions, such as brownouts and blackouts, during periods of peak electricity demand, and otherwise manage the electric power grid during short-term imbalances of supply and demand or during periods when energy prices are high.
	The Company provides its utility and grid operator customers with two demand response solutions: EnerNOC Demand Resource and EnerNOC Demand Manager, which it collectively refers to as EnerNOC DemandSMART.
	When the Company enters into an EnerNOC Demand Resource contract, it matches obligation, in the form of megawatts (MWs) that it agrees to deliver to its utility and electric power grid operator customers, with supply, in the form of MW that it is able to curtail from the electric power grid through its arrangements with C&I customers. The Company deploys a sales team to contract with its C&I customers and installs its advanced metering equipment at these customers’ sites to connect them to its network, resulting in an increased ability to curtail demand from the electric power grid. When the Company is called upon by its utility or electric power grid operator customers to deliver its contracted capacity, the Company uses its Network Operations Center (NOC) to remotely manage and reduce electricity consumption across its growing network of C&I customer sites, making demand response capacity available to electric power grid operators and utilities on demand while helping C&I customers achieve energy savings, improved financial results and environmental benefits. The Company receives recurring payments from electric power grid operators and utilities for providing its EnerNOC Demand Resource solution and it shares these recurring payments with its C&I customers in exchange for those C&I customers reducing their power consumption when called upon by the Company to do so. The Company occasionally reallocates and realigns its capacity supply and obligation through open market bidding programs, supplemental demand response programs, auctions or other similar capacity arrangements and bilateral contracts to account for changes in supply and demand forecasts, as well as changes in programs and market rules in order to achieve more favorable pricing opportunities. The Company refers to the above activities as managing its portfolio of demand response capacity.
	EnerNOC’s Demand Manager solution consists of long-term contracts with a utility customer for a Software-as-a-Service solution that allows utilities to manage demand response capacity in utility-sponsored demand response programs. The Company’s EnerNOC Demand Manager solution provides its utility customers with real-time load monitoring, dispatching applications, customizable reports, measurement and verification, and other professional services.
	The Company builds on its position as a leading demand response provider by using its NOC and energy intelligence software (EIS) platform to deliver a portfolio of additional EIS and solutions to new and existing C&I, electric power grid operator and utility customers. These additional EIS and solutions include the Company’s EfficiencySMART and SupplySMART applications and solutions, and certain wireless energy management products. EfficiencySMART is the Company’s data-driven energy efficiency suite that includes energy efficiency planning, audits, assessments, commissioning and retro-commissioning authority services, and a cloud-based energy analytics application used for managing energy across a C&I customer’s portfolio of sites. The cloud-based energy analytics application also includes the ability to integrate with a C&I customer’s existing energy management system, provide utility bill management and tools for measurement, tracking, analysis, reporting and management of greenhouse gas emissions. SupplySMART is the Company’s energy price and risk management application and solution that provides its C&I customers located in restructured or deregulated markets throughout the United States with the ability to more effectively manage the energy supplier selection process, including energy supply product procurement and implementation, budget forecasting, and utility bill management. The Company’s wireless energy management products are designed to ensure that its C&I customers can connect their equipment remotely and access meter data securely, and include both cellular modems and an agricultural specific wireless technology solution.
Reclassifications	'
	Reclassifications
	The Company has reclassified certain amounts in its unaudited condensed consolidated statements of operations for the three month period ended March 31, 2013, to conform to the 2014 presentation. The reclassifications made related to the presentation of the Company’s revenues from DemandSMART revenues and EfficiencySMART, SupplySMART and other revenues to revenues from grid operators, revenues from utilities, and revenues from enterprise customers and was done in order to provide the users of its consolidated financial statements with additional insight into how the Company and its management views and evaluates its revenues and related growth. This reclassification within the unaudited condensed consolidated statements of operations for the three month period ended March 31, 2013 had no impact on previously reported total consolidated revenues or consolidated results of operations.
Basis of Consolidation	'
	Basis of Consolidation
	The unaudited condensed consolidated financial statements of the Company include the accounts of its wholly-owned subsidiaries and have been prepared in conformity with accounting principles generally accepted in the United States (GAAP) and variable interest entities (VIE) in which the Company has variable interests are consolidated where the Company is the primary beneficiary and thus controls the VIE. Intercompany transactions and balances are eliminated upon consolidation.
	On February 13, 2014, the Company acquired all of the outstanding capital stock of Entelios AG (Entelios) and all of the outstanding capital stock of Activation Energy DSU Limited (Activation) in separate purchase business combinations. Accordingly, the results of operations of Entelios and Activation subsequent to that date are included in the Company’s unaudited condensed consolidated statements of operations.
Subsequent Events Consideration	'
	Subsequent Events Consideration
	The Company considers events or transactions that occur after the balance sheet date but prior to the issuance of the financial statements to provide additional evidence relative to certain estimates or to identify matters that require additional disclosure. Subsequent events have been evaluated as required.
	Liquidity Changes
	In May 2014, the Company was required to provide incremental financial assurance in connection with its capacity bid in a certain open market bidding program. The Company has provided this financial assurance utilizing a $22,000 letter of credit issued under its $70,000 senior secured revolving credit facility with the several lenders from time to time party thereto and Silicon Valley Bank (SVB), as administrative agent, swingline lender, issuing lender, lead arranger and book manager (SVB and together with the other lenders, and referred to herein as the lenders), which was subsequently amended in August 2013, December 2013 and January 2014 (2013 credit facility) and additionally, utilized $4,500 of its available unrestricted cash on hand. Based on the Company’s prior experience with this certain open market bidding program, the Company currently expects that it will recover a portion of this letter of credit and cash during the three month period ending June 30, 2014.
	Acquisition of Entech Utility Service Bureau, Inc. and Entech Utility Service Bureau Ltd.
	On April 17, 2014, the Company and two of its subsidiaries completed acquisitions of all of the outstanding stock of Entech Utility Service Bureau, Inc. (Entech US) and Entech Utility Service Bureau Ltd. (Entech UK) (collectively, Entech), privately-held companies headquartered in the United States and the United Kingdom, respectively, that are leading providers of global utility bill management (UBM) software, which is currently deployed in over 100 countries, including many of the world’s fastest growing economies, such as China, India, and Brazil. The Company concluded that these acquisitions represented business combinations and, therefore, will account for them as such. The Company believes that the combination of Entech’s software and technology, including real-time energy data, tariffs, and monthly utility bill data on the Company’s EIS platform will now enable real-time visibility and forecasting of energy costs and empower better energy management across global enterprises.
	The Company concluded that these acquisitions represented business combinations under ASC 805, but has concluded that they did not represent material business combinations and therefore, no pro forma financial information will be required.
	Entech US and Entech UK were not entities under common control and the Company separately negotiated the acquisitions, including purchase price, with each of the entity’s stockholders. The Company acquired Entech US for an aggregate purchase price of $6,796 all of which was cash paid at closing with $60 paid to the stockholders’ consultants to settle transactional fees due to these consultants. There are no earn-out or other additional contingent purchase price arrangements related to the acquisition of Entech US. The Company acquired Entech UK for an aggregate purchase price of $3,154 all of which was cash paid at closing with $18 paid to the stockholders’ consultants to settle the stockholders’ fees due to these consultants. There are no earn-out or other additional contingent purchase price arrangements related to the acquisition of Entech UK.
	Transaction costs related to this business combination have been expensed as incurred and are included in general and administrative expenses in the accompanying condensed consolidated statements of operations. The Company’s consolidated financial statements will reflect Entech’s results of operations from April 17, 2014 forward.
	The Company is in the process of gathering information to complete its preliminary valuation of certain assets and liabilities in order to complete a preliminary purchase price allocation.
	There were no other material recognizable subsequent events recorded or requiring disclosure in the March 31, 2014 unaudited condensed consolidated financial statements.
Use of Estimates in Preparation of Financial Statements	'
	Use of Estimates in Preparation of Financial Statements
	The accompanying unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to SEC rules and regulations. In the opinion of the Company’s management, the unaudited condensed consolidated financial statements and notes thereto have been prepared on the same basis as the audited consolidated financial statements contained in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2013, and include all adjustments (consisting of normal, recurring adjustments) necessary for the fair presentation of the Company’s financial position at March 31, 2014 and statements of operations, statements of comprehensive loss and statements of cash flows for the three month periods ended March 31, 2014 and 2013. Operating results for the three month period ended March 31, 2014 are not necessarily indicative of the results to be expected for any other interim period or the entire fiscal year ending December 31, 2014 (fiscal 2014).
	The preparation of these unaudited condensed consolidated financial statements requires the Company to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. On an on-going basis, the Company evaluates its estimates, including those related to revenue recognition, allowance for doubtful accounts, valuations and purchase price allocations related to business combinations, fair value of deferred acquisition consideration, fair value of accrued acquisition contingent consideration, expected future cash flows including growth rates, discount rates, terminal values and other assumptions and estimates used to evaluate the recoverability of long-lived assets and goodwill, estimated fair values of intangible assets and goodwill, amortization methods and periods, certain accrued expenses and other related charges, stock-based compensation, contingent liabilities, fair value of asset retirement obligations, tax reserves and recoverability of the Company’s net deferred tax assets and related valuation allowance.
	Although the Company regularly assesses these estimates, actual results could differ materially. Changes in estimates are recorded in the period in which they become known. The Company bases its estimates on historical experience and various other assumptions that it believes to be reasonable under the circumstances. Actual results may differ from management’s estimates if these results differ from historical experience or other assumptions prove not to be substantially accurate, even if such assumptions are reasonable when made.
	The Company is subject to a number of risks similar to those of other companies of similar and different sizes both inside and outside of its industry, including, but not limited to, rapid technological changes, competition from similar energy management applications, services and products provided by larger companies, customer concentration, government regulations, market or program rule changes, protection of proprietary rights and dependence on key individuals.
Revenue Recognition	'
	Revenue Recognition
	The Company recognizes revenues in accordance with ASC 605, Revenue Recognition (ASC 605). In all of the Company’s arrangements, it does not recognize any revenues until it can determine that persuasive evidence of an arrangement exists, delivery has occurred, the fee is fixed or determinable, and it deems collection to be reasonably assured. In making these judgments, the Company evaluates the following criteria:
		•		Evidence of an arrangement. The Company considers a definitive agreement signed by the customer and the Company or an arrangement enforceable under the rules of an open market bidding program to be representative of persuasive evidence of an arrangement.
		•		Delivery has occurred. The Company considers delivery to have occurred when service has been delivered to the customer and no significant post-delivery obligations exist. In instances where customer acceptance is required, delivery is deemed to have occurred when customer acceptance has been achieved.
		•		Fees are fixed or determinable. The Company considers fees to be fixed or determinable unless the fees are subject to refund or adjustment or are not payable within normal payment terms. If the fee is subject to refund or adjustment and the Company cannot reliably estimate this amount, the Company recognizes revenues when the right to a refund or adjustment lapses. If the Company offers payment terms significantly in excess of its normal terms, it recognizes revenues as the amounts become due and payable or upon the receipt of cash.
		•		Collection is reasonably assured. The Company conducts a credit review at the inception of an arrangement to determine the creditworthiness of the customer. Collection is reasonably assured if, based upon evaluation, the Company expects that the customer will be able to pay amounts under the arrangement as payments become due. If the Company determines that collection is not reasonably assured, revenues are deferred and recognized upon the receipt of cash.
	The Company maintains a reserve for customer adjustments and allowances as a reduction in revenues. In determining the Company’s revenue reserve estimate, and in accordance with company policy, the Company relies on historical data and known performance adjustments. These factors, and unanticipated changes in the economic and industry environment, could cause the Company’s reserve estimates to differ from actual results. The Company records a provision for estimated customer adjustments and allowances in the same period as the related revenues are recorded. These estimates are based on the specific facts and circumstances of a particular program, analysis of credit memo data, historical customer adjustments, and other known factors. If the data the Company uses to calculate these estimates does not properly reflect reserve requirements, then a change in the allowances would be made in the period in which such a determination is made and revenues in that period could be affected. As of March 31, 2014 and December 31, 2013, the Company’s revenue reserves were $475. During the three month period ended March 31, 2013, the Company recorded an increase to the revenue reserve of $50. There was no change to the revenue reserve for the three month period ended March 31, 2014.
	Revenues from grid operators and revenues from utilities principally represent demand response revenues. During the three month period ended March 31, 2014, revenues from grid operators and revenues from utilities were comprised of $44,100 of demand response revenues and $1,979 of enterprise EIS and solutions revenues. During the three month periods ended March 31, 2013, revenues from grid operators and revenues from utilities were comprised of $24,482 of demand response revenues and $2,350 of enterprise EIS and solutions revenues.
	All revenues from enterprise customers for the three month periods ended March 31, 2014 and 2013 were derived from enterprise EIS and solutions.
	Demand Response Revenues
	The Company enters into contracts and open market bidding programs with utilities and electric power grid operators to provide demand response applications and services. Currently the Company has two principal service offerings under which it provides demand response applications and services: (1) full-service turnkey offering to utilities under which it manages all aspects of demand response program delivery to deliver a firm capacity resource (Demand Resource) and (2) utility partnership offering under which utilities can utilize software through a software as a service offering, integrated metering hardware, and professional services to support their tariff-based C&I demand response programs on a service-level agreement basis (Demand Manager).
	The Company has evaluated the factors within ASC 605 regarding gross versus net revenue reporting for its demand response revenues and its payments to C&I customers. Based on the evaluation of the factors within ASC 605, the Company has determined that all of the applicable indicators of gross revenue reporting were met. The applicable indicators of gross revenue reporting included, but were not limited to, the following:
		•		The Company is the primary obligor in its arrangements with electric power grid operators and utility customers because the Company provides its demand response services directly to electric power grid operators and utilities under long-term contracts or pursuant to open market programs and contracts separately with C&I customers to deliver such services. The Company manages all interactions with the electric power grid operators and utilities, while C&I customers do not interact with the electric power grid operators and utilities. In addition, the Company assumes the entire performance risk under its arrangements with electric power grid operators and utility customers, including the posting of financial assurance to assure timely delivery of committed capacity with no corresponding financial assurance received from its C&I customers. In the event of a shortfall in delivered committed capacity, the Company is responsible for all penalties assessed by the electric power grid operators and utilities without regard for any recourse the Company may have with its C&I customers.
		•		The Company has latitude in establishing pricing, as the pricing under its arrangements with electric power grid operators and utilities is negotiated through a contract proposal and contracting process or determined through a capacity auction. The Company then separately negotiates payment to C&I customers and has complete discretion in the contracting process with the C&I customers.
		•		The Company has complete discretion in determining which suppliers (C&I customers) will provide the demand response services, provided that the C&I customer is located in the same region as the applicable electric power grid operator or utility.
		•		The Company is involved in both the determination of service specifications and performs part of the services, including the installation of metering and other equipment for the monitoring, data gathering and measurement of performance, as well as, in certain circumstances, the remote control of C&I customer loads.
	As a result, the Company determined that it earns revenue (as a principal) from the delivery of demand response services to electric power grid operators and utility customers and records the amounts billed to the electric power grid operators and utility customers as gross demand response revenues and the amounts paid to C&I customers as cost of revenues.
	EnerNOC Demand Resource Solution
	The majority of the Company’s demand response revenues are generated from the EnerNOC Demand Resource solution. Demand response revenues consist of two elements: revenue earned from the Company’s ability to deliver committed capacity to its electric power grid operator and utility customers, which the Company refers to as capacity revenue; and revenue earned from additional payments made to the Company for the amount of energy usage actually curtailed from the grid during a demand response event, which the Company refers to as energy event revenue.
	The Company recognizes demand response revenue when it has provided verification to the electric power grid operator or utility of its ability to deliver the committed capacity which entitles the Company to payments under the contract or open market program. Committed capacity is generally verified through the results of an actual demand response event or a measurement and verification test. Once the capacity amount has been verified, the revenue is recognized and future revenue becomes fixed or determinable and is recognized monthly until the next demand response event or test. In subsequent verification events, if the Company’s verified capacity is below the previously verified amount, the electric power grid operator or utility customer will reduce future payments based on the adjusted verified capacity amounts. Ongoing demand response revenue recognized between demand response events or tests that are not subject to penalty or customer refund are recognized in revenue. If the revenue is subject to refund and the amount of refund cannot be reliably estimated, the revenue is deferred until the right of refund lapses.
	Commencing in fiscal 2012, all demand response capacity revenues related to the Company’s participation in the PJM open market program are being recognized at the end of the four-month delivery period of June through September, or during the three month period ended September 30th of each year. Because the period during which the Company is required to perform (June through September) is shorter than the period over which payments are received under the program (June through May), a portion of the revenues that have been earned are recorded and accrued as unbilled revenue. Substantially all revenues related to the PJM open market program for the year ended September 30, 2013 were recognized during the three month period ended September 30, 2013 and as a result of the billing period not coinciding with the revenue recognition period, the Company had $26,465, and $64,643 in unbilled revenues from PJM at March 31, 2014 and December 31, 2013, respectively.
	Energy event revenues are recognized when earned. Energy event revenue is deemed to be substantive and represents the culmination of a separate earnings process and is recognized when the energy event is initiated by the electric power grid operator or utility customer and the Company has responded under the terms of the contract or open market program. During the three month periods ended March 31, 2014 and 2013, the Company recognized $20,570 and $1,935, respectively, of energy event revenues.
	The Company has evaluated the forward capacity programs in which the Company participates and has determined that its contractual obligations in these programs do not currently meet the definition of derivative contracts under ASC 815, Derivatives and Hedging (ASC 815).
	EnerNOC Demand Manager Solution
	Under the Company’s EnerNOC Demand Manager solution, the Company generally receives an ongoing fee for overall management of the utility demand response program based on enrolled capacity or enrolled C&I customers, which is not subject to adjustment based on performance during a demand response dispatch. The Company recognizes revenues from these fees ratably over the applicable service delivery period commencing upon when the C&I customers have been enrolled and the contracted services have been delivered. In addition, under this offering, the Company may receive additional fees for program start-up, as well as, for C&I customer installations. The Company has determined that these fees do not have stand-alone value due to that such services do not have value without the ongoing services related to the overall management of the utility demand response program and therefore, the Company recognizes these fees over the estimated customer relationship period, which is generally the greater of 3 years or the contract period, commencing upon the enrollment of the C&I customers and delivery of the contracted services. Through March 31, 2014, revenues from EnerNOC Demand Manager have not been material to the Company’s consolidated results of operations.
	Enterprise EIS and Solutions
	With respect to the Company’s enterprise EIS and solutions revenues, which represent the Company’s EfficiencySMART, SupplySMART and other revenues, these generally represent ongoing service arrangements where the revenues are recognized ratably over the service period commencing upon delivery of the contracted service with the customer. Under certain of the Company’s arrangements, in particular certain EfficiencySMART arrangements with utilities, a portion of the fees received may be subject to adjustment or refund based on the validation of the energy savings delivered after the implementation is complete. As a result, the Company defers the portion of the fees that are subject to adjustment or refund until such time as the right of adjustment or refund lapses, which is generally upon completion and validation of the implementation. In addition, under certain other of the Company’s arrangements, the Company sells proprietary equipment to C&I customers that is utilized to provide the ongoing services that the Company delivers. Currently, this equipment has been determined to not have stand-alone value. As a result, the Company defers revenues associated with the equipment and the Company begins recognizing such revenue ratably over the expected C&I customer relationship period (generally 3 years), once the C&I customer is receiving the ongoing services from the Company. In addition, the Company capitalizes the associated direct and incremental costs, which primarily represent the equipment and third-party installation costs, and recognizes such costs over the expected C&I customer relationship period.
	The Company follows the provisions of ASC Update No. 2009-13, Multiple-Deliverable Revenue Arrangements (ASU 2009-13). The Company typically determines the selling price of its services based on vendor specific objective evidence (VSOE). Consistent with its methodology under previous accounting guidance, the Company determines VSOE based on its normal pricing and discounting practices for the specific service when sold on a stand-alone basis. In determining VSOE, the Company’s policy is to require a substantial majority of selling prices for a product or service to be within a reasonably narrow range. The Company also considers the class of customer, method of distribution, and the geographies into which its products and services are sold when determining VSOE. The Company typically has had VSOE for its products and services.
	In certain circumstances, the Company is not able to establish VSOE for all deliverables in a multiple element arrangement. This may be due to the infrequent occurrence of stand-alone sales for an element, a limited sales history for new services or pricing within a broader range than permissible by the Company’s policy to establish VSOE. In those circumstances, the Company proceeds to the alternative levels in the hierarchy of determining selling price. Third Party Evidence (TPE) of selling price is established by evaluating largely similar and interchangeable competitor products or services in stand-alone sales to similarly situated customers. The Company is typically not able to determine TPE and has not used this measure since the Company has been unable to reliably verify standalone prices of competitive solutions. Management’s best estimate of selling price (ESP) is established in those instances where neither VSOE nor TPE are available, by considering internal factors such as margin objectives, pricing practices and controls, customer segment pricing strategies and the product life cycle. Consideration is also given to market conditions such as competitor pricing information gathered from experience in customer negotiations, market research and information, recent technological trends, competitive landscape and geographies. Use of ESP is limited to a very small portion of the Company’s services, principally certain EfficiencySMART services.
Foreign Currency Translation	'
	Foreign Currency Translation
	Foreign currency translation adjustments are recorded as a component of other comprehensive loss and included in accumulated other comprehensive loss within stockholders’ equity. Gains arising from transactions denominated in foreign currencies and the re-measurement of certain intercompany receivables and payables are included in other income, net in the unaudited condensed consolidated statements of operations and were $387 and $16 for the three month periods ended March 31, 2014 and 2013, respectively. Foreign currency exchange gains (losses) resulted primarily from foreign denominated intercompany receivables held by the Company from one of its Australian subsidiaries which mainly resulted from funding provided to complete the acquisition of Energy Response Holdings Pty Ltd (Energy Response) and fluctuations in the Australian dollar exchange rate and U.S. dollar denominated intercompany payables from one of the Company’s German subsidiaries to the Company which mainly resulted from funding provided to complete the acquisition of Entelios.
	During the three month period ended March 31, 2014, there were no material settlements of foreign denominated receivables or payables and therefore, there were no material realized gains (losses) during the three month period ended March 31, 2014. During the three month period ended March 31, 2013, $10,266 ($9,921 Australian) of the intercompany receivable from the Company’s Australian subsidiary was settled resulting in a realized loss of $280. As of March 31, 2014, the Company had an intercompany receivable from its Australian subsidiary that is denominated in Australian dollars and not deemed to be of a “long-term investment” nature totaling $10,951 at March 31, 2014 exchange rates ($11,844 Australian) and two of its German subsidiaries had an intercompany payable to the Company that is denominated in U.S. dollars and not deemed to be of a “long-term investment” nature totaling $18,059 at March 31, 2014. The increase in the Australian intercompany receivable from December 31, 2013 was primarily due to royalties and other support charges due to the U.S. parent for services and technology provided by the U.S. parent during the three month period ended March 31, 2014. Subsequent to March 31, 2014, the Company settled $5,627 ($5,977 Australian) of the intercompany receivable from the Company’s Australian subsidiary resulting in a realized loss of $387.
	In addition, a portion of the funding provided by the Company to one of its Australian subsidiaries to complete the acquisition of Energy Response was deemed to be of a “long-term investment nature” and therefore, the resulting translation adjustments are being recorded as a component of stockholders’ equity within accumulated other comprehensive loss. As of March 31, 2014, the intercompany funding that is denominated in Australian dollars and deemed to be of a “long-term investment” nature totaled $18,829 at March 31, 2014 exchange rates ($20,364 Australian) and during the three month period ended March 31, 2014, the Company recorded translation adjustments of $654 related to this intercompany funding within accumulated other comprehensive loss.
Comprehensive (Loss) Income	'
	Comprehensive (Loss) Income
	Comprehensive (loss) income is defined as the change in equity of a business enterprise during a period resulting from transactions and other events and circumstances from non-owner sources. As of March 31, 2014 and December 31, 2013, accumulated other comprehensive loss was comprised solely of cumulative foreign currency translation adjustments. The Company presents its components of other comprehensive loss, net of related tax effects, which have not been material to date.
Software Development Costs	'
	Software Development Costs
	Software development costs, including license fees and external consulting costs, of $1,398 and $2,631 for the three month periods ended March 31, 2014 and 2013, respectively, have been capitalized in accordance with Accounting Standard Codification (ASC) 350-40, Internal-Use Software (ASC 350-40). The capitalized amount was included as software in property and equipment at March 31, 2014 and December 31, 2013. Amortization of capitalized internal use software costs was $1,530 and $1,308 for the three month periods ended March 31, 2014 and 2013, respectively. Accumulated amortization of capitalized internal use software costs was $22,971 and $21,441 as of March 31, 2014 and December 31, 2013, respectively.
Impairment of Property and Equipment	'
	Impairment of Property and Equipment
	During the three month period ended March 31, 2014, as a result of the removal of certain demand response equipment from service, the Company concluded that there were no expected future direct cash flows associated with this demand response equipment and therefore, an impairment indicator existed. The Company determined that the residual value of this demand response equipment was nominal and as a result, recorded an impairment charge during the three month period ended March 31, 2014 of $95, to reduce the carrying value of such equipment to zero. During the three month period ended March 31, 2013, the Company recognized impairment charges of $142.
Industry Segment Information	'
	Industry Segment Information
	The Company operates in the following major geographic areas as noted in the below chart. The “All other” designation includes Australia, Germany, Japan, Ireland, New Zealand and the United Kingdom. Revenues are based upon customer location and internationally totaled $9,180 and $8,087 for the three month periods ended March 31, 2014 and 2013, respectively.
	Revenues by geography as a percentage of total revenues are as follows:
			Three Months Ended March 31,
			2014			2013
	United States			83	%		75	%
	Canada			11			15
	All other			6			10
	Total			100	%		100	%
	As of March 31, 2014 and December 31, 2013, the long-lived assets related to the Company’s international subsidiaries were not material to the accompanying unaudited condensed consolidated financial statements taken as a whole.
Leases	'
	In July 2012, the Company entered into a lease for its new principal executive offices at One Marina Park Drive, Floors 4-6, Boston, Massachusetts. The lease term is through July 2020 and the lease contains both a rent holiday period and escalating rental payments over the lease term. The lease requires payments for additional expenses such as taxes, maintenance, and utilities and contains a fair value renewal option. The Company began occupying the space during the second quarter of fiscal 2013. In accordance with the terms of the lease, the landlord provided certain lease incentives with respect to the leasehold improvements. In accordance with ASC 840, Leases (ASC 840), the Company recorded the incentives as deferred rent and will reflect these amounts as reductions of lease expense over the lease term. Although lease payments under this arrangement did not commence until August 2013, as the Company had the right to use and controlled physical access to the space, it determined that the lease term commenced in July 2012 and, as a result, began recording rent expense on this lease arrangement at that time on a straight-line basis. The lease also contains certain provisions requiring the Company to restore certain aspects of the leased space to its initial condition. The Company has determined that these provisions represent asset retirement obligations and recorded the estimated fair value of these obligations as the related leasehold improvements were incurred. The Company will accrete the liability to fair value over the life of the lease as a component of operating expenses. As of March 31, 2014, the Company recorded an asset retirement obligation of $410.

Description_of_Business_and_Ba2

Description of Business and Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Percentage of Total Revenues	'
	Revenues by geography as a percentage of total revenues are as follows:
		Three Months Ended March 31,
		2014			2013
	United States		83	%		75	%
	Canada		11			15
	All other		6			10
	Total		100	%		100	%

Acquisitions_Tables

Acquisitions (Tables)	3 Months Ended
	Mar. 31, 2014
Entelios AG [Member]	'
Components and Preliminary Allocation of Purchase Price	'
	The components and preliminary allocation of the purchase price consist of the following approximate amounts:
	Net tangible liabilities assumed as of February 13, 2014	$	(50	)
	Customer relationships		4,084
	Non-compete agreements		204
	Developed technology		1,770
	Trade name		218
	Deferred income tax asset		2,070
	Deferred income tax liability		(2,070	)
	Goodwill		15,653
	Total	$	21,879
Schedule of Net Tangible Assets and Liabilities Acquired	'
	Net tangible liabilities assumed in the acquisition of Entelios primarily related to the following:
	Cash	$	1,564
	Accounts receivable		19
	Capitalized incremental direct customer contract costs		36
	Prepaid expenses and other current assets		148
	Property and equipment		377
	Other assets		72
	Accounts payable		(178	)
	Accrued payroll and related expenses		(970	)
	Accrued expenses and other liabilities		(1,098	)
	Deferred revenues		(20	)
	Total	$	(50	)
Activation Energy DSU Limited [Member]	'
Components and Preliminary Allocation of Purchase Price	'
	The components and preliminary allocation of the purchase price consist of the following approximate amounts:
	Net tangible assets acquired as of February 13, 2014	$	752
	Customer relationships		2,042
	Non-compete agreements		220
	Developed technology		545
	Trade name		82
	Deferred income tax liability		(361	)
	Goodwill		1,596
	Total	$	4,876
Schedule of Net Tangible Assets and Liabilities Acquired	'
	Net tangible assets acquired in the acquisition of Activation primarily related to the following:
	Cash	$	711
	Accounts receivable		472
	Prepaid expenses and other current assets		27
	Property and equipment		92
	Accounts payable		(45	)
	Accrued expenses and other current liabilities		(55	)
	Accrued capacity payments		(450	)
	Total	$	752

Intangible_Assets_and_Goodwill1

Intangible Assets and Goodwill (Tables)	3 Months Ended
	Mar. 31, 2014
Goodwill And Intangible Assets Disclosure [Abstract]	'
Summary of Gross Carrying Amount and Accumulated Amortization of Definite-Lived Intangible Assets	'
	The following table provides the gross carrying amount and related accumulated amortization of intangible assets as of March 31, 2014 and December 31, 2013:
				As of March 31, 2014					As of December 31, 2013
		Weighted Average		Gross		Accumulated			Gross		Accumulated
		Amortization		Carrying		Amortization			Carrying		Amortization
		Period (in years)		Amount					Amount
	Customer relationships		3.63	$	35,573	$	(16,091	)	$	29,663	$	(15,416	)
	Customer contracts		2.81		5,152		(3,074	)		4,887		(2,900	)
	Employment agreements and non- compete agreements		1.09		1,988		(1,422	)		1,676		(1,475	)
	Software				120		(120	)		120		(120	)
	Developed technology		1.24		4,623		(2,048	)		2,277		(1,758	)
	Trade name		1.03		878		(503	)		575		(455	)
	Patents		5.9		180		(72	)		180		(68	)
	Total other definite-lived intangible assets				12,941		(7,239	)		9,715		(6,776	)
	Total			$	48,514	$	(23,330	)	$	39,378	$	(22,192	)
Schedule of Change in Carrying Amount of Goodwill	'
	The following table shows the change of the carrying amount of goodwill from December 31, 2013 to March 31, 2014:
	Balance at December 31, 2013	$	77,104
	Acquisitions (Note 2)		17,249
	Foreign currency translation		616
	Balance at March 31, 2014	$	94,969

Net_Loss_Per_Share_Tables

Net Loss Per Share (Tables)	3 Months Ended
	Mar. 31, 2014
Earnings Per Share [Abstract]	'
Reconciliation of Basic and Diluted Share Amounts	'
	A reconciliation of basic and diluted share amounts for the three month periods ended March 31, 2014 and 2013 are as follows (in thousands):
		Three Months Ended March 31,
		2014		2013
	Basic weighted average common shares outstanding		27,924		27,367
	Weighted average common stock equivalents		—		—
	Diluted weighted average common shares outstanding		27,924		27,367
	Weighted average anti-dilutive shares related to:
	Stock options		895		1,250
	Nonvested restricted shares		2,138		2,189
	Restricted stock units		18		81
	Escrow shares		—		64

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
Assets and Liabilities Measured at Fair Value on Recurring Basis	'
	The table below presents the balances of assets and liabilities measured at fair value on a recurring basis at March 31, 2014:
			Fair Value Measurement at March 31, 2014 Using
			Totals		Quoted Prices in		Significant		Unobservable
					Active Markets		Other		Inputs (Level 3)
					for Identical		Observable
					Assets (Level 1)		Inputs (Level 2)
	Assets:
	Money market funds (1)		$	88,611	$	88,611	$	—	$	—
	Liabilities:
	Accrued contingent purchase price consideration (2)		$	399	$	—	$	—	$	399
	Deferred acquisition consideration (2)		$	572	$	—	$	—	$	572
	-1	Total of $88,431 included in cash and cash equivalents and $180 included in restricted cash in the accompanying unaudited condensed consolidated balance sheets and represents the only asset that the Company measures and records at fair value on a recurring basis. These money market funds represent excess operating cash that is invested daily into an overnight investment account. The decrease from December 31, 2013 was primarily due to cash used in operations and cash utilized for the Company’s acquisitions of Entelios and Activation during the three month period ended March 31, 2014.
	-2	Accrued contingent purchase price consideration, which resulted from the Company’s acquisitions of Energy Response, Entelios and Activation, and deferred acquisition consideration, which is a result of the Company’s acquisition of M2M, represent the only assets or liabilities that the Company measures and records at fair value on a recurring basis using significant unobservable inputs (Level 3). The aggregate increase in fair value of liabilities for the three month period ended March 31, 2014 of $10 was due to the increase in the liabilities as a result of the amortization of the applicable discounts related to the time value of money of $6 and changes in exchange rates. There were no changes to the probability or timing of payment during the three month period ended March 31, 2014.
	With respect to assets measured at fair value on a non-recurring basis, these represent impaired long-lived assets (refer to Note 1 for discussion of the determination of fair value of these assets), impaired definite-lived intangible assets (refer to Note 2 for discussion of the determination of fair value of these assets) and cost method investments (refer to Note 4 for discussion of the determination of fair value of these assets).
	The table below presents the balances of assets and liabilities measured at fair value on a recurring basis at December 31, 2013:
			Fair Value Measurement at December 31, 2013 Using
			Totals		Quoted Prices in		Significant		Unobservable
					Active Markets		Other		Inputs (Level 3)
					for Identical		Observable
					Assets (Level 1)		Inputs (Level 2)
	Assets:
	Money market funds (1)		$	146,626	$	146,626	$	—	$	—
	Liabilities:
	Deferred acquisition consideration (2)		$	566	$	—	$	—	$	566
	-1	Total of $145,076 included in cash and cash equivalents and $1,550 included in restricted cash in the accompanying unaudited condensed consolidated balance sheets and represents the only assets that the Company measures and records at fair value on a recurring basis. These money market funds represent excess operating cash that is invested daily into an overnight investment account.
	-2	Deferred acquisition consideration which is a liability and was the result of the Company’s acquisition of M2M represents the only liability that the Company measures and records at fair value on a recurring basis using significant unobservable inputs (Level 3). The aggregate increase in fair value of this liability for the year ended December 31, 2013 of $33 was due to the increase in the liability as a result of the amortization of the discount related to the time value of money. There were no changes with respect to the timing of payment subsequent to December 31, 2013.

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2014
Commitments And Contingencies Disclosure [Abstract]	'
Future Minimum Lease Payments for Operating Leases	'
	As of March 31, 2014, future minimum lease payments for operating leases with non-cancelable terms of more than one year were as follows:
		Operating Leases
	Remainder of 2014	$	4,205
	2015		5,622
	2016		5,445
	2017		5,437
	2018		5,569
	Thereafter		7,517
	Total minimum lease payments (not reduced by sublease rentals of $191)	$	33,795

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	3 Months Ended
	Mar. 31, 2014
Weighted Average Assumptions Used to Estimate Fair Value of Stock Options	'
	The fair value of stock options granted was estimated at the date of grant using the following weighted average assumptions:
			Three Months Ended March 31,
			2014			2013
	Risk-free interest rate			2.67	%		1.9	%
	Vesting term, in years			2.22			2.22
	Expected annual volatility			72	%		75	%
	Expected dividend yield			—	%		—	%
	Exit rate pre-vesting			7.8	%		7.7	%
	Exit rate post-vesting			14.06	%		14.06	%
Components of Stock-Based Compensation Expense	'
	The components of stock-based compensation expense are disclosed below:
			Three Months Ended March 31,
			2014			2013
	Stock options		$	186		$	399
	Restricted stock and restricted stock units			4,041	(1)		4,305
	Total		$	4,227		$	4,704
	-1	Due to the fact that the Company’s chief executive officer is required to receive his 2014 performance based bonus, if achieved, in shares of common stock of the Company determined based on the cash value of such bonus divided by the fair market value of the Company’s common stock on the date that the Company’s Compensation Committee validates the achievement of the performance bonus metrics, in accordance with the Company’s policy, the Company is recording this amount as stock-based compensation expense ratably over the applicable performance and service period in accordance with ASC 718, Stock Compensation (ASC 718). During the three month period ended March 31, 2014, the Company recorded $125 of stock-based compensation expense.
Stock-Based Compensation	'
	Stock-based compensation is recorded in the accompanying unaudited condensed consolidated statements of
	operations, as follows:
			Three Months Ended March 31,
			2014			2013
	Selling and marketing expenses		$	1,193		$	1,390
	General and administrative expenses			2,696			2,952
	Research and development expenses			338			362
	Total		$	4,227		$	4,704
Summary of Company's Stock Option Activity	'
	The following is a summary of the Company’s stock option activity during the three month period ended March 31, 2014:
			Three Months Ended March 31, 2014
			Number of			Exercise		Weighted-		Aggregate
			Shares			Price Per		Average		Intrinsic
			Underlying			Share		Exercise Price		Value
			Options					Per Share
	Outstanding at December 31, 2013			960,742		$0.17 - $48.06		$	17.87	$	4,691	(2)
	Granted			1,809					21.09
	Exercised			(51,237	)				10.26	$	592	(3)
	Cancelled			(74,309	)				29.47
	Outstanding at March 31, 2014			837,005		$0.35 - $48.06			17.32	$	6,817	(4)
	Weighted average remaining contractual life in years: 3.1
	Exercisable at end of period			814,852		$0.35 - $48.06		$	17.28	$	6,695	(4)
	Weighted average remaining contractual life in years: 3.0
	Vested or expected to vest at March 31, 2014 (1)			835,658		$0.35 - $48.06		$	17.32	$	6,807	(4)
	-1	This represents the number of vested options as of March 31, 2014 plus the number of unvested options expected to vest as of March 31, 2014 based on the unvested options outstanding at March 31, 2014, adjusted for the estimated forfeiture rate of 7.8%.
	-2	The aggregate intrinsic value was calculated based on the positive difference between the estimated fair value of the Company’s common stock on December 31, 2013 of $17.21 and the exercise price of the underlying options.
	-3	The aggregate intrinsic value was calculated based on the positive difference between the fair value of the Company’s common stock on the applicable exercise dates and the exercise price of the underlying options.
	-4	The aggregate intrinsic value was calculated based on the positive difference between the estimated fair value of the Company’s common stock on March 31, 2014 of $22.28 and the exercise price of the underlying options.
Stock Options Activity Additional Information	'
	Additional Information About Stock Options
			Three Months Ended March 31,
			2014			2013
	Total number of options granted during the period			1,809			1,000
	Weighted-average fair value per share of options granted		$	11.69		$	10.08
	Total intrinsic value of options exercised (1)		$	592		$	553
	-1	Represents the difference between the market price at exercise and the price paid to exercise the options.
Restricted Stock [Member]	'
Summary of Company's Restricted Stock and Restricted Stock Units Activity	'
	The following table summarizes the Company’s restricted stock activity during the three month period ended March 31, 2014:
			Number of			Weighted Average
			Shares			Grant Date Fair
						Value Per Share
	Nonvested at December 31, 2013			2,395,322		$	13.48
	Granted			491,899			20.94
	Vested			(694,401	)		13.64
	Cancelled			(86,385	)		10.01
	Nonvested at March 31, 2014			2,106,435		$	15.84
Additional Information about Restricted Stock and Restricted Stock Units	'
	Additional Information About Restricted Stock
			Three Months Ended March 31,
			2014			2013
			In thousands, except
			share and per
			share amounts
	Total number of shares of restricted stock granted during the period			491,899			981,841
	Weighted average fair value per share of restricted stock granted		$	20.94		$	16.71
	Total number of shares of restricted stock vested during the period			694,401			577,293
	Total fair value of shares of restricted stock vested during the period		$	15,103		$	5,706
Restricted Stock Units [Member]	'
Summary of Company's Restricted Stock and Restricted Stock Units Activity	'
	The following table summarizes the Company’s restricted stock unit activity during the three month period ended March 31, 2014:
			Number of			Weighted Average
			Shares			Grant Date Fair
						Value Per Share
	Nonvested at December 31, 2013			34,250		$	28.59
	Granted			—			—
	Vested			(34,250	)		28.59
	Cancelled			—			—
	Nonvested at March 31, 2014			—		$	—
Additional Information about Restricted Stock and Restricted Stock Units	'
	Additional Information About Restricted Stock Units
			Three Months Ended
			March 31,
			2014			2013
			In thousands, except share amounts
	Total number of shares of restricted stock units vested during the period			34,250			53,478
	Total fair value of shares of restricted stock units vested during the period		$	772		$	911

Concentrations_of_Credit_Risk_

Concentrations of Credit Risk (Tables)

3 Months Ended

Mar. 31, 2014

Risks And Uncertainties [Abstract]

'

Concentrations of Credit Risk of Significant Customers

'

No other customers comprised more than 10% of consolidated revenues during the three month periods ended March 31, 2014 and 2013.

Three Months Ended March 31,

2014

2013

Revenues

% of Total

Revenues

% of Total

Revenues

Revenues

PJM

18,218

35

%

*

*%

ISO-NE

*

*%

4,761

14

%

TVA

*

*%

3,416

10

%

*

Represented less than 10% of consolidated revenues.

Assets_and_Liabilities_Held_fo1

Assets and Liabilities Held for Sale (Tables)	3 Months Ended
	Mar. 31, 2014
Text Block [Abstract]	'
Summary of Assets and Liabilities Held for Sale	'
	The following table summarizes the assets and liabilities held for sale as of March 31, 2014:
		March 31, 2014
	Customer relationship intangible assets, net	$	153
	Other definite-lived intangible assets, net		39
	Goodwill		489
	Total Assets Held for Sale		681
	Deferred tax liability		521
	Total Liabilities Held for Sale	$	521

Description_of_Business_and_Ba3

Description of Business and Basis of Presentation - Additional Information (Detail)

3 Months Ended

3 Months Ended

3 Months Ended

1 Months Ended

3 Months Ended

In Thousands, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2013

Apr. 30, 2014

Apr. 30, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

USD ($)

USD ($)

USD ($)

PJM [Member]

PJM [Member]

Credit Facility 2013 [Member]

Credit Facility 2013 [Member]

International Customers [Member]

International Customers [Member]

Entech [Member]

Entech [Member]

Australian Subsidiary [Member]

Australian Subsidiary [Member]

Australian Subsidiary [Member]

Australian Subsidiary [Member]

Australian Subsidiary [Member]

Australian Subsidiary [Member]

German Subsidiary [Member]

Demand Response Equipment [Member]

Demand Response Equipment [Member]

Enterprise EIS and Solutions Revenues [Member]

Enterprise EIS and Solutions Revenues [Member]

Software Development Costs [Member]

Software Development Costs [Member]

Software Development Costs [Member]

USD ($)

USD ($)

USD ($)

Revolving Credit Facility [Member]

USD ($)

USD ($)

United States [Member]

United Kingdom [Member]

USD ($)

AUD

USD ($)

AUD

Subsequent Event [Member]

Subsequent Event [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

AUD

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing letter of credit

'

'

'

'

'

'

$22,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of credit

'

'

'

'

'

'

70,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrestricted cash

'

'

'

'

'

4,500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate purchase price

'

'

'

'

'

'

'

'

'

6,796

3,154

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settle transactional fees

'

'

'

'

'

'

'

'

'

60

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue reserves

475

'

475

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase of revenue reserves

0

50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Demand response revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

44,100

24,482

'

'

'

'

'

Demand delivery revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,979

2,350

'

'

'

Unbilled revenue

'

'

'

26,465

64,643

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Energy event revenues

20,570

1,935

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income(Expense)arising from transactions denominated in foreign currencies

387

16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Inter company receivable from subsidiary

'

'

'

'

'

'

'

'

'

'

'

0

0

10,266

9,921

5,627

5,977

'

'

'

'

'

'

'

'

Realized gain (loss) form inter company receivable

'

'

'

'

'

'

'

'

'

'

'

0

'

280

'

387

'

'

'

'

'

'

'

'

'

Intercompany receivable

'

'

'

'

'

'

'

'

'

'

'

10,951

11,844

'

'

'

'

18,059

'

'

'

'

'

'

'

Intercompany funding deemed as long-term investment

'

'

'

'

'

'

'

'

'

'

'

18,829

20,364

'

'

'

'

'

'

'

'

'

'

'

'

Translation adjustments

547

-24

'

'

'

'

'

'

'

'

'

654

'

'

'

'

'

'

'

'

'

'

'

'

'

Capitalized software development costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,398

2,631

'

Amortization of capitalized software development costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,530

1,308

'

Accumulated amortization of capitalized software development costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22,971

'

21,441

Impairment charges of property and equipment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

95

142

'

'

'

'

'

Carrying value of impaired long-lived assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

Revenues based upon customer location

$52,508

$32,850

'

$18,218

'

'

'

$9,180

$8,087

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Description_of_Business_and_Ba4

Description of Business and Basis of Presentation - Percentage of Total Revenues (Detail)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Segment Reporting Information [Line Items]	'	'
Percentage of total revenues	100.00%	100.00%
United States [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Percentage of total revenues	83.00%	75.00%
Canada [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Percentage of total revenues	11.00%	15.00%
All Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Percentage of total revenues	6.00%	10.00%

Acquisitions_Additional_Inform

Acquisitions - Additional Information (Detail)

Mar. 31, 2014

Feb. 13, 2014

Feb. 13, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Feb. 13, 2014

Feb. 13, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

In Thousands, unless otherwise specified

USD ($)

Entelios AG [Member]

Entelios AG [Member]

Entelios AG [Member]

Entelios AG [Member]

Entelios AG [Member]

Entelios AG [Member]

Entelios AG [Member]

Entelios AG [Member]

Entelios AG [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

Activation Energy DSU Limited [Member]

USD ($)

EUR (€)

USD ($)

Minimum [Member]

Maximum [Member]

December 31, 2014 [Member]

December 31, 2014 [Member]

December 31, 2015 [Member]

December 31, 2015 [Member]

USD ($)

EUR (€)

USD ($)

Minimum [Member]

Maximum [Member]

December 31, 2014 [Member]

December 31, 2014 [Member]

December 31, 2015 [Member]

December 31, 2015 [Member]

USD ($)

EUR (€)

USD ($)

EUR (€)

USD ($)

EUR (€)

USD ($)

EUR (€)

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate purchase price

'

$21,784

€ 16,000

'

'

'

'

'

'

'

$3,844

€ 2,823

'

'

'

'

'

'

'

Closing price of outstanding debt obligations

'

6,884

5,056

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum contingent purchase price consideration related to an earn-out amount

'

2,042

1,500

'

'

'

817

600

1,225

900

1,398

1,027

'

'

'

350

257

1,048

770

Fair value of cash consideration

'

95

'

'

'

'

'

'

'

'

300

'

'

'

'

'

'

'

'

Fair value aggregate purchase price

'

21,879

'

'

'

'

'

'

'

'

4,876

'

'

'

'

'

'

'

'

Liability after adjusting for changes in exchange rates

303

'

'

96

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Direct acquisition fees and expenses

'

'

'

511

'

'

'

'

'

'

'

'

159

'

'

'

'

'

'

Discount rate

'

'

'

'

12.00%

17.00%

'

'

'

'

'

'

'

17.00%

20.00%

'

'

'

'

Working capital and other adjustments

'

'

'

'

'

'

'

'

'

'

$732

€ 538

'

'

'

'

'

'

'

Acquisitions_Components_and_Pr

Acquisitions - Components and Preliminary Allocation of Purchase Price (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Schedule Of Business Acquisitions Purchase Price Allocation [Line Items]	'	'
Goodwill	$94,969	$77,104
Entelios AG [Member]	'	'
Schedule Of Business Acquisitions Purchase Price Allocation [Line Items]	'	'
Net tangible liabilities assumed	-50	'
Customer relationships	4,084	'
Non-compete agreements	204	'
Developed technology	1,770	'
Trade name	218	'
Deferred income tax asset	2,070	'
Deferred income tax liability	-2,070	'
Goodwill	15,653	'
Total	21,879	'
Activation Energy DSU Limited [Member]	'	'
Schedule Of Business Acquisitions Purchase Price Allocation [Line Items]	'	'
Net tangible assets acquired and liabilities assumed	752	'
Customer relationships	2,042	'
Non-compete agreements	220	'
Developed technology	545	'
Trade name	82	'
Deferred income tax liability	-361	'
Goodwill	1,596	'
Total	$4,876	'

Acquisitions_Schedule_of_Net_T

Acquisitions - Schedule of Net Tangible Assets and Liabilities Acquired (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Business Acquisition [Line Items]	'	'	'
Capitalized incremental direct customer contract costs	$16,267	'	$9,509
Accrued payroll and related expenses	-10,978	'	-13,370
Accrued expenses and other current liabilities	-13,871	'	-10,145
Accrued capacity payments	-18,338	-17,073	'
Deferred revenues	-7,997	'	-6,819
Entelios AG [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Cash	1,564	'	'
Accounts receivable	19	'	'
Capitalized incremental direct customer contract costs	36	'	'
Prepaid expenses and other current assets	148	'	'
Property and equipment	377	'	'
Other assets	72	'	'
Accounts payable	-178	'	'
Accrued payroll and related expenses	-970	'	'
Accrued expenses and other liabilities	-1,098	'	'
Deferred revenues	-20	'	'
Total	-50	'	'
Activation Energy DSU Limited [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Cash	711	'	'
Accounts receivable	472	'	'
Prepaid expenses and other current assets	27	'	'
Property and equipment	92	'	'
Accounts payable	-45	'	'
Accrued expenses and other current liabilities	-55	'	'
Accrued capacity payments	-450	'	'
Total	$752	'	'

Japan_Joint_Venture_Additional

Japan Joint Venture - Additional Information (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014
EnerNoc [Member]	'
Investment In Joint Venture [Line Items]	'
Initial capital contribution	$580
Percentage of ownership	60.00%
Japan Joint Venture [Member] | Marubeni Corporation [Member]	'
Investment In Joint Venture [Line Items]	'
Joint venture date	10-Dec-13
Initial capital contribution	$392

Equity_Investment_and_License_

Equity Investment and License - Additional Information (Detail) (USD $)	1 Months Ended	3 Months Ended
In Thousands, unless otherwise specified	Feb. 28, 2014	Mar. 31, 2014	Mar. 31, 2013
Schedule Of Results Related To Equity Accounted Investees [Line Items]	'	'	'
Purchase price	$1,000	'	'
Fair value of investment	1,000	'	'
Fees paid related to acquisition of a perpetual software license	2,000	'	'
Depreciation expense	'	5,482	4,936
Technology Equipment [Member]	'	'	'
Schedule Of Results Related To Equity Accounted Investees [Line Items]	'	'	'
Fair value of license obtained	2,000	'	'
Estimated useful life	'	'3 years	'
Depreciation expense	'	111	'
Technology Equipment [Member] | Maximum [Member]	'	'	'
Schedule Of Results Related To Equity Accounted Investees [Line Items]	'	'	'
Future revenues from licensing of developed software technology	'	$2,000	'

Intangible_Assets_and_Goodwill2

Intangible Assets and Goodwill - Summary of Gross Carrying Amount and Accumulated Amortization of Definite-Lived Intangible Assets (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]	'	'
Weighted Average Amortization Period (in years)	'3 years 2 months 12 days	'
Gross Carrying Amount	$48,514	$39,378
Accumulated Amortization	-23,330	-22,192
Customer Relationships [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Weighted Average Amortization Period (in years)	'3 years 7 months 17 days	'
Gross Carrying Amount	35,573	29,663
Accumulated Amortization	-16,091	-15,416
Customer Contracts [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Weighted Average Amortization Period (in years)	'2 years 9 months 22 days	'
Gross Carrying Amount	5,152	4,887
Accumulated Amortization	-3,074	-2,900
Employment Agreements and Non-Compete Agreements [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Weighted Average Amortization Period (in years)	'1 year 1 month 2 days	'
Gross Carrying Amount	1,988	1,676
Accumulated Amortization	-1,422	-1,475
Software [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	120	120
Accumulated Amortization	-120	-120
Developed Technology [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Weighted Average Amortization Period (in years)	'1 year 2 months 27 days	'
Gross Carrying Amount	4,623	2,277
Accumulated Amortization	-2,048	-1,758
Trade Name [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Weighted Average Amortization Period (in years)	'1 year 11 days	'
Gross Carrying Amount	878	575
Accumulated Amortization	-503	-455
Patents [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Weighted Average Amortization Period (in years)	'5 years 10 months 24 days	'
Gross Carrying Amount	180	180
Accumulated Amortization	-72	-68
Total Other Definite-Lived Intangible Assets [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	12,941	9,715
Accumulated Amortization	($7,239)	($6,776)

Intangible_Assets_and_Goodwill3

Intangible Assets and Goodwill - Additional Information (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Nov. 30, 2013
Finite-Lived Intangible Assets [Line Items]	'	'	'
Purchase price of intangible assets	$403	'	'
Impairment charges	163	'	'
Amortization expenses of intangible assets	1,883	1,794	'
Intangible assets contractual term expiration date	31-Dec-14	'	'
Intangible asset estimated useful lives	'3 years 2 months 12 days	'	'
Estimated amortization, 2014	6,879	'	'
Estimated amortization, 2015	6,793	'	'
Estimated amortization, 2016	5,023	'	'
Estimated amortization, 2017	3,405	'	'
Estimated amortization, 2018	996	'	'
Estimated amortization, thereafter	2,088	'	'
Percentage of market capitalization exceeds the consolidated net assets	100.00%	'	'
Percentage excess of fair value of reporting unit over its book value of its net assets	'	'	50.00%
Maximum [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Intangible asset estimated useful lives	'10 years	'	'
Minimum [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Intangible asset estimated useful lives	'1 year	'	'
Developed Technology [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Amortization expenses of intangible assets	351	139	'
Intangible asset estimated useful lives	'1 year 2 months 27 days	'	'
Customer Contracts [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Amortization expenses of intangible assets	$240	'	'
Intangible asset estimated useful lives	'2 years 9 months 22 days	'	'

Intangible_Assets_and_Goodwill4

Intangible Assets and Goodwill - Schedule of Change in Carrying Amount of Goodwill (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014
Goodwill And Intangible Assets Disclosure [Abstract]	'
Balance at December 31, 2013	$77,104
Acquisitions (Note 2)	17,249
Foreign currency translation	616
Balance at March 31, 2014	$94,969

Net_Loss_Per_Share_Reconciliat

Net Loss Per Share - Reconciliation of Basic and Diluted Share Amounts (Detail)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'
Basic weighted average common shares outstanding	27,924	27,367
Weighted average common stock equivalents	'	'
Diluted weighted average common shares outstanding	27,924	27,367
Stock Options [Member]	'	'
Weighted average anti-dilutive shares related to:	'	'
Weighted average anti-dilutive shares	895	1,250
Nonvested Restricted Shares [Member]	'	'
Weighted average anti-dilutive shares related to:	'	'
Weighted average anti-dilutive shares	2,138	2,189
Restricted Stock Units [Member]	'	'
Weighted average anti-dilutive shares related to:	'	'
Weighted average anti-dilutive shares	18	81
Escrow Shares [Member]	'	'
Weighted average anti-dilutive shares related to:	'	'
Weighted average anti-dilutive shares	'	64

Net_Loss_Per_Share_Additional_

Net Loss Per Share - Additional Information (Detail)	0 Months Ended	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2014
		M2M Communications Corporation [Member]
Dilutive Securities Included And Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'
Number of common stock, shares released from escrow	0	'
Shares to be issued related to deferred consideration arrangement related to a business combination	'	254,654

Fair_Value_Measurements_Assets

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Assets:	'	'
Money market funds	$88,611	$146,626
Liabilities:	'	'
Accrued contingent purchase price consideration	399	'
Deferred acquisition consideration	572	566
Fair Value Measurement, Recurring [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]	'	'
Assets:	'	'
Money market funds	88,611	146,626
Liabilities:	'	'
Accrued contingent purchase price consideration	'	'
Deferred acquisition consideration	'	'
Fair Value Measurement, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]	'	'
Assets:	'	'
Money market funds	'	'
Liabilities:	'	'
Accrued contingent purchase price consideration	'	'
Deferred acquisition consideration	'	'
Fair Value Measurement, Recurring [Member] | Unobservable Inputs (Level 3) [Member]	'	'
Assets:	'	'
Money market funds	'	'
Liabilities:	'	'
Accrued contingent purchase price consideration	399	'
Deferred acquisition consideration	$572	$566

Fair_Value_Measurements_Assets1

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Parenthetical) (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Money market funds	$88,611	$146,626	'
Increase in fair value of liabilities	10	33	'
Time value of money before increase in fair value	6	'	30
Cash and Cash Equivalents [Member]	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Money market funds	88,431	145,076	'
Restricted Cash [Member]	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Money market funds	$180	$1,550	'

Financing_Arrangements_Additio

Financing Arrangements - Additional Information (Detail) (USD $)	3 Months Ended		0 Months Ended	3 Months Ended		3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2014	Apr. 18, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2012	Mar. 31, 2012	Mar. 31, 2014
		Credit Facility 2013 [Member]	Credit Facility 2013 [Member]	Credit Facility 2013 [Member]	Credit Facility 2013 [Member]	2013 Credit Facility [Member]	Credit Facility 2012 [Member]	Credit Facility 2012 [Member]	Swing Lines Loan [Member]
			Silicon Valley Bank [Member]	Silicon Valley Bank [Member]	Revolving Credit Facility [Member]			Silicon Valley Bank [Member]	Silicon Valley Bank [Member]
Line of Credit Facility [Line Items]	'	'	'	'	'	'	'	'	'
Borrowing limit	'	'	$70,000	'	$22,000	'	'	$50,000	$5,000
2013 Credit facility, termination date	'	'	'	'	'	18-Apr-15	12-Apr-13	'	'
Length of credit facility	'	'	'2 years	'	'	'	'	'	'
Maximum potential borrowing limit	'	'	100,000	'	'	'	'	'	'
Percentage of letter of credit fee-Minimum	'	'	'	2.00%	'	'	'	'	'
Interest rate description on term loan	'	'	'	'(i) the Eurodollar Rate with respect to the relevant interest period plus 2.00% per annum or (ii) the ABR (defined as the highest of (x) the "prime rate" as quoted in the Wall Street Journal , and (y) the Federal Funds Effective Rate plus 0.50%) plus 1.00%	'	'	'	'	'
Interest on Federal Funds	0.50%	'	'	'	'	'	'	'	'
Additional interest on Federal Funds	1.00%	'	'	'	'	'	'	'	'
Percentage of letter of credit fee	'	2.00%	'	'	'	'	'	'	'
Percentage of letters of credit outstanding collateralized by the Company	'	105.00%	'	'	'	105.00%	'	'	'
Financing cost incurred by the Company	'	'	'	'	'	859	'	'	'
Total outstanding letters of credit	'	46,213	'	'	'	'	'	'	'
Borrowing under letter of credit	0	'	'	'	'	'	'	'	'
Issuances of additional letters of credit	'	23,787	'	'	'	'	'	'	'
Unrestricted cash	'	$4,500	'	'	'	'	'	'	'

Commitments_and_Contingencies_1

Commitments and Contingencies - Additional Information (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Other Commitments [Line Items]	'	'
Asset retirement obligation	$410	'
Lease term	'2019-09	'
Lease commencement date	1-Apr-14	'
Terms for future minimum lease payments	'More than one year	'
Deferred rent liability	6,343	6,729
Restricted cash to secure insurance commitments	1,197	1,834
Performance guarantees	46,512	'
Restricted cash utilized to collateralize	180	'
Deposits held by certain customers	119	'
Estimated termination penalty	7,967	'
Deferred fees	2,593	'
Accrued performance adjustments	539	1,720
Period of warranty	'One year	'
Payment due upon termination	1,026	'
Contractual Obligations Settlement Transactions [Member]	'	'
Other Commitments [Line Items]	'	'
Revenues	3,771	'
Credit Facility 2013 [Member]	'	'
Other Commitments [Line Items]	'	'
Contingent liability under outstanding letters of credit	46,213	'
Electric power grid [Member]	'	'
Other Commitments [Line Items]	'	'
Repayment to electric power grid operator	$1,370	'

Commitments_and_Contingencies_2

Commitments and Contingencies - Future Minimum Lease Payments for Operating Leases (Detail) (USD $)	Mar. 31, 2014
In Thousands, unless otherwise specified
Commitments And Contingencies Disclosure [Abstract]	'
Remainder of 2014	$4,205
2015	5,622
2016	5,445
2017	5,437
2018	5,569
Thereafter	7,517
Total minimum lease payments (not reduced by sublease rentals of $191)	$33,795

Commitments_and_Contingencies_3

Commitments and Contingencies - Future Minimum Lease Payments for Operating Leases (Parenthetical) (Detail) (USD $)	Mar. 31, 2014
In Thousands, unless otherwise specified
Commitments And Contingencies Disclosure [Abstract]	'
Sublease rental not reduced from lease payments	$191

Stockholders_Equity_Additional

Stockholders' Equity - Additional Information (Detail) (USD $)

0 Months Ended

3 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

Aug. 06, 2013

28-May-13

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Restricted Stock and Restricted Stock Units [Member]

Restricted Stock Performance-Based Vesting Awards Probable Vesting [Member]

Restricted Stock Performance-Based Vesting Awards Not Probable Vesting [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Plan 2007 [Member]

Management [Member]

Advisors [Member]

Advisors [Member]

Advisors [Member]

Ratably Vesting [Member]

Tranche [Member]

Stockholders Equity [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Authorized repurchase of common stock

$30,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Total repurchase of common stock

'

'

0

'

'

'

'

'

'

'

'

'

'

'

Common stock available for repurchase

'

'

20,545,000

'

'

'

'

'

'

'

'

'

'

'

Common stock repurchased, shares

'

'

169,176

'

'

'

'

'

'

'

'

'

'

'

Common stock issued to executives

'

'

6,632

8,920

'

'

'

'

'

'

'

'

'

'

Annual increase to shares available for issuance under share-based compensation plan per accordance with provisions of such share-based compensation plan

'

'

'

'Equal to the lesser of 520,000 shares

'

'

'

'

'

'

'

'

'

'

Current fiscal year increase to shares available for issuance under share-based compensation plan per accordance with provisions of such share-based compensation plan

'

'

'

520,000

'

'

'

'

'

'

'

'

'

'

Remaining shares available for issuance under share-based compensation plan through the end of the expiration of such share-based compensation plan based on the amended shared-based compensation plan

'

2,500,000

'

'

'

'

'

'

'

'

'

'

'

'

Shares available under future grant under 2007 plan

'

'

'

'

'

'

'

'

'

'

'

'

'

2,329,080

Dividends paid to common stock

'

'

0

'

'

'

'

'

'

'

'

'

'

'

Material income tax benefit from share-based compensation

'

'

0

0

'

'

'

'

'

'

'

'

'

'

Material compensation cost capitalized

'

'

0

0

'

'

'

'

'

'

'

'

'

'

Stock options outstanding held by employees

'

'

828,512

'

'

'

'

'

'

'

'

'

'

'

Stock options outstanding held by non-employees

'

'

8,493

'

'

'

'

'

'

'

'

'

'

'

Nonvested stock-based compensation expense related to employees

'

'

195,000

'

15,266,000

10,773,000

0

'

'

'

'

'

'

'

Weighted average period of stock options

'

'

'1 year 3 months 18 days

'

'2 years 9 months 18 days

'2 years

'

'

'

'

'

'

'

'

Vesting period restricted stock Restricted stock awards and Restricted stock unit awards

'

'

'

'

'

'

'

'4 years

'

'3 years

'

'4 years

'

'

Stock options vesting, description

'

'

'

'

'

'

'

'25% cliff vesting after one year and the remaining 75% vesting ratably quarterly thereafter

'

'

'

'

'

'

Restricted stock granted to non-executive employees

'

'

'

'

'

'

'

4,500

'

'

'

'

'

'

Restricted stock granted to board of directors

'

'

'

'

'

'

'

31,365

'

'

'

'

'

'

Total number of shares of restricted stock granted during the period

'

'

'

'

'

'

'

491,899

981,841

'

33,000

22,000

11,000

'

Stock-based compensation expense

'

'

4,227,000

4,704,000

'

'

'

88,000

'

'

'

'

'

'

Unvested shares

'

'

'

'

'

'

'

28,875

'

'

'

'

'

'

Fair value of share-based award

'

'

'

'

'

'

'

$643,000

'

'

'

'

'

'

Non-vested restricted stock

'

'

'

'

'

'

'

'

'

388,034

'

'

'

'

Percentage of shares vest in 2015, based on operating result

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

Remaining nonvested restricted shares vested

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

Nonvested restricted shares forfeited based on operating results not achieved

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

Stockholders_Equity_Weighted_A

Stockholders' Equity - Weighted Average Assumptions Used to Estimate Fair Value of Stock Options (Detail)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Equity [Abstract]	'	'
Risk-free interest rate	2.67%	1.90%
Vesting term, in years	'2 years 2 months 19 days	'2 years 2 months 19 days
Expected annual volatility	72.00%	75.00%
Expected dividend yield	'	'
Exit rate pre-vesting	7.80%	7.70%
Exit rate post-vesting	14.06%	14.06%

Stockholders_Equity_Components

Stockholders' Equity - Components of Stock-Based Compensation Expense (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Stock-based compensation expense	$4,227	$4,704
Stock Options [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Stock-based compensation expense	186	399
Restricted Stock and Restricted Stock Units Awards [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Stock-based compensation expense	$4,041	$4,305

Stockholders_Equity_Components1

Stockholders' Equity - Components of Stock-Based Compensation Expense (Parenthetical) (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Stock-based compensation expense	$4,227	$4,704
Chief Executive Officer [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Stock-based compensation expense	$125	'

Stockholders_Equity_StockBased

Stockholders' Equity - Stock-Based Compensation (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'
Stock-based compensation	$4,227	$4,704
Selling and Marketing Expenses [Member]	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'
Stock-based compensation	1,193	1,390
General and Administrative Expenses [Member]	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'
Stock-based compensation	2,696	2,952
Research and Development Expenses [Member]	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'
Stock-based compensation	$338	$362

Stockholders_Equity_Summary_of

Stockholders' Equity - Summary of Company's Stock Option Activity (Detail) (USD $)	3 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Equity [Abstract]	'	'	'
Number of Shares Underlying Options Outstanding, Beginning of period	960,742	'	'
Number of Shares Underlying Options, Granted	1,809	1,000	'
Number of Shares Underlying Options, Exercised	-51,237	'	'
Number of Shares Underlying Options, Cancelled	-74,309	'	'
Number of Shares Underlying Options Outstanding, End of period	837,005	'	960,742
Number of Shares Underlying Options, Exercisable at end of period	814,852	'	'
Number of Shares Underlying Options, Vested or expected to vest at March 31, 2014	835,658	'	'
Exercise Price Per Share Minimum, Beginning of period	$0.35	'	$0.17
Exercise Price Per Share Minimum, End of period	$0.35	'	$0.17
Exercise Price Per Share Maximum, Beginning of period	$48.06	'	$48.06
Exercise Price Per Share Maximum, End of period	$48.06	'	$48.06
Exercise Price Per Share Minimum, Exercisable at end of period	$0.35	'	'
Exercise Price Per Share Maximum, Exercisable at end of period	$48.06	'	'
Exercise Price Per Share Minimum, Vested or expected to vest March 31, 2014	$0.35	'	'
Exercise Price Per Share Maximum, Vested or expected to vest at March 31, 2014	$48.06	'	'
Weighted-Average Exercise Price Per Share, Beginning of period	$17.87	'	'
Weighted-Average Exercise Price Per Share, Granted	$21.09	'	'
Weighted-Average Exercise Price Per Share, Exercised	$10.26	'	'
Weighted-Average Exercise Price Per Share, Cancelled	$29.47	'	'
Weighted-Average Exercise Price Per Share, End of period	$17.32	'	$17.87
Weighted-Average Exercise Price Per Share, Exercisable at end of period	$17.28	'	'
Weighted-Average Exercise Price Per Share, Vested or expected to vest at March 31, 2014	$17.32	'	'
Aggregate Intrinsic Value, Beginning of period	$4,691	'	'
Aggregate Intrinsic Value, Exercised	592	553	'
Aggregate Intrinsic Value, End of period	6,817	'	4,691
Aggregate Intrinsic Value, Exercisable at end of period	6,695	'	'
Aggregate Intrinsic Value, Vested or expected to vest at March 31, 2014	$6,807	'	'

Stockholders_Equity_Summary_of1

Stockholders' Equity - Summary of Company's Stock Option Activity (Parenthetical) (Detail) (USD $)	3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013
Equity [Abstract]	'	'
Weighted average remaining contractual life Exercisable at end of period	'3 years 1 month 6 days	'
Weighted average remaining contractual life Vested or expected to vest	'3 years	'
Estimated forfeiture rate	7.80%	'
Fair value of common stock	$22.28	$17.21

Stockholders_Equity_Stock_Opti

Stockholders' Equity - Stock Options Activity Additional Information (Detail) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Equity [Abstract]	'	'
Total number of options granted during the period	1,809	1,000
Weighted-average fair value per share of options granted	$11.69	$10.08
Total intrinsic value of options exercised	$592	$553

Stockholders_Equity_Summary_of2

Stockholders' Equity - Summary of Company's Restricted Stock Activity (Detail) (Restricted Stock [Member], USD $)	3 Months Ended
	Mar. 31, 2014
Restricted Stock [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Nonvested Number of Shares, Beginning balance	2,395,322
Granted, Number of Shares	491,899
Vested, Number of Shares	-694,401
Cancelled, Number of Shares	-86,385
Nonvested Number of Shares, Ending balance	2,106,435
Nonvested, Weighted Average Grant Date Fair Value Per Share, Beginning balance	$13.48
Granted, Weighted Average Grant Date Fair Value Per Share	$20.94
Vested, Weighted Average Grant Date Fair Value Per Share	$13.64
Cancelled, Weighted Average Grant Date Fair Value Per Share	$10.01
Nonvested, Weighted Average Grant Date Fair Value Per Share, Ending balance	$15.84

Stockholders_Equity_Additional1

Stockholders' Equity - Additional Information about Restricted Stock (Detail) (Restricted Stock [Member], USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Restricted Stock [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Total number of shares of restricted stock granted during the period	491,899	981,841
Weighted average fair value per share of restricted stock granted	$20.94	$16.71
Total number of shares of restricted stock vested during the period	694,401	577,293
Total fair value of shares of restricted stock vested during the period	$15,103	$5,706

Stockholders_Equity_Summary_of3

Stockholders' Equity - Summary of Company's Restricted Stock Unit Activity (Detail) (Restricted Stock Units [Member], USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Restricted Stock Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Nonvested Number of Shares, Beginning balance	34,250	'
Granted, Number of Shares	'	'
Vested, Number of Shares	-34,250	-53,478
Cancelled, Number of Shares	'	'
Nonvested, Weighted Average Grant Date Fair Value Per Share, Beginning balance	$28.59	'
Granted, Weighted Average Grant Date Fair Value Per Share	'	'
Vested, Weighted Average Grant Date Fair Value Per Share	$28.59	'
Cancelled, Weighted Average Grant Date Fair Value Per Share	'	'
Nonvested, Weighted Average Grant Date Fair Value Per Share, Ending balance	'	'

Stockholders_Equity_Additional2

Stockholders' Equity - Additional Information about Restricted Stock Units (Detail) (Restricted Stock Units [Member], USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Restricted Stock Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Total number of shares of restricted stock units vested during the period	34,250	53,478
Total fair value of shares of restricted stock units vested during the period	$772	$911

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014
Income Tax Disclosure [Abstract]	'
Worldwide tax benefit	$425

Concentrations_of_Credit_Risk_1

Concentrations of Credit Risk - Additional Information (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013
In Thousands, unless otherwise specified
Concentration Risk [Line Items]	'	'	'
Percentage of revenues threshold to determine major customer status	10.00%	'	10.00%
Deposits held by customers	$119	$128	'
Accounts Receivable [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Share in accounts receivable from major customers	10.00%	10.00%	'
PJM [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Unbilled revenue	26,465	64,643	'
PJM [Member] | Accounts Receivable [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Share in accounts receivable from major customers	51.00%	39.00%	'
Other Customers [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Unbilled revenue	$0	$0	'
Southern California Edison Company [Member] | Accounts Receivable [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Share in accounts receivable from major customers	'	18.00%	'

Concentrations_of_Credit_Risk_2

Concentrations of Credit Risk - Concentrations of Credit Risk of Significant Customers (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Concentration Risk [Line Items]	'	'
Revenues	$52,508	$32,850
PJM [Member]	'	'
Concentration Risk [Line Items]	'	'
Revenues	18,218	'
% of Total Revenues	35.00%	'
ISO-NE [Member]	'	'
Concentration Risk [Line Items]	'	'
Revenues	'	4,761
% of Total Revenues	'	14.00%
TVA [Member]	'	'
Concentration Risk [Line Items]	'	'
Revenues	'	$3,416
% of Total Revenues	'	10.00%

Concentrations_of_Credit_Risk_3

Concentrations of Credit Risk - Concentrations of Credit Risk of Significant Customers (Parenthetical) (Detail) (Revenue [Member])	3 Months Ended
	Mar. 31, 2014
Revenue [Member]	'
Concentration Risk [Line Items]	'
Benchmark percentage, revenues	10.00%

Assets_and_Liabilities_Held_fo2

Assets and Liabilities Held for Sale - Summary of Assets and Liabilities Held for Sale (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Summary Of Assets And Liabilities Held For Sale [Line Items]	'	'
Intangible assets held-for-sale	$681	'
Total Liabilities Held for Sale	521	521
Deferred Tax Liability [Member]	'	'
Summary Of Assets And Liabilities Held For Sale [Line Items]	'	'
Total Liabilities Held for Sale	521	'
Customer Relationships [Member]	'	'
Summary Of Assets And Liabilities Held For Sale [Line Items]	'	'
Intangible assets held-for-sale	153	'
Total Other Definite-Lived Intangible Assets [Member]	'	'
Summary Of Assets And Liabilities Held For Sale [Line Items]	'	'
Intangible assets held-for-sale	39	'
Goodwill [Member]	'	'
Summary Of Assets And Liabilities Held For Sale [Line Items]	'	'
Intangible assets held-for-sale	$489	'

Assets_and_Liabilities_Held_fo3

Assets and Liabilities Held for Sale - Additional Information (Detail) (USD $)	3 Months Ended	0 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Apr. 16, 2014
		Subsequent Event [Member]
Summary Of Assets And Liabilities Held For Sale [Line Items]	'	'
Company entered into an agreement	16-Apr-14	'
Sale of utility solutions consulting services	'	$4,750
Potential gain upon sale	'	2,275
Potential gain may be either reduced or deferred	'	$500