Quarterly Report (10-q)

Share Name	Share Symbol	Market	Type
Enernoc, Inc. (MM)	NASDAQ:ENOC	NASDAQ	Common Stock

	Price Change	% Change	Share Price	Bid Price	Offer Price	High Price	Low Price	Open Price	Shares Traded	Last Trade
	0.00	0.00%	7.65	7.65	7.70				0	00:00:00

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

(Mark One)



ý	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2017



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 001-33471

EnerNOC, Inc.

(Exact Name of Registrant as Specified in Its Charter)



Delaware	87-0698303
(State or Other Jurisdiction of Incorporation or Organization)	(IRS Employer Identification No.)



One Marina Park Drive Suite 400 Boston, Massachusetts	02210
(Address of Principal Executive Offices)	(Zip Code)

(617) 224-9900

(Registrant’s Telephone Number, Including Area Code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one):



Large accelerated filer	¨		Accelerated filer	ý
Non-accelerated filer	¨	(Do not check if a smaller reporting company)	Smaller reporting company	¨
Emerging growth company	¨	if an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13 (a) of the exchange act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No ý

There were 31,349,069 shares of the registrant’s common stock, $0.001 par value per share, outstanding as of August 4, 2017 .

EnerNOC, Inc.

FORM 10-Q

For the Quarterly Period Ended June 30, 2017

TABLE OF CONTENTS



		Page
Part I - Financial Information
Item 1.	Financial Statements
	Unaudited Condensed Consolidated Balance Sheets at June 30, 2017 and December 31, 2016	3
	Unaudited Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2017 and 2016	4
	Unaudited Condensed Consolidated Statements of Comprehensive Loss for the three and six months ended June 30, 2017 and 2016	5
	Unaudited Condensed Consolidated Statements of Cash Flows for the six months ended June 30, 2017 and 2016	6
	Notes to Unaudited Condensed Consolidated Financial Statements	7
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	36
Item 4.	Controls and Procedures	37
Part II - Other Information
Item 1.	Legal Proceedings	38
Item 1A	Risk Factors	38
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	39
Item 6.	Exhibits	40
	Signatures	41

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

EnerNOC, Inc.

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except par value and share data)



	June 30, 2017			December 31, 2016
ASSETS
Current assets:
Cash and cash equivalents	$	66,157		$	97,993
Restricted cash	441			1,062
Accounts receivable, net of allowance for doubtful accounts of $736 and $1,082 at June 30, 2017 and December 31, 2016, respectively.	26,957			36,722
Unbilled receivables	892			45,430
Contract assets	43,256			—
Capitalized fulfillment costs	1,345			2,290
Prepaid expenses and other current assets	15,606			10,906
Assets held for sale	—			3,415
Total current assets	154,654			197,818
Contract assets, net of current portion	15,795			—
Property and equipment, net of accumulated depreciation of $99,167 and $97,243 at June 30, 2017 and December 31, 2016	34,530			38,828
Goodwill	31,364			36,662
Intangible assets, net of accumulated amortization	32,003			35,771
Deposits and other assets	5,403			3,223
Total assets	$	273,749		$	312,302
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	1,797		$	4,748
Accrued capacity payments	45,410			63,943
Accrued compensation and related expenses	11,861			14,721
Accrued expenses and other current liabilities	15,908			13,597
Deferred revenue	5,127			8,193
Liabilities held for sale	—			1,780
Total current liabilities	80,103			106,982
Deferred revenue	3,544			2,665
Other liabilities	8,461			7,521
Convertible senior notes	117,290			115,223
Commitments and contingencies (Note 9)	—			—
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, 31,383,107 and 30,688,783 shares issued and outstanding at June 30, 2017 and December 31, 2016, respectively	31			31
Additional paid-in capital	390,844			386,871
Accumulated other comprehensive loss	(5,246		)	(2,477		)
Accumulated deficit	(322,228		)	(304,745		)
Total EnerNOC, Inc. stockholders’ equity	63,401			79,680
Noncontrolling interest	950			231
Total stockholders’ equity	64,351			79,911
Total liabilities and stockholders’ equity	$	273,749		$	312,302

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

EnerNOC, Inc.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except share and per share data)



	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2017			2016			2017			2016
Revenues:
Demand Response	$	54,196		$	116,462		$	88,680		$	152,809
Software	12,485			16,232			26,110			33,265
Total revenues	66,681			132,694			114,790			186,074
Cost of revenues	47,229			81,531			80,632			114,125
Gross profit	19,452			51,163			34,158			71,949
Operating expenses:
Selling and marketing	14,308			25,517			28,182			50,532
General and administrative	18,182			27,441			37,802			55,357
Research and development	5,203			7,634			10,605			15,677
Loss (gain) on sale of businesses (Note 4)	210			(17,376		)	(1,516		)	(17,376		)
Restructuring charges (Note 5)	—			3,694			—			3,694
Goodwill impairment (Note 6)	—			—			5,886			—
Total operating expenses	37,903			46,910			80,959			107,884
(Loss) income from operations	(18,451		)	4,253			(46,801		)	(35,935		)
Other income (loss), net	1,686			(3,421		)	3,661			(334		)
Interest expense	(1,927		)	(1,844		)	(3,853		)	(3,621		)
Loss before income tax	(18,692		)	(1,012		)	(46,993		)	(39,890		)
(Provision for) benefit from income tax	(6		)	1,109			(3,844		)	(582		)
Net (loss) income	(18,698		)	97			(50,837		)	(40,472		)
Net loss attributable to noncontrolling interest	(326		)	(5		)	(455		)	(36		)
Net (loss) income attributable to EnerNOC, Inc.	$	(18,372	)	$	102		$	(50,382	)	$	(40,436	)
Net (loss) income attributable to EnerNOC, Inc. per common share
Basic	$	(0.61	)	$0.00			$	(1.69	)	$	(1.40	)
Diluted	$	(0.61	)	$0.00			$	(1.69	)	$	(1.40	)
Weighted average number of common shares used in computing net loss per common share
Basic	29,918,229			29,114,200			29,834,253			28,962,021
Diluted	29,918,229			29,569,321			29,834,253			28,962,021

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

EnerNOC, Inc.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(in thousands)



	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2017			2016			2017			2016
Net (loss) income	$	(18,698	)	$	97		$	(50,837	)	$	(40,472	)
Foreign currency translation adjustments	(978		)	1,373			(421		)	1,756
Reclassification of cumulative translation adjustments due to liquidation of a foreign entity (Note 4)	—			—			(2,348		)	—
Comprehensive (loss) income	(19,676		)	1,470			(53,606		)	(38,716		)
Comprehensive loss attributable to noncontrolling interest	(331		)	(5		)	(456		)	(36		)
Comprehensive (loss) income attributable to EnerNOC, Inc.	$	(19,345	)	$	1,475		$	(53,150	)	$	(38,680	)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

EnerNOC, Inc.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)



	Six Months Ended
	June 30,
	2017			2016
Cash flows from operating activities
Net loss	$	(50,837	)	$	(40,472	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, amortization and impairment of long-lived assets	14,228			20,964
Goodwill impairment charge	5,886			—
Stock-based compensation	4,841			6,784
Gains on sale of businesses	(1,516		)	(17,376		)
Net foreign exchange translation loss (gain)	(2,703		)	(582		)
Non-cash interest expense	2,137			1,986
Other, net	131			1,266
Changes in operating assets and liabilities, net of effects of divestitures:
Accounts receivable, unbilled receivables and contract assets	31,433			68,859
Prepaid expenses and other assets	(481		)	(5,449		)
Capitalized fulfillment costs	(2,106		)	27,068
Other noncurrent liabilities	(1,856		)	(595		)
Deferred revenue	(916		)	(37,401		)
Accrued capacity payments	(20,903		)	(57,362		)
Accounts payable, accrued expenses and other current liabilities and accrued compensation	(6,188		)	(14,485		)
Net cash used in operating activities	(28,850		)	(46,795		)
Cash flows from investing activities
Purchases of property and equipment and capitalization of internal use software development costs	(6,435		)	(9,111		)
Proceeds from sale of businesses, net of divested cash	1,271			13,157
Proceeds from sale of fixed assets	330			—
Change in deposits	(8		)	363
Net cash (used in) provided by investing activities	(4,842		)	4,409
Cash flows from financing activities
Proceeds from exercises of stock options	1			8
Payments made for employee restricted stock minimum tax withholdings and other	(1,056		)	(1,504		)
Payments for contingent consideration	—			(195		)
Proceeds from sale of equity interests to non-controlling interest holders	1,173			—
Net cash provided by (used in) financing activities	118			(1,691		)
Effects of exchange rate changes on cash, cash equivalents and restricted cash	1,117			1,159
Net change in cash, cash equivalents and restricted cash	(32,457		)	(42,918		)
Cash, cash equivalents and restricted cash at beginning of period	99,055			138,584
Cash, cash equivalents and restricted cash at end of period	$	66,598		$	95,666
Supplemental disclosure of cash flow information
Cash paid for interest	$	2,187		$	1,668
Cash paid for income taxes	$	882		$	2,002
Non-cash investing and financing activities:
Acquisition of property and equipment in accrued expenses	$	855		$	271
Cash, cash equivalent and restricted cash information:
Cash and cash equivalents at beginning of period	$	97,993		$	138,120
Restricted cash at beginning of period	1,062			464
Cash, cash equivalents and restricted cash at beginning of period	$	99,055		$	138,584
Cash and cash equivalents at end of period	$	66,157		$	95,123
Restricted cash at end of period	441			543
Cash, cash equivalents and restricted cash at end of period	$	66,598		$	95,666

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

EnerNOC, Inc.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(in thousands, except share and per share data)

1. Description of Business and Basis of Presentation

Description of Business

EnerNOC, Inc. (the Company) is a leading provider of demand response solutions and energy intelligence software (EIS) to enterprises, utilities, and electric power grid operators.

The Company’s demand response solutions provide utilities and electric power grid operators with a managed service demand response resource that matches obligation in the form of megawatts (MW) that the Company agrees to deliver to utility customers and electric power grid operators, with supply, in the form of MW that are curtailed from the electric power grid through the Company's arrangements with commercial and industrial end-users of energy (C&I end-users). When called upon by utilities and electric power grid operators to deliver contracted capacity, the Company uses its global Network Operations Center (NOC) to remotely manage and reduce electricity consumption across its network of C&I end-user sites, making demand response capacity available to utilities and electric power grid operators on demand, while helping C&I end-users achieve energy savings, improve financial results and realize environmental benefits.

The Company’s EIS provides enterprises with a Software-as-a-Service (SaaS) energy management application that enables them to better manage and control energy costs for their organizations. The Company offers premium professional services that support the implementation of its EIS and help its enterprise customers set their energy management strategies. The Company's energy procurement solutions provide customers with the ability to more effectively manage their energy supplier selection and energy procurement process by providing highly structured auction events.

Sale of the Company

The Company entered into a definitive Agreement and Plan of Merger, dated as of June 21, 2017 (the Merger Agreement), with Enel Green Power North America, Inc., a Delaware corporation (Parent), Pine Merger Sub, Inc. a Delaware corporation and a wholly-owned subsidiary of Parent (Purchaser) and Enel S.p.A, an Italian joint-stock company and the parent of Parent. In accordance with the terms of the Merger Agreement, on July 10, 2017, Purchaser commenced a tender offer (the Offer) for all of the Company’s outstanding shares of common stock, par value $0.001 per share (the Shares), at a purchase price of $7.67 per Share, net to the seller in cash, without interest, less any applicable withholding taxes (the Offer Price).

The Offer expired at one minute after 11:59 p.m., New York City time on August 4, 2017, as scheduled, and was not extended. According to American Stock Transfer & Trust Company, LLC, the depositary for the Offer (the Depositary), a total of 22,207,831 Shares (excluding Shares with respect to which notices of guaranteed delivery were delivered, but the Shares represented thereby were not yet delivered) had been validly tendered and not validly withdrawn prior to the expiration of the Offer, which represented approximately 70.8% of the outstanding Shares as of such time. The condition to the Offer that at least one more than fifty percent of the total number of Shares then issued and outstanding be validly tendered and not withdrawn was satisfied and as a result, Purchaser accepted for payment all Shares that were validly tendered and not validly withdrawn, and payment for such Shares has been made to the Depositary. In accordance with the terms of the Offer, the Depositary will act as agent for tendering stockholders for the purpose of receiving payments for tendered Shares and transmitting such payments to tendering stockholders whose Shares have been accepted for payment. In addition, the Depository advised Parent and Purchaser that notices of guaranteed delivery had been delivered with respect to 239,928 additional Shares, representing approximately 0.8% of the outstanding Shares as of such time.

On August 7, 2017, Purchaser merged with and into the Company, with the Company surviving as a wholly owned subsidiary of Parent (the Merger). The Merger was governed by Section 251(h) of the General Corporation Law of the State of Delaware, with no stockholder vote required to consummate the Merger. At the effective time of the Merger, each Share then outstanding (other than Shares that are held by any stockholders who are entitled to and who properly demanded appraisal in connection with the Merger) was converted into the right to receive the Offer Price, except for Shares then owned by Purchaser or Parent and Shares held in treasury of the Company or by any of its wholly owned subsidiaries, which Shares were cancelled and retired and ceased to exist effective as of the Merger, and in exchange for which no consideration will be delivered.

The aggregate consideration paid by Purchaser in the Offer and Merger was approximately $250,000 , without giving effect to related transaction fees and expenses. The Parent provided Purchaser with sufficient funds to purchase all Shares validly tendered and not validly withdrawn and to pay for the acquisition of the remaining Shares in the Merger. Parent funded the payment from its general corporate funds on the terms and conditions previously disclosed in the Tender Offer Statement on Schedule TO filed by Parent and Purchaser with the Securities and Exchange Commission on July 10, 2017, as amended.

In connection with the Merger, the NASDAQ stock market (NASDAQ) filed a Form 25 on the Company’s behalf to provide notice to the SEC regarding the withdrawal of shares of the Company’s common stock from listing and to terminate the registration of such shares under Section 12(b) of the Exchange Act. Shares of the Company’s common stock were suspended

from trading on the NASDAQ Global Market prior to the opening of trading on August 7, 2017. The Company is in the process of filing with the SEC a certification on Form 15 under the Exchange Act, requesting the deregistration of its common stock and the suspension of its reporting obligations under Sections 13 and 15(d) of the Exchange Act. For additional information about the Merger Agreement see the Company’s Current Report on Form 8-K (No. 001-33471) filed with the SEC on June 23, 2017. For additional information regarding the Offer, see the Company’s Schedule 14D-9 (No. 005-83637) filed with the SEC on July 10, 2017.

Other than transaction expenses associated with the Offer and the Merger of $700 for the three and six months ended June 30, 2017, the terms of the Merger Agreement did not impact our condensed consolidated financial statements.

Reclassifications

In 2016, the Company adopted Accounting Standards Update (ASU) 2016-18, Restricted Cash and ASU 2016-15, Classification of Certain Cash Receipts and Cash Payments retrospectively. The Company adopted ASU 2016-18 by renaming the line item within cash flows from investing activities from "change in restricted cash and deposits" to "change in deposits" and restating the amounts in this line from $284 to $363 for the six months ended June 30, 2016 . This resulted in an increase in net cash used in investing activities of $79 , reflecting the reclassification of the change in restricted cash. As a result of the adoption of ASU 2016-15, the Company reclassified $840 of cash outflows previously presented within investing activities for the six months ended June 30, 2016 ; specifically, $195 and $645 were reclassified to financing and operating activity, respectively. In addition, the Company condensed certain lines on the condensed consolidated statements of cash flows for the six months ended June 30, 2016 . Therefore, the condensed consolidated statement of cash flows for the six months ended June 30, 2016 was reclassified to conform to the current period presentation.

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of the Company include the accounts of its wholly-owned subsidiaries and have been prepared in accordance with accounting principles generally accepted in the United States (GAAP) for interim financial information pursuant to Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. Intercompany transactions and balances are eliminated in consolidation. The Company owns 60% of EnerNOC Japan K.K., (ENOC Japan) and 67% of EnerNOC Taiwan Limited (ENOC Taiwan), which are each consolidated in accordance with Accounting Standards Codification (ASC) 810, Consolidation (ASC 810). The Company accounts for the remaining 40% and 33% ownership interests in these entities as a non-controlling interest on the consolidated financial statements.

Use of Estimates

The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the condensed consolidated financial statements and accompanying notes. Significant estimates made by management relate to revenue recognition, including determining the transaction price and associated constraint on variable consideration; allowance for doubtful accounts; the value of accrued liabilities associated with accrued capacity payments; the fair value of its reporting units; expected future cash flows used to evaluate the recoverability of long-lived assets; amortization methods and the useful lives of long-lived assets; the valuation of cost-method investments; the fair value of stock-based awards, which determines stock-based compensation; contingent liabilities; tax reserves and recoverability of net deferred tax assets and related valuation allowance. While the Company believes that such estimates are fair when considered in conjunction with the condensed consolidated financial statements taken as a whole, the actual amounts of such items, when known, could differ from these estimates.

Summary of Significant Accounting Policies

The Company’s significant accounting policies are described in Note 1, “Description of Business, Basis of Presentation and Summary of Significant Accounting Policies,” in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016 (2016 Form 10-K). Summarized below are the accounting pronouncements adopted subsequent to December 31, 2016.

In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) (ASU 2014-09). The Company adopted ASU 2014-09 and its related amendments (collectively known as ASC 606) effective on January 1, 2017 using the modified retrospective method. See Note 2 "Revenue from Contracts with Customers" for the required disclosures related to the impact of adopting this standard and a discussion of the Company's updated policies related to revenue recognition and accounting for costs to obtain and fulfill a customer contract.

On January 1, 2017, the Company adopted ASU 2017-04, Simplifying the Test for Goodwill Impairment (ASU 2017-04), which is effective for goodwill tests performed after January 1, 2017. ASU 2017-04 eliminates Step 2 from the goodwill impairment test and, alternatively, requires that an entity measure the impairment of goodwill assigned to a reporting unit as the amount in which the carrying value of assets and liabilities assigned to the reporting unit, including goodwill, exceed the reporting unit's fair value. See Note 6 "Goodwill and Intangible Assets" for further discussion of the Company's application of this standard in 2017.

On January 1, 2017, the Company adopted ASU 2017-05, Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets and ASC 610-20, Other Income-Gains and Losses from the Derecognition of Nonfinancial Assets , which was issued as part of ASC 606 in May 2014 and provides guidance for the recognition of gains and losses from the transfer of nonfinancial assets in contracts with noncustomers. The Company adopted this guidance using the modified retrospective method. The adoption of these updates did not have an impact on the condensed consolidated financial statements.

On January 1, 2017, the Company adopted ASU 2017-01, Clarifying the Definition of a Business , which clarifies the definition of a business for purposes of determining whether transactions should be accounted for as the acquisition or disposal of a business, and impacts all standards applicable to entities that meet the definition of a business. The Company applied this new guidance to a transaction completed in the first quarter of 2017 related to the sale of the its Energy Service Group operations, as discussed further in Note 4 "Gain on Sale of Businesses".

Effective January 1, 2017, the Company adopted ASU 2016-09, Improvements to Employee Share-Based Payment Accounting (ASU 2016-09) using the modified retrospective method. The adoption of ASU 2016-09 had no net impact on the Company's condensed consolidated financial statements. However, as a result of the adoption, the Company increased its deferred tax asset related to its net operating loss carryforwards related to previously deducted amounts for excess stock compensation. Under the previous guidance, such amounts could not be recognized until the amounts resulted in a reduction in the current tax liability. This increase was offset by an increase in the valuation allowance. ASU 2016-09 permits an entity to elect to record forfeitures of stock-based compensation as incurred or continue to estimate these forfeitures at grant date. The Company has elected to continue to estimate forfeitures under the current guidance.

2. Revenue from Contracts with Customers

The Company adopted ASC 606 on January 1, 2017 using the modified retrospective method for all contracts not completed as of the date of adoption. For contracts that were modified before the effective date, the Company reflected the aggregate effect of all modifications when identifying performance obligations and allocating transaction price in accordance with practical expedient ASC 606-10-65-1-(f)-4, which did not have a material effect on the adjustment to accumulated deficit. The reported results for 2017 reflect the application of ASC 606 guidance while the reported results for 2016 were prepared under the guidance of ASC 605, Revenue Recognition (ASC 605), which is also referred to herein as "legacy GAAP" or the "previous guidance". The adoption of ASC 606 represents a change in accounting principle that will more closely align revenue recognition with the delivery of the Company's services and will provide financial statement readers with enhanced disclosures. In accordance with ASC 606, revenue is recognized when a customer obtains control of promised services. The amount of revenue recognized reflects the consideration to which the Company expects to be entitled to receive in exchange for these services. To achieve this core principle, the Company applies the following five steps:


1)	Identify the contract with a customer

A contract with a customer exists when (i) the Company enters into an enforceable contract with a customer that defines each party’s rights regarding the services to be transferred and identifies the payment terms related to these services, (ii) the contract has commercial substance and, (iii) the Company determines that collection of substantially all consideration for services that are transferred is probable based on the customer’s intent and ability to pay the promised consideration. The Company applies judgment in determining the customer’s ability and intention to pay, which is based on a variety of factors including the customer’s historical payment experience or, in the case of a new customer, published credit and financial information pertaining to the customer.


2)	Identify the performance obligations in the contract

Performance obligations promised in a contract are identified based on the services that will be transferred to the customer that are both capable of being distinct, whereby the customer can benefit from the service either on its own or together with other resources that are readily available from third parties or from the Company, and are distinct in the context of the contract, whereby the transfer of the services is separately identifiable from other promises in the contract. To the extent a contract includes multiple promised services, the Company must apply judgment to determine whether promised services are capable of being distinct and distinct in the context of the contract. If these criteria are not met the promised services are accounted for as a combined performance obligation.


3)	Determine the transaction price

The transaction price is determined based on the consideration to which the Company will be entitled in exchange for transferring services to the customer. To the extent the transaction price includes variable consideration, the Company estimates the amount of variable consideration that should be included in the transaction price utilizing either the expected value method or the most likely amount method depending on the nature of the variable consideration. Variable consideration is included in the transaction price if, in the Company’s judgment, it is probable that a

significant future reversal of cumulative revenue under the contract will not occur. Determining the transaction price requires significant judgment, which is discussed by revenue category in further detail below.


4)	Allocate the transaction price to performance obligations in the contract

If the contract contains a single performance obligation, the entire transaction price is allocated to the single performance obligation. However, if a series of distinct services that are substantially the same qualifies as a single performance obligation in a contract with variable consideration, the Company must determine if the variable consideration is attributable to the entire contract or to a specific part of the contract. For example, a bonus or penalty may be associated with one or more, but not all, distinct services promised in a series of distinct services that forms part of a single performance obligation. Contracts that contain multiple performance obligations require an allocation of the transaction price to each performance obligation based on a relative standalone selling price basis unless the transaction price is variable and meets the criteria to be allocated entirely to a performance obligation or to a distinct service that forms part of a single performance obligation. The Company determines standalone selling price based on the price at which the performance obligation is sold separately. If the standalone selling price is not observable through past transactions, the Company estimates the standalone selling price taking into account available information such as market conditions and internally approved pricing guidelines related to the performance obligations.


5)	Recognize revenue when or as the Company satisfies a performance obligation

The Company satisfies performance obligations either over time or at a point in time as discussed in further detail below. Revenue is recognized at the time the related performance obligation is satisfied by transferring a promised service to a customer.

Disaggregation of Revenue

The following table summarizes revenue from contracts with customers for the three and six month periods ended June 30, 2017 :



	Three Months Ended June 30, 2017		Six Months Ended June 30, 2017
	Three Months Ended June 30, 2017		Six Months Ended June 30, 2017
Demand response	$	54,196	$	88,680
Procurement solutions	7,278		14,035
Subscription software	4,468		8,967
Professional services	739		3,108
Total Revenues	$	66,681	$	114,790

All of the Company's performance obligations, and associated revenue, are generally transferred to customers over time, with the exception of procurement solutions, which are generally transferred to the customer at a point in time.

Demand Response Solutions

The Company provides demand response solutions to grid operators and utility customers pursuant to contractual commitments over defined service delivery periods. These contracts typically include a single promise to stand ready, on a monthly basis, to deliver a set amount of curtailment (committed capacity) per month when and if called upon by the grid operator or utility. The Company has concluded this represents a series of distinct monthly services that are substantially the same, with the same pattern of transfer to the customer. Accordingly, the monthly promise to stand ready is accounted for as a single performance obligation. In order to provide this stand ready service, the Company utilizes a portfolio of C&I end-users that have the ability to curtail MW when called upon. The Company is the principal in these arrangements as it has control over the services prior to those services being transferred to the customer.

Capacity fees are paid to the Company by the grid operators and utilities for its stand ready commitment to curtail MWs and are typically based on the Company's ability to deliver the committed capacity throughout the contractual delivery period. In general, if the Company fails to curtail the contracted MW during energy or test dispatches, the MW shortfall results in a penalty that could require the Company to reduce, or in some cases refund, fees paid by the customer during the contract period. Depending on the contract, penalties are limited to the particular month in which the shortfall occurs, or they are applied retrospectively, prospectively, or both retrospectively and prospectively. Due to these penalty provisions, capacity fees represent variable consideration. Certain contracts also provide additional consideration in the form of energy fees for actual curtailment of MW during an emergency dispatch. As energy fees are only paid in the event of an emergency dispatch, these fees also represent variable consideration.

In order to determine the transaction price, the Company estimates the amount of variable consideration at the outset of the contract either utilizing the expected value or most likely amount method, depending on the facts and circumstances relative to the contract. These estimates consider i) the contractual rate per MW, ii) penalty rates iii) the maturity of the C&I portfolio, iv) historical performance and v) the probability of future dispatch events. The Company constrains (reduces) the estimates of

variable consideration such that it is probable that a significant reversal of previously recognized revenue will not occur throughout the life of the contract. When determining if variable consideration should be constrained, management considers whether there are factors outside the Company’s control that could result in a significant reversal of revenue. In making these assessments, the Company considers the likelihood and magnitude of a potential reversal of revenue. These estimates are re-assessed each reporting period as required. In the event of an emergency dispatch, any earned energy fees are associated and allocated to the specific month of performance, as these fees meet the criteria to allocate variable consideration to a distinct monthly service within a series of distinct services that comprise the single performance obligation. Therefore, energy fees are recognized in the month in which the Company is called upon to deliver on its stand-ready obligation to curtail capacity.

The Company has concluded that contracts that do not include retrospective and/or prospective penalty provisions generally meet the allocation of variable consideration exception criteria, with the variable consideration for these contracts allocated to each distinct month in the series within the contract. The Company has concluded that contracts that contain retrospective and/or prospective penalty provisions do not meet this exception. The Company believes that an output measure based on the monthly contractual MW stand-ready obligation is the best representation of the "transfer of value" to the customer. Accordingly, the Company recognizes monthly revenue based on the proportion of committed stand-ready capacity obligation that has been fulfilled to date.

Procurement Solutions

The Company operates an on-line auction platform that streamlines the competitive bidding process between energy suppliers and end-users of energy. Contracts are executed with an energy supplier that entitles the Company to a commission once an auction is complete. These contracts include a single promise, which is the facilitation of a procurement contract between an energy supplier and an end-user, which generally range from one to four years. This is deemed to be a single performance obligation, which is satisfied when an auction is completed, as the Company has no further obligations under the contract. The Company is the agent in this transaction as it does not have control over the energy being provided to the end-users prior to the good being transferred to the customer.

Consideration paid to the Company (by the energy supplier) is based on the end-user's energy consumption throughout the duration of the procured contract. The Company is only entitled to compensation if the energy supplier is paid by the end-user. As the consideration is dependent on energy consumption and payments made by the end-user, all consideration related to these contracts is variable. The Company estimates the amount of variable consideration to be included in the transaction price based on i) historical usage by the end-user, ii) contracted fees, iii) historical payment trends and iv) geographic trends throughout a class of similar end-users. The Company then constrains the variable consideration such that it is probable that a significant reversal of previously recognized revenue will not occur throughout the duration of the procurement contact.

In order to determine if variable consideration should be constrained, management considers whether there are factors outside the Company’s control that could result in a significant reversal of revenue. In making these assessments, the Company considers the likelihood and magnitude of a potential reversal of revenue. The revenue recorded upon the close of the auction is reflected as a contract asset that is realized over the contract period, subject to adjustments between actual usage and the original estimate.

Subscription Software and Services

The Company’s EIS provides a SaaS energy management application that enables the customer to address energy challenges, including energy cost visualization and budgeting, utility bill validation and payment, facility optimization, energy project tracking, reporting on sustainability and compliance, and peak energy demand and cost assessments. The Company generally offers these services under one to three year subscription agreements. These agreements typically include access to the SaaS platform, solution features and general support and maintenance. The Company has concluded that each promised service is delivered concurrently with all other promised service over the contract term and, as such, has concluded that these promises are a single performance obligation that includes a series of distinct services that have the same pattern of transfer to the customer.

Consideration for the Company’s subscription arrangements consist of fixed, variable and usage based fees. The Company invoices a portion of the fees at the outset of the contract and then monthly or quarterly thereafter. Advance non-refundable fees, which are deemed to be fixed, are not separate performance obligations and are recognized as the performance obligation in the customer contract is satisfied. Monthly subscription fees are generally based on the number of sites and the level of services selected by the customer. These fees are subject to the execution of predefined performance criteria, resulting in variable consideration. The Company has concluded the monthly promised services generally meet the allocation of variable consideration exception criteria, which permits the variable consideration to be allocated to each distinct month as the monthly services are delivered to the customer. In addition, certain fees are unit-based, calculated on the number of transactions processed monthly. Usage based fees are deemed to be variable consideration that meet the allocation exception for variable consideration as they are specific to the month that the usage occurs. Usage based fees are fully constrained until the related usage occurs.

The Company satisfies its performance obligation by providing access to its software-as-a-service over time, and processing transactions for usage based contracts. For non-usage based fees, the period of time over which the Company is performing is commensurate with the contract term because that is the period during which the Company has an obligation to provide the service. The performance obligation is recognized on time elapsed basis, by month for which the services are provided, once enablement/implementation is complete. For usage-based fees, revenue is recognized in the month in which the Company provides the usage to the customer.

Professional Services

The Company offers premium professional services that support the implementation of its EIS, including training and integration services, and professional service engagements to assist customers with their energy management strategy. These contracts generally have terms of one year or less. Services are either billed on a rate per hour or on a fixed monthly retainer basis. For the majority of these contacts, the Company has the right to invoice the customer in an amount that directly corresponds with the value to the customer of the Company's performance to date, the Company recognizes revenue based on the amount billable to the customer in accordance with practical expedient ASC 606-10-55-18. For other professional services contracts, the Company utilizes the input method and recognizes revenue based on labor hours expended to date relative to the total labor hours expected to be required to satisfy its performance obligation.

Contracts with Multiple Performance Obligations

The Company periodically enters into contracts, or multiple contracts at or near the same time, in which a customer may purchase a combination of EIS, procurement solutions, and/or professional services. These contracts include multiple promises that the Company evaluates to determine if the promises are separate performance obligations. Once the Company determines the performance obligations and the transaction price, including estimating the amount of variable consideration, the Company then allocates the transaction price to each performance obligation in the contract based on a relative stand-alone selling price method or using the variable consideration allocation exception if the required criteria are met. The corresponding revenues are recognized as the related performance obligations are satisfied as discussed in the revenue categories above.

Costs to Obtain and Fulfill a Contract

The Company capitalizes commission expenses paid to internal sales personnel that are incremental to obtaining customer contracts. These costs are deferred in “prepaid expenses and other current assets”, net of any long term portion included in “other noncurrent assets”. This requires an evaluation of whether the commissions are in fact incremental and would not have occurred absent the customer contract. Costs to obtain a contract are amortized as sales and marketing expense on a straight line basis over the expected period of benefit. These costs are periodically reviewed for impairment.

The Company capitalizes costs incurred to fulfill its contracts that i) relate directly to the contract ii) are expected to generate resources that will be used to satisfy the Company’s performance obligation under the contract and iii) are expected to be recovered through revenue generated under the contract. Contract fulfillment costs are expensed to cost of revenue as the Company satisfies its performance obligations. These costs, which are classified in "capitalized fulfillment costs" on the condensed consolidated balance sheets, principally relate to direct costs that enhance resources under the Company’s demand response contracts that will be used in satisfying future performance obligations.

Financial Statement Impact of Adopting ASC 606

The Company adopted ASC 606 using the modified retrospective method. The cumulative effect of applying the new guidance to all contracts with customers that were not completed as of January 1, 2017 was recorded as an adjustment to accumulated deficit as of the adoption date. As a result of applying the modified retrospective method to adopt the new revenue guidance, the following adjustments were made to the consolidated balance sheet as of January 1, 2017:



	As Reported			Adjustments												Adjusted
	December 31, 2016			Demand Response			Procurement			Professional Services & Other			Cost to Obtain or Fulfill a Contract			January 1, 2017
Cash, cash equivalent and restricted cash	$	99,055														$	99,055
Accounts receivable, net	36,722						$	(5,551	)							31,171
Unbilled receivables	45,430															45,430
Contract assets	—			$	1,719		23,359									25,078
Capitalized fulfillment costs	2,290			(1,613		)										677
Prepaid expenses and other current assets	14,321												$	2,007		16,328
Long lived assets	111,261															111,261
Other noncurrent assets	3,223												2,405			5,628
Contract assets, long term	—						16,206									16,206
Total assets	$	312,302		$	106		$	34,014		$	—		$	4,412		$	350,834
Accounts payable, accrued expenses, and other current liabilities	$	34,846											$	2,624		$	37,470
Accrued capacity payments	63,943			$	1,630											65,573
Deferred revenue, current	8,193			(2,089		)	$	(413	)	$	1,171					6,862
Deferred revenue, long term	2,665															2,665
Other noncurrent liabilities	7,521												2,710			10,231
Convertible senior notes	115,223															115,223
Total liabilities	232,391			(459		)	(413		)	1,171			5,334			238,024
Accumulated deficit	(304,745		)	565			34,427			(1,171		)	(922		)	(271,846		)
Additional paid-in capital, accumulated other comprehensive loss, and non-controlling interest	384,656															384,656
Total stockholders’ equity	79,911			565			34,427			(1,171		)	(922		)	112,810
Total liabilities and stockholders’ equity	$	312,302		$	106		$	34,014		$	—		$	4,412		$	350,834

Demand Response

Several of the Company's demand response contracts provide customers with a right of refund based on the Company's performance. Under the previous guidance, certain of these fees were not fixed or determinable and, as a result, the associated revenue was deferred until the completion of the contract. Under ASC 606, the Company estimates the variable consideration to be received and recognizes those amounts, subject to constraint, as the Company satisfies its performance obligation. In conjunction with the January 1, 2017 adoption of ASC 606, the Company adjusted accumulated deficit by $565 , reflecting the recognition of $3,808 of revenue and $3,243 of cost of revenues, for contracts that were not complete as of the date of adoption.

Procurement

Under the previous guidance, the fee for procurement services was not considered fixed or determinable until the associated energy usage occurred and, accordingly, revenue was recognized as the end-user consumed energy and fees became payable to the Company. Under ASC 606, the Company has satisfied its performance obligation upon completion of the auction, requiring the Company to estimate and recognize the variable consideration to be paid over the life of the contract, subject to constraint. In conjunction with the January 1, 2017 adoption of ASC 606, the Company reduced accumulated deficit by $34,427 , reflecting the revenue recognition for open contracts related to auctions completed prior to the adoption. Amounts recorded as accounts receivable under the previous guidance were reclassified to contract assets as the Company does not have an unconditional right to these amounts until the end-user utilizes energy and makes payment to the energy supplier. Please refer to Note 6 for further discussion of the indirect impact to goodwill as a result of the increased net assets of the Procurement reporting unit.

Professional Services and Other

Under the previous guidance, fees collected for training and integration services were deferred over the life of the corresponding subscription contract. Under ASC 606, these services are deemed distinct performance obligations and thus recognized as the Company satisfies its performance obligations. In addition, under ASC 605 certain multi-element contracts with resellers contained exclusivity clauses that the Company had recognized over the exclusivity term. Under ASC 606 the Company has determined exclusivity is not a distinct promised service. The net impact of these changes resulted in a $1,171 adjustment to accumulated deficit with an associated adjustment to deferred revenue.

Cost to Obtain a Customer Contract

Prior to the adoption of ASC 606, the Company expensed commissions paid to internal sales representatives for obtaining subscription software and professional service contracts. Under ASC 606, the Company currently capitalizes these incremental costs of obtaining customer contracts. In addition, commissions paid to external channel partners to secure procurement contracts were previously deferred and expensed upon cash receipt from energy suppliers, which closely aligned with the related pattern of revenue recognition. Under ASC 606, these commissions are estimated and recognized concurrently with the respective revenues upon successful completion of an auction. The net impact of these changes resulted in a $922 adjustment to accumulated deficit.

Income Taxes

The adoption of ASC 606 primarily resulted in an acceleration of revenue as of December 31, 2016, which in turn generated additional deferred tax liabilities that ultimately reduced the Company's net deferred tax asset position. As the Company fully reserves its net deferred tax assets in the jurisdictions impacted by the adoption of ASC 606, this impact was offset by a corresponding reduction to the valuation allowance.

Impact of New Revenue Guidance on Financial Statement Line Items

The following table compares the reported condensed consolidated balance sheet, statement of operations and cash flows, as of and for the six months ended June 30, 2017, to the pro-forma amounts had the previous guidance been in effect:



	As of June 30, 2017
Balance Sheet	As reported			Pro forma as if the previous accounting guidance was in effect
Cash, cash equivalent and restricted cash	$	66,598		$	66,598
Accounts receivable, net	26,957			37,880
Unbilled receivables	892			876
Contract assets	43,256			—
Capitalized fulfillment costs	1,345			1,745
Prepaid expenses and other current assets	15,606			13,550
Contract assets, long term	15,795			—
Long lived assets	97,897			97,897
Other noncurrent assets	5,403			3,849
Total assets	$	273,749		$	222,395
Accounts payable, accrued expenses, and other current liabilities	$	29,566		$	29,566
Accrued capacity payments	45,410			25,912
Deferred revenue, current	5,127			14,150
Deferred revenue, long term	3,544			1,691
Other noncurrent liabilities	8,461			6,036
Convertible senior notes	117,290			117,290
Total liabilities	209,398			194,645
Accumulated deficit	(322,228		)	(358,829		)
Additional paid-in capital, accumulated other comprehensive loss, and noncontrolling interest	386,579			386,579
Total stockholders’ equity	64,351			27,750
Total liabilities and stockholders’ equity	$	273,749		$	222,395

Total reported assets were $51,354 greater than the pro-forma balance sheet, which assumes the previous guidance remained in effect as of June 30, 2017. This was largely due to contract assets recognized in connection with the Company’s energy procurement services and capitalized cost to obtain contracts.

Total reported liabilities were $14,753 greater than the pro-forma balance sheet, which assumes the previous guidance remained in effect as of June 30, 2017. This was largely due to accrued fees due to procurement channel partners, partially offset by the ability to recognize certain deferred revenues associated with various demand response programs.



	Three Months Ended June 30, 2017						Six Months Ended June 30, 2017
Statement of Operations	As reported			Pro forma as if the previous accounting guidance was in effect			As reported			Pro forma as if the previous accounting guidance was in effect
Demand Response	$	54,196		$	32,789		$	88,680		$	65,985
Software	12,485			13,800			26,110			28,928
Total revenues	66,681			46,589			114,790			94,913
Cost of revenue	47,229			32,240			80,632			64,908
Gross profit	19,452			14,349			34,158			30,005
Selling and marketing	14,308			13,857			28,182			27,774
Other operating expenses	23,595			23,551			52,777			52,733
Total operating expenses	37,903			37,408			80,959			80,507
Loss from operations	(18,451		)	(23,059		)	(46,801		)	(50,502		)
Non-operating expenses and noncontrolling interest	85			(241		)	263			(192		)
Provision for income taxes	(6		)	(6		)	(3,844		)	(3,844		)
Net loss attributable to EnerNOC, Inc.	$	(18,372	)	$	(22,981	)	$	(50,382	)	$	(54,084	)

Net loss per common share
Basic	$	(0.61	)	$	(0.77	)	$	(1.69	)	$	(1.81	)
Diluted	$	(0.61	)	$	(0.77	)	$	(1.69	)	$	(1.81	)

The following summarizes the significant changes on the Company’s condensed consolidated statement of operations for the three and six months ended June 30, 2017 as a result of the adoption of ASC 606 on January 1, 2017 compared to if the Company had continued to recognize revenues under ASC 605:


•	ASC 606 accelerated the recognition of revenue and fulfillment costs related to certain demand response contracts in which recognition was previously deferred until the end of the applicable contract term due to the fees not being fixed or determinable. This resulted in greater demand response revenues relative to legacy GAAP.

•

The lower software revenue under ASC 606, as compared to the previous guidance, primarily relates to energy procurement solutions. Under the previous guidance, energy procurement revenue would have been approximately $1,300 and $2,600 higher, respectively, for the three and six months ended June 30, 2017, than under ASC 606, where energy procurement revenue is now recorded upon the completion of procurement auctions as opposed to when actual energy usage occurs.


•	ASC 606 resulted in the amortization of capitalized commission costs that were recorded as part of the cumulative effect adjustment upon adoption. Amortization of these capitalized costs to selling and marketing expenses, net of commission costs that were capitalized in the quarter resulted in no meaningful impact on selling and marketing expenses in the quarter.

The net impact of accounting for revenue under the new guidance increased net loss and net loss per share by $4,609 and $(0.16) per basic and diluted share, respectively for the three months ended June 30, 2017 and increased net loss and net loss per share by $3,702 and $(0.12) per basic and diluted share, respectively for the six months ended June 30, 2017.



	Six Months Ended June 30, 2017
Statement of Cash Flows	As reported			Pro forma as if the previous accounting guidance was in effect
Net loss	$	(50,837	)	$	(54,084	)
Non cash adjustments to reconcile net loss to net cash flows from operating activities	23,004			22,712
Changes in operating assets and liabilities
Accounts receivable, unbilled receivables and contract assets	31,433			46,757
Prepaid expenses and other assets	(481		)	(4,746		)
Capitalized fulfillment costs	(2,106		)	3,206
Deferred revenue	(1,856		)	3,884
Accounts payable, accrued expenses and other current liabilities and accrued compensation	(6,188		)	(24,950		)
Accrued capacity payments	(20,903		)	(20,903		)
Other noncurrent liabilities	(916		)	(726		)
Cash flows from operating activities	$	(28,850	)	$	(28,850	)

The adoption of ASC 606 had no impact on the Company’s cash flows from operations. The aforementioned impacts resulted in offsetting shifts in cash flows throughout net loss and various changes in working capital balances.



	Contract Assets				Deferred Revenue
	Current		Non-Current		Current		Non-Current
Balance at January 1, 2017	$	25,078	$	16,206	$	6,862	$	2,665
Balance at June 30, 2017	43,256		15,795		5,127		3,544

Revenue recognized during the six months ended June 30, 2017 from amounts included in deferred revenue at the beginning of the period was approximately $2,700 . Revenue recognized during the six months ended June 30, 2017 from performance obligations satisfied or partially satisfied in previous periods was approximately $2,100 . During the six months ended June 30, 2017 , the Company reclassified approximately $1,100 of contract assets to receivables as a result of the right to the transaction consideration becoming unconditional. The contract modifications entered into during the six months ended June 30, 2017 , which principally related to the Company’s demand response customer contracts, did not have a significant impact on the Company’s contract assets or deferred revenues.

Transaction Price Allocated to Future Performance Obligations

ASC 606 requires that the Company disclose the aggregate amount of transaction price that is allocated to performance obligations that have not yet been satisfied as of June 30, 2017. The guidance provides certain practical expedients that limit this requirement. The Company has various contracts that meet the following practical expedients provided by ASC 606:


1.	The performance obligation is part of a contract that has an original expected duration of one year or less.


2.	Revenue is recognized from the satisfaction of the performance obligations in the amount billable to the customer in accordance with ASC 606-10-55-18.


3.	The variable consideration is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct good or service that forms part of a single performance obligation in accordance with ASC 606-10-25-14(b), for which the criteria in ASC 606-10-32-40 have been met.

The following provides a discussion of the transaction price allocated to future performance obligations by service line as well as practical expedients applied by the Company.

Demand Response Solutions

As discussed above, each demand response program has unique contract delivery periods and penalty structures for which revenue may be reduced or refunded. Certain programs have an original expected duration less than one year (practical expedient 1 above) or are comprised of variable consideration that meets the criteria in practical expedient 3 above. The nature of the remaining performance obligations as well as nature of the variability and how it will be resolved is described above.

After considering the above practical expedients, the Company had approximately 30 demand response contracts as of June 30, 2017 , with unsatisfied performance obligations extending throughout 2024. The total aggregate transaction price allocated to the unsatisfied performance obligations of these contracts was approximately $230,000 , of which $120,000 is expected to be realized in 2017. This amount is presented net of any constraint and as a result, is lower than the potential contractual revenues. Specifically, certain contracts in which the performance delivery obligation does not commence within 12 months, the

Company is required to undertake numerous activities to fulfill these performance obligations, including various activities that are dependent on actions outside of the Company’s control. Accordingly, the Company has concluded that the related transaction consideration would be fully constrained at this time.

Procurement Solutions

The Company’s procurement solutions do not require material future performance obligations. Procurement solution obligations are generally satisfied once the auction is run and the energy supplier and energy consumer enter into a supply contract.

Subscription Services

As of June 30, 2017 , the Company had EIS subscription contracts with unsatisfied performance obligations extending throughout 2020. The total aggregate transaction price allocated to the unsatisfied performance obligations was approximately $38,000 , of which approximately $16,000 is expected to be recognized over the next 12 months. In addition, the Company had approximately $10,000 of contract backlog related to its UBM subscription service. These usage based fees are deemed to be variable consideration and are fully constrained until the related usage occurs.

Professional Services

The Company does not have material future performance obligations associated with professional services that extend beyond one year. Accordingly, the Company has applied practical expedient 1 above for all contracts with an original expected duration less than one year. The nature of the remaining performance obligations as well as nature of the variability and how it will be resolved is described above.

Concentrations of Credit Risk

The Company's significant customers largely include PJM Interconnection (PJM), the Korea Power Exchange (KPX), and the Australian Energy Market Operator (AEMO). PJM, is an electric power grid operator serving the mid-Atlantic region of the United States. KPX is an electric power grid operator in South Korea and AEMO is an entity that was established to administer and operate the Western Australia wholesale electricity market. Revenues from all three of these customers are included within the Demand Response operating segment.

PJM was the only customer that comprised more than 10% of the Company's revenue for three months ended June 30, 2017 representing $20,215 ( 30% ). For the six months ended June 30, 2017 PJM, KPX and AEMO represented $21,187 ( 18% ), $18,038 ( 16% ), and $11,863 ( 10% ), of the consolidated revenues, respectively. During the three and six months ended June 30, 2016, PJM was the only customer that comprised more than 10% of the Company's revenue representing $83,189 ( 62% ), and $84,781 ( 45% ) respectively.

The Company currently participates in three PJM programs, referred to as Limited, Extended and Annual. Although each program has a different delivery period, the Company receives payments for all three programs ratably throughout PJM’s fiscal year, which ends May 31. The delivery period for the Limited program is June through September. The delivery period for the Extended program is June through October plus the following May. The delivery period for the Annual program is June through the following May. This payment pattern relative to the delivery of services and associated revenue recognition has the ability to generate significant contract assets or contract liabilities. The Company refers to contract liabilities as “deferred revenue” on the condensed consolidated financial statements and the related disclosures.

As of June 30, 2017 , KPX was the only customer that comprised more than 10% of the Company's accounts receivable representing 19% . The current portion of the contract asset balance, as of June 30, 2017, is associated with demand response and procurement revenues. Current contract assets related to demand response were $22,043 , of which PJM and AEMO comprised approximately 61% and 19% , respectively. Current contract assets related to procurement solutions were $21,213 , of which two customers comprised 43% and 38% , respectively.

3. Segment Information

The Company operates two reportable segments: Demand Response and Software. The Company’s chief operating decision maker (CODM) primarily evaluates the business and assesses performance based on the revenue and segment adjusted EBITDA of the Company's Demand Response and Software segments. The Company defines segment adjusted EBITDA as segment income (loss) from operations excluding depreciation, amortization and asset impairments; stock-based compensation and restructuring charges. The Company does not allocate certain corporate level expenses; gains and losses on the sale of businesses; impairment of goodwill as well as direct and incremental expenses associated with acquisitions, divestitures, and reorganizations. Management considers segment adjusted EBITDA to be an important indicator of the segments' operational strength and the performance of its businesses.

The financial results of each segment are based on revenues, cost of revenues and operating expenses that are directly attributable to the segment and an allocation of costs from shared functions including, but not limited to, facilities, human resources, information technology, and engineering. Allocations are made based on management’s judgment of the most relevant cost drivers, such as headcount, number of customer sites, or other operational data. Certain corporate level expenses, including executive, legal, and finance, have not been allocated as they are not attributable to either segment. Segment level asset information has not been provided as it is not reviewed by the CODM for purposes of assessing segment performance and resource allocation. There are no intersegment sales or transactions. The accounting policies of the reportable segments are consistent with those described in Note 1, “Description of Business, Basis of Presentation and Summary of Significant Accounting Policies,” in the Company's 2016 Form 10-K.

Reportable Segments

The Demand Response segment provides utilities and electric power grid operators with the Company’s demand response solutions. The Software segment provides enterprises with the Company's EIS, which includes subscription software, energy procurement solutions, and professional services.

The following table presents segment revenue and adjusted EBITDA, along with the reconciliation of segment adjusted EBITDA to consolidated loss before income tax:



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016			2017			2016
Revenues:
Demand Response
Grid Operator	$	40,905		$	104,673		$	67,297		$	131,485
Utility	13,291			11,789			21,383			21,324
Demand Response Revenue	54,196			116,462			88,680			152,809

Software
Subscription software	4,468			5,569			8,967			11,745
Procurement solutions	7,278			8,795			14,035			17,728
Professional services	739			1,868			3,108			3,792
Software Revenue	12,485			16,232			26,110			33,265

Total Revenues	$	66,681		$	132,694		$	114,790		$	186,074

Segment Adjusted EBITDA:
Demand Response adjusted EBITDA	$	1,246		$	27,965		$	(2,210	)	$	24,481
Software adjusted EBITDA	(4,768		)	(20,030		)	(9,806		)	(38,037		)
Total Segment adjusted EBITDA	(3,522		)	7,935			(12,016		)	(13,556		)
Reconciliation to consolidated loss before income tax
Corporate unallocated expenses	(4,025		)	(4,536		)	(9,842		)	(10,207		)
Depreciation, amortization and asset impairments ⁽¹⁾	(6,687		)	(8,783		)	(14,228		)	(18,470		)
Stock-based compensation	(2,810		)	(3,669		)	(4,841		)	(6,784		)
(Loss) gain on sale of businesses (Note 4)	(210		)	17,376			1,516			17,376
Restructuring charges (Note 5)	—			(3,694		)	—			(3,694		)
Direct and incremental expenses associated with divestitures ⁽²⁾	(871		)	(371		)	(1,049		)	(564		)
Impairment of goodwill (Note 6)	—			—			(5,886		)	—
Noncontrolling interest expense	(326		)	(5		)	(455		)	(36		)
Interest and other income (expense), net	(241		)	(5,265		)	(192		)	(3,955		)
Consolidated loss before income tax	$	(18,692	)	$	(1,012	)	$	(46,993	)	$	(39,890	)

⁽¹⁾ Includes impairments of production equipment no longer in operation.

⁽²⁾ Includes expenses that are direct and incremental to business divestitures, including third-party professional fees for legal, accounting and valuation services.

4. Gains on Sale of Businesses

German Demand Response Operations (DACH)

In December 2016, the Company entered into an agreement to sell its German business operations (DACH), which was a component of the Demand Response segment. The carrying value of business, including long-lived assets of $2,034 , current assets of $1,381 and current liabilities of $1,780 , were classified as "held for sale" on the consolidated balance sheet as of December 31, 2016. In January 2017, the Company completed the sale of the DACH business for nominal consideration. The Company finalized the working capital amounts during the second quarter, resulting in additional amounts due to the buyer of $210 . This amount has been recorded as a loss on sale of businesses and accrued as of June 30, 2017. As a result of the complete liquidation of a foreign entity, the cumulative translation adjustments associated with the business, which were in an unrealized gain position of $2,348 prior to the closing of the transaction, were recognized and included in "gains on sale of businesses".

Energy Services Group

In March 2017, the Company sold its Energy Service Group (ESG) for $2,000 in cash plus adjustments for working capital balances sold. ESG was a component of the Software segment and provides professional services with a focus on energy audits and facility commissioning and retro-commissioning services. The Company concluded that the service line met the definition of a business in accordance with ASU 2017-01: accordingly, goodwill of $231 was allocated to the asset group. The transaction was structured as an asset purchase agreement and was intended to transfer control of the business, including certain ongoing customer contracts, to the buyer. Certain customer contracts (the "non-assigned contracts") had not been transferred to the buyer as of June 30, 2017 as the required customer consents for transfer had not been obtained. However, the agreement entered into between the Company and the buyer transferred all economic risks and rewards of the ESG business, including ownership of the non-assigned contracts, to the buyer on the closing date. As a result, a gain on the sale of the business was recognized upon closing in March 2017.

The following table summarizes the sale price, net assets sold and gain on sale of businesses recognized for the six months ended June 30, 2017.



	DACH			ESG		Total
Sale price, net of cash divested	$	(835	)	$	2,000	$	1,165
Less:
Net working capital (deficit)	(400		)	—		(400		)
Fixed assets	398			28		426
Intangible assets	1,636			—		1,636
Goodwill	—			231		231
Net assets sold	1,634			259		1,893
Cumulative translation adjustments reclassified from accumulated other comprehensive loss	(2,348		)	—		(2,348		)
Direct and incremental transaction costs	89			15		104
(Loss) gains on sale of businesses	$	(210	)	$	1,726	$	1,516

Net working capital deficit related to DACH primarily includes accounts receivable and accrued capacity payments.

5. Restructuring Activities

During the year ended December 31, 2016, the Company implemented a series of restructuring plans that resulted in workforce reductions, the sale of businesses, the consolidation of leased office space and the termination of vendor and customer contracts. The following table rolls forward the accrued restructuring liabilities for the period ended June 30, 2017 .



	Employee Related			Contract Terminations			Total
Accrued restructuring liability at December 31, 2016	$	1,024		$	29		$	1,053
Cash payments	(1,024		)	(29		)	(1,053		)
Accrued restructuring liability at June 30, 2017	$	—		$	—		$	—

6. Goodwill and Intangible Assets

Goodwill

The Company operates two reportable segments. The allocation of goodwill is shown in the following table. As discussed in Note 4 , the company sold business components from each segment during the six months ended June 30, 2017. Goodwill was allocated to these business components based on their fair value relative to the overall reporting unit prior to the divestiture.

The following table rolls forward goodwill for the six months ended June 30, 2017 :



	Demand Response		Software				Total Goodwill ¹
Balance at December 31, 2016	$	26,760	$	9,902			$	36,662
Foreign exchange	765		54			819
Impairment	—		(5,886		)		(5,886		)
Sale of business component (Note 4)	—		(231		)		(231		)
Balance at June 30, 2017	$	27,525	$	3,839			$	31,364

¹ Accumulated impairment losses as of June 30, 2017 and December 31, 2016 were $114,649 and $108,763 , respectively.

The Company performs its annual goodwill impairment test as of November 30. The goodwill test is performed at the reporting unit level, which is one level below the operating segment level and is generally based on how segment management reviews financial results of the business. For purposes of the annual goodwill impairment test conducted as of November 30, 2016, management concluded that it had three reporting units for which the fair value of each reporting unit was determined to be in excess of the carrying amount of its net assets.

As discussed in Note 2 , the Company adopted the new revenue guidance under ASC 606 using the modified retrospective method as of January 1, 2017. In connection with the adoption of ASC 606, the Company recorded significant contract assets associated with its Energy Procurement Solutions reporting unit, which triggered an interim goodwill impairment test for the first quarter of 2017. As discussed in Note 1, the Company adopted the new goodwill impairment guidance of ASU 2017-04, which measures goodwill impairment as the amount in which the current value of net assets exceeds the respective fair value. Based on the estimated fair value of the Energy Procurement Solutions reporting unit, the Company recorded an impairment charge for the six months ended June 30, 2017 of $5,886 , which represented all of the goodwill assigned to this reporting unit. The Company reviewed qualitative and quantitative information with respect to its other reporting units and concluded that goodwill was not impaired for these reporting units.

In order to determine the fair value of its reporting units, which are classified as Level 3 on the fair value hierarchy, the Company utilizes a discounted cash flow model. The key assumptions that drive fair value in the discounted cash flow model are the discount rates, terminal values, growth and profitability rates, and the amount and timing of expected future cash flows based on management's projected financial information. The Company ensures that the collective fair value of the reporting units reconciles to its market capitalization, which is calculated as the market price per share of the Company's common stock multiplied by common shares outstanding, while taking into consideration a reasonable premium that a market participant would pay to obtain control of the Company, which is also referred to as the control premium.

Intangible Assets

The following table provides the gross carrying amount and related accumulated amortization of the Company's definite-lived intangible assets as of June 30, 2017 and December 31, 2016 :



	As of June 30, 2017					As of December 31, 2016
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
Customer relationships	$	50,578	$	(28,547	)	$	51,029	$	(26,231	)
Customer contracts	8,242		(8,202		)	7,993		(7,789		)
Employment and non-compete agreements	972		(952		)	941		(844		)
Software	537		(243		)	536		(212		)
Developed technology	15,682		(6,113		)	15,597		(5,307		)
Trade name	354		(354		)	344		(344		)
Patents	180		(131		)	180		(122		)
Total	$	76,545	$	(44,542	)	$	76,620	$	(40,849	)



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
Amortization expense included in cost of revenues	$	370	$	628	$	738	$	1,489
Amortization expense included in operating expenses	1,594		2,267		3,270		4,691
Total amortization expense	$	1,964	$	2,895	$	4,008	$	6,180

Definite-lived intangible asset lives range from 1 to 14 years and have a weighted average remaining life of 5.3 years at June 30, 2017 .

7. Fair Value Measurements

The Company measures the fair value of financial instruments pursuant to the guidelines of ASC 820, Fair Value Measurement , which establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to quoted market prices in active markets for identical assets and liabilities (Level 1); then to quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-based valuation techniques for which all significant assumptions are observable in the market (Level 2); and then to model-based techniques that use significant assumptions that are not observable in the market (Level 3).

Financial Instruments and Investments

The Company’s financial instruments mainly consist of cash and cash equivalents, restricted cash, accounts receivable and accounts payable whose carrying amounts approximate their fair value due to their short-term nature. In addition, the Company has long-term investments in non-marketable equity securities that are accounted for as cost-method investments. These investments are periodically assessed for indications of a reduction in fair value that is other-than-temporary. The Company's financial instruments also include its 2.25% convertible senior notes due August 15, 2019 (the Convertible Notes) for which fair value is disclosed.

Recurring Fair Value Measurements

The table below presents the assets and liabilities measured at fair value on a recurring basis at June 30, 2017 and December 31, 2016 :



			Fair Value Measured and Recorded Using
	Totals		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Unobservable Inputs (Level 3)
As of June 30, 2017
Assets: Money market funds	$	49,122	$	49,122	$	—	$	—



As of December 31, 2016
Assets: Money market funds	$	76,008	$	76,008	$	—	$	—

Non-Recurring Fair Value Measurements

Cost-method investments and non-financial assets, such as intangible assets, property and equipment, and assets and liabilities held for sale, are adjusted to fair value only if an impairment is recognized. During the six months ended June 30, 2017 , the Company recorded impairment charges of $305 related to the retirement of production equipment and the sale of furniture, fixtures and leasehold improvements associated with sublease arrangements. Cost-method investments had a carrying value of $736 as of June 30, 2017 and no impairments were recognized during the six months ended June 30, 2017 .

Assets and Liabilities for which Fair Value Disclosure is Required

The following table shows the gross and net carrying amount of Convertible Notes at June 30, 2017 and December 31, 2016 :



	June 30, 2017			December 31, 2016
Principal amount outstanding	$	126,800		$	126,800
Less: debt discount and issuance costs	(9,510		)	(11,577		)
Carrying value, including unamortized debt discount and issuance costs	$	117,290		$	115,223
Fair Value	$	126,008		$	100,648

The fair value was determined based on the quoted market price of the Convertible Notes as of those dates and is classified as a Level 1 measurement.

8. Borrowings and Credit Arrangements

Credit Agreement

In August 2014, the Company entered into a $30,000 senior secured revolving credit facility (the 2014 credit facility) with Silicon Valley Bank (SVB) pursuant to a loan and security agreement, as amended, which is available for issuances of letters of credit and revolving loans. As of June 30, 2017 , the Company had outstanding letters of credit totaling $21,236 under the 2014 credit facility and no outstanding borrowings. In August 2017, in connection with the sale of the Company (discussed in Note 1), the 2014 credit facility was subsequently terminated and per the agreement, the Company was required to deposit cash with SVB of $22,298 into restricted accounts to replace the outstanding letters of credit.

Convertible Notes

As of June 30, 2017 , the Company had $126,800 in outstanding principal due on the Convertible Notes. The carrying value of the Convertible Notes was $117,290 , which is net of unamortized debt discount and issuance cost of $9,510 , on the condensed consolidated balance sheet as of June 30, 2017 . In connection with the sale of the Company (discussed in Note 1), and as required by the terms of the agreement dated August 18, 2014, between the Company and Wells Fargo Bank, National Association (the Indenture), the Company expects to launch a tender offer to purchase the Convertible Notes at their principal amount plus accrued and unpaid interest to, but excluding, the repurchase date (the Repurchase Right). In connection with the Merger, holders of the Notes also have the right, in lieu of the Repurchase Right, to convert each $1,000 principal amount of their Notes for cash at the then-applicable conversion rate under the Indenture pursuant to the terms of a supplemental indenture, however this would result holders receiving less cash for their Convertible Notes than if they had instead exercised the Repurchase Right.

Interest expense under the Convertible Notes is as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
Accretion of debt discount and issuance costs	$	1,041	$	987	$	2,066	$	1,949
2.25% accrued interest	713		713		1,426		1,418
Total interest expense from Convertible Notes	$	1,754	$	1,700	$	3,492	$	3,367

9. Commitments and Contingencies

Performance Guarantees

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 June 30, 2017 were $19,739 and reflected in the outstanding letters of credit. As discussed in Note 8, these letters of credit were replaced with restricted cash in August 2017. These amounts primarily represent financial assurance 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 assurance may be forfeited. The Company assessed the probability of default under these customer contracts and open market bidding programs and determined the likelihood of default 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. As of June 30, 2017 , the maximum termination penalty to which the Company could be subject under these arrangements, which the Company has deemed not probable, was approximately $3,273 .

Lease Arrangements

The Company leases office space under various operating leases, including its corporate headquarters in Boston, Massachusetts. The Company has entered into sublease arrangements for certain excess space related to these leased facilities. As of June 30, 2017 , total future non-cancelable sublease payments for all subleases are $11,593 over the next four years.

Contingencies and Indemnifications

In August 2016, a former employee filed a complaint and demand for a trial jury in state court in the Commonwealth of Massachusetts against the Company related to the payment of commissions and other claims. In September 2016, the Company answered the complaint, denying the claims. The Company does not currently believe it is probable that a loss has been incurred and therefore, no amounts have been accrued related to this matter. However, the Company has determined that it is reasonably possible that a loss may have been incurred related to this matter. The potential amount of such a loss is not currently estimable because the matter is in its early stages and involves unresolved questions of fact.

On June 27, 2017, CLEAResult Consulting Inc. (CLEAResult) filed a complaint against the Company in the United States District Court for the District of Delaware making claims for, inter alia, breach of contract and fraud, in the alternative, in connection with an Asset Purchase Agreement among the Company, Global Energy Partners, Inc., Global Energy Partners, LLC and CLEAResult, dated as of May 3, 2016 relating to the sale of the UPG business. The total amount claimed by CLEAResult is approximately $13,460 . The Company has determined that it is reasonably possible that a loss may have been incurred. However, the Company believes that CLEAResult’s assertions are without merit. Therefore, the Company has concluded that it is not probable that a loss has been incurred.

General Contingencies

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 such matters to have a material adverse effect on its consolidated financial condition, results of operations or cash flows.

10. Stockholder's Equity

Stock-Based Compensation

The Company grants share-based awards to employees, consultants, members of the board of directors and advisory board members. All share-based awards granted, including grants of stock options, restricted stock and restricted stock units, are recognized in the statement of operations based on their fair value as of the date of grant.

Stock-based compensation recorded in the condensed consolidated statements of operations was as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
Selling and marketing	$	437	$	974	$	822	$	1,792
General and administrative	2,083		2,358		3,470		4,319
Research and development	290		337		549		673
Total stock-based compensation	$	2,810	$	3,669	$	4,841	$	6,784

The Company’s Chief Executive Officer is required to receive his performance-based bonus, if achieved, in shares of the Company's common stock. The Company recorded $253 of stock based compensation related to this performance based bonus for each of the six month periods ended June 30, 2017 and 2016.

Stock Options

During the six months ended June 30, 2017, no stock options were granted and 167 shares were exercised. As of June 30, 2017, the Company had 123,002 options outstanding with 4,998 shares issuable upon the exercise of "in-the-money" options.

Restricted Stock and Restricted Stock Units

The following table summarizes the Company’s restricted stock and restricted stock unit activity during the six months ended June 30, 2017 :



	Restricted Stock				Restricted Stock Units
	Number of Shares		Weighted Average Grant Date Fair Value Per Share		Number of Shares		Weighted Average Grant Date Fair Value Per Share
Nonvested at December 31, 2016	1,374,967		$	11.71	705,851		$	8.90
Granted	909,783		5.56		794,750		5.70
Vested	(266,730	)	10.96		(164,737	)	12.29
Cancelled	(483,173	)	10.71		(202,556	)	6.68
Nonvested at June 30, 2017	1,534,847		$	8.51	1,133,308		$	6.56

As of June 30, 2017 , the Company had $14,503 of unrecognized stock-based compensation expense related to nonvested restricted stock and restricted stock units. The vesting of all nonvested restricted stock and restricted stock units was accelerated upon the sale of the Company, discussed in Note 1.

Share Repurchase Activity

In connection with the vesting of restricted stock and restricted stock units under its equity incentive plans, the Company withheld 179,161 shares of its common stock during the six months ended June 30, 2017 to satisfy employee minimum

statutory income tax withholding obligations which the Company pays in cash to the appropriate taxing authorities on behalf of its employees. All withheld shares became immediately available for future issuance under the Company's equity incentive plans.

Accumulated Other Comprehensive Loss

Changes in accumulated other comprehensive loss, which are entirely comprised of foreign currency translation adjustments, net of tax, are as follows:



	Foreign Currency Translation Adjustments
Balance at December 31, 2016	$	2,477
Other comprehensive loss before reclassifications	(421		)
Reclassification due to liquidation of a foreign entity (Note 4)	2,348
Balance at June 30, 2017	$	5,246

11. Net Income (Loss) Per Share

The computation of basic and diluted net income (loss) per share is as follows (in thousands, except share and per share information):



	Three Months Ended June 30,					Six Months Ended June 30,
Numerator:	2017			2016		2017			2016
Net (loss) income for basic earnings per share	$	(18,372	)	$	102	$	(50,382	)	$	(40,436	)
ADD: Interest expense related to Convertible Notes	—			—		—			—
Net (loss) income for diluted earnings per share	$	(18,372	)	$	102	$	(50,382	)	$	(40,436	)



Denominator:
Basic weighted average common shares outstanding	29,918,229			29,114,200		29,834,253			28,962,021
Weighted average common stock equivalents	—			455,121		—			—
Diluted weighted average common shares outstanding	29,918,229			29,569,321		29,834,253			28,962,021

Basic net (loss) income per share	$	(0.61	)	$	0.00	$	(1.69	)	$	(1.40	)
Diluted net (loss) income per share	$	(0.61	)	$	0.00	$	(1.69	)	$	(1.40	)

Weighted average anti-dilutive shares related to:
Incremental shares from assumed conversion of Convertible Notes	4,576,630			4,576,630		4,576,630			4,576,630
Stock options	122,804			303,441		122,804			308,599
Nonvested restricted stock	681,125			2,102,692		1,329,015			2,233,510
Restricted stock units	113,455			113,503		789,855			544,503

For purposes of the calculation of diluted net income per share, it is assumed that conversion of the Convertible Notes would be settled entirely in shares of common stock. For the three and six months ended June 30, 2017 , the Convertible Notes are not assumed to be converted as the impact of conversion is anti-dilutive . For further information regarding the Convertible Notes, please refer to Note 8 .

Restricted stock awards are excluded from the calculation of basic weighted-average common shares outstanding until they vest. For restricted stock awards that vest based on achievement of performance conditions, the number of contingently issuable common shares included in diluted weighted-average common shares outstanding is 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, assuming the result would be dilutive.

The Company includes 254,654 shares of common stock related to a component of the deferred purchase price consideration for a business acquired in 2011 in the calculation of both the basic and diluted weighted-average common shares outstanding as the shares are not subject to adjustment and the issuance of such shares is not subject to any contingency. These shares were issued in June 2017.

12. Income Taxes

The quarterly income tax provision is measured using an estimated annual effective tax rate applied to the pre-tax income of certain entities within the Company's global consolidated group. The Company 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 to use that rate to provide for income taxes on a current year-to-date basis. However, if the Company 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. For the six months ended June 30, 2017 , the Company determined that it was able to reliably estimate its annual effective tax rate in all jurisdictions in which it operates.

The Company recorded a consolidated income tax expense of $6 and $3,844 for the three and six months ended June 30, 2017 , reflecting an effective tax rate of (8.18)% on consolidated profit before tax for the six months ended June 30, 2017. The income tax expense for the six months ended June 30, 2017 is driven by the mix of earnings from foreign operations, the composition of entities that are included or excluded from the calculation of annual effective tax rate, changes relating to valuation allowances associated with deferred tax assets for certain foreign entities, and discrete items, of which there were no material items in the six months ended June 30, 2017. The Company recorded an income tax benefit of $1,109 and income tax expense of $582 for the three and six months ended June 30, 2016 .

ASC 740, Income Taxes , 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 six months ended June 30, 2017 , there were no material changes in the Company’s uncertain tax positions.

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 June 30, 2017 , due to the uncertainty around the realizability of certain domestic and foreign deferred tax assets, the Company continues to maintain a valuation allowance.

13. Subsequent Events

As discussed in Note 1 “Description of Business and Basis of Presentation,” on August 4, 2017, the Offer was consummated and on August 7, 2017, the Company closed the Merger, pursuant to which Parent became the owner of 100% of the outstanding common stock of the Company. In connection with the Merger, NASDAQ filed a Form 25 on the Company’s behalf to provide notice to the SEC regarding the withdrawal of shares of the Company’s common stock from listing and to terminate the registration of such shares under Section 12(b) of the Exchange Act. Shares of the Company’s common stock were suspended from trading on the NASDAQ Global Market prior to the opening of trading on August 7, 2017. The Company is in the process of filing with the SEC a certification on Form 15 under the Exchange Act, requesting the deregistration of its common stock and the suspension of its reporting obligations under Sections 13 and 15(d) of the Exchange Act.

Between July 14, 2017 and July 18, 2017, three putative class action lawsuits were filed on behalf of the public stockholders of the Company (captioned Basch v. EnerNOC, Inc., et al., No. 1:17-cv-11305; Nelson v. EnerNOC, Inc., et al., No. 1:17-cv-11324; and Berg v. EnerNOC, Inc. et al., No. 1-17-cv-11331) in the United States District Court for the District of Massachusetts (the Court) against the Company, the members of the Company’s board of directors (the Board) and, in one case, Parent, Purchaser and Enel (collectively, the Stockholder Litigation). The complaints generally allege that the Company and the members of the Board violated Section 14 of the Exchange Act by issuing a Schedule 14D-9 that was materially misleading and omitted material facts related to the Offer and the Merger. The complaints also allege that the members of the Board and also, in one case, Parent, Purchaser and Enel, violated Section 20(a) of the Exchange Act, as controlling persons who had the ability to prevent the Schedule 14D-9 from being materially false and misleading. The complaints seek, among other things, an injunction against the consummation of the Offer and Merger, an award of damages, and an award of costs and disbursements for the actions, including reasonable attorneys’ and experts’ fees. On July 17, 2017, the plaintiff in the Basch action filed a motion for preliminary injunction, and the Court set a hearing date on that motion. On July 25, 2017, the Company filed an amendment to the Schedule 14D-9, which contained certain supplemental disclosures that were included to moot the claims alleged in the Stockholder Litigation (the “Supplemental Disclosures”). On July 26, 2017, in light of the Supplemental Disclosures, the plaintiff in the Basch action withdrew his motion for preliminary injunction and the Court vacated the preliminary injunction hearing.



Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following discussion should be read in conjunction with our unaudited condensed consolidated financial statements and related notes thereto included elsewhere in this Quarterly Report on Form 10-Q, as well as our audited financial statements and notes thereto and Management’s Discussion and Analysis of Financial Condition and Results of Operations included in our

Annual Report on Form 10-K, as amended, for the fiscal year ended December 31, 2016 , as filed with the Securities and Exchange Commission (the SEC) on March 16, 2017 (our 2016 Form 10-K). This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act). Without limiting the foregoing, the words “may,” “will,” “should,” “could,” “expect,” “plan,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “continue,” “likely,” “target” and variations of those terms or the negatives of those terms and similar expressions are intended to identify forward-looking statements. All forward-looking statements included in this Quarterly Report on Form 10-Q are based on current expectations, estimates, forecasts and projections and the beliefs and assumptions of our management including, without limitation, our expectations regarding our results of operations, operating expenses and the sufficiency of our cash for future operations. We assume no obligation to revise or update any such forward-looking statements. Our actual results could differ materially from those anticipated in these forward-looking statements as a result of certain important factors, including those set forth below under this Item 2 - “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” Part II, Item 1A - “Risk Factors” and elsewhere in this Quarterly Report on Form 10-Q, as well as in our 2016 Form 10-K. You should carefully review those factors and also carefully review the risks outlined in other documents that we file from time to time with the SEC.

Overview

We are a leading provider of demand response solutions and energy intelligence software (EIS), to enterprises, utilities, and electric power grid operators.

Demand Response Solutions

Our demand response solutions provide utility customers and electric power grid operators with a managed service demand response resource where we match obligation, in the form of megawatts (MW), that we agree to deliver to utility customers and electric power grid operators, with supply, in the form of MW, that we are able to curtail from the electric power grid through our arrangements with commercial and industrial end users of energy, or C&I end-users. When we are called upon by our utility customers and electric power grid operators to deliver contracted capacity, we use our global Network Operations Center, or NOC, to remotely manage and reduce electricity consumption across our network of C&I end-user sites, making demand response capacity available to our utility customers and electric power grid operators on demand, while helping C&I end-users achieve energy savings, improve financial results and realize environmental benefits.

Energy Intelligence Software

Our EIS includes our subscription software, energy procurement solutions, and professional services.

Subscription Software

Our EIS provides enterprises with a Software-as-a-Service (SaaS), energy management application that enables them to address their most important energy challenges, including: energy cost visualization, budgets, forecasts, and accruals; utility bill validation and payment; facility optimization; energy project tracking; reporting for energy and sustainability disclosure and compliance; and peak energy demand and the related cost impacts.

Energy Procurement Solutions

Our EIS also provides our enterprise and utility customers located in restructured or deregulated markets with the ability to more effectively manage energy supplier selection and the energy procurement process by providing highly structured auction events designed to yield transparent and competitive energy pricing. Our energy procurement solutions also include supply procurement advisory services that assist our enterprise customers in developing and implementing risk management and purchasing strategies that provide maximum price transparency and structural savings.

Professional Services

We offer premium professional services that support the implementation of our EIS and help our enterprise customers set their energy management strategy. Professional services are offered to our customers as a means to further implement and extend our technology across their organizations.

Significant Recent Developments

We entered into a definitive Agreement and Plan of Merger, dated as of June 21, 2017 (the Merger Agreement), with Enel Green Power North America, Inc., a Delaware corporation (Parent), Pine Merger Sub, Inc. a Delaware corporation and a wholly-owned subsidiary of Parent (Purchaser) and Enel S.p.A, an Italian joint-stock company and the parent of Parent. In accordance with the terms of the Merger Agreement, on July 10, 2017, Purchaser commenced a tender offer (the Offer) for all of our outstanding shares of common stock, par value $0.001 per share (the Shares), at a purchase price of $7.67 per Share, net to the seller in cash, without interest, less any applicable withholding taxes (the Offer Price).

The Offer expired at 11:59 p.m., New York City time on August 4, 2017, as scheduled, and was not extended. According to American Stock Transfer & Trust Company, LLC, the depositary for the Offer (the Depositary), a total of 22,207,831 Shares

(excluding Shares with respect to which notices of guaranteed delivery were delivered, but the Shares represented thereby were not yet delivered) had been validly tendered and not validly withdrawn prior to the expiration of the Offer, which represented approximately 70.8% of the outstanding Shares as of such time. The condition to the Offer that at least one more than fifty percent of the total number of Shares then issued and outstanding be validly tendered and not withdrawn was satisfied and as a result, Purchaser accepted for payment all Shares that were validly tendered and not validly withdrawn, and payment for such Shares has been made to the Depositary. In accordance with the terms of the Offer, the Depositary will act as agent for tendering stockholders for the purpose of receiving payments for tendered Shares and transmitting such payments to tendering stockholders whose Shares have been accepted for payment. In addition, the Depository advised Parent and Purchaser that notices of guaranteed delivery had been delivered with respect to 239,928 additional Shares, representing approximately 0.8% of the outstanding Shares as of such time.

On August 7, 2017, Purchaser merged with and into EnerNOC, Inc., with EnerNOC, Inc. surviving as a wholly owned subsidiary of Parent (the Merger). The Merger was governed by Section 251(h) of the General Corporation Law of the State of Delaware, with no stockholder vote required to consummate the Merger. At the effective time of the Merger, each Share then outstanding (other than Shares that are held by any stockholders who are entitled to and who properly demanded appraisal in connection with the Merger) was converted into the right to receive the Offer Price, except for Shares then owned by Purchaser or Parent and Shares held in treasury of us or by any of our wholly owned subsidiaries, which Shares were cancelled and retired and ceased to exist effective as of the Merger, and in exchange for which no consideration will be delivered.

The aggregate consideration paid by Purchaser in the Offer and Merger was approximately $250 million without giving effect to related transaction fees and expenses. The Parent provided Purchaser with sufficient funds to purchase all Shares validly tendered and not validly withdrawn and to pay for the acquisition of the remaining Shares in the Merger. Parent funded the payment from its general corporate funds on the terms and conditions previously disclosed in the Tender Offer Statement on Schedule TO filed by Parent and Purchaser with the Securities and Exchange Commission on July 10, 2017, as amended.

In connection with the Merger, the NASDAQ stock market (NASDAQ) filed a Form 25 on our behalf to provide notice to the SEC regarding the withdrawal of shares of our common stock from listing and to terminate the registration of such shares under Section 12(b) of the Exchange Act. Shares of our common stock were suspended from trading on the NASDAQ Global Market prior to the opening of trading on August 7, 2017. We are in the process of filing with the SEC a certification on Form 15 under the Exchange Act, requesting the deregistration of our common stock and the suspension of our reporting obligations under Sections 13 and 15(d) of the Exchange Act.

Consolidated Results of Operations

Three and Six Months Ended June 30, 2017 Compared to the Three and Six Months Ended June 30, 2016

Revenues

The following table summarizes our consolidated revenues for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,				Dollar			Percentage
	2017		2016		Change			Change
Revenues:
Demand Response	$	54,196	$	116,462	$	(62,266	)	(53.5	)%
Software	12,485		16,232		(3,747		)	(23.1	)%
Total	$	66,681	$	132,694	$	(66,013	)	(49.7	)%
	Six Months Ended June 30,				Dollar			Percentage
	2017		2016		Change			Change
Revenues:
Demand Response	$	88,680	$	152,809	$	(64,129	)	(42.0	)%
Software	26,110		33,265		(7,155		)	(21.5	)%
Total	$	114,790	$	186,074	$	(71,284	)	(38.3	)%

For discussion and analysis of quarterly revenue as compared to the prior year, please refer to Segment Results of Operations below.

Gross Profit and Gross Margin

The following table summarizes our consolidated gross profit and gross margin percentages for the three and six months ended June 30, 2017 and 2016 (dollars in thousands):



Three Months Ended June 30,
2017				2016
Gross Profit		Gross Margin		Gross Profit		Gross Margin
$	19,452	29.2	%	$	51,163	38.6	%
Six Months Ended June 30,
2017				2016
Gross Profit		Gross Margin		Gross Profit		Gross Margin
$	34,158	29.8	%	$	71,949	38.7	%

The decrease in consolidated gross profit and gross margin for the three and six months ended June 30, 2017 , as compared to the same periods in 2016 , was principally due to the recognition of revenues associated with the 2015/2016 PJM Extended program that were deferred until the second quarter of 2016. Subsequent to the adoption of Accounting Standards Update 606 (ASC 606), PJM revenues were recognized on a ratable basis, resulting in a decline in the revenues when compared to the same periods in the prior year.

Operating Expenses

The following table summarizes our consolidated operating expenses for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,						Percentage
Operating expenses:	2017			2016			Change
Selling and marketing	$	14,308		$	25,517		(43.9	)%
General and administrative	18,182			27,441			(33.7	)%
Research and development	5,203			7,634			(31.8	)%
Gains on sale of businesses	210			(17,376		)	n/m
Restructuring charges	—			3,694			n/m
Goodwill impairment charge	—			—			n/m
Total operating expenses	$	37,903		$	46,910		(19.2	)%
	Six Months Ended June 30,						Percentage
	2017			2016			Change
Selling and marketing	$	28,182		$	50,532		(44.2	)%
General and administrative	37,802			55,357			(31.7	)%
Research and development	10,605			15,677			(32.4	)%
Gains on sale of businesses	(1,516		)	(17,376		)	n/m
Restructuring charges	—			3,694			n/m
Goodwill impairment charge	5,886			—			n/m
Total operating expenses	$	80,959		$	107,884		(25.0	)%

Selling and Marketing Expenses

The following table summarizes our consolidated selling and marketing expenses for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,				Percentage
	2017		2016		Change
Payroll and related costs	$	8,719	$	15,889	(45.1	)%
Stock-based compensation	437		974		(55.1	)%
Amortization of intangible assets	1,554		2,173		(28.5	)%
Other	3,598		6,481		(44.5	)%
Total selling and marketing expenses	$	14,308	$	25,517	(43.9	)%
	Six Months Ended June 30,				Percentage
	2017		2016		Change
Payroll and related costs	$	17,497	$	32,209	(45.7	)%
Stock-based compensation	822		1,792		(54.1	)%
Amortization of intangible assets	3,152		4,377		(28.0	)%
Other	6,711		12,154		(44.8	)%
Total selling and marketing expenses	$	28,182	$	50,532	(44.2	)%

The decrease in payroll and related costs for the three and six months ended June 30, 2017 , as compared to the same periods in 2016 , was primarily due to the divestiture of the utility customer engagement (UCE), business in the second quarter of 2016 and the restructuring actions completed in the third quarter of 2016, which contributed to a reduction in the number of full-time selling and marketing employees from 322 at June 30, 2016 to 197 at June 30, 2017 . Stock-based compensation for the current year six month period was lower as compared to the same period in 2016 due to fewer outstanding equity awards. Amortization of intangible assets declined due to prior year divestitures and assets becoming fully amortized. Other selling and marketing expenses, which include advertising, marketing, professional services, and a company-wide overhead cost allocation, were lower in the current period, as compared to the same period in 2016, due to the execution of restructuring activities in the prior year and cost saving initiatives.

General and Administrative Expenses

The following table summarizes our consolidated general and administrative expenses for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,				Percentage
	2017		2016		Change
Payroll and related costs	$	8,740	$	16,832	(48.1	)%
Stock-based compensation	2,083		2,358		(11.7	)%
Amortization of intangible assets	15		107		(86.0	)%
Other	7,344		8,144		(9.8	)%
Total general and administrative expenses	$	18,182	$	27,441	(33.7	)%
	Six Months Ended June 30,				Percentage
	2017		2016		Change
Payroll and related costs	$	17,957	$	33,456	(46.3	)%
Stock-based compensation	3,470		4,319		(19.7	)%
Amortization of intangible assets	78		327		(76.1	)%
Other	16,297		17,255		(5.6	)%
Total general and administrative expenses	$	37,802	$	55,357	(31.7	)%

The decrease in payroll and related costs for the three and six months ended June 30, 2017 , as compared to the same periods in 2016 , was primarily due to the divestiture of the UCE business in the second quarter of 2016 and the restructuring actions completed in the third quarter of 2016, which contributed to a reduction in the number of general and administrative full time employees from 530 at June 30, 2016 to 274 at June 30, 2017 . Stock-based compensation for the current year six month period was lower as compared to the same period in 2016 due to fewer outstanding equity awards. Amortization of intangible assets declined due to prior year divestitures and assets becoming fully amortized. Other general and administrative expenses, which include professional services, rent, depreciation and a company-wide overhead cost allocation declined in the current period

due to lower depreciation costs as a result of fully depreciated assets and reduced IT and software subscription costs as a result of the 2016 restructuring activities and cost savings initiatives.

Research and Development Expenses

The following table summarizes our consolidated research and development expenses for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,				Percentage
	2017		2016		Change
Payroll and related costs	$	2,818	$	4,752	(40.7	)%
Stock-based compensation	290		337		(13.9	)%
Other	2,095		2,545		(17.7	)%
Total research and development marketing expenses	$	5,203	$	7,634	(31.8	)%
	Six Months Ended June 30,				Percentage
	2017		2016		Change
Payroll and related costs	$	5,734	$	9,891	(42.0	)%
Stock-based compensation	549		673		(18.4	)%
Other	4,322		5,113		(15.5	)%
Total research and development expenses	$	10,605	$	15,677	(32.4	)%

The decrease in payroll and related costs for the three and six months ended June 30, 2017 , as compared to the same periods in 2016 , was primarily due to the divestiture of the UCE business in the second quarter of 2016 and the restructuring actions completed in the third quarter of 2016, which contributed to a reduction in the number of research and development full time employees from 197 at June 30, 2016 to 85 at June 30, 2017. Stock-based compensation for the current year six month period was lower, as compared to the same period in 2016, due to fewer outstanding equity awards. Other research and development expenses, which include technology expenses, professional services, facilities and a company-wide overhead cost allocation, declined in the current six month period, as compared to the same period in 2016, as a result of a reduction in third party software and data storage costs.

Gains on Sale of Businesses

As discussed in Note 4 to the accompanying financial statements, during the six months ended June 30, 2017 , we sold a component of the Software segment that provides professional services with a focus on energy audits and facility commissioning and retro-commissioning services for approximately $2.0 million and recognized a gain of $1.7 million . In addition, we closed on the sale of our German demand response business in the first quarter of 2017 and finalized the working capital adjustment during the second quarter of 2017, resulting in a loss of $0.2 million . During the six months ended June 30, 2016, we sold the Utility Programs Group (UPG) for approximately $14.5 million and recognized a gain of $17.3 million.

Goodwill Impairment

As discussed in Note 6 to the accompanying financial statements, we recorded a goodwill impairment charge of $5.9 million during the six months ended June 30, 2017 . The impairment related to our Energy Procurement Solutions reporting unit was driven by the significant contract assets that were recorded upon the adoption of ASC 606 on January 1, 2017. These assets increased the carrying value above that of the corresponding fair value of the reporting unit. As a result, an impairment charge was recognized during the period. There was no such impairment in the prior year.

Other Income, Net

Other income includes realized and unrealized foreign currency gains and losses related to intercompany balances and the settlement of commodity contracts.

For the three months ended June 30, 2017, we recorded a foreign currency gain of $1.1 million as compared to a gain of $3.4 million for the same period in 2016. This decrease was driven by fluctuations in foreign exchange rates and a decline in intercompany loans payable, which gave rise to the foreign exchange gains/(losses). For the six months ended June 30, 2017, we recorded a foreign currency gain of $2.7 million , as compared to a loss of $0.3 million for the same period in 2016.

In one of our demand response programs, we manage market pricing risk through the use of a commodity swap arrangement whereby we deliver MW capacity and receive a variable price based on market conditions. These variable fees are converted to a fixed fee via a third-party arrangement. For the three and six months ended June 30, 2017 , we recorded gains of $0.4 million and $0.8 million in other income, net, related to this program. We did not have a similar instrument in the same period in 2016.

Interest Expense

Interest expense was relatively consistent at $1.9 million and $3.9 million , respectively, for the three and six months ended June 30, 2017 , as compared to $1.8 million and $3.6 million , respectively, for the three and six months ended June 30, 2016 . The outstanding principal of our 2.25% convertible senior notes due August 15, 2019 (the Convertible Notes) was consistent across each period.

Income Taxes

For the six months ended June 30, 2017 , we recorded a worldwide tax provision of $3.8 million , representing an effective tax rate of (8.18)% , as compared to $0.6 million in the six months ended June 30, 2016 . The year-to-date income tax expense is predominantly due to taxable income in our German subsidiary generated from the settlement of intercompany loans in connection with the divestiture of our German demand response operations. We do not expect to record a provision for income taxes at a similar effective rate throughout the remainder of 2017. Our annual income tax provision is subject to the mix of our taxable income globally and is impacted by discrete items that may occur throughout the year.

Segment Results of Operations

We operate two reportable segments: Demand Response and Software. We evaluate and assess the performance of our operating segments based on revenues and adjusted EBITDA, which is the measure of segment profit or loss that is reported to our chief operating decision maker for purposes of making decisions about allocating resources to each segment and assessing segment performance. Please refer to Note 3 to the accompanying financial statements for a reconciliation of segment adjusted EBITDA to consolidated loss before income taxes. We define segment adjusted EBITDA as segment income (loss) from operations excluding depreciation, amortization and asset impairments; stock-based compensation and restructuring charges. In addition, we do not allocate to our operating segments certain corporate level expenses; gains on sale of businesses; and direct and incremental expenses and gains associated with acquisitions, divestitures, reorganizations and escrow settlements.

Three and Six Months Ended June 30, 2017 Compared to the Three and Six Months Ended June 30, 2016

Revenues

Demand Response Segment Revenues

The following table summarizes our Demand Response segment revenues for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,				Dollar			Percentage
	2017		2016		Change			Change
Revenues:
Grid Operator	$	40,905	$	104,673	$	(63,768	)	(60.9	)%
Utility	13,291		11,789		1,502			12.7	%
Total Demand Response Revenues	$	54,196	$	116,462	$	(62,266	)	(53.5	)%
	Six Months Ended June 30,				Dollar			Percentage
	2017		2016		Change			Change
Revenues:
Grid Operator	$	67,297	$	131,485	$	(64,188	)	(48.8	)%
Utility	21,383		21,324		59			0.3	%
Total Demand Response Revenues	$	88,680	$	152,809	$	(64,129	)	(42.0	)%

The significant changes in our Demand Response segment revenues from grid operators and utilities for the three and six months ended June 30, 2017, as compared to the same periods in 2016, are highlighted in the following tables (in thousands):



	Increase (Decrease)
	Three Months Ended June 30, 2016 to June 30, 2017			Six Months Ended June 30, 2016 to June 30, 2017
PJM Interconnection (PJM)	$	(62,965	)	$	(62,038	)
Texas (ERCOT)	(1,859		)	(2,811		)
Western Australia (AEMO)	(1,280		)	(2,233		)
New England (ISO-NE)	(1,001		)	(4,018		)
South Korea (KPX)	2,048			6,775
NYISO	1,009			364
Other ⁽¹⁾	280			(227		)
Total increase in Grid Operator Demand Response revenues	$	(63,768	)	$	(64,188	)

⁽¹⁾ The amounts included in 'other' relate to net increases (decreases) in various demand response programs, domestic and international, none of which are individually material.

Grid operator revenues decreased approximately $64 million for the three and six months ended June 30, 2017 as compared to the same periods in 2016. The decline in PJM and ERCOT revenues was largely due to the adoption of ASC 606. Specifically, in 2016, all PJM revenue associated with the 2015/2016 Extended program was recognized at the conclusion of the program period in May 2016. In addition, 2016 ERCOT revenues reflected four months of the 2015/2016 Winter program and four months of the 2016 Spring program, which were deferred and recognized upon program completion in January 2016 and May 2016, respectively. The recognition pattern in the current year more closely aligns with the service performance period. The decline in AEMO revenues was largely driven by a decrease in enrolled MW as compared to the same period in 2016. The decline in ISO-NE revenues was largely due to reduced participation in the forward capacity market program and having recognized previously deferred economic program revenues in 2016 with the resolution of the United States Supreme Court's January 2016 ruling in FERC v. Electric Power Supply Association (FERC 745). The declines above were partially offset by increased enrolled MW in our KPX program, increased rates in our NYISO program and immaterial increases throughout various other programs.



	Increase (Decrease)
	Three Months Ended June 30, 2016 to June 30, 2017			Six Months Ended June 30, 2016 to June 30, 2017
PacifiCorp	$	1,326		$	1,322
California DRAM (DRAM)	1,983			2,838
Southern California Edison (SCE)	(1,892		)	(2,096		)
New Zealand	(661		)	(1,286		)
Other ⁽¹⁾	746			(719		)
Total decrease in Utility Demand Response revenues	$	1,502		$	59

⁽¹⁾ The amounts included in 'other' primarily relate to various utility demand response programs and services, none of which are individually material.

Utility revenues increased $1.5 million for the three months ended June 30, 2017, as compared to the same period in 2016, and remained flat for the six months ended June 30, 2017, as compared to the same period in 2016. The increase in PacifiCorp revenues was largely due to the adoption of ASC 606, for which revenues were deferred and recognized at the end of the program period in the third quarter of 2016. The increase in DRAM revenues reflects new programs initiated during 2017. These increases were partially offset by decreasing revenues in our SCE and New Zealand programs. The SCE program concluded at the end of 2016. Revenues related to New Zealand declined as a result of current year price declines.

Software Segment Revenues

The following table summarizes our Software segment revenues for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,				Dollar			Percentage
	2017		2016		Change			Change
Revenues:
Subscription software	$	4,468	$	5,569	$	(1,101	)	(19.8	)%
Procurement solutions	7,278		8,795		(1,517		)	(17.2	)%
Professional services	739		1,868		(1,129		)	(60.4	)%
Total Software Revenues	$	12,485	$	16,232	$	(3,747	)	(23.1	)%
	Six Months Ended June 30,				Dollar			Percentage
	2017		2016		Change			Change
Revenues:
Subscription software	$	8,967	$	11,745	$	(2,778	)	(23.7	)%
Procurement solutions	14,035		17,728		(3,693		)	(20.8	)%
Professional services	3,108		3,792		(684		)	(18.0	)%
Total Software Revenues	$	26,110	$	33,265	$	(7,155	)	(21.5	)%

The decrease in subscription software revenues from 2017, as compared to 2016 was largely due to the divestiture of our UCE business in the second quarter of 2016. The decline in procurement solutions revenues was largely driven by the adoption of ASC 606, which accelerated the recognition on much of our backlog through accumulated deficit as of January 1, 2017. The decrease in professional services revenues was largely due to the divestiture of UPG in the second quarter of 2016 and ESG in the first quarter of 2017.

Segment adjusted EBITDA:

The following table summarizes segment adjusted EBITDA for the three and six months ended June 30, 2017 and 2016 (in thousands):



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016			2017			2016
Demand Response adjusted EBITDA	$	1,246		$	27,965		$	(2,210	)	$	24,481
Software adjusted EBITDA	$	(4,768	)	$	(20,030	)	$	(9,806	)	$	(38,037	)

Demand Response Segment adjusted EBITDA

Demand Response segment adjusted EBITDA decreased significantly as compared to the prior year, primarily due to our participation in the 2015/2016 PJM Extended program for which, under ASC 605, all PJM revenues associated with the 2015/2016 Extended program were recognized at the conclusion of the program period in May 2016.

Software Segment adjusted EBITDA

Software segment adjusted EBITDA improved by $15.3 million and $28.2 million for the three and six months ended June 30, 2017, as compared to the same periods in 2016, primarily due to reduced operating expenses attributable to our restructuring actions.

Liquidity and Capital Resources

Cash Flows

The following table summarizes our condensed consolidated cash flows for the six months ended June 30, 2017 and 2016 (in thousands):



	Six Months Ended June 30,
	2017			2016
Cash used in operating activities	$	(28,850	)	$	(46,795	)
Cash (used in) provided by investing activities	(4,842		)	4,409
Cash provided by (used in) financing activities	118			(1,691		)
Effects of exchange rate changes on cash, cash equivalents and restricted cash	1,117			1,159
Net change in cash, cash equivalents and restricted cash	$	(32,457	)	$	(42,918	)

Cash Used In Operating Activities

The following table summarizes our consolidated cash flows used in operating activities for the six months ended June 30, 2017 and 2016 (in thousands):



	Six Months Ended June 30,
	2017			2016
Net loss	$	(50,837	)	$	(40,472	)
Goodwill impairment charge	5,886			—
Other non-cash items	18,634			30,418
Gains on sale of businesses, excluding transaction costs (Note 4)	(1,516		)	(17,376		)
Change in working capital and other activities	(1,017		)	(19,365		)
Net cash used in operating activities	$	(28,850	)	$	(46,795	)

Cash used in operating activities for the six months ended June 30, 2017 and 2016 reflect net losses adjusted for non-cash activity, gains on the sale of businesses, and the impact of changes in our working capital balances relative to the beginning of the year. The increase in working capital in the current period is primarily due to decreases in liabilities, largely offset by an increase in accounts receivable, unbilled receivables and contract assets, which was primarily a result of cash collections related to various demand response programs (primarily PJM) for performance obligations satisfied in 2016. The $28.9 million of cash used in operations for the six months ended June 30, 2017 compares to $46.8 million used for the same period in the prior year. The $17.9 million improvement is primarily due to a decrease in cash operating losses and improved working capital balances in the current period, as compared to the same period in 2016.

Cash Provided By (Used In) Investing Activities

Cash used in investing activities was $4.8 million for the six months ended June 30, 2017 , which consisted primarily of capital expenditures of $6.4 million including $2.4 million for the capitalization of internal-use software development costs, partially offset by $1.3 million in net cash received for the sale of businesses. Cash provided by investing activities was $4.4 million for the six months ended June 30, 2016 . During the six months ended June 30, 2016 , we incurred $9.1 million of capital expenditures partially offset by $13.2 million in net cash received for the sale of businesses and an increase of $0.4 million in deposits.

Cash Provided By (Used In) Financing Activities

Cash provided by financing activities was $0.1 million for the six months ended June 30, 2017 and consisted primarily of cash received for the sale of equity interests in our ENOC Japan and ENOC Taiwan entities, largely offset by payments made for employee restricted stock minimum tax withholdings. Cash used in financing activities was $1.7 million for the six months ended June 30, 2016 and consisted of payments made for employee restricted stock minimum tax withholdings totaling $1.5 million and $0.2 million in payments for consideration related to acquisitions completed in the first quarter of 2016.

Borrowing and Credit Arrangements

Credit Agreement

In August 2014, we entered into a $30 million senior secured revolving credit facility (the 2014 credit facility) with Silicon Valley Bank (SVB) pursuant to a loan and security agreement, as amended. As of June 30, 2017 , we had outstanding letters of credit totaling $21.2 million under the 2014 credit facility and no outstanding borrowings. In August 2017, in connection with the Merger Agreement (discussed in Note 1), the 2014 credit facility was subsequently terminated and per the agreement, the we were required to deposit cash with SVB of $22.3 million into restricted accounts to replace the outstanding letters of credit.

Convertible Notes

As of June 30, 2017 , we had $126.8 million in outstanding principal due on the Convertible Notes. The carrying value of the Convertible Notes was $117.3 million , which is net of unamortized debt discount and issuance cost of $9.5 million , on the condensed consolidated balance sheet as of June 30, 2017 . In connection with the sale of the Company (discussed in Note 1), and as required by the terms of the agreement, dated August 18, 2014, between the Company and Wells Fargo Bank, National Association (the Indenture), the Company expects to launch a tender offer to purchase the Convertible Notes at their principal amount plus accrued and unpaid interest to, but excluding, the repurchase date (the Repurchase Right). In connection with the Merger, holders of the Notes also have the right, in lieu of the Repurchase Right, to convert each $1,000 principal amount of their Notes for cash at the then-applicable conversion rate under the Indenture pursuant to the terms of a supplemental indenture, however this would result holders receiving less cash for their Convertible Notes than if they had instead exercised the Repurchase Right.

For further discussion of the Convertible Notes, please refer to Note 8 to the accompanying financial statements.

Interest expense under the Convertible Notes is as follows (dollars in thousands):



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
Accretion of debt discount and issuance costs	$	1,041	$	987	$	2,066	$	1,949
2.25% accrued interest	713		713		1,426		1,418
Total interest expense from Convertible Notes	$	1,754	$	1,700	$	3,492	$	3,367

Contractual Commitments and Obligations

The disclosure of our contractual obligations and commitments was reported in our Annual Report on Form 10-K for the year ended December 31, 2016. There have been no material changes from the contractual commitments and obligations previously disclosed in our Annual Report on Form 10-K other than the changes described in Note 9 to the accompanying financial statements.

Capital Spending

We have made capital expenditures primarily for general corporate purposes to support growth and for equipment installations related to our business. Our capital expenditures totaled $6.4 million and $9.1 million during the six months ended June 30, 2017 and 2016 , respectively.

Off-Balance Sheet Arrangements

As of June 30, 2017 , we did not have any off-balance sheet arrangements, as defined in Item 303(a)(4)(ii) of Regulation S-K, that have or are reasonably likely to have a current or future material effect on our financial condition, changes in our financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources. We have issued letters of credit in the ordinary course of business in order to participate in certain demand response programs. As of June 30, 2017 , we had outstanding letters of credit totaling $21.2 million . For information on these commitments and contingent obligations, please refer to “Liquidity and Capital Resources- Borrowings and Credit Arrangements” above and Note 8 to the accompanying financial statements.

Critical Accounting Policies and Use of Estimates

The discussion and analysis of our financial condition and results of operations are based upon our interim unaudited condensed consolidated financial statements, which have been prepared in accordance with GAAP. The preparation of these condensed consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities.

As described in our Form 2016 10-K, the most critical accounting policies and estimates upon which our condensed consolidated financial statements were prepared were those relating to revenue recognition, assumptions used to determine fair value of goodwill and intangible assets, capitalization of software development costs, deferred tax assets and related valuation allowance, and stock-based compensation. We have reviewed our policies and estimates and determined that these remain the most critical accounting policies and estimates for the six months ended June 30, 2017 . We have updated our revenue recognition policies in conjunction with our adoption of ASC 606 as further described in Note 2 to the accompanying financial statement. Readers should refer to our 2016 Form 10-K under “Management’s Discussion and Analysis of Financial Condition and Results of Operation—Critical Accounting Policies and Use of Estimates” and Note 1 to the accompanying financial statements for descriptions of these policies and estimates.

Recent Accounting Pronouncements

For discussion of recent accounting pronouncements, please refer to Note 1 to the accompanying financial statements.



Item 3.	Quantitative and Qualitative Disclosures About Market Risk

Except as disclosed herein, there have been no material changes during the six months ended June 30, 2017 in the foreign exchange risk information and interest rate risk information disclosed in the “Quantitative and Qualitative Disclosures About Market Risk” subsection of the section entitled “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our 2016 Form 10-K.

Foreign Currency Exchange Risk

Our international business is subject to risks, including, but not limited to, unique economic conditions, changes in political climate, differing tax structures, other regulations and restrictions, and foreign exchange rate volatility. Accordingly, our future results could be materially adversely impacted by changes in these or other factors.

A majority of our foreign expense and revenue activities are transacted in local currencies, including Australian dollars, Euros, Brazilian real, British pounds, Canadian dollars, Indian rupee, Japanese yen, South Korean won and New Zealand dollars. Fluctuations in foreign currency rates could affect our sales, cost of revenues and profit margins and could result in exchange losses. In addition, currency fluctuations can result in a loss if we maintain deposits or receivables (third party or intercompany) in a foreign currency. During the three and six months ended June 30, 2017 our sales generated outside the United States as a percentage of consolidated sales were 31% and 40% , respectively, as compared to the three and six months ended June 30, 2016 for which our sales generated outside the United States were 15% and 23% , respectively. We anticipate that sales generated outside the United States will continue to represent greater than 10% of our consolidated sales.

The operating expenses of our international subsidiaries that are incurred in local currencies did not have a material adverse effect on our business, results of operations or financial condition for the three and six months ended June 30, 2017 . Our operating results and certain assets and liabilities that are denominated in foreign currencies are affected by changes in the relative strength of the U.S. dollar against applicable foreign currencies. Our operating expenses denominated in foreign currencies are positively affected when the U.S. dollar strengthens against the applicable foreign currency and adversely affected when the U.S. dollar weakens.

During the three and six months ended June 30, 2017 , we recognized net foreign exchange gains of $1.1 million and $2.7 million , respectively. These net gains primarily relate to intercompany loans, largely driven by fluctuations in the Canadian dollar, Euro, Australian dollar and British pound.

We currently do not have a program in place that is designed to mitigate our exposure to changes in foreign currency exchange rates. From time to time we evaluate potential programs, including the use of derivative financial instruments, to reduce our exposure to foreign exchange gains and losses, and the volatility of future cash flows caused by changes in currency exchange rates. The utilization of forward foreign currency contracts could reduce, but not eliminate, the impact of currency exchange rate movements.

Interest Rate Risk

We incur interest expense on borrowings outstanding under our Convertible Notes and 2014 credit facility. The Convertible Notes have a fixed interest rate. The interest on revolving loans under the 2014 credit facility accrues, at our election, at either (i) the LIBOR (determined based on the per annum rate of interest at which deposits in United States dollars are offered to SVB in the London interbank market) plus 2.00%, or (ii) the “prime rate” as quoted in the Wall Street Journal with respect to the relevant interest period plus 1.00%.

As of June 30, 2017 , we had no outstanding borrowings and had outstanding letters of credit totaling $21.2 million under the 2014 credit facility, which were replaced with restricted cash in August 2017.

The return we earn from cash and cash equivalents will vary as short-term interest rates change. A hypothetical 10% increase or decrease in interest rates would not have a material effect on our financial condition.



Item 4.	Controls and Procedures

Disclosure Controls and Procedures

Our management, including our Chief Financial Officer, who serves as our principal financial officer and who is temporarily performing the function of our principal executive officer while there is a vacancy in that position, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of the end of the period covered by this Quarterly Report on Form 10-Q, concluded that, based on such evaluation, our disclosure controls and procedures were effective to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms, and is accumulated and communicated to our management, including our principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

Internal Control over Financial Reporting

During the period covered by this report, other than as listed below, there were no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

We adopted the new revenue guidance under ASC 606 on January 1, 2017. The adoption of this guidance required the implementation of new accounting processes and procedures, which required us to update our internal controls over accounting for revenue recognition, including the adjustments to accumulated deficit required under the modified retrospective method of adoption, and the related disclosures required under the new guidance. As a result, we implemented new internal controls designed to mitigate the risks associated with these new processes and to provide assurance at a reasonable level of the fair presentation of our consolidated financial statements and related disclosures.

PART II — OTHER INFORMATION



Item 1.	Legal Proceedings

We are subject to legal proceedings, claims and litigation arising in the ordinary course of business. We do not expect the ultimate costs to resolve such matters to have a material adverse effect on our consolidated financial condition, results of operations or cash flows.



Item 1A.	Risk Factors

We operate in a rapidly changing environment that involves a number of risks that could materially affect our business, financial condition or future results, some of which are beyond our control. In addition to the other information set forth in this Quarterly Report on Form 10-Q, the risks and uncertainties that we believe are most important for you to consider are discussed in Part I-Item 1A under the heading “Risk Factors” in our 2016 Form 10-K. As of the date of this Quarterly Report on Form 10-Q, there are no material changes to the risk factors that were disclosed in our 2016 Form 10-K.



Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds

Issuer’s Purchases of Equity Securities

The following table provides information about our purchases of our common stock during the three months ended June 30, 2017 :



Fiscal Period	Total Number of Shares Purchased (1)	Average Price Paid per Share (2)		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
April 1, 2017 - April 30, 2017	93,441	$	6.00	—
May 1, 2017 - May 31, 2017	59	5.75		—
June 1, 2017 - June 30, 2017	5,807	5.45		—
Total for the second quarter of 2017	99,307	$	5.97	—

(1)

In connection with the vesting of restricted stock under our equity incentive plans, we repurchased a total of 99,307 shares of our common stock in the second quarter of fiscal 2017 to cover employee minimum statutory income tax withholding obligations, which we pay in cash to the appropriate taxing authorities on behalf of our employees. Shares withheld (or not issued) to satisfy a tax withholding obligation in connection with an award will immediately be added to the share reserve and become available for issuance.


(2)	Average price paid per share is calculated based on the average price per share related to shares repurchased to cover employee minimum statutory income tax withholding obligations in connection with the vesting of restricted stock under our equity incentive plans. Amounts disclosed are rounded to the nearest two decimal places.



Item 6.	Exhibits



2.1	Agreement and Plan of Merger, dated June 21, 2017, among EnerNOC, Inc., Enel Green Power North America, Inc., Pine Merger Sub, Inc. and Enel S.p.A. (incorporated by reference to Exhibit 2.1 to EnerNOC Inc.’s Current Report on Form 8-K (No. 001-33471) filed with the SEC on June 23, 2017).

31.1*	Certification of Chief Financial Officer of EnerNOC, Inc. pursuant to Rule 13a-14(a) or Rule 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended.

32.1*	Certification of the Chief Financial Officer of EnerNOC, Inc. pursuant to Rule 13a-14(b) promulgated under the Securities Exchange Act of 1934, as amended, and 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101*	The following materials from EnerNOC, Inc.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2017, formatted in XBRL (Extensible Business Reporting Language): (i) the Unaudited Condensed Consolidated Balance Sheets, (ii) the Unaudited Condensed Consolidated Statements of Operations, (iii) the Unaudited Condensed Consolidated Statements of Comprehensive Income (Loss), (iv) the Unaudited Condensed Consolidated Statements of Cash Flows, and (v) Notes to Unaudited Condensed Consolidated Financial Statements.


*	Filed herewith

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



		EnerNOC, Inc.

Date:	August 9, 2017	By:	/s/ William G. Sorenson
			William G. Sorenson
			Chief Financial Officer (principal executive officer and financial officer)

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