Form 10-Q

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

x	Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended June 30, 2013; or

¨	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: 001-34289

World Energy Solutions, Inc.

(Exact name of registrant as specified in its charter)


Delaware		04-3474959
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)

100 Front Street

Worcester, Massachusetts 01608

(Address of principal executive offices) (Zip code)

508-459-8100

(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 past 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 x 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 x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definition of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 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 x

As of August 2, 2013, the registrant had 12,128,630 shares of common stock outstanding.

TABLE OF CONTENTS


		Page
PART I. Financial Information

Item 1.	Financial Statements (Unaudited)

	Condensed Consolidated Balance Sheets as of June 30, 2013 and December 31, 2012		2

	Condensed Consolidated Statements of Operations for the Three and Six Months Ended June 30, 2013 and 2012		3

	Condensed Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2013 and 2012		4

	Notes to Condensed Consolidated Financial Statements		5

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		13

Item 3.	Quantitative and Qualitative Disclosure about Market Risk		22

Item 4.	Controls and Procedures		22

PART II. Other Information

Item 1.	Legal Proceedings		24

Item 1A.	Risk Factors		24

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		24

Item 3.	Defaults Upon Senior Securities		25

Item 4.	Mine Safety Disclosures (Not applicable)		25

Item 5.	Other Information		25

Item 6.	Exhibits		25

PART I

FINANCIAL INFORMATION

Item 1.

Financial Statements

WORLD ENERGY SOLUTIONS, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS


	June 30, 2013			December 31, 2012
	(Unaudited)
Assets
Current assets
Cash and cash equivalents	$	2,191,478		$	3,307,822
Trade accounts receivable, net		7,005,602			7,242,603
Inventory		454,984			154,626
Current portion of deferred tax asset		1,566,280			1,632,280
Prepaid expenses and other current assets		682,800			361,813

Total current assets		11,901,144			12,699,144
Property and equipment, net		604,828			639,839
Intangibles, net		17,143,482			19,092,998
Goodwill		16,167,834			16,167,834
Deferred tax asset, net of current portion		5,690,370			5,844,980
Other assets, net		596,155			685,867

Total assets	$	52,103,813		$	55,130,662

Liabilities and Stockholders’ Equity
Current liabilities
Accounts payable	$	1,704,106		$	1,044,459
Accrued commissions		1,443,132			1,052,802
Accrued compensation		2,244,976			2,494,404
Accrued contingent consideration		3,155,545			3,792,505
Accrued expenses and other current liabilities		698,776			1,390,188
Deferred revenue and customer advances		2,421,488			1,929,377
Current portion of related party subordinated notes payable		2,000,000			1,500,000
Current portion of long-term debt, net of unamortized debt discount of $39,873 at June 30, 2013 and December 31, 2012		1,960,127			1,960,127

Total current liabilities		15,628,150			15,163,862
Long-term debt, net of unamortized debt discount of $69,777 at June 30, 2013 and $89,714 at December 31, 2012		3,430,223			4,410,286
Subordinated notes payable		4,000,000			4,000,000
Deferred revenue and customer advances, net of current portion		4,564,103			3,379,635
Accrued contingent consideration, net of current portion		—			966,752
Related party subordinated notes payable, net of current portion		—			500,000
Other liabilities		16,702			—

Total liabilities		27,639,178			28,420,535

Commitments and contingencies
Stockholders’ equity:
Preferred stock, $0.0001 par value; 5,000,000 shares authorized; no shares issued or outstanding		—			—
Common stock, $0.0001 par value; 30,000,000 shares authorized; 12,064,480 shares issued and 12,006,567 shares outstanding at June 30, 2013 and 11,998,313 shares issued and 11,949,376 shares outstanding at December 31, 2012		1,201			1,195
Additional paid-in capital		44,170,225			43,770,108
Accumulated deficit		(19,447,863	)		(16,836,823	)
Treasury stock, at cost; 57,913 shares at June 30, 2013 and 48,937 shares at December 31, 2012		(258,928	)		(224,353	)

Total stockholders’ equity		24,464,635			26,710,127

Total liabilities and stockholders’ equity	$	52,103,813		$	55,130,662

See accompanying notes to condensed consolidated financial statements.

WORLD ENERGY SOLUTIONS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Revenue:
Brokerage commissions, transaction fees and efficiency projects	$	7,744,234		$	6,944,619		$	16,215,193		$	13,485,403
Management fees		191,423			240,580			377,946			493,203

Total revenue		7,935,657			7,185,199			16,593,139			13,978,606
Cost of revenue		2,144,455			2,158,485			4,377,606			3,981,898

Gross profit		5,791,202			5,026,714			12,215,533			9,996,708

Operating expenses:
Sales and marketing		4,890,347			3,718,771			9,868,428			7,532,954
General and administrative		2,167,021			2,104,202			4,228,694			3,979,239

Total operating expenses		7,057,368			5,822,973			14,097,122			11,512,193

Operating loss		(1,266,166	)		(796,259	)		(1,881,589	)		(1,515,485	)
Interest expense, net		(277,397	)		(98,263	)		(480,134	)		(187,707	)
Other income		20,713			—			13,293			53,106

Loss before income taxes		(1,522,850	)		(894,522	)		(2,348,430	)		(1,650,086	)
Income tax expense		131,305			22,500			262,610			50,000

Net loss	$	(1,654,155	)	$	(917,022	)	$	(2,611,040	)	$	(1,700,086	)

Net loss per share:
Net loss per common share – basic and diluted	$	(0.14	)	$	(0.08	)	$	(0.22	)	$	(0.14	)

Weighted average shares outstanding – basic and diluted		11,982,656			11,893,365			11,974,428			11,880,669

See accompanying notes to condensed consolidated financial statements.

WORLD ENERGY SOLUTIONS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
	2013			2012
Cash flows from operating activities:
Net loss	$	(2,611,040	)	$	(1,700,086	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization		2,077,268			1,582,882
Deferred income taxes		220,610			—
Share-based compensation		292,309			199,444
Loss on disposal of property and equipment		11,177			—
Gain on sale of investment		—			(53,106	)
Non-cash interest expense on warrants		19,937			—
Interest on accrued contingent consideration		19,836			49,864
Changes in operating assets and liabilities:
Trade accounts receivable		237,001			(1,620,889	)
Inventory		(300,358	)		(228,068	)
Prepaid expenses and other current assets		(320,987	)		(335,039	)
Accounts payable		659,647			624,664
Accrued commissions		390,330			71,564
Accrued compensation		(249,428	)		(319,339	)
Accrued expenses, contingent consideration and other current liabilities		(875,756	)		149,153
Deferred revenue and customer advances		1,676,579			2,536,350

Net cash provided by operating activities		1,247,125			957,394

Cash flows from investing activities:
Decrease in other assets		72,699			—
Proceeds from sale of investment		—			770,042
Proceeds from sale of property and equipment		8,750			—
Purchases of property and equipment		(74,239	)		(276,142	)

Net cash provided by investing activities		7,210			493,900

Cash flows from financing activities:
Proceeds from exercise of stock options		107,814			99,722
Purchase of treasury stock		(34,575	)		(2,221	)
Proceeds from issuance of long-term debt		—			2,500,000
Principal payments on long-term debt		(1,000,000	)		—
Payments of contingent consideration		(1,435,548	)		(2,250,000	)
Principal payments on capital lease obligations		(8,370	)		(9,751	)

Net cash (used in) provided by financing activities		(2,370,679	)		337,750

Net (decrease) increase in cash and cash equivalents		(1,116,344	)		1,789,044
Cash and cash equivalents, beginning of period		3,307,822			1,837,801

Cash and cash equivalents, end of period	$	2,191,478		$	3,626,845

Supplemental disclosure of cash flow information:
Cash paid for interest	$	(480,623	)	$	(94,543	)

Cash paid for income taxes	$	(98,050	)	$	(76,030	)

Non-cash activities:
Equipment acquired under capital leases	$	21,416		$	—

See accompanying notes to condensed consolidated financial statements.

WORLD ENERGY SOLUTIONS, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

June 30, 2013

1. Nature of Business and Basis of Presentation

World Energy Solutions, Inc. (“World Energy” or the “Company”) offers a range of energy management solutions to commercial and industrial businesses, institutions, utilities, and governments to reduce their overall energy costs. The Company comes to market with a holistic approach to energy management helping customers a) contract for a competitive price for energy, b) engage in energy efficiency projects to minimize quantity used and c) pursue available rebate and incentive programs. The Company made its mark on the industry with an innovative approach to procurement via its online auction platform, the World Energy Exchange^®. With recent investments and acquisitions, World Energy is building out its energy efficiency practice by engaging new customers while also pursuing more cross-selling opportunities for its procurement services.

2. Interim Financial Statements

The December 31, 2012 condensed consolidated balance sheet has been derived from audited consolidated financial statements and the accompanying June 30, 2013 unaudited interim condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim reporting. Accordingly, they do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete financial statements and should be read in conjunction with the audited consolidated financial statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, as filed with the SEC on April 16, 2013.

In the opinion of the Company’s management, the unaudited interim condensed consolidated financial statements have been prepared on the same basis as the audited consolidated financial statements and include all adjustments consisting of normal recurring adjustments and accruals necessary for the fair presentation of the Company’s financial position as of June 30, 2013, the results of its operations for the three and six months ended June 30, 2013 and 2012 and the results of its cash flows for the six months ended June 30, 2013 and 2012, respectively. The results of operations for the three and six months ended June 30, 2013 are not necessarily indicative of the results to be expected for the fiscal year ending December 31, 2013.

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Accordingly, actual results could differ from these estimates.

The Company’s most judgmental estimates affecting its condensed consolidated financial statements are those relating to revenue recognition and the estimate of actual energy delivered from the bidder to the lister of such energy; share-based compensation; the valuation of intangible assets and goodwill; the valuation of contingent consideration; impairment of long-lived assets; and estimates of future taxable income as it relates to the realization of our net deferred tax assets. The Company regularly evaluates its estimates and assumptions based upon historical experience and various other factors that the Company believes to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. To the extent actual results differ from those estimates, future results of operations may be affected.

3. Loss Per Share

As of June 30, 2013 and 2012, the Company only had one issued and outstanding class of stock – common stock. As a result, the basic loss per share for the three and six months ended June 30, 2013 and 2012 is computed by dividing net loss by the weighted average number of common shares outstanding for the period.

The following table provides a reconciliation of the denominators of the Company’s reported basic and diluted earnings per share computation for the three and six months ended June 30, 2013 and 2012, respectively:


	For the three months ended June 30,				For the six months ended June 30,
	2013		2012		2013		2012
Weighted number of common shares – basic		11,982,656		11,893,365		11,974,428		11,880,669
Common stock equivalents		—		—		—		—

Weighted number of common shares – diluted		11,982,656		11,893,365		11,974,428		11,880,669

The computed loss per share does not assume conversion, exercise, or contingent exercise of securities that would have an antidilutive effect on loss per share. As the Company was in a net loss position for the three and six month periods ended June 30, 2013 and 2012, all common stock equivalents in that period were antidilutive.

The following represents issuable weighted average share information for the respective periods:


	For the three months ended June 30,				For the six months ended June 30,
	2013		2012		2013		2012
Common stock options		43,882		18,495		36,970		29,144
Common stock warrants		742		12,737		1,042		39,648
Unvested restricted stock		36,286		3,863		38,426		2,959

Total common stock equivalents		80,910		35,095		76,438		71,751

In addition, common stock options, unvested restricted stock and common stock warrants of 452,822, 30,000 and 45,045, respectively, were excluded from the calculation of net loss per share, as inclusion of such shares would be antidilutive due to exercise prices or value of proceed shares exceeding the average market price of the Company’s common stock during the three months ended June 30, 2013, and common stock options, unvested restricted stock and common stock warrants of 598,852, 30,000 and 45,045, respectively, were excluded from the calculation of net loss per share, as inclusion of such shares would be antidilutive due to exercise prices or value of proceed shares exceeding the average market price of the Company’s common stock during the six months ended June 30, 2013.

Common stock options and unvested restricted stock of 571,451 and 148, respectively, were excluded from the calculation of net loss per share, as inclusion of such shares would be antidilutive due to exercise prices or value of proceed shares exceeding the average market price of the Company’s common stock during the three months ended June 30, 2012, and common stock options and unvested restricted stock of 527,451 and 148, respectively, were excluded from the calculation of net loss per share, as inclusion of such shares would be antidilutive due to exercise prices or value of proceed shares exceeding the average market price of the Company’s common stock during the six months ended June 30, 2012.

4. Concentration of Credit Risk and Off-Balance Sheet Risk

Financial instruments that potentially expose the Company to concentrations of credit risk consist principally of cash and trade accounts receivable. The Company has no material off-balance sheet risk such as foreign exchange contracts, option contracts, or other foreign hedging arrangements. The Company places its cash with one institution, which management believes is of high credit quality. As of June 30, 2013, all of the Company’s cash is held in an interest bearing account.

The Company provides credit in the form of invoiced and unbilled accounts receivable in the normal course of business. Collateral is not required for trade accounts receivable, but ongoing credit evaluations are performed. While the majority of the Company’s revenue is generated from retail energy transactions where the winning bidder pays a commission to the Company, commission payments for certain auctions can be paid by the lister, bidder or a combination of both. Management provides for an allowance for doubtful accounts on a specifically identified basis, as well as through historical experience applied to an aging of accounts, if necessary. Trade accounts receivable are written off when deemed uncollectible. To date, write-offs have not been material.

The following represents revenue and trade accounts receivable from bidders exceeding 10% of the total in each category:


	Revenue for the three months ended June 30,						Revenue for the six months ended June 30,						Trade Accounts Receivable as of June 30,
Bidder	2013			2012			2013			2012			2013			2012
A		8	%		8	%		9	%		11	%		8	%		8	%
B		12	%		12	%		11	%		12	%		13	%		13	%
C		9	%		8	%		8	%		7	%		9	%		10	%

In addition to its direct relationship with bidders, the Company also has direct contractual relationships with listers for the online procurement of certain of their energy, demand response or environmental needs. These listers are primarily large businesses and government organizations and do not have a direct creditor relationship with the Company. For the three and six months ended June 30, 2013 and 2012, no lister represented more than 10% individually of the Company’s aggregate revenue, respectively.

5. Trade Accounts Receivable, Net

The Company does not invoice bidders for the commissions earned on retail electricity, certain natural gas and demand response transactions and, therefore, reports a significant portion of its receivables as “unbilled.” Unbilled accounts receivable represent management’s best estimate of energy provided by the energy suppliers to the energy consumers for a specific completed time period at contracted commission rates.

The Company generally invoices bidders for commissions earned on retail natural gas and wholesale transactions as well as energy efficiency customers, which are reflected as billed accounts receivable. For natural gas and wholesale transactions, the total commission earned on these transactions is recognized upon completion of the procurement event and are generally due within 30 days of invoice date. For efficiency projects, revenue is recognized and invoiced upon project installation and acceptance, as required, and are generally due within 30 days of invoice date. In addition, the Company invoices the bidder, lister or combination of both for certain auctions performed for environmental commodity product transactions. These transactions are earned and invoiced either upon lister acceptance of the auction results or, in some cases, upon delivery of the credits or cash settlement of the transaction. Trade accounts receivable, net consists of the following:


	June 30, 2013			December 31, 2012
Unbilled accounts receivable	$	5,848,070		$	5,343,559
Billed accounts receivable		1,332,711			2,074,223

		7,180,781			7,417,782
Allowance for doubtful accounts		(175,179	)		(175,179	)

Trade accounts receivable, net	$	7,005,602		$	7,242,603

6. Inventory

Inventory is maintained in the Company’s Energy efficiency services segment and consists of prepaid expendables and project materials. Prepaid expendables represents consumable components that are used in project installations and are stated at the lower of cost or market, with cost being determined on a first-in, first-out (FIFO) basis. Historical inventory usage and current trends are considered in estimating both excess and obsolete inventory. To date, there have been no write-downs of inventory and therefore no allowance for excess or obsolete inventory was recorded at June 30, 2013 or December 31, 2012, respectively. Project materials represent direct costs incurred on projects-in-process as of each reporting period. Inventory consists of the following:


	June 30, 2013		December 31, 2012
Prepaid expendables	$	51,461	$	32,419
Project materials		403,523		122,207

Total inventory	$	454,984	$	154,626

7. Intangibles, Net

Intangibles, net with finite lives were comprised of the following as of June 30, 2013 and December 31, 2012:


		June 30, 2013						December 31, 2012
	Estimated Useful Life	Carrying Amount		Accumulated Amortization		Net		Carrying Amount		Accumulated Amortization		Net
Customer contracts	1 - 4 years	$	5,276,000	$	2,169,000	$	3,107,000	$	5,276,000	$	1,322,000	$	3,954,000
Customer relationships	7 -10 years		13,792,000		4,105,000		9,687,000		13,792,000		3,398,000		10,394,000
Non-compete agreements	5 years		2,585,000		704,000		1,881,000		2,585,000		445,000		2,140,000
Trade names	4 years		1,090,000		358,000		732,000		1,090,000		221,000		869,000

Total		$	22,743,000	$	7,336,000	$	15,407,000	$	22,743,000	$	5,386,000	$	17,357,000

The Company also recorded acquisition related intangible assets with indefinite lives in the amount of $1,736,000 pertaining to customer relationships, not reflected in the above tables.

Amortization expense was approximately $2.0 million and $1.5 million for the six months ended June 30, 2013 and 2012, respectively. In addition, approximately $2.4 million of fully amortized intangible assets were removed from the 2013 and 2012 presentations. The approximate future amortization expense of intangible assets is as follows:


	Amount
Remainder of 2013	$	1,949,000
2014		3,369,000
2015		2,801,000
2016		2,416,000
2017		1,272,000
2018 and thereafter		3,600,000

	$	15,407,000

8. Deferred Revenue and Customer Advances

Deferred revenue and customer advances are primarily related to the Company’s mid-market product line where energy suppliers pay all or a portion of the total commission due from the completed procurements before the Company has met all of the necessary criteria to recognize revenue. As a result, cash received from commission payments are deferred until actual usage data is received or contract end. Deferred revenue and customer advances expected to be recognized as revenue by year are approximately as follows:


	Amount
Remainder of 2013	$	1,823,000
2014		1,579,000
2015		1,995,000
2016		1,184,000
2017		260,000
2018 and thereafter		145,000

Total deferred revenue and customer advances	$	6,986,000

The following table provides a rollforward of deferred revenue and customer advances:


	Amount
Balance at January 1, 2013	$	5,309,000
Cash received		2,651,000
Revenue recognized		(974,000	)

Balance at June 30, 2013	$	6,986,000

9. Segment Reporting

The Company operates its business based on two industry segments: Energy procurement and Energy efficiency services. The Company delivers its Energy procurement services to four markets: retail energy, wholesale energy, demand response and environmental commodity. The Energy procurement process is substantially the same regardless of the market being serviced and is supported by the same operations personnel utilizing the same basic technology and back office support. There is no discrete financial information for these product lines nor are there segment managers who have operating responsibility for each product line. Energy efficiency services focuses on turn-key electrical, mechanical and lighting energy efficiency measures servicing commercial, industrial and institutional customers.

Segment operating loss represents loss from operations including share-based compensation, amortization of intangible assets and depreciation. The following tables present certain continuing operating division information in accordance with the provisions of Accounting Standards Codification (“ASC”) 280, “Segment Reporting”.


	For the three months ended June 30,						For the six months ended June 30,
	2013			2012			2013			2012
Consolidated revenue from external customers:
Energy procurement	$	6,956,838		$	5,847,938		$	14,377,997		$	11,854,201
Energy efficiency services		978,819			1,337,261			2,215,142			2,124,405

Consolidated total revenue	$	7,935,657		$	7,185,199		$	16,593,139		$	13,978,606

Consolidated loss before income taxes:
Energy procurement	$	(1,173,962	)	$	(794,914	)	$	(1,799,501	)	$	(1,332,571	)
Energy efficiency services		(348,888	)		(99,608	)		(548,929	)		(317,515	)

Consolidated loss before income taxes	$	(1,522,850	)	$	(894,522	)	$	(2,348,430	)	$	(1,650,086	)

Energy Procurement:
Amortization	$	943,974		$	668,338		$	1,887,950		$	1,391,130

Depreciation	$	49,263		$	44,999		$	97,827		$	91,052

Interest expense, net	$	277,397		$	60,968		$	480,134		$	112,912

Energy Efficiency Services:
Amortization	$	39,290		$	39,290		$	78,579		$	88,682

Depreciation	$	5,807		$	4,521		$	12,912		$	12,018

Interest expense, net	$	—		$	37,295		$	—		$	74,795


	June 30, 2013			December 31, 2012
Consolidated total assets:
Energy procurement	$	46,425,018		$	48,839,503
Energy efficiency services		5,678,795			6,291,159

Consolidated total assets	$	52,103,813		$	55,130,662

10. Fair Value Measurement and Fair Value of Financial Instruments

The Company follows ASC 820, “Fair Value Measurements and Disclosures” (“ASC 820”) for fair value measurements. ASC 820 defines fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. The standard provides a consistent definition of fair value, which focuses on an exit price, which is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The standard also prioritizes, within the measurement of fair value, the use of market-based information over entity specific information and establishes a three-level hierarchy for fair value measurements based on the nature of inputs used in the valuation of an asset or liability as of the measurement date.

The hierarchy established under ASC 820 gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).

Level 1 - Pricing inputs are quoted prices available in active markets for identical investments as of the reporting date. As required by ASC 820, the Company does not adjust the quoted price for these investments, even in situations where the Company holds a large position and a sale could reasonably impact the quoted price.

Level 2 - Pricing inputs are quoted prices for similar investments, or inputs that are observable, either directly or indirectly, for substantially the full term through corroboration with observable market data. Level 2 includes investments valued at quoted prices adjusted for legal or contractual restrictions specific to these investments.

Level 3 - Pricing inputs are unobservable for the investment, that is, inputs that reflect the reporting entity’s own assumptions about the assumptions market participants would use in pricing the asset or liability. Level 3 includes investments that are supported by little or no market activity.

Assets and liabilities of the Company measured at fair values on a recurring basis as of June 30, 2013 and December 31, 2012 are summarized as follows:


	June 30, 2013		(Level 1)		(Level 2)		(Level 3)
Assets
Cash and cash equivalents	$	2,191,478	$	2,191,478	$	—	$	—

Total Assets	$	2,191,478	$	2,191,478	$	—	$	—

Liabilities
Contingent consideration	$	3,155,545	$	—	$	—	$	3,155,545
Debt discount		109,650		—		109,650		—

Total Liabilities	$	3,265,195	$	—	$	109,650	$	3,155,545


	December 31, 2012		(Level 1)		(Level 2)		(Level 3)
Assets
Cash and cash equivalents	$	3,307,822	$	3,307,822	$	—	$	—

Total Assets	$	3,307,822	$	3,307,822	$	—	$	—

Liabilities
Contingent consideration	$	4,759,257	$	—	$	—	$	4,759,257
Debt discount		129,587		—		129,587		—

Total Liabilities	$	4,888,844	$	—	$	129,587	$	4,759,257

The Company determines the fair value of acquisition-related contingent consideration based on assessment of the probability that the Company would be required to make such future payment. Changes to the fair value of contingent consideration are recorded in general and administrative expense. The following table provides a rollforward of the fair value, as determined by Level 3 inputs, of the contingent consideration.


	June 30, 2013
Outstanding balance at January 1, 2013	$	4,759,257
Payments		(1,435,548	)
Change in fair value included in earnings		(188,000	)
Accrued interest		19,836

Outstanding balance at June 30, 2013	$	3,155,545

The change in fair value reflects the Company’s updated probability related to the NEP earn-out. See Note 13 for additional details. The carrying amounts and fair values of the Company’s debt obligations are as follows:


	June 30, 2013				December 31, 2012
	Carrying Value		Fair Value		Carrying Value		Fair Value
Long-term debt, net of debt discount	$	5,390,350	$	5,390,350	$	6,370,413	$	6,370,413
Debt discount		109,650		109,650		129,587		129,587
Subordinated notes payable		4,000,000		4,000,000		4,000,000		4,000,000
Related party subordinated notes payable		2,000,000		2,000,000		2,000,000		2,000,000

Total debt obligations	$	11,500,000	$	11,500,000	$	12,500,000	$	12,500,000

The carrying amount for fixed rate long-term debt and variable rate long-term approximate fair value because the underlying instruments are primarily at current market rates available to the Company for similar borrowings. The interest rate on the Silicon Valley Bank (“SVB”) debt is tied to the prime rate and will fluctuate with changes in that rate. Related party notes payable are classified as short-term on the Company’s consolidated balance sheet.

11. Credit Arrangements

Credit Facility

The Company has a $9.0 million credit facility with SVB consisting of a $6.5 million term note and a $2.5 million line-of-credit. Under the Fifth Loan Modification and Waiver Agreement with SVB, entered into by the Company on May 13, 2013, the $6.5 million term loan is for 42 months and bears interest at prime rate (currently 3.25%) plus 4.5%. This interest rate can be adjusted downward based on certain EBITDA and leverage ratios. The term loan was interest only for the first three months followed by 39 equal principal payments which commenced on January 1, 2013 and is subject to a 1% prepayment penalty within the first year of funding. The outstanding balance of the term loan is $5.5 million, of which $2.0 million is classified as a current liability at June 30, 2013.

The $2.5 million line-of-credit matures on March 14, 2014 and no borrowings have been made under the line-of-credit to date. Advances under the line-of-credit are subject to availability against certain eligible accounts receivable and eligible retail backlog. The credit facility bears interest at a floating rate per annum based on the prime rate plus 1.25% on advances made against eligible accounts receivable and prime rate plus 2.00% on advances made against eligible retail backlog. These interest rates are subject to change based on the Company’s maintenance of an adjusted quick ratio of one-to-one. The facility contains minimum cash and availability and minimum fixed charge coverage ratio covenants and financial reporting requirements. The Company was in compliance with its covenants as of June 30, 2013.

Subordinated Notes

On October 3, 2012, the Company entered into a Note Purchase Agreement with Massachusetts Capital Resource Company (“MCRC”), in which the Company entered into an 8-year, $4 million Subordinated Note due 2020 with MCRC (the “MCRC Note”). The MCRC Note bears interest at 10.5% and is interest only for the first four years followed by 48 equal principal payments commencing October 31, 2016. The Company must pay a premium of 5% of the total principal outstanding if it prepays the MCRC Note before October 1, 2013, a 3% premium if it prepays the MCRC Note before October 1, 2014, and a 1% premium if it prepays the MCRC Note before October 1, 2015. The MCRC Note is subordinated to the Company’s credit facility with SVB and contains a consolidated net earnings available for interest charges to interest charges covenant, as adjusted, of not less than one-to-one and financial reporting requirements that the Company was in compliance with as of June 30, 2013.

12. Commitments and Contingencies

Litigation

Three former employees/consultants of GSE Consulting, LP (“GSE”) have filed three separate complaints in Texas County Court alleging, among other things, claims related to breach of contract, quantum meruit, promissory estoppel, tortious interference and are seeking declaratory relief. Each plaintiff claims that GSE and/or the Company failed to pay commissions due for services that they provided prior to the date of the Company’s purchase of certain GSE assets. The Company denies the allegations and has filed counterclaims for damages, asserting claims for conversion, unjust enrichment, misappropriation, and violation of the Texas Theft Liability Act. The Company also filed a cross claim against GSE asserting claims of breach of contract and indemnification and request for declaratory relief under the terms of the asset purchase agreement between the Company and GSE. The parties are in the process of discovery in each matter and the court has assigned respective trial dates in September, October and November of 2013. The parties have requested that the Court continue the trial date in September to January 2014.

The Company has estimated the potential commissions due to these former employees to be approximately $400,000. The Company intends to defend these actions vigorously and is currently unable to estimate a range of payments, if any, it may be required to pay, with respect to these claims. However, the Company believes that the resolution of these matters will not result in a material effect to its consolidated financial statements. However, due to uncertainties that accompany litigation of this nature, there could be no assurance that the Company will be successful, and the resolution of the lawsuits could have a material effect on its consolidated financial statements.

13. Acquisitions

The Company accounts for acquisitions using the purchase method in accordance with ASC 805, “Business Combinations.” The results of operations of each acquisition have been included in the accompanying condensed consolidated financial statements as of the date of the acquisition.

NEP

On October 3, 2012, the Company acquired substantially all of the assets and certain obligations of Northeast Energy Partners, LLC (“NEP”) pursuant to an Asset Purchase Agreement (the “Asset Purchase Agreement”) between the Company, NEP, and its members. NEP is a Connecticut-based energy management and procurement company.

The acquisition-date fair value of the consideration transferred totaled approximately $12.1 million. As part of the total consideration, NEP can earn up to $3,180,000 in contingent consideration if certain performance criteria are met post-acquisition. This potential contingent consideration consists of $2.5 million in cash and 153,153 shares of common stock and is due on December 31, 2013. The fair value of the contingent consideration was based on the weighted probability of achievement of certain revenue and earnings before interest, taxes, depreciation and amortization (“EBITDA”) levels for the 12-months ending September 30, 2013. The Company valued this contingent payment at $2.2 million, which has been recorded within current liabilities as accrued contingent consideration. In initially measuring the fair value of the contingent consideration, the Company assigned probabilities to these performance criteria, based among other things on the nature of the performance criteria and the Company’s due diligence performed at the time of the acquisition. Based on financial results through June 30, 2013, the Company reduced the accrued contingent consideration by $0.2 million to $2.0 million. The $0.2 million reduction in this liability has been recorded within general and administrative expense in the second quarter.

The NEP acquisition operating results have been included within the Company’s Energy procurement services segment since the date of acquisition and, therefore, discrete operating results are not maintained for its operations. The following unaudited pro forma information assumes that the acquisitions of NEP had been completed as of the beginning of 2012:


	Three Months Ended June 30, 2012			Six Months Ended June 30, 2012
Revenues	$	8,549,575		$	16,683,639
Net loss	$	(1,124,226	)	$	(2,161,558	)
Net loss per share:
Basic and diluted	$	(0.09	)	$	(0.18	)
Weighted average shares outstanding – basic and diluted		11,893,365			11,880,669

The pro forma financial information is not necessarily indicative of the results to be expected in the future as a result of the acquisition of NEP, as the acquisition did not necessarily reflect the purchase of stand-alone or complete operations, and included several non-recurring revenue events.

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

This quarterly report on Form 10-Q including this Item 2, contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, which involve risks and uncertainties. Readers can identify these statements by forward-looking words such as “may,” “could,” “should,” “would,” “intend,” “will,” “expect,” “anticipate,” “believe,” “estimate,” “continue” or similar words. Our actual results and the timing of certain events may differ significantly from the results and timing discussed in the forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed or referred to in this report and in the “Risk Factors” section of our Annual Report on Form 10-K and any later publicly available filing with the Securities and Exchange Commission (“SEC”). The following discussion and analysis of our financial condition and results of operations should be read in light of those factors and in conjunction with our accompanying condensed consolidated financial statements and notes thereto.

Overview

World Energy offers a range of energy management solutions to commercial and industrial businesses, institutions, utilities, and governments to reduce their overall energy costs. We come to market with a holistic approach to energy management helping customers a) contract for a competitive price for energy, b) engage in energy efficiency projects to minimize quantity used and c) pursue available rebate and incentive programs. We made our mark on the industry with an innovative approach to procurement via our online auction platform, the World Energy Exchange^®. With recent investments and acquisitions, we are building out our energy efficiency practice by engaging new customers while also pursuing more cross-selling opportunities for our procurement services.

We provide energy management services utilizing state-of-the-art technology and the experience of a seasoned management team to bring lower energy costs to its customers. We use a simple equation

E = P · Q – i

to help customers to understand the holistic nature of the energy management problem. Total energy cost (E) is a function of Energy Price (P) times the Quantity of Energy Consumed (Q), minus any rebates or incentives (i) the customer can earn. This approach not only makes energy management more approachable for customers, simplifying what has become an increasingly dynamic and complex problem, it also highlights the inter-related nature of the energy management challenge. We assert that point solution vendors may optimize one of the three elements, but we believe it takes looking at the problem holistically to unlock the most savings.

Acquisitions are an important component of our business strategy. Our focus is on both our core procurement business as well as new product lines within the energy management services industry such as energy efficiency services.

On October 3, 2012, we acquired substantially all of the assets and assumed certain obligations of Northeast Energy Partners, LLC (“NEP”) pursuant to an Asset Purchase Agreement (the “Asset Purchase Agreement”) between us, NEP, and its members. NEP is a Connecticut based energy management and procurement company. The purchase price was approximately $7.9 million in cash and a $2.0 million Promissory Note with NEP (the “NEP Note”). The NEP Note bears interest at 4% with $1.5 million of principal plus interest due on October 1, 2013 and the remaining $500,000 of principal plus interest due April 1, 2014. NEP may also earn up to an additional $3.2 million in cash and shares, with up to $2.5 million in cash, and 153,153 in shares, based on achieving certain 12-month revenue and earnings before interest, taxes, depreciation and amortization (“EBITDA”) targets, as defined. The NEP Note is unsecured and subordinated to financing with Silicon Valley Bank (“SVB”). We financed this acquisition through the use of long-term debt. We borrowed $4.0 million in the form of a 42-month term loan from SVB and $4.0 million in the form of an 8-year subordinated note from Massachusetts Capital Resource Company (“MCRC”).

Our business model is heavily dependent on our people. We have significantly grown our employee base from 20 at the time of our initial public offering in November 2006 to 125 at June 30, 2013. This planned investment in staffing has been, and will continue to be, a key component of our strategic initiatives and revenue growth. While these infrastructure investments result in increased operating costs in the short–term, once they commence to generate incremental revenue the operating leverage within our business model results in positive cash flow and profitability although there can be no assurances of this. To date we have funded our acquisitions and strategic investments primarily with cash on-hand, notes payable, cash from operations and, most recently, long-term notes payable. We have also deferred portions of the purchase prices through the use of earn-outs that are tied to the ongoing performance of the acquired entity. Through the utilization of

seller notes and earn-outs, we have been able to finance a portion of the cost of the acquisitions over time with the targets’ ongoing cash flow. These acquisition activities will increase our operating costs both in the short and long-term and may require us to borrow against our current credit facility and/or raise funds through additional capital raises.

Operations

Revenue

Retail Electricity Transactions

We earn a monthly commission on energy sales contracted through our online auction platform from each bidder or energy supplier based on the energy usage transacted between the bidder and lister or energy consumer. Our commissions are not based on the retail price for electricity; rather on the amount of energy consumed. Commissions are calculated based on the volume of energy usage transacted between the energy supplier and energy consumer multiplied by our contractual commission rate. Our contractual commission rate is negotiated with the energy consumer on a procurement-by-procurement basis based on energy consumer specific circumstances, including the size of auction, the effort required to organize and run the respective auction and competitive factors, among others. Once the contractual commission is agreed to with the energy consumer, all energy suppliers participating in the auction agree to that rate. That commission rate remains fixed for the duration of the contractual term regardless of energy usage. Energy consumers provide us with a letter of authorization to request their usage history from the local utility. We then use this data to compile a usage profile for that energy consumer that will become the basis for the auction. This data may also be used to estimate revenue on a going forward basis, as noted below.

Historically, our revenue and operating results have varied from quarter-to-quarter and are expected to continue to fluctuate in the future. These fluctuations are primarily due to the buying patterns of our wholesale and natural gas customers, which tend to have large, seasonal purchases during the fourth and first quarters and electricity usage having higher demand in our second and third quarters. In addition, the activity levels on the World Energy Exchange can fluctuate due to a number of factors, including market prices, weather conditions, energy consumers’ credit ratings, the ability of suppliers to obtain financing in credit markets, and economic and geopolitical events. To the extent these factors affect the purchasing decisions of energy consumers our future results of operations may be affected. Contracts between energy suppliers and energy consumers are signed for a variety of term lengths, with a one to two year contract term being typical for commercial and industrial energy consumers, and government contracts typically having two to three year terms.

We do not invoice our electricity energy suppliers for monthly commissions earned and, therefore, we report a substantial portion of our receivables as “unbilled.” Unbilled accounts receivable represents management’s best estimate of energy provided by the energy suppliers to the energy consumers for a specific completed time period at contracted commission rates and is made up of two components. The first component represents energy usage for which we have received actual data from the supplier and/or the utility, but for which payment has not been received at the balance sheet date. The majority of our contractual relationships with energy suppliers require them to supply actual usage data to us on a monthly basis and remit payment to us based on that usage. The second component represents energy usage for which we have not received actual data, but for which we have estimated usage. Commissions paid in advance by certain bidders are recorded as deferred revenue and amortized to commission revenue on a monthly basis on the energy exchanged that month.

Retail Natural Gas Transactions

There are two primary fee components to our retail natural gas services: transaction fees and management fees. Transaction fees are billed to and paid by the energy supplier awarded business on the platform. These fees are established prior to award and are the same for each supplier. For the majority of our natural gas transactions, we bill the supplier upon the conclusion of the transaction based on the estimated energy volume transacted for the entire award term multiplied by the transaction fee. Management fees are paid by our energy consumers and are generally billed on a monthly basis for services rendered based on terms and conditions included in contractual arrangements. While substantially all of our retail natural gas transactions are accounted for in accordance with this policy, a certain percentage is accounted for as the natural gas is consumed by the energy consumer and recognized as revenue in accordance with the retail electricity transaction revenue recognition methodology described above.

Mid-Market Transactions

We earn a monthly commission on energy sales from each energy supplier based on the energy usage transacted between the energy supplier and energy consumer. The commissions are not based on the retail price for electricity but rather on the amount of energy consumed. Commissions are calculated based on the energy usage transacted between the energy supplier

and energy consumer multiplied by our contractual commission rate. Revenue from commissions is recognized as earned over the life of each contract as energy is consumed, provided there is persuasive evidence of an arrangement, the sales price is fixed or determinable, collection of the fee is reasonably assured, and customer acceptance criteria, if any, has been successfully demonstrated. We generally recognize revenue on these transactions when we have received verification from the electricity supplier of the end-users power usage and electricity supplier’s subsequent collection of the fees billed to the end user. The verification is generally accompanied with payment of the agreed upon fee to us, at which time the revenue is recognized. Commissions paid in advance are recorded as customer advances and are recognized monthly as commission revenue based on the energy exchanged that month. To the extent we do not receive verification of actual energy usage or we cannot reliably estimate what actual energy usage was for a given period, revenue is deferred until usage and collection data is received from the energy supplier.

Demand Response Transactions

Demand response transaction fees are recognized when we have received confirmation from the demand response provider (“DRP”) that the energy consumer has performed under the applicable Regional Transmission Organization (“RTO”) or Independent System Operator (“ISO”) program requirements. The energy consumer is either called to perform during an actual curtailment event or is required to demonstrate its ability to perform in a test event during the performance period. For the PJM Interconnection (“PJM”), an RTO that coordinates the movement of wholesale electricity in all or parts of 13 states and the District of Columbia, the performance period is June through September in a calendar year. Test results are submitted to the PJM by the DRPs and we receive confirmation of the energy consumer’s performance in the fourth quarter. DRPs typically pay us ratably on a quarterly basis throughout the demand response fiscal (June to May) year.

Wholesale and Environmental Commodity Transactions

Wholesale transaction fees are invoiced upon the conclusion of the auction based on a fixed fee. These revenues are not tied to future energy usage and are recognized upon the completion of the online auction. For reverse auctions where our customers bid for a consumer’s business, the fees are paid by the bidder. For forward auctions where a lister is selling energy products, the fees are typically paid by the lister.

Environmental commodity transaction fees are accounted for utilizing two primary methods. For regulated allowance programs like RGGI, fees are paid by the lister and are recognized quarterly as revenue as auctions are completed and approved. For most other environmental commodity transactions both the lister and the bidder pay the transaction fee and revenue is recognized upon the consummation of the underlying transaction as credits are delivered by the lister and payment is made by the bidder.

Energy Efficiency Services

Our Energy efficiency services segment is primarily project driven where we identify efficiency measures that energy consumers can implement to reduce their energy usage. We present retrofit opportunities to customers, get approval from them to proceed and submit the proposal to the local utility for cost reimbursement. Once the utility approves funding for the project, we install the equipment, typically new heating, ventilation or air conditioning equipment, or replace lighting fixtures to more efficient models. We recognize revenue for Energy efficiency services when persuasive evidence of an arrangement exists, delivery has occurred, the price is fixed or determinable and collectability is reasonably assured. Due to the short-term nature of projects (typically two to three weeks), we utilize the completed-contract method. We also assess multiple contracts entered into by the same customer in close proximity to determine if the contracts should be combined for revenue recognition purposes. Revenues are recognized based upon factors such as passage of title, installation, payments and customer acceptance.

Cost of revenue

Cost of revenue consists primarily of:

•

salaries, employee benefits and share-based compensation associated with our auction management and efficiency services, which are directly related to the development and production of the online auction and maintenance of market-related data on our auction platform and monthly management fees (our supply desk function);

•

project costs including direct labor equipment and materials directly associated with efficiency projects; and

•

rent, depreciation and other related overhead and facility-related costs.

Sales and marketing

Sales and marketing expenses consist primarily of:

•

salaries, employee benefits and share-based compensation related to sales and marketing personnel;

•

third party commission expenses to our channel partners;

•

travel and related expenses;

•

amortization related to customer relationships and contracts;

•

rent, depreciation and other related overhead and facility-related costs; and

•

general marketing costs such as trade shows, marketing materials and outsourced services.

General and administrative

General and administrative expenses consist primarily of:

•

salaries, employee benefits and share-based compensation related to general and administrative personnel;

•

accounting, legal, investor relations, information technology, insurance and other professional fees; and

•

rent, depreciation and other related overhead and facility-related costs.

Interest income (expense), net

Interest income (expense), net consists primarily of:

•

interest income earned on cash held in the bank; and

•

interest expense related to bank term loans, note payable and contingent consideration.

Income tax expense

Income tax expense reflects the release of our deferred tax assets to apply to projected annualized taxable income, federal alternative minimum tax liability and state income taxes.

Results of Operations

The following table sets forth certain items as a percent of revenue for the periods presented:


	For the Three Months Ended June 30,						For the Six Months Ended June 30,
	2013			2012			2013			2012
Revenue		100	%		100	%		100	%		100	%
Cost of revenue		27			30			26			28

Gross profit		73			70			74			72
Operating expenses:
Sales and marketing		62			52			59			54
General and administrative		27			29			26			29

Operating loss		(16	)		(11	)		(11	)		(11	)
Interest expense, net		(3	)		(2	)		(3	)		(1	)
Other income		—			—			—			—
Income tax expense		(2	)		—			(2	)		—

Net loss		(21	)%		(13	)%		(16	)%		(12	)%

Comparison of the Three Months Ended June 30, 2013 and 2012

Revenue


	For the Three Months Ended
	June 30,
	2013		2012		Increase (Decrease)
Energy procurement	$	6,956,838	$	5,847,938	$	1,108,900		19	%
Energy efficiency services		978,819		1,337,261		(358,442	)	(27	)

Total revenue	$	7,935,657	$	7,185,199	$	750,458		10	%

Revenue increased 10% for the three months ended June 30, 2013 as compared to the same period in 2012 as our Energy procurement revenue grew 19%, which was partially offset by a 27% decrease in our Energy efficiency segment. Our Energy procurement segment increased 19% due to the acquisition of NEP and increased transaction activity from new customers in our retail product line. These increases were partially offset by a decrease in our wholesale product line due to the timing of certain transactions in 2013 compared to 2012. Revenue from our Energy efficiency services segment decreased 27% as compared to the prior year as several projects completed at or near quarter end did not get approved under one of our utility programs until the third quarter due to a change in the utility’s close-out procedures implemented at quarter end.

Cost of revenue


	For the Three Months Ended June 30,
	2013					2012
	$		% of Revenue			$		% of Revenue			Increase (Decrease)
Energy procurement	$	1,249,181		18	%	$	1,183,327		20	%	$	65,854		6	%
Energy efficiency services		895,274		91			975,158		73			(79,884	)	(8	)

Total cost of revenue	$	2,144,455		27	%	$	2,158,485		30	%	$	(14,030	)	(1	)%

Cost of revenue decreased 1% for the three months ended June 30, 2013 as compared to the same period in 2012 primarily due to a decrease in equipment, material and labor costs associated with projects completed by our Energy efficiency services segment. Cost of revenue from our Energy procurement segment increased 6% as increased payroll costs associated with our NEP acquisition were partially offset by a decrease in amortization expense. Cost of revenue associated with our Energy procurement segment as a percent of revenue decreased by 2% due to the 19% increase in revenue which was only partially offset by the cost increases. Cost of revenue associated with our Energy efficiency services segment decreased 8% primarily due to a 17% decrease in project material costs directly related to the 27% revenue decrease. This decrease in project costs was partially offset by a 56% increase in payroll costs reflecting the investment in our energy efficiency team over the previous twelve months. Cost of revenue associated with our Energy efficiency services segment as a percent of revenue increased by 18% due to a low contribution margin on a large municipal project completed during the quarter and the increase in headcount noted above.

Operating expenses


	For the Three Months Ended June 30,
	2013					2012
	$		% of Revenue			$		% of Revenue			Increase
Sales and marketing	$	4,890,347		62	%	$	3,718,771		52	%	$	1,171,576	32	%
General and administrative		2,167,021		27			2,104,202		29			62,819	3

Total operating expenses	$	7,057,368		89	%	$	5,822,973		81	%	$	1,234,395	21	%

Sales and marketing expenses increased 32% for the three months ended June 30, 2013 as compared to the same period in 2012 primarily due to increases in payroll, internal and third-party commissions and amortization of intangible assets. Payroll and internal commissions increased due to an increase of nine sales and marketing employees versus the same period in 2012 primarily due to our acquisition of NEP and hires in our Energy efficiency services segment. Third-party commissions increased 19% due to the 43% increase in channel partners compared to the prior period. Amortization expense related to intangible assets increased in 2013 due to our 2012 acquisition of NEP. Sales and marketing expense as a percentage of revenue increased 10% due to the increase in costs described above and due to a change in commission policy for our mid-market group implemented during the period. Under the revised policy, we continue to pay commissions based on cash received from mid-market transactions that are deferred for revenue purposes. In addition, our mid-market sales reps are entitled to certain bookings and quota bonuses to offset the impact of a change in our policy to only accept monthly payment terms for all mid-market transactions. Both of these increases were partially offset by the 10% increase in revenue.

The 3% increase in general and administrative expenses for the three months ended June 30, 2013 as compared to the same period in 2012 was primarily due to increases in legal, occupancy and amortization expense. The increases in occupancy and amortization costs were primarily due to our 2012 acquisition of NEP. These increases were substantially offset by the decrease in accrued contingent consideration during the quarter. The 2% decrease in general and administrative expenses as a percent of revenue was due to the 10% increase in revenue that was substantially offset by the above noted cost increases.

Interest and other income (expense), net

Interest expense, net was approximately $277,000 for the three months ended June 30, 2013 compared to interest expense, net of approximately $98,000 for the three months ended June 30, 2012. The increase in interest expense, net in 2013 was primarily due to interest charged on our long-term debt.

Income tax expense

We recorded income tax expense of approximately $131,000 for the three months ended June 30, 2013 compared to income tax expense of approximately $23,000 for the three months ended June 30, 2012. In the second quarter of 2013 income tax expense reflects a deferred tax provision, federal alternative minimum tax liability and state income taxes. In 2012 income tax expense reflected a federal alternative minimum tax liability and state income taxes.

Net loss

We reported a net loss of approximately $1.7 million for the three months ended June 30, 2013 and a net loss of approximately $0.9 million for the three months ended June 30, 2012, due to the $1.2 million increase in operating expenses which was partially offset by the 10% increase in revenue and the gross margin improvement.

Comparison of the Six Months Ended June 30, 2013 and 2012

Revenue


	For the Six Months Ended
	June 30,
	2013		2012		Increase
Energy procurement	$	14,377,997	$	11,854,201	$	2,523,796	21	%
Energy efficiency services		2,215,142		2,124,405		90,737	4

Total revenue	$	16,593,139	$	13,978,606	$	2,614,533	19	%

Revenue increased 19% for the six months ended June 30, 2013 as compared to the same period in 2012 due to a 21% increase in our Energy procurement segment and a 4% increase in revenue from our Energy efficiency services segment. Our Energy procurement segment increased due to the acquisition of NEP, and, to a lesser extent, increased transaction activity due to new customers. These increases were partially offset by a decrease in wholesale and gas transaction activity due to the timing of certain transactions in 2013 compared to 2012. Revenue from our Energy efficiency services segment increased 4% as compared to the prior year as we completed more projects covered by the four utility efficiency programs than in 2012 and capitalized on cross-sell opportunities.

Cost of revenue


	For the Six Months Ended June 30,
	2013					2012
	$		% of Revenue			$		% of Revenue			Increase
Energy procurement	$	2,497,684		17	%	$	2,429,680		20	%	$	68,004	3	%
Energy efficiency services		1,879,922		85			1,552,218		73			327,704	21

Total cost of revenue	$	4,377,606		26	%	$	3,981,898		28	%	$	395,708	10	%

Cost of revenue increased 10% for the six months ended June 30, 2013 as compared to the same period in 2012 primarily due to increases in equipment, material and labor costs associated with projects completed by our Energy efficiency services segment and the addition of NEP. Cost of revenue for our Energy procurement segment increased 3% as increased payroll costs associated with NEP and our retail product group were substantially offset by a decrease in amortization expense. Cost of revenue associated with our Energy procurement segment as a percent of revenue decreased by 3% due to the 21% increase in revenue with only a marginal increase in costs. Cost of revenue associated with our Energy efficiency services segment increased 21% primarily due to increased payroll costs due to the hiring of additional personnel during 2012 and a 10% increase in project material costs directly related to the 4% revenue increase. Cost of revenue associated with our Energy efficiency services segment as a percent of revenue increased by 12% due to the headcount increases noted above and the impact of a low contribution margin on a large municipal project completed during the second quarter.

Operating expenses


	For the Six Months Ended June 30,
	2013					2012
	$		% of Revenue			$		% of Revenue			Increase
Sales and marketing	$	9,868,428		59	%	$	7,532,954		54	%	$	2,335,474	31	%
General and administrative		4,228,694		26			3,979,239		29			249,455	6

Total operating expenses	$	14,097,122		85	%	$	11,512,193		83	%	$	2,584,929	22	%

Sales and marketing expenses increased 31% for the six months ended June 30, 2013 as compared to the same period in 2012 primarily due to increases in payroll, internal and third party commissions and amortization of intangible assets. Payroll and internal commissions increased due to an increase of nine sales and marketing employees versus the same period in 2012 primarily due to our acquisition of NEP and hires in our Energy efficiency services segment. Third-party commissions increased 25% due to the 43% increase in channel partners compared to the prior period. Amortization expense related to intangible assets increased in 2013 due to our 2012 acquisition of NEP. Sales and marketing expense as a percentage of revenue increased 5% due to the increase in costs and the change in our mid-market commission plan both described above, which were partially offset by the 19% increase in revenue.

The 6% increase in general and administrative expenses for the six months ended June 30, 2013 as compared to the same period in 2012 was primarily due to increases in payroll, legal and amortization expense. These increased costs were primarily due to additions in our back office operations to support our growth, costs associated with the GSE litigation and our 2012 acquisition of NEP and were partially offset by a decrease in accrued contingent consideration in the second quarter. General and administrative expenses as a percent of revenue decreased 3% as the 19% increase in revenue offset the above noted cost increases.

Interest and other income (expense), net

Interest expense, net was approximately $480,000 for the six months ended June 30, 2013 compared to interest expense, net of approximately $188,000 for the six months ended June 30, 2012. The increase in interest expense, net in 2013 was primarily due to interest charged on our long-term debt. Other income in the first quarter of 2012 primarily consisted of $53,000 that was recognized from the sale of our investment in Retroficiency.

Income tax expense

We recorded income tax expense of approximately $263,000 for the six months ended June 30, 2013 compared to income tax expense of $50,000 for the six months ended June 30, 2012. In the first six months of 2013 income tax expense reflects a deferred tax provision, federal alternative minimum tax liability and state income taxes. In 2012 income tax expense reflected a federal alternative minimum tax liability and state income taxes.

Net loss

Net loss increased approximately $0.9 million for the six months ended June 30, 2013 compared to the same period in 2012, primarily due to the $2.6 million increase in operating expenses which was partially offset by the 19% increase in revenue and the gross margin improvement.

Liquidity and Capital Resources

At June 30, 2013 we had no commitments for material capital expenditures. We have identified and executed against a number of strategic initiatives that we believe are key components of our future growth, including: making strategic acquisitions; entering into other energy-related markets including wholesale transactions with utilities, energy efficiency, and demand response; expanding our community of listers, bidders and channel partners on our exchanges; strengthening and extending our long-term relationships with government agencies; and growing our direct and inside sales force. As of June 30, 2013 our workforce numbered 125, a decrease of one employee from the number that we employed at December 31, 2012. At June 30, 2013, we had 57 professionals in our sales and marketing and account management groups, 47 in our supply desk group and 21 in our general and administrative group.

We paid $10.4 million to acquire three businesses in 2011 through the use of cash on hand, cash flow from ongoing operations as well cash flow generated by the acquisitions. Since 2011, we have paid an additional $3.0 million in required installments against seller notes and an additional $3.7 million for earn-outs related to these acquisitions. In early 2012 we expanded our credit facility with SVB to include a 4-year, $2.5 million term loan. We borrowed an additional $10.0 million to acquire NEP in October 2012 which included: increasing our term loan with SVB by $4.0 million to $6.5 million, borrowing $4.0 million in subordinated long-term debt from MCRC, and entering into a $2.0 million seller note with NEP. In addition, NEP can earn an additional $3.2 million in the form of earn-outs if certain operating performance criteria are met post-acquisition. We currently have $5.4 million of outstanding principal with SVB, with $2.0 million classified as short-term, and $4.0 million outstanding with MCRC classified as long-term. In addition, the $2.0 million seller note related to the

NEP acquisition and $3.5 million in maximum potential cash earn-out obligations related to NEP and GSE are due within the next twelve months. While the expansion/addition of these debt instruments significantly increased our commitments, we believe we have the resources to meet both our short- and long-term obligations under these arrangements based on cash on-hand, operating cash flows from our base business and cash expected to be generated from all of our acquired businesses. During the first six months of 2013 we generated cash flow from operations of $1.3 million and ended the quarter with $2.2 million in cash and cash equivalents.

Comparison of June 30, 2013 to December 31, 2012


	June 30, 2013			December 31, 2012			Increase (Decrease)
Cash and cash equivalents	$	2,191,478		$	3,307,822		$	(1,116,344	)	(34	)%
Trade accounts receivable, net		7,005,602			7,242,603			(237,001	)	(3	)
Days sales outstanding		80			65			15		23
Deferred revenue and customer advances		6,985,591			5,309,012			1,676,579		32
Working capital (deficit)		(3,727,006	)		(2,464,718	)		(1,262,288	)	(51	)
Stockholders’ equity		24,464,635			26,710,127			(2,245,492	)	(8	)

Cash and cash equivalents decreased 34% primarily due to approximately $1.4 million of payments of contingent consideration and $1.0 million of principal payments on the SVB term note. These decreases were partially offset by cash flows from operations of approximately $1.2 million. Trade accounts receivable decreased $0.2 million as compared to the fourth quarter of 2012 due to a $2.3 million, or 22%, decrease in revenue in the second quarter of 2013 versus the fourth quarter of 2012. This decrease was substantially offset by an increase in days sales outstanding. Days sales outstanding (representing accounts receivable outstanding at June 30, 2013 divided by the average sales per day during the current quarter, as adjusted) increased 23% due to the timing of in-period revenue recognized within the second quarter of 2013 as compared to the fourth quarter of 2012. Revenue from bidders representing 10% or more of our revenue decreased to 11% from one bidder during the six months ended June 30, 2013, from 23% from two bidders during the same period in 2012.

Deferred revenue and customer advances increased due primarily to upfront commission payments related to our mid-market product line being deferred to future periods for revenue recognition purposes. The working capital balance at June 30, 2013 (consisting of current assets less current liabilities) decreased $1.3 million from December 31, 2012 primarily due to the reclassifications of $1.0 million of long-term debt, $1.0 million of accrued contingent consideration and $0.5 million of related party subordinated notes payable from non-current to current. These decreases were partially offset by adjusted EBITDA of $0.5 million for the six months ended June 30, 2013 and cash received classified as long-term deferred revenue during the six months. Stockholders’ equity decreased 8% for the six months ended June 30, 2013 due to a $2.6 million net loss, partially offset by share-based compensation and proceeds from the exercise of stock options.

Cash provided by operating activities for the six months ended June 30, 2013 was approximately $1.2 million compared to cash provided by operating activities for the six months ended June 30, 2012 of approximately $1.0 million. Cash flow from operations in 2013 was primarily due to a $1.7 million increase in deferred revenue and customer advances offset by an inventory increase of $0.3 million. Cash used in investing and financing activities for the six months ended June 30, 2013 was approximately $2.4 million primarily due to the payment of $1.4 million of contingent consideration and $1.0 million of principal payments on our SVB term loan. Cash from investing and financing activities for the six months ended June 30, 2012 was approximately $0.8 million primarily due to cash received from the sale of our Retroficiency investment and proceeds from our term loan with SVB, offset by the payment of $2.3 million of contingent consideration related to our 2011 acquisitions and $0.3 million of fixed asset additions related to our office moves.

EBITDA, representing net loss before interest, income taxes, depreciation and amortization was $0.2 million for the six months ended June 30, 2013, an increase from approximately $0.1 million for the same period in the prior year. Please refer to the section below discussing non-GAAP financial measures for a reconciliation of non-GAAP measures to the most directly comparable measure calculated and presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”).

In this Quarterly Report on Form 10-Q, we provide certain “non-GAAP financial measures”. A non-GAAP financial measure refers to a numerical financial measure that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable financial measure calculated and presented in accordance with GAAP in our financial statements. In this Quarterly Report on Form 10-Q, we provide EBITDA and adjusted EBITDA as additional information relating to our operating results. These non-GAAP measures exclude expenses related to share-based compensation, depreciation related to our fixed assets, amortization expense related to acquisition-related assets and other assets, interest expense on bank borrowings, notes payable to sellers and contingent consideration, interest income on invested funds and notes receivable, and income taxes. Management uses these non-GAAP measures for internal reporting and bank reporting

purposes. We have provided these non-GAAP financial measures in addition to GAAP financial results because we believe that these non-GAAP financial measures provide useful information to certain investors and financial analysts in assessing our operating performance due to the following factors:

•

We believe that the presentation of a non-GAAP measure that adjusts for the impact of share-based compensation expenses, depreciation of fixed assets, amortization expense related to acquisition-related assets and other assets, interest expense on bank borrowings, seller notes and contingent consideration, interest income on invested funds and notes receivable, and income taxes, provides investors and financial analysts with a consistent basis for comparison across accounting periods and, therefore, is useful to investors and financial analysts in helping them to better understand our operating results and underlying operational trends;

•

Although share-based compensation is an important aspect of the compensation of our employees and executives, share-based compensation expense is generally fixed at the time of grant, then amortized over a period of several years after the grant of the share-based instrument, and generally cannot be changed or influenced by management after the grant;

•

We do not acquire intangible assets on a predictable cycle. Our intangible assets relate solely to business acquisitions. Amortization costs are fixed at the time of an acquisition, are then amortized over a period of several years after the acquisition and generally cannot be changed or influenced by management after the acquisition;

•

We do not regularly incur capitalized software and website costs. Our capitalized software costs relate primarily to the build-out of our exchanges. Amortization costs are fixed at the time the costs are incurred and are then amortized over a period of several years and generally cannot be changed or influenced by management after the initial costs are incurred;

•

We do not regularly invest in fixed assets. Our fixed assets relate primarily to computer and office equipment and furniture and fixtures. Depreciation costs are fixed at the time of purchase and are then depreciated over several years and generally cannot be changed or influenced by management after the purchase;

•

We do not regularly enter into bank debt, seller notes and/or pay interest on contingent consideration. Our seller notes and contingent consideration relate to acquisition activities. Interest expense is fixed at the time of purchase and recorded over the life of the lease and generally cannot be changed or influenced by management after the purchase;

•

We do not regularly earn interest on our cash accounts and notes receivable. Our cash is invested in U.S. Treasury funds and has not yielded material returns to date and these returns generally cannot be changed or influenced by management; and

•

We do not regularly pay federal or state income taxes due to our net operating loss carryforwards. Our income tax expense reflects the release of our deferred tax assets to apply to projected annualized taxable income, and an anticipated alternative minimum tax liability based on statutory rates that generally cannot be changed or influenced by management.

Pursuant to the requirements of the SEC, we have provided below a reconciliation of the non-GAAP financial measures used to the most directly comparable financial measures prepared in accordance with GAAP. These non-GAAP financial measures are not prepared in accordance with GAAP. These measures may differ from the GAAP information, even where similarly titled used by other companies, and therefore should not be used to compare our performance to that of other companies. The presentation of this additional information is not meant to be considered in isolation or as a substitute for net loss prepared in accordance with GAAP.


	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
GAAP net loss	$	(1,654,155	)	$	(917,022	)	$	(2,611,040	)	$	(1,700,086	)
Add: Interest expense, net		277,397			98,263			480,134			187,707
Add: Income taxes		131,305			22,500			262,610			50,000
Add: Amortization of intangibles		974,758			698,894			1,949,516			1,458,141
Add: Amortization of other assets		8,506			8,734			17,013			21,671
Add: Depreciation		55,070			49,520			110,739			103,070

Non-GAAP EBITDA (deficit)	$	(207,119	)	$	(39,111	)	$	208,972		$	120,503

Non-GAAP EBITDA per share	$	(0.02	)	$	—		$	0.02		$	0.01

Add: Share-based compensation		146,323			79,903			292,309			199,444

Non-GAAP adjusted EBITDA (deficit)	$	(60,796	)	$	40,792		$	501,281		$	319,947

Non-GAAP adjusted EBITDA per share	$	(0.01	)	$	—		$	0.04		$	0.03

Weighted average diluted shares		11,982,656			11,928,460			12,050,866			11,952,420

Critical Accounting Policies

The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Accordingly, actual results could differ from these estimates.

The most judgmental estimates affecting our consolidated financial statements are those relating to revenue recognition and the estimate of actual energy delivered from the bidder to the lister of such energy; share-based compensation; the valuation of intangible assets and goodwill; the valuation of contingent consideration; impairment of long-lived assets; and estimates of future taxable income as it relates to the realization of our net deferred tax assets. We regularly evaluate our estimates and assumptions based upon historical experience and various other factors that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. To the extent actual results differ from those estimates; future results of operations may be affected. Refer to Note 2 of our consolidated financial statements within our Annual Report on Form 10-K as filed with the SEC on April 16, 2013 for a description of our accounting policies.

Off-Balance Sheet Arrangements

We currently have no off-balance sheet arrangements that have or are reasonably likely to have a current or future material effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

Item 3.

Quantitative and Qualitative Disclosure about Market Risk

As a smaller reporting company as defined by Rule 12b-2 of the Exchange Act and in Item 10(f)(1) of Regulation S-K, we are electing scaled disclosure reporting obligations and therefore are not required to provide the information requested by this Item.

Item 4.

Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As required by Rule 13a-15 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), we carried out an evaluation under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). In designing and evaluating our disclosure controls and procedures, our management recognizes that there are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their desired control objectives. Additionally, in evaluating and implementing possible controls and procedures, our management was required to apply its reasonable judgment.

In making this assessment, our management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control-Integrated Framework. Based upon this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were not effective as of June 30, 2013.

Internal Control Over Financial Reporting

On October 3, 2012, we acquired substantially all of the assets and certain obligations of NEP. While our financial statements for the three and six months ended June 30, 2013 included the results of NEP from the acquisition date through June 30, 2013, as permitted by the rules and regulations of the SEC, our management’s assessment of our internal control over financial reporting did not include an evaluation of NEP’s internal control over financial reporting. Further, our management’s conclusion regarding the effectiveness of our internal control over financial reporting as of June 30, 2013 and December 31, 2012 does not extend to NEP’s internal control over financial reporting. We are currently integrating policies, processes, technology and operations for the combined companies and will continue to evaluate our internal control over financial reporting as we develop and execute our integration plans.

Based on its evaluation, our management concluded that, as of June 30, 2013, our internal control over financial reporting was not effective based on the COSO criteria and that we had a material weakness. A “material weakness” is defined as a significant deficiency, or a combination of significant deficiencies, that results in more than a remote likelihood that a material misstatement of the annual or interim financial statements will not be prevented or detected.

As disclosed in our previous filings with the Securities and Exchange Commission, on March 29, 2013, our Board of Directors, based on the recommendation of the Audit Committee and in consultation with management, made the determination to restate our previously issued audited financial statements for the year ended December 31, 2011 included in our Annual Report on Form 10-K, and our unaudited financial statements for the quarterly periods ended March 31, 2012, June 30, 2012, and September 30, 2012 included in our Quarterly Reports on Forms 10-Q and the unaudited pro forma disclosures included in our Current Report on Form 8-K/A filed on December 17, 2012. In connection with the preparation of our annual report on Form 10-K for the year ended December 31, 2012, we identified a material weakness in the design and operating effectiveness of our internal control over financial reporting related to the recording of revenue recognition for certain commission payments related to our mid-market product line. Specifically, we did not select and apply the appropriate accounting policies for GSE, which we acquired on October 31, 2011. Consequently, effective controls did not exist to ensure that revenue from this product line was appropriately and accurately recorded.

Plan for Remediation of Material Weakness

As soon as we learned of the material weakness, we began taking steps intended to remediate this material weakness and to improve our control processes and procedures with respect to revenue recognition in general as part of our efforts to become compliant with the requirements of Section 404 of the Sarbanes-Oxley Act of 2002. These activities include:

•

implementing a revised accounting policy for our mid-market product-line;

•

establishing new policies, procedures and controls to ensure the new policy is administered correctly;

•

evaluating the proper organizational structure, including hiring a sufficient complement of personnel with the requisite knowledge and expertise of revenue recognition accounting standards under U.S. GAAP; and

•

to the extent necessary, hiring consultants with accounting expertise with specific expertise with revenue recognition.

In particular, our remediation plan is being designed to ensure that the recording of revenue recognition for certain commission payments is appropriate.

Changes in Internal Control Over Financial Reporting

There was no change in our internal control over financial reporting that occurred during the three months ended June 30, 2013 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II

OTHER INFORMATION

Item 1.

Legal Proceedings

Three former employees/consultants of GSE Consulting, LP (“GSE”) have filed three separate complaints in Texas County Court alleging, among other things, claims related to breach of contract, quantum meruit, promissory estoppel, tortious interference and are seeking declaratory relief. Each plaintiff claims that GSE and/or we failed to pay commissions due for services that they provided prior to the date of our purchase of certain GSE assets. We deny the allegations and have filed counterclaims for damages, asserting claims for conversion, unjust enrichment, misappropriation, and violation of the Texas Theft Liability Act. We have also filed a cross claim against GSE asserting claims of breach of contract and indemnification and request for declaratory relief under the terms of the asset purchase agreement between us and GSE. The parties are in the process of discovery in each matter and the court has assigned respective trial dates in September, October and November of 2013. The parties have requested that the Court continue the trial date in September to January 2014.

We have estimated the potential commissions due to these former employees to be approximately $400,000. We intend to defend these actions vigorously and are currently unable to estimate a range of payments, if any, we may be required to pay, with respect to these claims. However, we believe that the resolution of these matters will not result in a material effect to our consolidated financial statements. However, due to uncertainties that accompany litigation of this nature, there could be no assurance that we will be successful, and the resolution of the lawsuits could have a material effect on our consolidated financial statements.

From time to time, we are subject to legal proceedings and claims arising from the conduct of our business operations, including litigation related to employment matters. While it is impossible to ascertain the ultimate legal and financial liability with respect to contingent liabilities, including lawsuits, we believe that the aggregate amount of such liabilities, if any, will not have a material adverse effect on our consolidated financial position and/or results of operations. It is possible, however, that future financial position or results of operations for any particular period could be materially affected by changes in our assumptions or strategies related to those contingencies or changes out of our control.

Item 1A.

Risk Factors

There have been no material changes from risk factors previously disclosed in our annual report on Form 10-K for the fiscal year ended December 31, 2012, as filed with the Securities and Exchange Commission on April 16, 2013.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

Recent Sales of Unregistered Securities; Use of Proceeds from Registered Securities

During the quarter ended June 30, 2013, we did not sell any unregistered equity securities.

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

In connection with the vesting of restricted stock granted to employees, we withheld certain shares with value equivalent to employees’ minimum statutory obligations for the applicable income and other employment taxes.

A summary of the shares withheld to satisfy employee tax withholding obligations for the three months ended June 30, 2013 is as follows:


Period	Total Number of Shares Purchased		Average Price Paid Per Share		Total Number of Shares Purchased As Part of Publicly Announced Plans Or Programs		Maximum Number of Shares That May Yet Be Purchased Under The Plans Or Programs
4/01/13 – 4/30/13		—	$	—		—		—
5/01/13 – 5/31/13		—	$	—		—		—
6/01/13 – 6/30/13		8,968	$	3.85		—		—

Total		8,968	$	3.85		—		—

Item 3.

Defaults Upon Senior Securities

None.

Item 4.

Mine Safety Disclosures (not applicable)

None.

Item 5.

Other Information

None.

Item 6.

Exhibits


31.1		Certification of the Chief Executive Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.

31.2		Certification of the Chief Financial Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.

32.1		Certification of the Chief Executive Officer pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002.

32.2		Certification of the Chief Financial Officer pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002.

101*		The following materials from World Energy Solutions, Inc.’s Quarterly Report on Form 10-Q for the three and six months ended June 30, 2013, formatted in Extensible Business Reporting Language: (i) the condensed consolidated balance sheets; (ii) the condensed consolidated statements of operations; (iii) the condensed consolidated statements of cash flows; and (iv) notes to the condensed consolidated financial statements.

This exhibit shall not be deemed “filed” for purposes of Section 18 of the Exchange Act, or otherwise subject to the liability of that section, nor shall it be deemed incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Exchange Act, whether made before or after the date hereof and irrespective of any general incorporation language in any filing, except to the extent the Company specifically incorporates it by reference.

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.


	World Energy Solutions, Inc.

Dated: August 8, 2013	By:	/s/ Philip Adams
		Philip Adams
		Chief Executive Officer

Dated: August 8, 2013	By:	/s/ James Parslow
		James Parslow
		Chief Financial Officer

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