SEC Filing | Orion Energy Systems

ORION ENERGY SYSTEMS, INC.

Registrant

/s/ Scott R. Jensen

Scott R. Jensen

Chief Financial Officer

(Principal Financial Officer and Authorized Signatory)

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Form 10-Q

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 December 31, 2011

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

Commission file number 001-33887

Orion Energy Systems, Inc.

(Exact name of Registrant as specified in its charter)


Wisconsin		39-1847269
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification number)


2210 Woodland Drive, Manitowoc, Wisconsin		54220
(Address of principal executive offices)		(Zip code)

Registrant’s telephone number, including area code: (920) 892-9340

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days. Yes 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) during the preceding 12 months (or for 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 the definitions of “accelerated filer,” “large accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):


Large accelerated filer	¨	Accelerated filer x

Non-accelerated filer	¨ (Do not check if a smaller reporting company)	Smaller reporting company ¨

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

There were 22,562,258 shares of the Registrant’s common stock outstanding on June 6, 2012.

Orion Energy Systems, Inc.

Quarterly Report On Form 10-Q

For The Quarter Ended December 31, 2011

Table Of Contents


		Page(s)
PART I FINANCIAL INFORMATION		3
ITEM 1. Financial Statements (unaudited)		3
Condensed Consolidated Balance Sheets as of March 31, 2011 and December 31, 2011		3
Condensed Consolidated Statements of Operations for the Three and Nine Months Ended December 31, 2010 and 2011		4
Condensed Consolidated Statements of Cash Flows for the Nine Months Ended December 31, 2010 and 2011		5
Notes to the Condensed Consolidated Financial Statements		6
ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		21
ITEM 3. Quantitative and Qualitative Disclosures about Market Risk		32
ITEM 4. Controls and Procedures		32
PART II OTHER INFORMATION
ITEM 1A. Risk Factors		33
ITEM 5. Other Information		34
ITEM 6. Exhibits		35
SIGNATURES		36

PART I – FINANCIAL INFORMATION

Item 1: Financial Statements

ORION ENERGY SYSTEMS, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands, except share and per share amounts)

		September 30,			September 30,
	March 31,			December 31,
	2011			2011
Assets
Cash and cash equivalents	$	11,560		$	18,233
Short-term investments		1,011			1,015
Accounts receivable, net of allowances of $757 and $831		23,401			20,509
Inventories, net		15,877			19,473
Deferred contract costs		9,589			2,686
Deferred tax assets		1,049			1,254
Prepaid expenses and other current assets		1,727			2,280

Total current assets		64,214			65,450
Property and equipment, net		30,017			30,595
Patents and licenses, net		1,620			1,702
Long-term accounts receivable		7,251			8,496
Long-term inventory		13,212			13,212
Deferred tax assets		2,354			2,461
Other long-term assets		2,419			2,985

Total assets	$	121,087		$	124,901

Liabilities and Shareholders’ Equity
Accounts payable	$	12,483		$	15,488
Accrued expenses and other		2,184			3,511
Deferred revenue, current		8,427			2,596
Current maturities of long-term debt		1,137			2,344

Total current liabilities		24,231			23,939
Long-term debt, less current maturities		4,225			6,341
Deferred revenue, long-term		1,777			1,527
Other long-term liabilities		399			400

Total liabilities		30,632			32,207

Commitments and contingencies (See Note F)
Shareholders’ equity:
Preferred stock, $0.01 par value: Shares authorized: 30,000,000 at March 31, 2011 and December 31, 2011; no shares issued and outstanding at March 31, 2011 and December 31, 2011		—			—
Common stock, no par value: Shares authorized: 200,000,000 at March 31, 2011 and December 31, 2011; shares issued: 30,312,758 and 30,411,704 at March 31, 2011 and December 31, 2011; shares outstanding: 22,893,803 and 22,924,746 at March 31, 2011 and December 31, 2011		—			—
Additional paid-in capital		124,132			126,072
Stockholder notes receivable		(193	)		(217	)
Treasury stock: 7,431,897 and 7,486,958 common shares at March 31, 2011 and December 31, 2011		(31,708	)		(32,025	)
Accumulated deficit		(1,776	)		(1,136	)

Total shareholders’ equity		90,455			92,694

Total liabilities and shareholders’ equity	$	121,087		$	124,901

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

ORION ENERGY SYSTEMS, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except share and per share amounts)


	Three Months Ended December 31,						Nine Months Ended December 31,
	2010			2011			2010			2011
Product revenue	$	21,633		$	24,274		$	52,476		$	71,746
Service revenue		2,011			3,132			3,997			7,356

Total revenue		23,644			27,406			56,473			79,102
Cost of product revenue		14,134			17,445			34,186			50,484
Cost of service revenue		1,676			2,447			3,091			5,716

Total cost of revenue		15,810			19,892			37,277			56,200

Gross profit		7,834			7,514			19,196			22,902
Operating expenses:
General and administrative		2,709			2,841			8,642			8,641
Sales and marketing		3,235			4,053			10,124			11,557
Research and development		614			556			1,797			1,771

Total operating expenses		6,558			7,450			20,563			21,969

Income (loss) from operations		1,276			64			(1,367	)		933
Other income (expense):
Interest expense		(98	)		(160	)		(223	)		(397	)
Dividend and interest income		189			226			435			594

Total other income (expense)		91			66			212			197

Income (loss) before income tax		1,367			130			(1,155	)		1,130
Income tax expense (benefit)		1,549			56			(976	)		490

Net income (loss)	$	(182	)	$	74		$	(179	)	$	640

Basic net income (loss) per share attributable to common shareholders	$	(0.01	)	$	0.00		$	(0.01	)	$	0.03
Weighted-average common shares outstanding		22,726,426			22,996,050			22,629,776			22,969,169
Diluted net income (loss) per share attributable to common shareholders	$	(0.01	)	$	0.00		$	(0.01	)	$	0.03
Weighted-average common shares outstanding		22,726,426			23,254,830			22,629,776			23,388,651

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

ORION ENERGY SYSTEMS, INC. AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)


	Nine Months Ended December 31,
	2010			2011
Operating activities
Net income (loss)	$	(179	)	$	640
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization		2,414			3,029
Stock-based compensation expense		931			966
Deferred income tax benefit		(595	)		(312	)
Gain on sale of property and equipment		13			(15	)
Change in bad debt expense		85			74
Other		38			61
Changes in operating assets and liabilities:
Accounts receivable		(10,138	)		1,573
Inventories		(6,239	)		(3,596	)
Deferred contract costs		(5,562	)		6,903
Prepaid expenses and other		(2,044	)		(1,089	)
Deferred revenue		3,162			(6,081	)
Accounts payable		7,602			3,005
Accrued expenses		(73	)		1,328

Net cash (used in) provided by operating activities		(10,585	)		6,486
Investing activities
Purchase of property and equipment		(2,986	)		(3,398	)
Purchase of property and equipment held under operating leases		(2,126	)		(3	)
Purchase of short-term investments		(10	)		(4	)
Additions to patents and licenses		(138	)		(184	)
Proceeds from sales of property, plant and equipment		1			5
Long-term assets		(330	)		—

Net cash used in investing activities		(5,589	)		(3,584	)
Financing activities
Payment of long-term debt		(528	)		(1,260	)
Proceeds from long-term debt		2,689			4,583
Proceeds from repayment of shareholder notes		1			47
Repurchase of common stock into treasury		—			(279	)
Excess tax benefits from stock-based compensation		193			682
Deferred financing costs		(61	)		(124	)
Proceeds from issuance of common stock		374			122

Net cash provided by financing activities		2,668			3,771

Net increase (decrease) in cash and cash equivalents		(13,506	)		6,673
Cash and cash equivalents at beginning of period		23,364			11,560

Cash and cash equivalents at end of period	$	9,858		$	18,233

Supplemental cash flow information:
Cash paid for interest	$	192		$	347
Cash paid for income taxes	$	31		$	96
Supplemental disclosure of non-cash investing and financing activities:
Shares issued from treasury for shareholder note receivable	$	158		$	71
Shares surrendered into treasury from stock option exercise	$	51		$	—

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

ORION ENERGY SYSTEMS, INC. AND SUBSIDIARIES

UNAUDITED NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

NOTE A — DESCRIPTION OF BUSINESS

Organization

The Company includes Orion Energy Systems, Inc., a Wisconsin corporation, and all consolidated subsidiaries. The Company is a developer, manufacturer and seller of lighting and energy management systems and a seller and integrator of renewable energy technologies to commercial and industrial businesses, predominantly in North America.

In August 2009, the Company created Orion Engineered Systems, a new operating division offering additional alternative renewable energy systems. The Company first introduced the presentation of operating segments for the quarter ended December 31, 2010. See Note I “Segment Reporting” of these financial statements for further discussion of our reportable segments.

The Company’s corporate offices and manufacturing operations are located in Manitowoc, Wisconsin and an operations facility occupied by Orion Engineered Systems is located in Plymouth, Wisconsin.

NOTE B — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The condensed consolidated financial statements include the accounts of Orion Energy Systems, Inc. and its wholly-owned subsidiaries. All significant intercompany transactions and balances have been eliminated in consolidation.

Reclassifications

Where appropriate, certain reclassifications have been made to prior years’ financial statements to conform to the current year presentation.

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (GAAP) for interim financial information and with the rules and regulations of the Securities and Exchange Commission. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In the opinion of management, all adjustments, consisting of normal recurring adjustments, considered necessary for a fair presentation have been included. Interim results are not necessarily indicative of results that may be expected for the year ending March 31, 2012 or other interim periods.

The condensed consolidated balance sheet at March 31, 2011 has been derived from the audited and adjusted consolidated financial statements at that date but does not include all of the information required by GAAP for complete financial statements.

The accompanying unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and footnotes thereto included in the Company’s Annual Report on Form 10-K/A for the fiscal year ended March 31, 2011, which we filed with the SEC on June 14, 2012.

Use of Estimates

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 disclosures of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during that reporting period. Areas that require the use of significant management estimates include revenue recognition, inventory obsolescence and bad debt reserves, accruals for warranty expenses, income taxes and certain equity transactions. Accordingly, actual results could differ from those estimates.

Cash and Cash Equivalents

The Company considers all highly liquid, short-term investments with original maturities of three months or less to be cash equivalents.

Short-term Investments

The amortized cost and fair value of marketable securities, with gross unrealized gains and losses, as of March 31, 2011 and December 31, 2011 were as follows (in thousands):


			March 31, 2011
	Amortized		Unrealized		Unrealized				Cash and Cash		Short-term
	Cost		Gains		Losses		Fair Value		Equivalents		Investments
Money market funds	$	485	$	—	$	—	$	485	$	485	$	—
Bank certificate of deposit		1,011		—		—		1,011		—		1,011

Total	$	1,496	$	—	$	—	$	1,496	$	485	$	1,011


			December 31, 2011
	Amortized		Unrealized		Unrealized				Cash and Cash		Short-term
	Cost		Gains		Losses		Fair Value		Equivalents		Investments
Money market funds	$	485	$	—	$	—	$	485	$	485	$	—
Bank certificate of deposit		1,015		—		—		1,015		—		1,015

Total	$	1,500	$	—	$	—	$	1,500	$	485	$	1,015

As of March 31, 2011 and December 31, 2011, the Company’s financial assets described in the table above were measured at cost (level 1 inputs).

The Company’s certificate of deposit is pledged as security for an equipment lease.

Fair Value of Financial Instruments

The Company’s financial instruments consist of cash, short-term investments, accounts receivable, accounts payable, accrued liabilities and long-term debt. The carrying amounts of the Company’s financial instruments approximate their respective fair values due to the relatively short-term nature of these instruments, or in the case of long-term, because of the interest rates currently available to the Company for similar obligations. Valuation techniques used to measure fair value must maximize the use of observable inputs and minimize the use of unobservable inputs. GAAP describes a fair value hierarchy based on the following three levels of inputs, of which the first two are considered observable and the last unobservable, that may be used to measure fair value:

Level 1 — Valuations are based on unadjusted quoted prices in active markets for identical assets or liabilities.

Level 2 — Valuations are based on quoted prices for similar assets or liabilities in active markets, or quoted prices in markets that are not active for which significant inputs are observable, either directly or indirectly.

Level 3 — Valuations are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. Inputs reflect management’s best estimate of what market participants would use in valuing the asset or liability at the measurement date.

Accounts Receivable

The majority of the Company’s accounts receivable are due from companies in the commercial, industrial and agricultural industries, as well as wholesalers. Credit is extended based on an evaluation of a customer’s financial condition. Generally, collateral is not required for end users; however, the payment of certain trade accounts receivable from wholesalers is secured by irrevocable standby letters of credit. Accounts receivable are due within 30-60 days. Accounts receivable are stated at the amount the Company expects to collect from outstanding balances. The Company provides for probable uncollectible amounts through a charge to earnings and a credit to an allowance for doubtful accounts based on its assessment of the current status of individual accounts. Balances that are still outstanding after the Company has used reasonable collection efforts are written off through a charge to the allowance for doubtful accounts and a credit to accounts receivable.

Financing Receivables

The Company considers its lease balances included in consolidated current and long-term accounts receivable from its Orion Throughput Agreement, or OTA, sales-type leases to be financing receivables. Additional disclosures on the credit quality of the Company’s OTA receivables included in accounts receivable are as follows:

Aging Analysis as of December 31, 2011 (in thousands):


			1-90 days		Greater than 90						Total sales-type
	Not Past Due		past due		days past due			Total past due			leases
Lease balances included in consolidated accounts receivable—current	$	2,829	$	6	$	20		$	26		$	2,855
Lease balances included in consolidated accounts receivable—long-term		6,001		—		—			—			6,001

Total gross sales-type leases		8,830		6		20			26			8,856
Allowance		—		—		(13	)		(13	)		(13	)

Total net sales-type leases	$	8,830	$	6	$	7		$	13		$	8,843

Allowance for Credit Losses

The Company’s allowance for credit losses is based on management’s assessment of the collectability of customer accounts. A considerable amount of judgment is required in order to make this assessment, including a detailed analysis of the aging of the lease receivables and the current credit worthiness of the Company’s customers and an analysis of historical bad debts and other adjustments. If there is a deterioration of a major customer’s credit worthiness or if actual defaults are higher than historical experience, the estimate of the recoverability of amounts due could be adversely affected. The Company reviews in detail the allowance for doubtful accounts on a quarterly basis and adjusts the allowance estimate to reflect actual portfolio performance and any changes in future portfolio performance expectations. The Company believes that there is no impairment of the receivables for the sales-type leases. The Company believes that there is no impairment of the receivables for the sales-type leases. The Company incurred $0 and $57,000 of provision write-offs or credit losses against its OTA sales-type lease receivable balances in fiscal 2011 and for the quarter ended December 31, 2011, respectively.

Inventories

Inventories consist of raw materials and components, such as ballasts, metal sheet and coil stock and molded parts; work in process inventories, such as frames and reflectors; and finished goods, including completed fixtures and systems, and wireless energy management systems and accessories, such as lamps, meters and power supplies. All inventories are stated at the lower of cost or market value with cost determined using the first-in, first-out (FIFO) method. The Company reduces the carrying value of its inventories for differences between the cost and estimated net realizable value, taking into consideration usage in the preceding 12 months, expected demand, and other information indicating obsolescence. The Company records as a charge to cost of product revenue the amount required to reduce the carrying value of inventory to net realizable value. As of March 31, 2011 and December 31, 2011, the Company had inventory obsolescence reserves of $1.3 million and $1.3 million.

Costs associated with the procurement and warehousing of inventories, such as inbound freight charges and purchasing and receiving costs, are also included in cost of product revenue.

Inventories were comprised of the following (in thousands):


	March 31,		December 31,
	2011		2011
Raw materials and components	$	12,005	$	13,400
Work in process		459		1,221
Finished goods		3,413		4,852

	$	15,877	$	19,473

Deferred Contract Costs

Deferred contract costs consist primarily of the costs of products delivered, and services performed, that are subject to additional performance obligations or customer acceptance. These deferred contract costs are expensed at the time the related revenue is recognized. Deferred costs amounted to $9.6 million and $2.7 million as of March 31, 2011 and December 31, 2011.

Prepaid Expenses and Other Current Assets

Prepaid expenses and other current assets consist primarily of prepaid insurance premiums, prepaid license fees, purchase deposits, advance payments to contractors, prepaid taxes and miscellaneous receivables.

Property and Equipment

Property and equipment were comprised of the following (in thousands):


	March 31,			December 31,
	2011			2011
Land and land improvements	$	1,474		$	1,545
Buildings		15,104			14,724
Furniture, fixtures and office equipment		8,323			11,019
Leasehold improvements		9			54
Equipment leased to customers under Power Purchase Agreements		4,994			4,997
Plant equipment		8,067			9,646
Construction in progress		2,272			1,562

		40,243			43,547
Less: accumulated depreciation and amortization		(10,226	)		(12,952	)

Net property and equipment	$	30,017		$	30,595

Depreciation is provided over the estimated useful lives of the respective assets, using the straight-line method. Depreciable lives by asset category are as follows:


Land improvements		10 - 15 years
Buildings		10 - 39 years
Leasehold improvements		Shorter of asset life or life of lease
Furniture, fixtures and office equipment		2 - 10 years
Plant equipment		3 - 10 years

Patents and Licenses

Patents and licenses are amortized over their estimated useful life, ranging from 7 to 17 years, using the straight line method.

Long-Term Receivables

The Company records a long-term receivable for the non-current portion of its sales-type capital lease OTA contracts. The receivable is recorded at the net present value of the future cash flows from scheduled customer payments. The Company uses the implied cost of capital from each individual contract as the discount rate. Long-term receivables from OTA contracts were $6.0 million as of December 31, 2011.

Also included in other long-term receivables are amounts due from a third party finance company to which the Company has sold, without recourse, the future cash flows from OTAs entered into with customers. Such receivables are recorded at the present value of the future cash flows discounted between 8.8% and 11%. As of December 31, 2011, the following amounts were due from the third party finance company in future periods (in thousands):


Fiscal 2013	$	955
Fiscal 2014		1,015
Fiscal 2015		958
Fiscal 2016		310
Fiscal 2017		9

Total gross long-term receivable		3,247
Less: amount representing interest		(583	)

Net long-term receivable	$	2,664

Long-Term Inventories

The Company records long-term inventory for the non-current portion of its wireless controls inventory. All inventories are stated at the lower of cost or market value with cost determined using the first-in, first-out (FIFO) method.

Other Long-Term Assets

Other long-term assets include long-term security deposits, prepaid licensing costs and deferred financing costs. Other long-term assets include $55,000 and $95,000 of deferred financing costs as of March 31, 2011 and December 31, 2011. Deferred financing costs related to debt issuances are amortized to interest expense over the life of the related debt issue (2 to 10 years).

Accrued Expenses

Accrued expenses include warranty accruals, accrued wages and benefits, accrued vacation, sales tax payable and other various unpaid expenses. Accrued expenses include $0.5 million and $1.4 million of accrued subcontracted installation costs as of March 31, 2011 and December 31, 2011.

The Company generally offers a limited warranty of one year on its own manufactured products in addition to those standard warranties offered by major original equipment component manufacturers. The manufacturers’ warranties cover lamps and ballasts, which are significant components in the Company’s manufactured products.

Changes in the Company’s warranty accrual were as follows (in thousands):


	Three Months Ended						Nine Months Ended
	December 31,						December 31,
	2010			2011			2010			2011
Beginning of period	$	59		$	65		$	60		$	59
Provision to product cost of revenue		20			30			95			89
Charges		(18	)		(24	)		(94	)		(77	)

End of period	$	61		$	71		$	61		$	71

Revenue Recognition

The Company offers a financing program, called an OTA, for a customer’s lease of the Company’s energy management systems. The OTA is structured as a sales-type capital lease and upon successful installation of the system and customer acknowledgement that the system is operating as specified, product revenue is recognized at the Company’s net investment in the lease, which typically is the net present value of the future cash flows.

The Company offers a separate program, called a power purchase agreement, or PPA, for the Company’s renewable energy product offerings. A PPA is a supply side agreement for the generation of electricity and subsequent sale to the end user. Upon the customer’s acknowledgement that the system is operating as specified, product revenue is recognized on a monthly basis over the life of the PPA contract, typically in excess of 10 years.

For sales of solar photovoltaic systems, which are governed by customer contracts that require the Company to deliver functioning solar power systems and are generally completed within three to 15 months, the Company recognizes revenue from fixed price construction contracts using the percentage-of-completion method in accordance with ASC 605-35, Construction-Type and Production-Type Contracts. Under this method, revenue arising from fixed price construction contracts is recognized as work is performed based upon the percentage of incurred costs to estimated total forecasted costs. The Company has determined that the appropriate method of measuring progress on these sales is measured by the percentage of costs incurred to date of the total estimated costs for each contract as materials are installed. The percentage-of-completion method requires revenue recognition from the delivery of products to be deferred and the cost of such products to be capitalized as a deferred cost and current asset on the balance sheet. The Company performs periodic evaluations of the progress of the installation of the solar photovoltaic systems using actual costs incurred over total estimated costs to complete a project. Provisions for estimated losses on uncompleted contracts, if any, are recognized in the period in which the loss first becomes probable and reasonably estimable.

Revenue is recognized on the sales of our lighting and related energy efficiency systems and products when the following four criteria are met:

•

persuasive evidence of an arrangement exists;

•

delivery has occurred and title has passed to the customer;

•

the sales price is fixed and determinable and no further obligation exists; and

•

collectability is reasonably assured

These four criteria are met for the Company’s product-only revenue upon delivery of the product and title passing to the customer. At that time, the Company provides for estimated costs that may be incurred for product warranties and sales returns. Revenues are presented net of sales tax and other sales related taxes.

For sales of the Company’s lighting and energy management technologies, consisting of multiple elements of revenue, such as a combination of product sales and services, the Company determines revenue by allocating the total contract revenue to each element based on their relative selling prices. In such circumstances, the Company uses a hierarchy to determine the selling price to be used for allocating revenue to deliverables: (1) vendor-specific objective evidence (VSOE) of fair value, if available, (2) third-party evidence (TPE) of selling price if VSOE is not available, and (3) best estimate of the selling price if neither VSOE nor TPE is available (a description as to how the Company determined VSOE, TPE and estimated selling price is provided below).

The nature of the Company’s multiple element arrangements for the sale of its lighting and energy management technologies is similar to a construction project, with materials being delivered and contracting and project management activities occurring according to an installation schedule. The significant deliverables include the shipment of products and related transfer of title and the installation.

To determine the selling price in multiple-element arrangements, the Company established VSOE of the selling price for its HIF lighting and energy management system products using the price charged for a deliverable when sold separately. In addition, the Company records in service revenue the selling price for its installation and recycling services using management’s best estimate of selling price, as VSOE or TPE evidence does not exist. Service revenue is recognized when services are completed and customer acceptance has been received. Recycling services provided in connection with installation entail the disposal of the customer’s legacy lighting fixtures. The Company’s service revenues, other than for installation and recycling that are completed prior to delivery of the product, are included in product revenue using management’s best estimate of selling price, as VSOE or TPE evidence does not exist. These services include comprehensive site assessment, site field verification, utility incentive and government subsidy management, engineering design, and project management. For these services and for installation and recycling services, management’s best estimate of selling price is determined by considering several external and internal factors including, but not limited to, pricing practices, margin objectives, competition, geographies in which the Company offers its products and services and internal costs. The determination of estimated selling price is made through consultation with and approval by management, taking into account all of the preceding factors.

Deferred revenue relates to advance customer billings, investment tax grants received related to PPAs and a separate obligation to provide maintenance on OTAs, and is classified as a liability on the Consolidated Balance Sheet. The fair value of the maintenance is readily determinable based upon pricing from third-party vendors. Deferred revenue related to maintenance services is recognized when the services are delivered, which occurs in excess of a year after the original OTA is executed.

Income Taxes

The Company recognizes deferred tax assets and liabilities for the future tax consequences of temporary differences between financial reporting and income tax basis of assets and liabilities, measured using the enacted tax rates and laws expected to be in effect when the temporary differences reverse. Deferred income taxes also arise from the future tax benefits of operating loss and tax credit carryforwards. A valuation allowance is established when management determines that it is more likely than not that all or a portion of a deferred tax asset will not be realized.

ASC 740, Income Taxes, also prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of tax positions taken or expected to be taken in a tax return. For those benefits to be recognized, a tax position must be more-likely-than-not to be sustained upon examination. The Company has classified the amounts recorded for uncertain tax benefits in the balance sheet as other liabilities (non-current) to the extent that payment is not anticipated within one year. The Company recognizes penalties and interest related to uncertain tax liabilities in income tax expense. Penalties and interest are immaterial and are included in the unrecognized tax benefits.

Deferred tax benefits have not been recognized for income tax effects resulting from the exercise of non-qualified stock options. These benefits will be recognized in the period in which the benefits are realized as a reduction in taxes payable and an increase in additional paid-in capital. For the nine months ended December 31, 2010 and 2011, realized tax benefits from the exercise of stock options were $0.2 million and $0.7 million, respectively.

Stock Option Plans

The fair value of each option grant for the three and nine months ended December 31, 2010 and 2011 was determined using the assumptions in the following table:


	Three Months Ended December 31,				Nine Months Ended December 31,
	2010		2011		2010		2011
Weighted average expected term		6.0 years		6.0 years		5.6 years		3.6 years
Risk-free interest rate		1.47%		1.14%		2.06%		0.99%
Expected volatility		74.8%		70.0%		60.0% - 74.8%		70.0%
Expected forfeiture rate		10.0%		11.4%		10.0%		11.4%

Net Income (Loss) per Common Share

Basic net income (loss) per common share is computed by dividing net income (loss) attributable to common shareholders by the weighted-average number of common shares outstanding for the period and does not consider common stock equivalents.

Diluted net income (loss) per common share reflects the dilution that would occur if warrants and employee stock options were exercised. In the computation of diluted net income per common share, the Company uses the “treasury stock” method for outstanding options and warrants. Diluted net income (loss) per common share is the same as basic net income (loss) per common share for the periods ended December 31, 2010, because the effects of potentially dilutive securities are anti-dilutive. The effect of net income (loss) per common share is calculated based upon the following shares (in thousands except share amounts):


	Three Months Ended December 31,					Nine Months Ended December 31,
	2010			2011		2010			2011
	(As Adjusted)			(As Adjusted)		(As Adjusted)			(As Adjusted)
Numerator:
Net income (loss) (in thousands)	$	(182	)	$	74	$	(179	)	$	640

Denominator:
Weighted-average common shares outstanding		22,726,426			22,996,050		22,629,776			22,969,169
Weighted-average effect of assumed conversion of stock options and warrants		—			258,780		—			419,482

Weighted-average common shares and common share equivalents outstanding		22,726,426			23,254,830		22,629,776			23,388,651

Net income (loss) per common share:
Basic	$	(0.01	)	$	0.00	$	(0.01	)	$	0.03
Diluted	$	(0.01	)	$	0.00	$	(0.01	)	$	0.03

The following table indicates the number of potentially dilutive securities as of the end of each period:


	December 31,		December 31,
	2010		2011
Common stock options		3,651,648		4,083,078
Common stock warrants		45,040		38,980

Total		3,696,688		4,122,058

Concentration of Credit Risk and Other Risks and Uncertainties

The Company currently depends on one supplier for a number of components necessary for its products, including ballasts and lamps. If the supply of these components were to be disrupted or terminated, or if this supplier were unable to supply the quantities of components required, the Company may have short-term difficulty in locating alternative suppliers at required volumes. Purchases from this supplier accounted for 21% and 22% of total cost of revenue for the three months ended December 31, 2010 and 2011, respectively, and 29% and 15% of total cost of revenue for the nine months ended December 31, 2010 and 2011, respectively.

For the three months ended December 31, 2010 and December 31, 2011, no customer accounted for more than 10% of revenue. For the nine months ended December 31, 2010, no customer accounted for more than 10% of revenue. For the nine months ended December, 31 2011, one customer accounted for 11% of revenue and one customer accounted for 11% of revenue.

As of March 31, 2011, one customer accounted for 17% of the accounts receivable balance. As of December 31, 2011, one customer accounted for 15% of the accounts receivable balance and one customer accounted for 11% of the accounts receivable balance.

Recent Accounting Pronouncements

In July 2010, the FASB issued Accounting Standards Update 2010-20, Disclosures about the Credit Quality of Financing Receivables and the Allowance for Credit Losses (ASU 2010-20). ASU 2010-20 requires further disaggregated disclosures that improve financial statement users’ understanding of (1) the nature of an entity’s credit risk associated with its financing receivables and (2) the entity’s assessment of that risk in estimating its allowance for credit losses as well as changes in the allowance and the reasons for those changes. The new and amended disclosures as of the end of a reporting period are effective for interim and annual reporting periods ending on or after December 15, 2010. The adoption of ASU 2010-20 did not have a significant impact on the Company’s consolidated financial statements.

In April, 2011, the FASB issued ASU No. 2011-03 Transfers and Servicing (Topic 860): Reconsideration of Effective Control for Repurchase Agreements (“ASU 2011-03”). ASU No. 2011-03 affects all entities that enter into agreements to transfer financial assets that both entitle and obligate the transferor to repurchase or redeem the financial assets before their maturity. The amendments in ASU 2011-03 remove from the assessment of effective control the criterion relating to the transferor’s ability to repurchase or redeem financial assets on substantially all of the agreed terms, even in the event of default by the transferee. ASU 2011-03 also eliminates the requirement to demonstrate that the transferor possesses adequate collateral to fund substantially all the cost of purchasing replacement financial assets. The guidance is effective for the Company’s reporting period ended March 31, 2012. ASU 2011-03 is required to be applied prospectively to transactions or modifications of existing transaction that occur on or after January 1, 2012. The Company does not expect that the adoption of ASU 2011-03 will have a significant impact on the Company’s consolidated financial statements.

In May 2011, the FASB issued ASU No. 2011-04 Fair Value Measurements (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in US GAAP and International Financial Reporting Standards (“IFRS”) (“ASU 2011-04”). ASU 2011-04 represents the converged guidance of the FASB and the IASB (the “Boards”) on fair value measurements. The collective efforts of the Boards and their staffs, reflected in ASU 2011-04, have resulted in common requirements for measuring fair value and for disclosing information about fair value measurements, including a consistent meaning of the term “fair value.” The Boards have concluded the common requirements will result in greater comparability of fair value measurements presented and disclosed in financial statements prepared in accordance with GAAP and IFRSs. The amendments in this ASU are required to be applied prospectively, and are effective for interim and annual periods beginning after December 15, 2011. The Company does not expect that the adoption of ASU 2011-04 will have a significant impact on the Company’s consolidated financial statements.

In June 2011, the FASB issued ASU No. 2011-05, “Comprehensive Income (ASC Topic 220): Presentation of Comprehensive Income,” (“ASU 2011-05”) which amends current comprehensive income guidance. This accounting update eliminates the option to present the components of other comprehensive income as part of the statement of shareholders’ equity. Instead, the Company must report comprehensive income in either a single continuous statement of comprehensive income which contains two sections, net income and other comprehensive income, or in two separate but consecutive statements. ASU 2011-05 will be effective for public companies during the interim and annual periods beginning after December 15, 2011 with early adoption permitted. However, in December 2011, the FASB issued ASU No. 2011-12, “Deferral of the Effective Date for Amendments to the Presentation of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05” (“ASU 2011-12”), which deferred the guidance on whether to require entities to present reclassification adjustments out of accumulated other comprehensive income by component in both the statement where net income is presented and the statement where other comprehensive income is presented for both interim and annual financial statements. ASU 2011-12 reinstated the requirements for the presentation of reclassifications that were in place prior to the issuance of ASU 2011-05 and did not change the effective date for ASU 2011-05. For public entities, the amendments in ASU 2011-05 and ASU2011-12 are effective for fiscal years, and interim periods within those years, beginning after December 15, 2011, and should be applied retrospectively. The adoption of ASU 2011-05 and ASU 2011-12 did not have a significant impact on the Company’s consolidated statements as it only requires a change in the format of the current presentation.

NOTE C — RELATED PARTY TRANSACTIONS

During the nine months ended December 31, 2010 and 2011, the Company purchased goods and services from an entity in the amounts of $34,000 and $35,000, respectively, for which a director of the Company serves as a member of the board of directors. The terms and conditions of such relationship are believed to be not materially more favorable to the Company or the entity than could be obtained from an independent third party.

During the nine months ended December 31, 2010, the Company recorded revenue of $18,000 for products and services sold to an entity for which a former director of the Company was formerly the executive chairman. The Company also entered into an OTA finance contract with such entity in September 2010 with future expected gross contracted revenue to the Company of $2.9 million. The terms and conditions of such relationship are believed to be not materially more favorable to the Company or the entity than could be obtained from an independent third party. As of December 31, 2011, the related party relationship no longer exists.

During the nine months ended December 31, 2010, the Company recorded revenue of $183,000 for products and services sold to various entities affiliated or associated with an entity for which a director of the Company previously served as a member of the board of directors. The Company is not able to identify the respective amount of revenues attributable to specifically identifiable entities within such group of affiliated or associated entities or the extent to which any such individual entities are related to the entity on whose board of directors the Company’s executive officer serves. The terms and conditions of such relationship are believed to be not materially more favorable to the Company or the entity than could be obtained from an independent third party. As of December 31, 2011, the related party relationship no longer exists.

NOTE D — DEBT

Long-term debt as of March 31, 2011 and December 31, 2011 consisted of the following (in thousands):


	March 31,			December 31,
	2011			2011
Term note	$	782		$	596
Customer equipment finance notes payable		1,793			5,597
First mortgage note payable		853			795
Debenture payable		807			776
Other long-term debt		1,127			921

Total long-term debt		5,362			8,685
Less current maturities		(1,137	)		(2,344	)

Long-term debt, less current maturities	$	4,225		$	6,341

New Debt Arrangements

In September 2011, the Company entered into a credit agreement with JP Morgan Chase Bank, N.A. (JP Morgan) that provided the Company with $5.0 million immediately available to fund completed customer contracts under the Company’s OTA finance program and an additional $5.0 million upon the Company’s achievement of meeting a trailing 12-month earnings before interest, taxes, depreciation and amortization (EBITDA) target of $8.0 million. The Company has one year from the date of the commitment to borrow under the credit agreement. In September 2011, the Company borrowed $1.8 million. The borrowing is collateralized by the OTA-related equipment and the expected future monthly payments under the supporting 27 individual OTA customer contracts. The current borrowing under the credit agreement bears interest at LIBOR plus 4% and matures in September 2016.

Revolving Credit Agreement

On June 30, 2010, the Company entered into a new credit agreement (Credit Agreement) with JP Morgan. The Credit Agreement replaced the former credit agreement with a different bank.

The Credit Agreement provides for a revolving credit facility (Credit Facility) that matures on June 30, 2012. The Company is currently working on an amendment to the Credit Facility to extend the maturity date to June 30, 2013. Borrowings under the Credit Facility are limited to (i) $15.0 million or (ii) during periods in which the outstanding principal balance of outstanding loans under the Credit Facility is greater than $5.0 million, the lesser of (A) $15.0 million or (B) the sum of 75% of the outstanding principal balance of certain accounts receivable of the Company and 45% of certain inventory of the Company. The Credit Agreement contains certain financial covenants, including minimum unencumbered liquidity requirements and requirements that the Company maintain a total liabilities to tangible net worth ratio not to exceed 0.50 to 1.00 as of the last day of any fiscal quarter. The Credit Agreement also contains certain restrictions on the ability of the Company to make capital or lease expenditures over prescribed limits, incur additional indebtedness, consolidate or merge, guarantee obligations of third parties, make loans or advances, declare or pay any dividend or distribution on its stock, redeem or repurchase shares of its stock or pledge assets. The Company also may cause JP Morgan to issue letters of credit for the Company’s account in the aggregate principal amount of up to $2.0 million, with the dollar amount of each issued letter of credit counting against the overall limit on borrowings under the Credit Facility. As of December 31, 2011, the Company had outstanding letters of credit totaling $1.7 million, primarily for securing collateral requirements under equipment operating leases. In fiscal 2011, the Company incurred $57,000 of total deferred financing costs related to the Credit Agreement which is being amortized over the two-year term of the Credit Agreement. There were no borrowings by the Company under the Credit Agreement as of March 31, 2011 or December 31, 2011.

The Credit Agreement is secured by a first lien security interest in the Company’s accounts receivable, inventory and general intangibles, and a second lien priority in the Company’s equipment and fixtures. All OTAs, PPAs, leases, supply agreements and/or similar agreements relating to solar PV and wind turbine systems or facilities, as well as all accounts receivable and assets of the Company related to the foregoing, are excluded from these liens.

The Credit Agreement provides that the Company has the option to select whether borrowings under the Credit Facility will bear interest at either (i) a daily borrowing LIBOR rate tied to a one-month maturity or (ii) a LIBOR rate tied to a maturity corresponding to an interest period selected by the Company plus, in the case of either (i) or (ii), a per annum rate spread of 2.00%, 2.50% or 3.00%, depending on the ratio of (A) earnings before interest, taxes, depreciation and amortization less income taxes pain in cash less 50% of depreciation expense to (B) the sum of interest expense paid in cash in respect of indebtedness for borrowed money plus scheduled principal payments made with respect to indebtedness for borrowed money, all as determined for the 12-month period ending as of the end of the applicable fiscal quarter.

The Company must pay a fee of 0.25% on the average daily unused amount of the Credit Facility and a fee of 2.00% on the daily average face amount of undrawn issued letters of credit. The fee on unused amounts is waived if the Company or its affiliates maintain funds on deposit with JP Morgan or its affiliates above a specified amount. The deposit threshold requirement was met as of December 31, 2011.

NOTE E — INCOME TAXES

The income tax provision for the nine months ended December 31, 2011 was determined by applying an estimated annual effective tax rate of 43.4% to income before taxes. The estimated effective income tax rate was determined by applying statutory tax rates to pretax income adjusted for certain permanent book to tax differences and tax credits.

Below is a reconciliation of the statutory federal income tax rate and the effective income tax rate:


	Nine Months Ended December 31,
	2010			2011
Statutory federal tax rate		34.0	%		34.0	%
State taxes, net		2.0	%		9.2	%
Stock-based compensation expense		(113.3	)%		0.0	%
Federal tax credit		(14.7	)%		(11.6	)%
State tax credit		(2.2	)%		(5.9	)%
Change in valuation reserve		8.0	%		5.9	%
Permanent items		7.0	%		6.6	%
Prior Year Permanent Differences		(5.5	)%		3.4	%
Other, net		0.2	%		1.8	%

Effective income tax rate		(84.5	)%		43.4	%

The Company is eligible for tax benefits associated with the excess of the tax deduction available for exercises of non-qualified stock options, or NQSOs, over the amount recorded at grant. The amount of the benefit is based on the ultimate deduction reflected in the applicable income tax return. Benefits of $0.1 million were recorded in fiscal 2011 as a reduction in taxes payable and a credit to additional paid in capital based on the amount that was utilized during the year. Benefits of $0.7 million were recorded for the nine months ended December 31, 2011.

During fiscal 2011, the Company converted almost all of its existing incentive stock options, or ISOs, to NQSOs. This conversion was applied retrospectively, allowing the Company to benefit by reducing $0.6 million of income tax expense during fiscal 2011 related to non-deductible ISO stock compensation expense that was previously deferred for income tax purposes. The conversion will greatly reduce the impact of stock-based compensation expense on the effective tax rate in the table above. Since July 30, 2008, all stock option grants have been issued as NQSOs.

As of December 31, 2011, the Company had federal net operating loss carryforwards of approximately $5.9 million, of which $2.2 million are associated with the exercise of NQSOs that have not yet been recognized by the Company in its financial statements. The Company also has state net operating loss carryforwards of approximately $4.4 million, of which $1.9 million are associated with the exercise of NQSOs. The Company also has federal tax credit carryforwards of approximately $1.0 million and state tax credits of $0.6 million. A full valuation allowance has been set up for the state tax credits due to the state apportioned income and the potential expiration of the state tax credits due to the carry forward period. These federal and state net operating losses and credit carryforwards are available, subject to the discussion in the following paragraph, to offset future taxable income and, if not utilized, will begin to expire in varying amounts between 2014 – 2030.

In 2007, the Company’s past issuances and transfers of stock caused an ownership change. As a result, the Company’s ability to use its net operating loss carryforwards, attributable to the period prior to such ownership change, to offset taxable income will be subject to limitations in a particular year, which could potentially result in increased future tax liability for the Company. The Company does not believe the ownership change affects the use of the full amount of the net operating loss carryforwards.

As of December 31, 2011, an examination of the Company’s U.S. federal income tax returns for tax years 2009 to 2011 was complete. The resolution of this examination did not have a material effect on its business, financial condition, results of operations or liquidity.

Uncertain tax positions

As of December 31, 2011, the balance of gross unrecognized tax benefits was approximately $0.4 million, all of which would reduce the Company’s effective tax rate if recognized. The Company does not expect this amount to change in the next 12 months as none of the issues are currently under examination, the statutes of limitations do not expire within the period, and the Company is not aware of any pending litigation. Due to the existence of net operating loss and credit carryforwards, all years since 2002 are open to examination by tax authorities.

The Company has classified the amounts recorded for uncertain tax benefits in the balance sheet as other liabilities (non-current) to the extent that payment is not anticipated within one year. The Company recognizes penalties and interest related to uncertain tax liabilities in income tax expense. Penalties and interest are immaterial as of the date of adoption and are included in the unrecognized tax benefits. For the nine months ended December 31, 2010 and 2011, the Company had the following unrecognized tax benefit activity (in thousands):


	Nine Months Ended		Nine Months Ended
	December 31, 2010		December 31, 2011
Unrecognized tax benefits as of beginning of period	$	398	$	399
Additions based on tax positions related to the current period positions		1		1

Unrecognized tax benefits as of end of period	$	399	$	400

NOTE F — COMMITMENTS AND CONTINGENCIES

Operating Leases and Purchase Commitments

The Company leases vehicles and equipment under operating leases. Rent expense under operating leases was $0.5 million and $0.5 million for the three months ended December 31, 2010 and 2011; and $1.3 million and $1.6 million for the nine months ended December 31, 2010 and 2011. The Company enters into non-cancellable purchase commitments for certain inventory items in order to secure better pricing and ensure materials are on hand to meet anticipated order volume and customer expectations, as well as for capital expenditures. As of December 31, 2011, the Company had entered into $12.1 million of purchase commitments related to the next 12 months, including $1.7 million for operating lease commitments and $10.4 million for inventory purchase commitments.

NOTE G — SHAREHOLDERS’ EQUITY

Shareholder Rights Plan

On January 7, 2009, the Company’s Board of Directors adopted a shareholder rights plan and declared a dividend distribution of one common share purchase right (a “Right”) for each outstanding share of the Company’s common stock. The issuance date for the distribution of the Rights was February 15, 2009 to shareholders of record on February 1, 2009. Each Right entitles the registered holder to purchase from the Company one share of the Company’s common stock at a price of $30.00 per share, subject to adjustment (the “Purchase Price”).

The Rights will not be exercisable (and will be transferable only with the Company’s common stock) until a “Distribution Date” occurs (or the Rights are earlier redeemed or expire). A Distribution Date generally will occur on the earlier of a public announcement that a person or group of affiliated or associated persons (an “Acquiring Person”) has acquired beneficial ownership of 20% or more of the Company’s outstanding common stock (a “Shares Acquisition Date”) or 10 business days after the commencement of, or the announcement of an intention to make, a tender offer or exchange offer that would result in any such person or group of persons acquiring such beneficial ownership.

If a person becomes an Acquiring Person, holders of Rights (except as otherwise provided in the shareholder rights plan) will have the right to receive that number of shares of the Company’s common stock having a market value of two times the then-current Purchase Price, and all Rights beneficially owned by an Acquiring Person, or by certain related parties or transferees, will be null and void. If, after a Shares Acquisition Date, the Company is acquired in a merger or other business combination transaction or 50% or more of its consolidated assets or earning power are sold, proper provision will be made so that each holder of a Right (except as otherwise provided in the shareholder rights plan) will thereafter have the right to receive that number of shares of the acquiring company’s common stock which at the time of such transaction will have a market value of two times the then-current Purchase Price.

Until a Right is exercised, the holder thereof, as such, will have no rights as a shareholder of the Company. At any time prior to a person becoming an Acquiring Person, the Board of Directors of the Company may redeem the Rights in whole, but not in part, at a price of $0.001 per Right. Unless they are extended or earlier redeemed or exchanged, the Rights will expire on January 7, 2019.

Employee Stock Purchase Plan

In August 2010, the Company’s Board of Directors approved a non-compensatory employee stock purchase plan, or ESPP. The ESPP authorizes 2,500,000 shares to be issued from treasury or authorized shares to satisfy employee share purchases under the ESPP. All full-time employees of the Company are eligible to be granted a non-transferable purchase right each calendar quarter to purchase directly from the Company up to $20,000 of the Company’s common stock at a purchase price equal to 100% of the closing sale price of the Company’s common stock on the NYSE Amex exchange on the last trading day of each quarter. The ESPP allows for employee loans from the Company, except for Section 16 officers, limited to 20% of an individual’s annual income and no more than $250,000 outstanding at any one time. Interest on the loans is charged at the 10-year loan IRS rate and is payable at the end of each calendar year or upon loan maturity. The loans are secured by a pledge of any and all the Company’s shares purchased by the participant under the ESPP and the Company has full recourse against the employee, including offset against compensation payable. The Company had the following shares issued from treasury during fiscal 2011 and for the nine months ended December 31, 2011:


	Under ESPP		Closing Market		Under Loan		Dollar Value of		Repayment of
	Plan		Price		Program		Loans Issued		Loans
Fiscal Year Ended March 31, 2011		65,776	$	3.37		58,655	$	196,100	$	2,685
Quarter Ended June 30, 2011		9,788		3.93		8,601		33,800		1,649
Quarter Ended September 30, 2011		16,753		2.65		11,264		29,850		11,102
Quarter Ended December 31, 2011		3,756		2.95		2,542		7,500		34,650

Total		96,073	$	3.29		81,062	$	267,250	$	50,086

Loans issued to employees are reflected on the Company’s balance sheet as a contra-equity account.

Share Repurchase Program

In October 2011, the Company’s Board of Directors approved a share repurchase program authorizing the Company to repurchase in aggregate up to a maximum of $1.0 million of the Company’s outstanding common stock. In November 2011, the Company’s Board of Directors approved an increase to the share repurchase program authorizing the Company to repurchase in aggregate up to a maximum of $2.5 million of the Company’s outstanding common stock. As of December 31, 2011, the Company had repurchased 98,300 shares of common stock at a cost of $279,000 under the program.

NOTE H — STOCK OPTIONS AND WARRANTS

The Company grants stock options under its 2003 Stock Option and 2004 Stock and Incentive Awards Plans (the Plans). Under the terms of the Plans, the Company has reserved 13,500,000 shares for issuance to key employees, consultants and directors. The Company’s Board of Directors approved an increase to the number of shares available under the Plan by 1,000,000 shares contingent upon the Company’s achievement of at least 100% of each of the targeted financial metrics under its bonus program for fiscal 2012. The contingent share increase was approved by the Company’s shareholders at the 2011 annual shareholders meeting, but such shares are not included in the total above. The options generally vest and become exercisable ratably between one month and five years although longer vesting periods have been used in certain circumstances. Exercisability of the options granted to employees are contingent on the employees’ continued employment and non-vested options are subject to forfeiture if employment terminates for any reason. Options under the Plans have a maximum life of 10 years. In the past, the Company has granted both ISOs and NQSOs, although in July 2008, the Company adopted a policy of thereafter only granting NQSOs. Restricted stock awards have no vesting period and have been issued to certain non-employee directors in lieu of cash compensation pursuant to elections made under the Company’s non-employee director compensation program. The Plans also provide to certain employees accelerated vesting in the event of certain changes of control of the Company as well as under other special circumstances.

In fiscal 2011, the Company converted all of its existing ISO awards to NQSO awards. No consideration was given to the employees for their voluntary conversion of ISO awards.

The Company granted accelerated vesting stock options in May 2011 under its 2004 Stock and Incentive Awards Plan to provide an opportunity for its employees to earn long-term equity incentive awards based on the Company’s financial performance for fiscal 2012. An aggregate of 459,041 stock options were granted on the third business day following the Company’s public release of its fiscal 2011 results at an exercise price per share of $4.19, which was the closing sale price of the Company’s Common Stock on that date. The stock options will only vest, however, if the optionee remains employed and the Company is successful in achieving at least 100% of the target levels for each of the Company’s three financial metric targets for fiscal 2012, and if the Company’s stock price equals or exceeds $5.00 per share for at least 20 trading days during any 90-day period during the options’ ten-year term.

For the three and nine months ended December 31, 2011, the Company granted 8,637 and 19,533 shares from the 2004 Stock and Incentive Awards Plan to certain non-employee directors who elected to receive stock awards in lieu of cash compensation. The shares were valued ranging from $2.75 per share to $4.19 per share, the closing market prices as of the grant dates.

The following amounts of stock-based compensation were recorded (in thousands):


	Three Months Ended December 31,				Nine Months Ended December 31,
	2010		2011		2010		2011
Cost of product revenue	$	42	$	37	$	116	$	114
General and administrative		147		144		417		440
Sales and marketing		123		119		377		391
Research and development		9		9		21		21

Total	$	321	$	309	$	931	$	966

As of December 31, 2011, compensation cost related to non-vested common stock-based compensation, excluding performance stock option awards, amounted to $3.4 million over a remaining weighted average expected term of 6.7 years.

The following table summarizes information with respect to the Plans:


	Options Outstanding
	Shares Available for Grant			Number of Shares			Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (in years)		Aggregate Intrinsic Value
Balance at March 31, 2011		1,577,676			3,658,768		$	3.83		6.60
Granted stock options		(1,251,356	)		1,251,356			3.79
Granted shares		(19,533	)		—			—
Forfeited		747,633			(747,633	)		4.25
Exercised		—			(79,413	)		1.25

Balance at December 31, 2011		1,054,420			4,083,078		$	3.89		6.95	$	810,806

Exercisable at December 31, 2011					1,846,129		$	3.86		5.17	$	610,279

The aggregate intrinsic value represents the total pre-tax intrinsic value, which is calculated as the difference between the exercise price of the underlying stock options and the fair value of the Company’s closing common stock price of $2.95 as of December 31, 2011.

A summary of the status of the Company’s outstanding non-vested stock options as of December 31, 2011 was as follows:


Non-vested at March 31, 2011	1,832,167
Granted	1,251,356
Vested	(341,845	)
Forfeited	(504,729	)

Non-vested at December 31, 2011	2,236,949

The Company has previously issued warrants in connection with various private placement stock offerings and services rendered. The warrants granted the holder the option to purchase common stock at specified prices for a specified period of time. No warrants were issued in fiscal 2011 or during the nine months ended December 31, 2011.

Outstanding warrants are comprised of the following:


			Weighted
	Number of		Average
	Shares		Exercise Price
Balance at March 31, 2011		38,980	$	2.25

Balance at December 31, 2011		38,980	$	2.25

A summary of outstanding warrants at December 31, 2011 follows:


	Number of
Exercise Price	Warrants		Expiration
$2.25		38,980		Fiscal 2015

NOTE I — SEGMENTS

The descriptions of the Company’s segments and their summary financial information are summarized below.

Energy Management

The Energy Management Division develops, manufactures, integrates and sells commercial high intensity fluorescent, or HIF, lighting systems and energy management systems.

Engineered Systems

The Engineered Systems Division sells and integrates alternative renewable energy systems, such as solar and wind.

Corporate and Other

Corporate and Other is comprised of selling, general and administrative expenses not directly allocated to the Company’s segments and adjustments to reconcile to consolidated results, which primarily include intercompany eliminations.


	Revenues				Operating Income (Loss)
	For the Three Months Ended December 31,				For the Three Months Ended December 31,
	2010		2011		2010			2011
(dollars in thousands)
Segments:
Energy Management	$	22,042	$	20,544	$	3,499		$	1,459
Engineered Systems		1,602		6,862		(640	)		(132	)
Corporate and Other		—		—		(1,583	)		(1,263	)

	$	23,644	$	27,406	$	1,276		$	64


	Revenues				Operating Income (Loss)
	For the Nine Months Ended December 31,				For the Nine Months Ended December 31,
	2010		2011		2010			2011
(dollars in thousands)
Segments:
Energy Management	$	54,121	$	55,061	$	5,268		$	4,060
Engineered Systems		2,352		24,041		(1,658	)		663
Corporate and Other		—		—		(4,977	)		(3,790	)

	$	56,473	$	79,102	$	(1,367	)	$	933


	Total Assets				Deferred Revenue
	March 31, 2011		December 31, 2011		March 31, 2011			December 31, 2011
(dollars in thousands)
Segments:
Energy Management	$	66,795	$	67,770	$	533		$	1,017
Engineered Systems		20,422		13,252		9,671			3,106
Corporate and Other		33,870		43,879		—			—

	$	121,087	$	124,901	$	10,204		$	4,123

The Company’s revenue and long-lived assets outside the United States are insignificant.

ITEM 2.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis of our financial condition and results of operations should be read together with our unaudited condensed consolidated financial statements and related notes included elsewhere in the Form 10-Q. It should also be read in conjunction with our audited consolidated financial statements and related notes included in our Annual Report on Form 10-K/A for the year ended March 31, 2011.

Cautionary Note Regarding Forward-Looking Statements

Any statements in this Quarterly Report on Form 10-Q about our expectations, beliefs, plans, objectives, prospects, financial condition, assumptions or future events or performance are not historical facts and are “forward-looking statements” as that term is defined under the federal securities laws. These statements are often, but not always, made through the use of words or phrases such as “believe”, “anticipate”, “should”, “intend”, “plan”, “will”, “expects”, “estimates”, “projects”, “positioned”, “strategy”, “outlook” and similar words. You should read the statements that contain these types of words carefully. Such forward-looking statements are subject to a number of risks, uncertainties and other factors that could cause actual results to differ materially from what is expressed or implied in such forward-looking statements. There may be events in the future that we are not able to predict accurately or over which we have no control. Potential risks and uncertainties include, but are not limited to, those discussed in “Part I, Item 1A. Risk Factors” in our fiscal 2011 Annual Report filed on Form 10-K/A for the fiscal year ended March 31, 2011 and elsewhere in this Quarterly Report. We urge you not to place undue reliance on these forward-looking statements, which speak only as of the date of this report. We do not undertake any obligation to release publicly any revisions to such forward-looking statements to reflect events or uncertainties after the date hereof or to reflect the occurrence of unanticipated events.

Overview

We design, manufacture, market and implement energy management systems consisting primarily of high-performance, energy efficient lighting systems, controls and related services and market and implement renewable energy systems consisting primarily of solar generating photovoltaic, or PV, systems and wind turbines. We operate in two business segments, which we refer to as our Energy Management Division and our Engineered Systems Division.

We currently generate the substantial majority of our revenue from sales of high intensity fluorescent, or HIF, lighting systems and related services to commercial and industrial customers. We typically sell our HIF lighting systems in replacement of our customers’ existing high intensity discharge, or HID, fixtures. We call this replacement process a “retrofit.” We frequently engage our customer’s existing electrical contractor to provide installation and project management services. We also sell our HIF lighting systems on a wholesale basis, principally to electrical contractors and value-added resellers to sell to their own customer bases.

We have sold and installed more than 2,232,000 of our HIF lighting systems in over 7,673 facilities from December 1, 2001 through December 31, 2011. We have sold our products to 139 Fortune 500 companies, many of which have installed our HIF lighting systems in multiple facilities. Our top direct customers by revenue in fiscal 2011 included Coca-Cola Enterprises Inc., U.S. Foodservice, SYSCO Corp., Ball Corporation, MillerCoors and Pepsico, Inc. and its affiliates.

Our fiscal year ends on March 31. We call our prior fiscal year which ended on March 31, 2011, “fiscal 2011”. We call our current fiscal year, which will end on March 31, 2012, “fiscal 2012.” Our fiscal first quarter ended on June 30, our fiscal second quarter ended on September 30, our fiscal third quarter ended on December 31 and our fiscal fourth quarter ends on March 31.

Because of the recessed state of the global economy, especially as it impacted capital equipment manufacturers, our results for the first half of fiscal 2011 were impacted by lengthened customer sales cycles and sluggish customer capital spending. During the second half of fiscal 2011 and the first nine months of fiscal 2012, capital equipment purchases were slightly improved and we continue to remain optimistic regarding customer behaviors for the remainder of fiscal year 2012. To address these difficult economic conditions, we implemented $3.2 million of annualized cost reductions during the first quarter of fiscal 2010. These cost containment initiatives included reductions related to headcount, work hours and discretionary spending and began to show results in the second half of fiscal 2010 and the first half of fiscal 2011. During the second quarter of fiscal 2011, we identified an additional $1 million of annualized cost reductions related to decreased product costs, improved manufacturing efficiencies and reduced operating expenses. We realized these cost reductions beginning during the fiscal 2011 third quarter through reduction in general and administrative expenses and improved product margins for our HIF lighting systems.

Despite these recent economic challenges, we remain optimistic about our near-term and long-term financial performance. Our near-term optimism is based upon our record level of revenue in fiscal 2011 along with our return to profitability, our record level of order backlog heading into the fourth quarter of fiscal 2012, the increasing volume of unit sales in the first nine months of fiscal 2012 of our new products, specifically our exterior HIF fixtures, InteLite wireless dynamic controls, and our Apollo light pipes, and our cost reduction plans completed during fiscal 2011. Our long-term optimism is based upon the considerable size of the existing market opportunity for lighting retrofits, the continued development of our new products and product enhancements, the opportunity for additional revenue from sales of renewable technologies through our Orion Engineered Systems Division, the opportunity for our participation in the replacement part aftermarket and the increasing national recognition of the importance of environmental stewardship, including legislation in the State of Wisconsin passed in fiscal 2011 that recognized our solar Apollo light pipe as a renewable product offering and qualified it for incentives currently offered to other renewable technologies.

In August 2009, we created Orion Engineered Systems, a new operating division which has been offering our customers additional alternative renewable energy systems. In fiscal 2010, we sold and installed three solar PV electricity generating projects, completing our test analysis on two of the three in the fiscal 2010 third quarter, and executed our first cash sale and our first power purchase agreement, or PPA, as a result of the successful testing of these systems. We completed the installation and customer acceptance of the third system, a cash sale, during our fiscal 2011 first quarter. During our fiscal 2011 second quarter, we received an $8.3 million cash order for a solar PV generating system for which we recognized revenue in fiscal 2012.

During our fiscal 2011 third quarter, we introduced the presentation of operating segments. We now report our Energy Management and Engineered Systems groups as separate segments. Our Energy Management division develops, manufactures, integrates and sells commercial high intensity fluorescent, or HIF, lighting systems and energy management systems. Our Engineered Systems division sells and integrates alternative renewable energy systems.

In response to the constraints on our customers’ capital spending budgets, we have more aggressively promoted the advantages to our customers of purchasing our energy management systems through our Orion Throughput Agreement, or OTA, financing program. Our OTA financing program provides for our customer’s purchase of our energy management systems without an up-front capital outlay. The OTA contracts under this sales-type financing are either structured with a fixed term, typically 60 months, and a bargain purchase option at the end of the term, or are one year in duration and, at the completion of the initial one-year term, provide for (i) one to four automatic one-year renewals at agreed upon pricing; (ii) an early buyout for cash; or (iii) the return of the equipment at the customer’s expense. The revenue that we are entitled to receive from the sale of our energy management systems under our OTA financing program is fixed and is based on the cost of the energy management system and applicable profit margin. Our revenue from agreements entered into under this program is not dependent upon our customers’ actual energy savings. During the third quarter of fiscal 2012, we entered into an arrangement with a national equipment finance company to provide immediate non-recourse funding of pre-credit approved OTA finance contracts upon project completion and customer acceptance. We have now secured multiple funding sources for our OTA projects. We expect that the number of customers who choose to purchase our systems by using our OTA financing program will continue to increase in future periods. Additionally, we have provided a financing program to our alternative renewable energy system customers called a solar power purchase agreement, or PPA, as an alternative to purchasing our systems for cash. The PPA is a supply side agreement for the generation of electricity and subsequent sale to the end user. We do not intend to use our own cash balances to fund future PPA opportunities and have been able to secure several external sources of funding for PPA’s on behalf of our customers.

Revenue and Expense Components

Revenue. We sell our energy management products and services directly to commercial and industrial customers, and indirectly to end users through wholesale sales to electrical contractors and value-added resellers. We currently generate the substantial majority of our revenue from sales of HIF lighting systems and related services to commercial and industrial customers. While our services include comprehensive site assessment, site field verification, utility incentive and government subsidy management, engineering design, project management, installation and recycling in connection with our retrofit installations, we separately recognize service revenue only for our installation and recycling services. Our service revenues are recognized when services are complete and customer acceptance has been received. In fiscal 2011, we increased our efforts to expand our value-added reseller channels, including through developing a partner standard operating procedural kit, providing our partners with product marketing materials and providing training to channel partners on our sales methodologies. These wholesale channels accounted for approximately 53% of our total revenue in fiscal 2011, not taking into consideration our renewable technologies revenue generated through our Orion Engineered Systems Division. During the first nine months of fiscal 2012, wholesale revenues accounted for approximately 64% of our total revenue, not taking into consideration our renewable technologies revenue generated through our Orion Engineered Systems Division, compared to 51% for the first nine months of fiscal 2011. We are changing the manner in which we sell our solar PV systems. Instead of reselling the solar PV equipment from a solar PV equipment manufacturer, we are encouraging our customers to purchase their solar PV systems directly from the manufacturer, while we provide the value-added installation and integration services. This change in approach is expected to result in reduced revenue from solar orders, but is expected to result in improved gross margins as discussed below.

Additionally, we offer our OTA sales-type financing program under which we finance the customer’s purchase of our energy management systems. We recognize revenue from OTA contracts at the net present value of the future cash flows at the completion date of the installation of the energy management systems and the customer’s acknowledgement that the system is operating as specified.

In fiscal 2011, we recognized $10.7 million of revenue from 127 completed OTA contracts. For the three months ended December 31, 2011, we recognized $2.5 million of revenue from 29 completed contracts. For the nine months ended December 31, 2011, we recognized $9.1 million of revenue from 111 completed contracts. In the future, we expect an increase in the volume of OTA contracts as our customers take advantage of the value proposition without incurring any up-front capital cost.

Our PPA financing program provides for our customer’s purchase of electricity from our renewable energy generating assets without an upfront capital outlay. Our PPA is a longer-term contract, typically in excess of 10 years, in which we receive monthly payments over the life of the contract. This program creates an ongoing recurring revenue stream, but reduces near-term revenue as the payments are recognized as revenue on a monthly basis over the life of the contract versus upfront upon product shipment or project completion. In fiscal 2011, we recognized $0.4 million of revenue from completed PPAs. In the first nine months of fiscal 2012, we recognized $0.5 million of revenue from completed PPAs. As of December 31, 2011, we had signed one customer to two separate PPAs representing future potential discounted revenue streams of $3.2 million. We discount the future revenue from PPAs due to the long-term nature of the contracts, typically in excess of 10 years. The timing of expected future discounted GAAP revenue recognition and the resulting operating cash inflows from PPAs, assuming the systems perform as designed, was as follows as of December 31, 2011 (in thousands):


Fiscal 2012	$	130
Fiscal 2013		646
Fiscal 2014		536
Fiscal 2015		436
Fiscal 2016		436
Beyond		1,027

Total expected future discounted revenue from PPAs	$	3,211

We recognize revenue on product only sales at the time of shipment. For projects consisting of multiple elements of revenue, such as a combination of product sales and services, we recognize revenue by allocating the total contract revenue to each element based on their relative selling prices. We determine the selling price of products based upon the price charged when these products are sold separately. For services, we determine the selling price based upon management’s best estimate giving consideration to pricing practices, margin objectives, competition, scope and size of individual projects, geographies in which we offer our products and services, and internal costs. We recognize revenue at the time of product shipment on product sales and on services completed prior to product shipment. We recognize revenue associated with services provided after product shipment, based on their relative selling price, when the services are completed and customer acceptance has been received. When other significant obligations or acceptance terms remain after products are delivered, revenue is recognized only after such obligations are fulfilled or acceptance by the customer has occurred.

Our dependence on individual key customers can vary from period to period as a result of the significant size of some of our retrofit and multi-facility roll-out projects. Our top 10 customers accounted for approximately 30% and 45% of our total revenue for the first nine months of fiscal 2011 and fiscal 2012, respectively. No customers accounted for more than 10% of our revenue in the first nine months of fiscal 2011 and two customers accounted for more than 10% of our total revenue in the first nine months of fiscal 2012. To the extent that large retrofit and roll-out projects and/or large solar projects or solar roll-outs become a greater component of our total revenue, we may experience more customer concentration in given periods. The loss of, or substantial reduction in sales volume to, any of our significant customers could have a material adverse effect on our total revenue in any given period and may result in significant annual and quarterly revenue variations.

Our level of total revenue for any given period is dependent upon a number of factors, including (i) the demand for our products and systems, including our OTA and PPA programs and any new products, applications and service that we may introduce through our Orion Engineered Systems division; (ii) the number and timing of large retrofit and multi-facility retrofit, or “roll-out,” projects; (iii) the level of our wholesale sales; (iv) our ability to realize revenue from our services; (v) market conditions; (vi) our execution of our sales process; (vii) our ability to compete in a highly competitive market and our ability to respond successfully to market competition; (viii) the selling price of our products and services; (ix) changes in capital investment levels by our customers and prospects; and (x) customer sales and budget cycles. As a result, our total revenue may be subject to quarterly variations and our total revenue for any particular fiscal quarter may not be indicative of future results.

Backlog. We define backlog as the total contractual value of all firm orders and OTA contracts received for our lighting products and services where delivery of product or completion of services has not yet occurred as of the end of any particular reporting period. Such orders must be evidenced by a signed proposal acceptance or purchase order from the customer. Our backlog does not include PPAs or national contracts that have been negotiated, but under which we have not yet received a purchase order for the specific location. As of December 31, 2011, we had a backlog of firm purchase orders of approximately $50.6 million, which included $44.4 million of solar PV orders, compared to $23.6 million as of September 30, 2011, which included $16.5 million of solar PV orders. We currently expect approximately $9.9 million of our backlog to be recognized as revenue in our fiscal 2012 fourth quarter. We expect approximately $22.4 million of our backlog to be recognized in fiscal 2013 and the remainder in future years. We generally expect this level of firm purchase order backlog related to HIF lighting systems to be converted into revenue within the following quarter. We generally expect our firm purchase order backlog related to solar PV systems to be recognized within the following three to 15 months, although during the third quarter of fiscal 2012 we received an $18.3 million single order for which the solar PV system construction will not begin until our fiscal 2014. Principally as a result of the increased volume of our solar PV orders, the continued lengthening of our customer’s purchasing decisions because of current recessed economic conditions and related factors, the continued shortening of our installation cycles and the number of projects sold through OTAs, a comparison of backlog from period to period is not necessarily meaningful and may not be indicative of actual revenue recognized in future periods.

Cost of Revenue. Our total cost of revenue consists of costs for: (i) raw materials, including sheet, coiled and specialty reflective aluminum; (ii) electrical components, including ballasts, power supplies and lamps; (iii) wages and related personnel expenses, including stock-based compensation charges, for our fabricating, coating, assembly, logistics and project installation service organizations; (iv) manufacturing facilities, including depreciation on our manufacturing facilities and equipment, taxes, insurance and utilities; (v) warranty expenses; (vi) installation and integration; and (vii) shipping and handling. Our cost of aluminum can be subject to commodity price fluctuations, which we attempt to mitigate with forward fixed-price, minimum quantity purchase commitments with our suppliers. We also purchase many of our electrical components through forward purchase contracts. We buy most of our specialty reflective aluminum from a single supplier, and most of our ballast and lamp components from a single supplier, although we believe we could obtain sufficient quantities of these raw materials and components on a price and quality competitive basis from other suppliers if necessary. Purchases from our current primary supplier of ballast and lamp components constituted 27% of our total cost of revenue for the first nine months of fiscal 2012 and were 29% of our total cost of revenue for the first nine months of fiscal 2011. Our cost of revenue from OTA projects is recorded upon customer acceptance and acknowledgement that the system is operating as specified. Our production labor force is non-union and, as a result, our production labor costs have been relatively stable. We have been expanding our network of qualified third-party installers to realize efficiencies in the installation process.

Gross Margin. Our gross profit has been, and will continue to be, affected by the relative levels of our total revenue and our total cost of revenue, and as a result, our gross profit may be subject to quarterly variation. Our gross profit as a percentage of total revenue, or gross margin, is affected by a number of factors, including: (i) our level of solar PV sales which generally have substantially lower relative gross margins than our traditional energy management systems; (ii) our mix of large retrofit and multi-facility roll-out projects with national accounts; (iii) the level of our wholesale and partner sales (which generally have historically resulted in lower relative gross margins, but higher relative net margins, than our sales to direct customers); (iv) our realization rate on our billable services; (v) our project pricing; (vi) our level of warranty claims; (vii) our level of utilization of our manufacturing facilities and production equipment and related absorption of our manufacturing overhead costs; (viii) our level of efficiencies in our manufacturing operations; and (ix) our level of efficiencies from our subcontracted installation service providers. We are changing the manner in which we sell our solar PV systems. Instead of reselling the solar PV equipment obtained from a solar PV equipment manufacturer, we are encouraging our customers to purchase their solar PV systems directly from the manufacturer, while we provide the value-added installation and integration services. This change in approach is expected to result in increased solar PV gross margins.

Operating Expenses. Our operating expenses consist of: (i) general and administrative expenses; (ii) sales and marketing expenses; and (iii) research and development expenses. Personnel related costs are our largest operating expense. In fiscal 2012, we are increasing personnel in our sales areas for telemarketing and direct sales employees as we believe that future opportunities within our business remain strong.

Our general and administrative expenses consist primarily of costs for: (i) salaries and related personnel expenses, including stock-based compensation charges related to our executive, finance, human resource, information technology and operations organizations; (ii) public company costs, including investor relations, external audit and internal audit; (iii) occupancy expenses; (iv) professional services fees; (v) technology related costs and amortization; (vi) bad debt and asset impairment charges; and (vii) corporate-related travel.

Our sales and marketing expenses consist primarily of costs for: (i) salaries and related personnel expenses, including stock-based compensation charges related to our sales and marketing organization; (ii) internal and external sales commissions and bonuses; (iii) travel, lodging and other out-of-pocket expenses associated with our selling efforts; (iv) marketing programs; (v) pre-sales costs; and (vi) other related overhead.

Our research and development expenses consist primarily of costs for: (i) salaries and related personnel expenses, including stock-based compensation charges, related to our engineering organization; (ii) payments to consultants; (iii) the design and development of new energy management products and enhancements to our existing energy management system; (iv) quality assurance and testing; and (v) other related overhead. We expense research and development costs as incurred.

In fiscal 2011 and continuing in the first nine months of fiscal 2012, we invested in marketing efforts to our direct end customers and to our channel partners through increasing advertising, marketing collateral materials and participating in national industry and customer trade shows. We expense all pre-sale costs incurred in connection with our sales process prior to obtaining a purchase order. These pre-sale costs may reduce our net income in a given period prior to recognizing any corresponding revenue. We also intend to continue investing in our research and development of new and enhanced energy management products and services.

We recognize compensation expense for the fair value of our stock option awards granted over their related vesting period. We recognized $1.0 million for the first nine months of fiscal 2012 and $0.9 million for the first nine months of fiscal 2011. As a result of prior option grants, we expect to recognize an additional $3.4 million of stock-based compensation over a weighted average period of approximately seven years, including $0.3 million over the remaining quarter of fiscal 2012. These charges have been, and will continue to be, allocated to cost of product revenue, general and administrative expenses, sales and marketing expenses and research and development expenses based on the departments in which the personnel receiving such awards have primary responsibility. A substantial majority of these charges have been, and likely will continue to be, allocated to general and administrative expenses and sales and marketing expenses.

Interest Expense. Our interest expense is comprised primarily of interest expense on outstanding borrowings under long-term debt obligations, including the amortization of previously incurred financing costs. We amortize deferred financing costs to interest expense over the life of the related debt instrument, ranging from two to ten years.

Interest Income. We report interest income earned on our cash and cash equivalents and short term investments. We also report interest income earned from our financed OTA contracts.

Income Taxes. As of December 31, 2011, we had net operating loss carryforwards of approximately $5.9 million for federal tax purposes and $4.4 million for state tax purposes. Included in these loss carryforwards were $2.2 million for federal and $1.9 million for state tax purposes of compensation expenses that were associated with the exercise of nonqualified stock options. The benefit from our net operating losses created from these compensation expenses has not yet been recognized in our financial statements and will be accounted for in our shareholders’ equity as a credit to additional paid-in capital as the deduction reduces our income taxes payable. We also had federal tax credit carryforwards of approximately $1.0 million and state credit carryforwards of approximately $0.6 million. A full valuation allowance has been set up for the state tax credits. We believe it is more likely than not that we will realize the benefits of most of these assets and we have reserved for an allowance due to our state apportioned income and the potential expiration of the state tax credits due to the carryforward period. These federal and state net operating losses and credit carryforwards are available, subject to the discussion in the following paragraph, to offset future taxable income and, if not utilized, will begin to expire in varying amounts between 2014 and 2030.

Generally, a change of more than 50% in the ownership of a company’s stock, by value, over a three-year period constitutes an ownership change for federal income tax purposes. An ownership change may limit a company’s ability to use its net operating loss carryforwards attributable to the period prior to such change. In fiscal 2007 and prior to our IPO, past issuances and transfers of stock caused an ownership change for certain tax purposes. When certain ownership changes occur, tax laws require that a calculation be made to establish a limitation on the use of net operating loss carryforwards created in periods prior to such ownership change. For fiscal year 2008, utilization of our federal loss carryforwards was limited to $3.0 million. There was no limitation that occurred for fiscal 2010 or fiscal 2011. For fiscal 2012, we do not anticipate a limitation on the use of our net operating loss carryforwards.

Results of Operations

The following table sets forth the line items of our consolidated statements of operations on an absolute dollar basis and as a relative percentage of our total revenue for each applicable period, together with the relative percentage change in such line item between applicable comparable periods set forth below (dollars in thousands):


	Three Months Ended December 31,														Nine Months Ended December 31,
	2010						2011								2010						2011
				% of					% of			%						% of					% of			%
	Amount			Revenue			Amount		Revenue			Change			Amount			Revenue			Amount		Revenue			Change
Product revenue	$	21,633			91.5	%	$	24,274		88.6	%		12.2	%	$	52,476			92.9	%	$	71,746		90.7	%		36.7	%
Service revenue		2,011			8.5	%		3,132		11.4	%		55.7	%		3,997			7.1	%		7,356		9.3	%		84.0	%

Total revenue		23,644			100.0	%		27,406		100.0	%		15.9	%		56,473			100.0	%		79,102		100.0	%		40.1	%
Cost of product revenue		14,134			59.8	%		17,445		63.7	%		23.4	%		34,186			60.5	%		50,484		63.8	%		47.7	%
Cost of service revenue		1,676			7.1	%		2,447		8.9	%		46.0	%		3,091			5.5	%		5,716		7.2	%		84.9	%

Total cost of revenue		15,810			66.9	%		19,892		72.6	%		25.8	%		37,277			66.0	%		56,200		71.0	%		50.8	%

Gross profit		7,834			33.1	%		7,514		27.4	%		(4.1	)%		19,196			34.0	%		22,902		29.0	%		19.3	%
General and administrative expenses		2,709			11.4	%		2,841		10.4	%		4.9	%		8,642			15.3	%		8,641		10.9	%		—	%
Sales and marketing expenses		3,235			13.7	%		4,053		14.8	%		25.3	%		10,124			17.9	%		11,557		14.6	%		14.2	%
Research and development expenses		614			2.6	%		556		2.0	%		(9.4	)%		1,797			3.2	%		1,771		2.3	%		(1.4	)%

Income (loss) from operations		1,276			5.4	%		64		0.2	%		(95.0	)%		(1,367	)		(2.4	)%		933		1.2	%		(168.3	) %
Interest expense		98			0.4	%		160		0.5	%		63.3	%		223			0.4	%		397		0.5	%		78.0	%
Dividend and interest income		189			0.8	%		226		0.8	%		19.6	%		435			0.8	%		594		0.7	%		36.6	%

Income before income tax		1,367			5.8	%		130		0.5	%		(90.5	)%		(1,155	)		(2.0	)%		1,130		1.4	%		197.8	%
Income tax expense (benefit)		1,549			6.6	%		56		0.2	%		(96.4	)%		(976	)		(1.7	)%		490		0.6	%		150.2	%

Net income (loss)	$	(182	)		(0.8	)%	$	74		0.3	%		140.7	%	$	(179	)		(0.3	)%	$	640		0.8	%		457.5	%

Revenue. Product revenue increased from $21.6 million for the fiscal 2011 third quarter to $24.3 million for the fiscal 2012 third quarter, an increase of $2.7 million, or 12.2%. The increase in product revenue was a result of increased sales of our solar PV systems. Service revenue increased from $2.0 million for the fiscal 2011 third quarter to $3.1 million for the fiscal 2012 third quarter, an increase of $1.1 million, or 55.7%. The increase in service revenues was a result of the increase in sales of PV systems and the related installation revenue. Total revenue from solar PV systems was $6.9 million for the fiscal 2012 third quarter compared to $1.6 million for the fiscal 2011 third quarter, an increase of $5.3 million or 331%. Product revenue increased from $52.5 million for the first nine months of fiscal 2011 to $71.7 million for the first nine months of fiscal 2012, an increase of $19.2 million, or 36.7%. Service revenue increased from $4.0 million for the first nine months of fiscal 2011 to $7.4 million for the first nine months of fiscal 2012, an increase of $3.4 million, or 84.0%. Total revenue from renewable energy systems was $24.0 million for the fiscal 2012 first nine months compared to $2.4 million for the fiscal 2011 first nine months, an increase of $21.6 million, or 900%. The increase in service revenue was due to the related installation services resulting from the increased sales of PV systems for both the three and nine month periods. For the first nine months of fiscal 2012, our wholesale channels accounted for approximately 64% of our total revenue, not taking into consideration sales of solar PV systems, compared to 51% for the first nine months of fiscal 2011. We continue to experience revenue growth through the use of our OTA finance contracts.

Cost of Revenue and Gross Margin. Our cost of product revenue increased from $14.1 million for the fiscal 2011 third quarter to $17.4 million for the fiscal 2012 third quarter, an increase of $3.3 million, or 23.4%. Our cost of service revenue increased from $1.7 million for the fiscal 2011 third quarter to $2.4 million for the fiscal 2012 third quarter, an increase of $0.7 million, or 46.0%. Total gross margin was 33.1% and 27.4% for the fiscal 2011 third quarter and fiscal 2012 third quarters, respectively. Our gross margin on renewable revenues was 13.1% during the fiscal 2012 third quarter. Gross margin from our HIF integrated systems revenue for the fiscal 2012 third quarter was 32.2%. Total cost of product revenue increased from $34.2 million for the fiscal 2011 first nine months to $50.5 million for the fiscal 2012 first nine months, an increase of $16.3 million, or 47.7%. Our cost of service revenue increased from $3.1 million for the fiscal 2011 first nine months to $5.7 million for the fiscal 2012 first nine months, an increase of $2.6 million, or 84.9%. Total gross margin decreased from 34.0% for the fiscal 2011 first nine months to 29.0% for the fiscal 2012 first nine months. For the fiscal 2012 first nine months, our gross margin declined due to a higher mix of renewable product and service revenues from our Orion Engineered Systems division. Our gross margin on renewable revenues was 17.1% during the fiscal 2012 first nine months. Gross margin from our HIF integrated systems revenue for the fiscal 2012 first nine months was 34.3%.

General and Administrative. Our general and administrative expenses increased from $2.7 million for the fiscal 2011 third quarter to $2.8 million for the fiscal 2012 third quarter, an increase of $0.1 million, or 4.9%. Our general and administrative expenses were $8.6 million for both the first nine months of fiscal 2011 and the first nine months of fiscal 2012. For the first nine months of fiscal 2012, expenses increased as a result of $0.1 million incurred for depreciation and software license costs for our new enterprise resource planning, or ERP, system and $0.1 million for increased stock compensation costs versus the prior fiscal year’s period. These increases were offset by reduced legal expenses and discretionary spending reductions.

Sales and Marketing. Our sales and marketing expenses increased from $3.2 million for the fiscal 2011 third quarter to $4.1 million for the fiscal 2012 third quarter, an increase of $0.9 million, or 25.3%. Our sales and marketing expenses increased from $10.1 million for the first nine months of fiscal 2011 to $11.6 million for the first nine months of fiscal 2012, an increase of $1.5 million, or 14.2%. The increase was a result of increased costs for headcount additions in our newly formed telemarketing department, higher commission expense on our increased revenue and increased depreciation for our new customer relationship management, or CRM, system. Total sales and marketing headcount was 87 and 97 at December 31, 2010 and 2011, respectively.

Research and Development. Our research and development expenses were $0.6 million for both the fiscal 2011 third quarter and the fiscal 2012 third quarter. Our research and development expenses of $1.8 million for the first nine months of fiscal 2012 were similar to our research and development expenses for the first nine months of fiscal 2011. Expenses incurred in the first nine months of fiscal 2012 related to compensation costs for the development and support of our new products, depreciation expenses for lab and research equipment and sample and testing costs related to our dynamic control devices and our light emitting diode, or LED, product initiatives.

Interest Expense. Our interest expense increased from $0.1 million for the fiscal 2011 third quarter to $0.2 million for the fiscal 2012 third quarter, an increase of $0.1 million, or 63.3%. Our interest expense increased from $0.2 million for the first nine months of fiscal 2011 to $0.4 million for the first nine months of fiscal 2012, an increase of $0.2 million, or 78.0%. The increase in our interest expense was due to additional debt funding completed during the second half of fiscal 2011 and the first half of fiscal 2012 for the purpose of financing our OTA projects.

Interest Income. Interest income was relatively unchanged at $0.2 million for both the fiscal 2011 and fiscal 2012 third quarters. Interest income increased from $0.4 million for the first nine months of fiscal 2011 to $0.6 million for the first nine months of fiscal 2012, an increase of $0.2 million or 36.6%. Interest income increased due to an increase in completed OTA contracts and the related interest income under the financing terms.

Income Taxes. Our income tax expense decreased from an expense of $1.5 million for the fiscal 2011 third quarter to an income tax expense of $0.1 million for the fiscal 2012 third quarter, a decrease of $1.4 million or 96.4%. Our income tax benefit decreased from a benefit of $1.0 million for the first nine months of fiscal 2011 to an income tax expense of $0.5 million for the first nine months of fiscal 2012, a decrease of $1.5 million or 150.2%. Our effective income tax rate for the first nine months of fiscal 2011 was (84.5)%, compared to 43.4% for the nine months of fiscal 2012. The change in our effective tax rate was due to the conversion of our incentive stock options, or ISOs, to non-qualified stock options, or NQSOs, completed during the second half of fiscal 2011 and a decrease due to prior year permanent adjustments. The conversion of our ISOs to NQSOs eliminated the volatility in our effective tax rates at lower pre-tax earnings levels and should result in an effective tax rate in the 38% to 40% range for future periods.

Energy Management Segment

The following table summarizes our Energy Management segment operating results:


	For the Three Months Ended December 31,						For the Nine Months Ended December 31,
(dollars in thousands)	2010			2011			2010			2011
Revenues	$	22,042		$	20,544		$	54,121		$	55,061
Operating income	$	3,499		$	1,459		$	5,268		$	4,060
Operating margin		15.9	%		7.1	%		9.7	%		7.4	%

Energy Management segment revenue decreased $1.5 million, or 6.8%, from $22.0 million for the fiscal 2011 third quarter to $20.5 million for the fiscal 2012 third quarter. The decrease was due to reduced order volumes at calendar-year end as our customers did not allocate capital budget dollars as they had in prior calendar year-ends. Energy Management segment revenue increased $1.0 million, or 1.7%, from $54.1 million for the first nine months of fiscal 2011 to $55.1 million for the first nine months of fiscal 2012. The increase was due to increased sales of our HIF lighting systems to our national account and wholesale customers, increased revenue from new product offerings, including exterior lighting and LED fixtures.

Energy Management segment operating income decreased $2.0 million, or 58.3%, from $3.5 million for the fiscal 2011 third quarter to $1.5 million for the fiscal 2012 third quarter due to the reduction in volume and the increase in sales and marketing expenses. Energy Management segment operating income decreased $1.2 million, or 22.9%, from $5.3 million for the first nine months of fiscal 2011 to $4.1 million for the first nine months of fiscal 2012. The decrease in operating income for the first nine months of fiscal 2012 was due to our increase in sales and marketing expenses.

Engineered Systems Segment

The following table summarizes our Engineered Systems segment operating results:


	For the Three Months Ended December 31,						For the Nine Months Ended December 31,
(dollars in thousands)	2010			2011			2010			2011
Revenues	$	1,602		$	6,862		$	2,352		$	24,041
Operating income (loss)	$	(640	)	$	(132	)	$	(1,658	)	$	663
Operating margin		(40.0	) %		(1.9	)%		(70.5	) %		2.8	%

Engineered Systems segment revenue increased $5.3 million, or 328.3%, from $1.6 million for the fiscal 2011 third quarter to $6.9 million for the fiscal 2012 third quarter. Energy Systems segment revenue increased $21.6 million, or 922.2%, from $2.4 million for the first nine months of fiscal 2011 to $24.0 million for the first nine months of fiscal 2012. The increase was due to increased sales of solar renewable technologies for the fiscal 2012 third quarter and the first nine months of fiscal 2012. We believe that revenue activity increased at the calendar year end as customers took advantage of expiring tax benefits. During the same periods of fiscal 2010, our Engineered Systems segment efforts were primarily focused on research of renewable technology products and understanding if there was a market for these technologies within our customer base.

Engineered Systems segment operating loss decreased $0.5, or 79.4%, million from an operating loss of $0.6 million for the fiscal 2011 third quarter to $0.1 million for the fiscal 2012 third quarter. Energy Systems segment operating income increased $2.4 million, or 140%, from an operating loss of $1.7 million for the first nine months of fiscal 2011 to operating income of $0.7 million for the first nine months of fiscal 2012. The increase in operating income for both the quarter and year-to-date, was a result of the increased revenue volume and resulting contribution margin from sales of solar renewable energy systems.

Liquidity and Capital Resources

Overview

We had approximately $18.2 million in cash and cash equivalents and $1.0 million in short-term investments as of December 31, 2011, compared to $11.6 million and $1.0 million at March 31, 2011. Our cash equivalents are invested in money market accounts with maturities of less than 90 days and an average yield of 0.24%. Our short-term investment account consists of a bank certificate of deposit in the amount of $1.0 million with an expiration date of March 2012 and a yield of 0.50%. Additionally, as of December 31, 2011, we had $13.3 million of borrowing availability under our revolving credit agreement. We also had $3.2 million of availability on our recently completed OTA credit agreement, which can be utilized for the sole purpose of funding customer OTA projects. During the first nine months of fiscal 2012, we borrowed $4.6 million to finance our OTA projects. In November 2011, we entered into an arrangement with a national equipment finance company to provide immediate non-recourse funding of pre-credit approved OTA finance contracts upon project completion and customer acceptance. We have now secured multiple debt and equipment finance sources for our OTA finance contracts and believe that our sources of OTA funding are sufficient to meet near-term OTA finance program requirements. In October 2011, our board of directors approved a $1.0 million share repurchase plan, which was increased to $2.5 million in November 2011. We believe that our existing cash and cash equivalents, our anticipated cash flows from operating activities and our borrowing capacity under our revolving credit facility and our OTA credit facility will be sufficient to meet our anticipated cash needs for at least the next 12 months, dependent upon our growth opportunities with our cash and finance customers.

Cash Flows

The following table summarizes our cash flows for the nine months ended December 31, 2010 and 2011 (in thousands):


	Nine Months Ended December 31,
	2010			2011
Operating activities	$	(10,585	)	$	6,486
Investing activities		(5,589	)		(3,584	)
Financing activities		2,668			3,771

(Decrease) increase in cash and cash equivalents	$	(13,506	)	$	6,673

Cash Flows Related to Operating Activities. Cash provided by operating activities for the first nine months of fiscal 2012 was $6.5 million and consisted of net cash provided from changes in operating assets and liabilities of $2.0 million and net income adjusted for non-cash expense items of $4.5 million. Cash provided by changes in operating assets and liabilities consisted of a decrease of $6.9 million in deferred contract costs due to project progress for solar projects, a $1.6 million decrease in total accounts receivable due to customer payments received and a $3.0 million increase in accounts payable related to payment terms on inventory purchases. Cash used from changes in operating assets and liabilities included a $3.6 million increase in inventory for purchases described under “— Liquidity and Capital Resources — Working Capital” below and a $6.1 million decrease in deferred revenue as a result of project completions.

Cash used in operating activities for the first nine months of fiscal 2011, was $10.6 million and consisted of net cash of $13.3 million used for changes in operating assets and liabilities offset by a net loss adjusted for non-cash expense items of $2.7 million. Cash used for changes in operating assets and liabilities consisted of an increase in accounts receivables of $10.1 million due to the increase in revenue, an increase in deferred contract costs of $5.6 million for solar project costs incurred and an increase of $6.2 million for inventory purchases, including $1.8 million for purchases of wireless control inventories and a $4.4 million increase in ballast component inventories due to concerns over supply availability and component shortages. Cash provided by changes in operating assets and liabilities included a $7.6 million increase in accounts payable related to payment terms on inventory purchases and a $3.2 million increase in deferred revenue.

Cash Flows Related to Investing Activities. For the first nine months of fiscal 2012, cash used in investing activities was $3.6 million. This included a net $3.4 million for capital improvements related to our information technology systems, manufacturing and tooling improvements and facility investments and $0.2 million for investment in patent activities.

For the first nine months of fiscal 2011, cash used in investing activities was $5.6 million. This included $3.0 million for capital improvements related to our information technology systems, renewable technologies, manufacturing and tooling improvements and facility investments, $2.1 million invested in equipment related to our PPA finance programs, $0.3 million for long-term investments and $0.1 million for patent investments.

Cash Flows Related to Financing Activities. For the first nine months of fiscal 2012, cash flows provided by financing activities were $3.8 million. This included $4.6 million in new debt borrowings to fund OTAs, $0.7 million for excess tax benefits from stock-based compensation and $0.1 million received from stock option and warrant exercises. Cash flows used in financing activities included $1.3 million for repayment of long-term debt, $0.3 million for common share repurchases and $0.1 million for debt closing costs.

For the first nine months of fiscal 2011, cash flows provided by financing activities were $2.7 million. This included $2.7 million in new debt borrowings to fund OTA and capital projects, $0.4 million received from stock option exercises and $0.2 million for excess tax benefits from stock-based compensation. Cash flows used in financing activities included $0.5 million for repayment of long-term debt and $0.1 million for costs related to our new credit agreement.

Working Capital

Our net working capital as of December 31, 2011 was $41.5 million, consisting of $65.4 million in current assets and $23.9 million in current liabilities. Our net working capital as of March 31, 2011 was $40.0 million, consisting of $64.2 million in current assets and $24.2 million in current liabilities. Our accounts receivables have decreased from fiscal 2011 year-end by $2.9 million as a result of cash collections from customers. Our inventories increased from our fiscal 2011 year-end by $3.6 million due to a $1.6 million increase in fluorescent lamps due to supply concerns, a $1.2 million increase in raw materials for new products and to help address certain electronic component supply concerns and a $0.8 million increase in our work-in process inventories for product orders to be delivered in our fiscal 2012 fourth quarter.

During fiscal 2011, we increased our inventory levels of key electronic components, specifically electronic ballasts, to avoid potential shortages and customer service issues as a result of lengthening supply lead times and product availability issues. During fiscal 2012, we have maintained these higher levels of ballast inventories. We continue to monitor supply side concerns within the electronic component market and believe that our current inventory levels are sufficient to protect us against the risk of being unable to deliver product as specified by our customers’ requirements. During fiscal 2012, we were made aware of concerns over shortages of rare earth minerals used in the production of fluorescent lamps. We have increased our purchase commitments related to these components to ensure that we will have product availability to meet customer demands. We are continually monitoring supply side concerns through conversations with our key vendors and currently believe that supply availability concerns appear to have moderated, but have not diminished to the point where we anticipate reducing safety stock to the levels that existed prior to the electrical components supply issues.

We generally attempt to maintain at least a three-month supply of on-hand inventory of purchased components and raw materials to meet anticipated demand, as well as to reduce our risk of unexpected raw material or component shortages or supply interruptions. Our accounts receivables, inventory and payables may increase to the extent our revenue and order levels increase.

Indebtedness

Revolving Credit Agreement

On June 30, 2010, we entered into a new credit agreement, or Credit Agreement, with JP Morgan Chase Bank, N.A., or JP Morgan. The Credit Agreement replaced our former credit agreement.

The Credit Agreement provides for a revolving credit facility, or Credit Facility, that matures on June 30, 2012. We are currently working on an amendment to the Credit Facility to extend the maturity date to June 30, 2013. Borrowings under the Credit Facility are limited to (i) $15.0 million or (ii) during periods in which the outstanding principal balance of outstanding loans under the Credit Facility is greater than $5.0 million, the lesser of (A) $15.0 million or (B) the sum of 75% of the outstanding principal balance of certain accounts receivable and 45% of certain inventory. We also may cause JP Morgan to issue letters of credit for our account in the aggregate principal amount of up to $2.0 million, with the dollar amount of each issued letter of credit counting against the overall limit on borrowings under the Credit Facility. As of December 31, 2011, we had outstanding letters of credit totaling $1.7 million, primarily for securing collateral requirements under equipment operating leases. In fiscal 2011, we incurred $57,000 of total deferred financing costs related to the Credit Agreement which is being amortized over the two-year term of the Credit Agreement. We had no outstanding borrowings under the Credit Agreement as of March 31, 2011 or December 31, 2011.

The Credit Agreement is secured by a first lien security interest in our accounts receivable, inventory and general intangibles, and a second lien priority in our equipment and fixtures. All OTAs, PPAs, leases, supply agreements and/or similar agreements relating to solar photovoltaic and wind turbine systems or facilities, as well as all of our accounts receivable and assets related to the foregoing, are excluded from these liens.

We must pay a fee of 0.25% on the average daily unused amount of the Credit Facility and a fee of 2.00% on the daily average face amount of undrawn issued letters of credit. The fee on unused amounts is waived if we or our affiliates maintain funds on deposit with JP Morgan or its affiliates above a specified amount. We satisfied the deposit requirement to waive the unused fee as of December 31, 2011.

OTA Credit Agreement

In September 2011, we entered into a credit agreement with JP Morgan that provided us with $5.0 million immediately available to fund completed customer contracts under our OTA finance program and an additional $5.0 million upon our achievement of meeting a trailing 12-month earnings before interest, taxes, depreciation and amortization (EBITDA) target of $8.0 million. We have one-year from the date of the commitment to borrow under the credit agreement. In September 2011, we borrowed $1.8 million. We did not borrow on the credit facility during our fiscal 2012 third quarter. The borrowing is collateralized by the OTA-related equipment and the expected future monthly payments under the supporting 27 individual OTA customer contracts. The current borrowing under the credit agreement bears interest at LIBOR plus 4% and matures in September 2016. The credit agreement includes certain financial covenants, including funded debt to EBITDA and debt service coverage ratios.

Capital Spending

Capital expenditures totaled $3.4 million during the first nine months of fiscal 2012 due to investments in information technologies and other tooling and equipment for new products, as well as cost improvements in our manufacturing facility and a research and training addition to our Manitowoc facility. We expect to incur approximately $1.0 million in capital expenditures during the remainder of fiscal 2012, excluding capital to support expected OTA growth. Our capital spending plans predominantly consist of the completion of projects that have been in place for several months and for which we have already invested significant capital. We consider the investment into our training and research facility critical to our long-term success. We expect to finance these capital expenditures primarily through our existing cash, equipment secured loans and leases, to the extent needed, long-term debt financing, or by using our available capacity under our credit facility.

Contractual Obligations and Commitments

The following table is a summary of our long-term contractual obligations as of December 31, 2011 (dollars in thousands):


			Less than						More than
	Total		1 Year		1-3 Years		3-5 Years		5 Years
Bank debt obligations	$	8,685	$	2,344	$	3,960	$	1,492	$	889
Cash interest payments on debt		1,241		401		456		155		229
Operating lease obligations		8,177		1,728		1,837		1,702		2,910
Purchase order and cap-ex commitments(1)		14,937		10,454		4,483		—		—

Total	$	33,040	$	14,927	$	10,736	$	3,349	$	4,028

(1)	Reflects non-cancellable purchase order commitments in the amount of $14.9 million for certain inventory items entered into in order to secure better pricing and ensure materials on hand.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements.

Inflation

Our results from operations have not been, and we do not expect them to be, materially affected by inflation.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of our consolidated financial statements requires us to make certain estimates and judgments that affect our reported assets, liabilities, revenue and expenses, and our related disclosure of contingent assets and liabilities. We re-evaluate our estimates on an ongoing basis, including those related to revenue recognition, inventory valuation, the collectability of receivables, stock-based compensation, warranty reserves and income taxes. We base our estimates on historical experience and on various assumptions that we believe to be reasonable under the circumstances. Actual results may differ from these estimates. A summary of our critical accounting policies is set forth in the “Critical Accounting Policies and Estimates” section of our Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in our Annual Report on Form 10-K/A for the year ended March 31, 2011. There have been no material changes in any of our accounting policies since March 31, 2011.

Recent Accounting Pronouncements

For a complete discussion of recent accounting pronouncements, refer to Note B in the condensed consolidated financial statements included elsewhere in this report.

ITEM 3.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our exposure to market risk was discussed in the “Quantitative and Qualitative Disclosures About Market Risk” section contained in our Annual Report on Form 10-K/A for the year ended March 31, 2011. There have been no material changes to such exposures since March 31, 2011.

ITEM 4.

CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

We maintain a system of disclosure controls and procedures designed to provide reasonable assurance as to the reliability of our published financial statements and other disclosures included in this report. Our management evaluated, with the participation of our Chief Executive Officer and our Chief Financial Officer, the effectiveness of the design and operation of our disclosure controls and procedures as of the end of the quarter ended December 31, 2011 pursuant to Rules 13a-15(b) of the Securities Exchange Act of 1934, or the Exchange Act.

Material Weaknesses in Internal Control over Financial Reporting

In connection with the assessment of our internal control over financial reporting as of December 31, 2011, management has identified the following deficiencies that constituted individually, or in the aggregate, material weaknesses in our internal control over financial reporting as of December 31, 2011:

•

We did not maintain an effective control environment, as evidenced by the combination of (i) having an insufficient number of personnel appropriately qualified to perform an appropriately detailed review of the accounting for nonroutine revenue transactions, and (ii) having inadequate disclosure controls to ensure timely internal notification of business transactions impacting revenue recognition and decisions requiring accounting entries.

•

We did not maintain an effective control environment over our financial close and reporting processes as evidenced by having an insufficient number of personnel appropriately qualified to support timely and thorough reconciliation of significant accounts.

The material weaknesses described above resulted in a restatement of our annual and interim consolidated financial statements. Because of these material weaknesses, management concluded that we did not maintain effective internal control over financial reporting as of December 31, 2011.

Plans for Remediation of Material Weaknesses

Our Board, the Audit & Finance Committee and management have added resources and are developing and implementing new processes, procedures and internal controls to remediate the material weaknesses that existed in our internal control over financial reporting as it related to revenue recognition, our financial close process and our disclosure controls and procedures, as of December 31, 2011.

We have developed a remediation plan (the “Remediation Plan”) to address the material weaknesses for the affected areas presented above. The Remediation Plan ensures that each area affected by a material control weakness is put through a comprehensive remediation process. The Remediation Plan entails a thorough analysis which includes the following phases:

•

Define and assess each control deficiency: ensure a thorough understanding of the “as is” state, process owners, and procedural or technological gaps causing the deficiency;

•

Design and evaluate a remediation action for each control deficiency for each affected area; validate or improve the related policy and procedures; evaluate skills of the process owners with regard to the policy and adjust as required;

•

Implement specific remediation actions: train process owners, allow time for process adoption and adequate transaction volume for next steps;

•

Test and measure the design and effectiveness of the remediation actions; test and provide feedback on the design and operating effectiveness of the controls, and:

•

Review and acceptance of completion of the remediation effort by management and the Audit & Finance Committee.

The following are steps we have taken in this process:

•

In the second quarter of fiscal 2012, we hired a Corporate controller and in the third quarter of fiscal 2012, we hired a corporate tax manager;

•

In April 2012, we developed and implemented a new sub-certification process with our management group in order to identify new revenue sources and identify legal contractual terms and conditions revisions;

•

In the first quarter of fiscal 2012, we implemented a new enterprise resource planning, or ERP, system to improve our process transactions and the underlying data that supports our financial closing and reporting process.

•

We have identified external resources for the purpose of engaging them to perform detailed accounting analysis on complex nonroutine revenue transactions.

The Remediation Plan is being administered by our Chief Financial Officer and involves key leaders from across the organization.

We will continue to monitor the effectiveness of our internal control over financial reporting in the areas affected by the material weaknesses described above and employ any additional tools and resources deemed necessary to ensure that our financial statements are fairly stated in all material respects.

Changes in Internal Control over Financial Reporting

Except as described above in Plans for Remediation of Material Weaknesses, there were no other changes in our internal control over financial reporting that occurred during the quarter ended December 31, 2011 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

ITEM 1A.

RISK FACTORS

We operate in a rapidly changing environment that involves a number of risks that could materially affect our business, financial condition or future results, some of which are beyond our control. In addition to the other information set forth in this Quarterly Report on Form 10-Q, the risks and uncertainties that we believe are most important for you to consider are discussed in Part I — Item 1A under the heading “Risk Factors” in our Annual Report on Form 10-K/A for the fiscal year ended March 31, 2011, which we filed with the SEC on June 14, 2012. During the nine months ended December 31, 2011, there were no material changes to the risk factors that were disclosed in Part I — Item 1A under the heading “Risk Factors” in our Annual Report on Form 10-K/A for the fiscal year ended March 31, 2011.

ITEM 2.

UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

(c)

Purchases of Equity Securities

The table below summarizes stock repurchases for the three-month period ended December 31, 2011.


					Total Number of
	Total				Shares Purchased as		Approximate Dollar Value
	Number of				Part of Publicly		of Shares that May Yet Be
	Shares		Average Price		Announced Plans		Purchased Under the
Period	Purchased		Paid per Share		or Programs(1)		Plans or Programs(1)
October 1—October 31, 2011		—	$	—		—		$	2,500,000
November 1—November 30, 2011		8,300	$	2.62		8,300		$	2,478,000
December 1—December 31, 2011		90,000	$	2.86		90,000		$	2,221,000

		98,300				98,300

(1)

On November 23, 2011, we announced that our board of directors had authorized the repurchase of up to an additional $1.5 million of our outstanding common stock. The action supplemented the $1 million share repurchase authorization announced on November 2, 2011. Unless terminated earlier by resolution of our board of directors, this repurchase program will expire when we have repurchased all shares authorized for repurchase thereunder.

ITEM 5.

OTHER INFORMATION

Statistical Data

The following table presents certain statistical data, cumulative from December 1, 2001 through December 31, 2011, regarding sales of our HIF lighting systems, total units sold (including HIF lighting systems), customer kilowatt demand reduction, customer kilowatt hours saved, customer electricity costs saved, indirect carbon dioxide emission reductions from customers’ energy savings, and square footage we have retrofitted. The assumptions behind our calculations are described in the footnotes to the table below.


	Cumulative From
	December 1, 2001
	Through December 31, 2011
	(in thousands, unaudited)
HIF lighting systems sold (1)		2,232
Total units sold (including HIF lighting systems)		3,005
Customer kilowatt demand reduction (2)		700
Customer kilowatt hours saved (2)(3)		19,268,376
Customer electricity costs saved (4)	$	1,483,665
Indirect carbon dioxide emission reductions from customers’ energy savings (tons) (5)		12,457
Square footage retrofitted (6)		1,155,627

(1)	“HIF lighting systems” includes all HIF units sold under the brand name “Compact Modular” and its predecessor, “Illuminator.”

(2)

A substantial majority of our HIF lighting systems, which generally operate at approximately 224 watts per six-lamp fixture, are installed in replacement of HID fixtures, which generally operate at approximately 465 watts per fixture in commercial and industrial applications. We calculate that each six-lamp HIF lighting system we install in replacement of an HID fixture generally reduces electricity consumption by approximately 241 watts (the difference between 465 watts and 224 watts). In retrofit projects where we replace fixtures other than HID fixtures, or where we replace fixtures with products other than our HIF lighting systems (which other products generally consist of products with lamps similar to those used in our HIF systems, but with varying frames, ballasts or power packs), we generally achieve similar wattage reductions (based on an analysis of the operating wattages of each of our fixtures compared to the operating wattage of the fixtures they typically replace). We calculate the amount of kilowatt demand reduction by multiplying (i) 0.241 kilowatts per six-lamp equivalent unit we install by (ii) the number of units we have installed in the period presented, including products other than our HIF lighting systems (or a total of approximately 3.0 million units).

(3)	We calculate the number of kilowatt hours saved on a cumulative basis by assuming the demand (kW) reduction for each fixture and assuming that each such unit has averaged 7,500 annual operating hours since its installation.

(4)

We calculate our customers’ electricity costs saved by multiplying the cumulative total customer kilowatt hours saved indicated in the table by $0.077 per kilowatt hour. The national average rate for 2011, which is the most current full year for which this information is available, was $0.1002 per kilowatt hour according to the United States Energy Information Administration.

(5)

We calculate this figure by multiplying (i) the estimated amount of carbon dioxide emissions that result from the generation of one kilowatt hour of electricity (determined using the Emissions and Generation Resource Integration Database, or EGrid, prepared by the United States Environmental Protection Agency), by (ii) the number of customer kilowatt hours saved as indicated in the table.

(6)	Based on 3.0 million total units sold, which contain a total of approximately 15.0 million lamps. Each lamp illuminates approximately 75 square feet. The majority of our installed fixtures contain six lamps and typically illuminate approximately 450 square feet.

ITEM 6.

EXHIBITS

(a)

Exhibits



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

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

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

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

101.INS		XBRL Instance Document

101.SCH		Taxonomy extension schema document

101.CAL		Taxonomy extension calculation linkbase document

101.LAB		Taxonomy extension label linkbase document

101.PRE		Taxonomy extension presentation linkbase document

SIGNATURE

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, on June 14, 2012.

Exhibit Index to Form 10-Q for the Period Ended December 31, 2011



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

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

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

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

101.INS		XBRL Instance Document

101.SCH		Taxonomy extension schema document

101.CAL		Taxonomy extension calculation linkbase document

101.LAB		Taxonomy extension label linkbase document

101.PRE		Taxonomy extension presentation linkbase document

EX-31.1

Exhibit 31.1

Certification

I, Neal R. Verfuerth, certify that:

1.	I have reviewed this Quarterly Report on Form 10-Q of Orion Energy Systems, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: June 14, 2012

/s/ Neal R. Verfuerth

Neal R. Verfuerth

Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification

I, Scott R. Jensen, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Orion Energy Systems, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

5.	The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: June 14, 2012

/s/ Scott R. Jensen

Scott R. Jensen

Chief Financial Officer

EX-32.1

Exhibit 32.1

Certification of CEO Pursuant To

18 U.S.C. Section 1350,

As Adopted Pursuant To

Section 906 Of The Sarbanes-Oxley Act Of 2002

In connection with the Quarterly Report of Orion Energy Systems, Inc., a Wisconsin corporation (the “Company”), on Form 10-Q for the period ended December 31, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Neal R. Verfuerth, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, based on my knowledge:

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: June 14, 2012

/s/ Neal R. Verfuerth

Neal R. Verfuerth

Chief Executive Officer

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

Certification of CFO Pursuant To

18 U.S.C. Section 1350,

As Adopted Pursuant To

Section 906 Of The Sarbanes-Oxley Act Of 2002

In connection with the Quarterly Report of Orion Energy Systems, Inc., a Wisconsin corporation (the “Company”), on Form 10-Q for the period ended December 31, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Scott R. Jensen, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, based on my knowledge:

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: June 14, 2012

/s/ Scott R. Jensen

Scott R. Jensen

Chief Financial Officer