RASER TECHNOLOGIES INC - FORM 10-Q

RASER TECHNOLOGIES INC - FORM 10-Q - November 9, 2009

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Attached files

RASER TECHNOLOGIES INC Reports

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EX-32.1 - SECTION 906 CEO AND CFO CERTIFICATION - RASER TECHNOLOGIES INC	dex321.htm
EX-31.3 - SECTION 302 CEO CERTIFICATION - RASER TECHNOLOGIES INC	dex313.htm
EX-31.2 - SECTION 302 CFO CERTIFICATION - RASER TECHNOLOGIES INC	dex312.htm
EX-31.1 - SECTION 302 CEO CERTIFICATION - RASER TECHNOLOGIES INC	dex311.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended September 30, 2009

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

Commission File Number: 001-32661

RASER TECHNOLOGIES, INC.

(Exact name of registrant as specified in its charter)


Delaware		87-0638510
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

5152 North Edgewood Drive, Suite 375, Provo, UT		84604
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code: (801) 765-1200

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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ¨ 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 “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

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

The number of shares outstanding of the registrant’s common stock as of November 6, 2009 was 79,227,825 shares.

Raser Technologies, Inc.

SEC Form 10-Q

Table of Contents


		Page No.
Part I. Financial Information		2

Item 1. Financial Statements		2
Condensed Consolidated Balance Sheets		2
Condensed Consolidated Statements of Operations		3
Condensed Consolidated Statements of Cash Flows		4
Condensed Consolidated Statement of Stockholders’ Equity (Deficit)		5
Notes to Condensed Consolidated Financial Statements		6
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		25
Item 3. Quantitative and Qualitative Disclosures About Market Risk		46
Item 4. Controls and Procedures		48

Part II. Other Information		48

Item 1. Legal Proceedings		48
Item 1A. Risk Factors		48
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		60
Item 6. Exhibits		60
SIGNATURES		61

PART I. FINANCIAL INFORMATION

Item 1.

Financial Statements

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Condensed Consolidated Balance Sheets

(Unaudited)


	September 30, 2009			December 31, 2008
Assets
Current assets:
Cash and cash equivalents	$	3,817,632		$	1,534,820
Restricted cash		76,921			75,704
Notes receivable, net		—			144,525
Accounts receivable, net		274,871			—
Restricted marketable securities (held to maturity)		4,382,258			6,521,347
Other current assets		1,421,559			1,147,562

Total current assets		9,973,241			9,423,958
Restricted cash		12,387,611			20,900,135
Land		1,811,063			1,811,063
Geothermal property, plant and equipment, net		107,708,919			—
Power project leases and prepaid delay rentals		6,730,136			8,630,643
Geothermal well field development-in-progress		857,234			31,388,628
Power project construction-in-progress		8,036,019			74,072,394
Power project equipment, net		—			19,727,500
Equipment, net		679,585			608,886
Intangible assets, net		1,543,323			1,587,310
Deferred financing costs, net		6,812,908			7,670,382
Power project development deposits		—			4,196,550
Other assets		1,618,608			4,006,999

Total assets	$	158,158,647		$	184,024,448

Liabilities and Stockholders’ Equity
Current liabilities:
Accounts payable and accrued expenses	$	15,536,392		$	64,471,336
Unsecured line of credit, net of discount of $462,403		10,211,449			—
Short-term portion of long-term notes		3,001,754			1,831,147
Note payable		—			945,833
Deferred revenue		200,000			200,000

Total current liabilities		28,949,595			67,448,316
Asset retirement obligation		2,695,217			2,152,230
Long-term 7.00% senior secured note (non-recourse), net of discount of $4,575,832 and $4,898,833, respectively		24,946,381			25,120,464
Long-term 8.00% convertible senior notes		55,000,000			55,000,000
Warrants		14,254,259			—

Total liabilities		125,845,452			149,721,010

Contingencies and commitments, (see Notes A,D,E,G)
Non-controlling interest in Thermo No. 1 subsidiary		27,850,256			28,025,116
Stockholders’ equity:
Preferred stock, $.01 par value, 5,000,000 shares authorized; no shares issued and outstanding		—			—
Common stock, $.01 par value, 250,000,000 shares authorized, 76,020,619 and 63,519,455 shares issued and outstanding, respectively		760,206			635,195
Additional paid in capital		107,419,484			102,350,814
Accumulated deficit		(103,716,751	)		(96,707,687	)

Total stockholders’ equity		4,462,939			6,278,322

Total liabilities and stockholders’ equity	$	158,158,647		$	184,024,448

See accompanying notes to condensed consolidated financial statements.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Condensed Consolidated Statements of Operations

(Unaudited)


	Three months ended September 30,						Nine months ended September 30,
	2009			2008			2009			2008
Revenue	$	845,265		$	30,000		$	1,252,506		$	166,423
Cost of revenue
Direct costs		2,150,652			—			3,283,296			74,112
Depreciation and amortization		735,126			—			1,445,900			—

Gross margin		(2,040,513	)		30,000			(3,476,690	)		92,311

Operating expenses
General and administrative		2,352,612			2,447,878			7,633,943			7,562,902
Power project development		1,245,849			3,232,729			6,509,230			8,012,210
Research and development		364,557			970,925			1,592,124			3,134,138

Total operating expenses		3,963,018			6,651,532			15,735,297			18,709,250

Operating loss		(6,003,531	)		(6,621,532	)		(19,211,987	)		(18,616,939	)
Interest income		33,538			94,030			122,342			265,306
Interest expense		(3,481,165	)		(1,077,695	)		(8,714,110	)		(2,180,976	)
Gain on derivative instruments		5,918,100			—			12,917,454			—
Other		—			—			(131,442	)		75,775

Loss before income taxes		(3,533,058	)		(7,605,197	)		(15,017,743	)		(20,456,834	)
Tax benefit (expense)		—			—			—			—

Net loss	$	(3,533,058	)	$	(7,605,197	)	$	(15,017,743	)	$	(20,456,834	)
Non-controlling interest in the Thermo No. 1 subsidiary		(248,513	)		(1,226,070	)		806,458			(1,226,070	)

Net loss applicable to common stockholders	$	(3,781,571	)	$	(8,831,267	)	$	(14,211,285	)	$	(21,682,904	)

Loss per common share-basic and diluted	$	(0.05	)	$	(0.15	)	$	(0.21	)	$	(0.38	)

Weighted average common shares-basic and diluted		74,881,000			57,785,000			68,321,000			56,646,000

See accompanying notes to condensed consolidated financial statements

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Nine Months Ended September 30,
	2009			2008
Cash flows from operating activities:
Net loss applicable to common stockholders	$	(14,211,285	)	$	(21,682,904	)
Adjustments to reconcile net loss to net cash used in operating activities:
Depreciation, amortization and accretion expense		1,849,449			224,965
Deferred financing costs amortization		4,933,692			320,814
Gain on derivative instrument		(12,917,454	)		—
Impairment of abandoned patent applications		101,613			11,534
Impairment of power project lease acquisitions		24,000			283,903
Loss on disposal of assets		16,813			8,448
Gain on completion of contract		—			(75,357	)
Gain on extinguishment of debt		(68,588	)		—
Bad debt expense		145,403			27,216
Common stock, stock options and warrants issued for services		3,070,171			2,638,765
Non-controlling interest in Thermo No. 1 subsidiary		(806,458	)		1,226,070
Increase in accounts receivable		(274,871	)		(5,880	)
Decrease in unbilled receivables		—			192,157
Increase in other assets		2,106,841			168,978
Increase in interest receivable		(57,623	)		(66,102	)
(Decrease) increase in accounts payable and accrued liabilities		(8,594,859	)		6,488,338
Increase in deferred revenues		—			200,000
Decrease in asset retirement obligation		—			(26,453	)

Net cash used in operating activities		(24,683,156	)		(10,065,508	)

Cash flows from investing activities:
Purchase of marketable equity securities		—			(8,687,175	)
Proceeds from marketable equity securities		2,200,000			—
Decrease in notes receivable		—			(142,500	)
Proceeds from notes receivable		—			350,000
(Increase) decrease in deposits		—			(440,573	)
Increase (decrease) in restricted cash		8,511,308			(9,716,405	)
Increase in intangible assets		(101,236	)		(946,910	)
Purchase of equipment		(335,804	)		(180,679	)
Well field development costs		(11,887,887	)		(24,127,329	)
Construction costs		(11,984,002	)		(19,382,251	)
Purchase of real property		—			(1,811,063	)
Power project lease acquisitions		(82,000	)		(490,858	)
Proceeds from sales of fixed assets		11,991			2,403
Power project equipment deposits		7,056,375			(10,298,987	)

Net cash used in investing activities		(6,611,255	)		(75,872,327	)

Cash flows from financing activities:
Proceeds from registered direct equity financing		23,575,332			—
Proceeds from exercise of common stock warrants		—			27,854
Proceeds from exercise of common stock options		—			650,744
Proceeds from the issuance of 8.00% convertible senior notes		—			55,000,000
Proceeds from the issuance of 7.00% senior secured notes (non-recourse)		—			26,130,874
Principal payments of 7.00% senior secured notes (non-recourse)		(471,109	)		—
Proceeds from ATM equity financing		—			24,160,319
Purchase of forward stock purchase transaction		—			(15,000,000	)
Purchase of call spread option transaction		—			(5,850,000	)
Proceeds from issuance of a note payable		—			900,000
Incurrence of deferred financing fees		—			(4,161,587	)
Proceeds from minority interest capital contribution		—			3,675,000
Proceeds from 10.0% line of credit		13,373,000			—
Principal payment of the 10.0% line of credit		(2,900,000	)		—

Net cash provided by financing activities		33,577,223			85,533,204

Net increase (decrease) in cash and cash equivalents		2,282,812			(404,631	)
Cash and cash equivalents at beginning of period		1,534,820			5,912,210

Cash and cash equivalents at end of period	$	3,817,632		$	5,507,579

See accompanying notes to condensed consolidated financial statements.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Condensed Consolidated Statement of Stockholders’ Equity

(Unaudited)


	Preferred stock			Common stock			Additional paid-in capital			Accumulated deficit			Total
	Shares	Amount		Shares	Amount		Additional paid-in capital			Accumulated deficit			Total
Balance at December 31, 2008	—	$	—	63,519,455	$	635,195	$	102,350,814		$	(96,707,687	)	$	6,278,322
Cumulative effect for the change in accounting principle											7,202,222			7,202,222
Employee compensatory share grants and stock options								2,739,409						2,739,409

Warrants vested and issued for:
Payment of outstanding contractor services for the construction of our Thermo No. 1 geothermal power plant								250,000						250,000
Per agreement relating to the Line of Credit receipts with the fair market value computed on each individual grant date (a)								4,161,628						4,161,628

Common stock issued for:
Units purchases in the July 2009 registered direct offering				8,550,339		85,503		23,489,828						23,575,331
Compliance with the anti-dilution provision of the November 2008 Fletcher Agreement				445,901		4,459		(4,459	)					—
Settlement of outstanding debt with service providers and promissory note holders				3,420,760		34,207		9,235,198						9,269,405
Employee severance payments				54,580		546		202,894						203,440
Director and employee share grant vesting				29,584		296		(296	)					—
Reclassification of warrants from equity to liabilities								(34,373,934	)					(34,373,934	)
Non-controlling interest								(631,598	)		806,458			174,860
Net loss											(15,017,744	)		(15,017,744	)

Balance at September 30, 2009	—	$	—	76,020,619	$	760,206	$	107,419,484		$	(103,716,751	)	$	4,462,939

(a)

Under the Line of Credit, each lender received warrants (each a “Warrant”) to purchase our common stock for each advance of funds made under the Line of Credit. The number of shares underlying each Warrant is equal to 50% of the total amounts funded by the applicable lender divided by the closing price of our common stock on the date of the advance. The Warrants have an exercise price of $6.00 per share.

See accompanying notes to condensed consolidated financial statements.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements

(Unaudited)

A. Basis of Presentation

The interim consolidated financial statements include the accounts of Raser Technologies, Inc. and its subsidiaries. Unless the context requires otherwise, “Raser,” the “Company,” “we,” “our” or “us” refer to Raser Technologies, Inc. and its subsidiaries.

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) for interim financial information and pursuant to the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities Exchange Act of 1934, as amended. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. The accompanying condensed consolidated balance sheet as of December 31, 2008 has been derived from audited financial statements at that date but does not include all of the information and notes required by GAAP for complete financial statements. Certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). These condensed consolidated financial statements reflect all adjustments (consisting only of normal recurring adjustments) that, in the opinion of our management, are necessary to present fairly the results of our operations for the periods presented. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in our Form 10-K for the year ended December 31, 2008. The results of operations for the nine and three months ended September 30, 2009 are not necessarily indicative of the results that may be expected for the fiscal year ending December 31, 2009 or any other period.

Certain reclassifications have been made in the prior year’s consolidated financial statements to conform to the current year presentation, which has no impact on the net loss for any period presented. Events subsequent to September 30, 2009, were evaluated until the time of the Form 10-Q filing with the Securities and Exchange Commission on November 9, 2009.

Overview

We are an environmental energy technology company focused on geothermal power development and technology licensing. We operate two business segments: Power Systems and Transportation & Industrial. Our Power Systems segment develops clean, renewable geothermal electric power plants and anticipates also developing bottom-cycling operations in the future. Our Transportation & Industrial segment focuses on using our Symetron™ family of technologies to improve the efficiency of electric motors, generators and power electronic drives used in electric and hybrid electric vehicle propulsion systems. Through these two business segments, we are employing a strategy to produce a positive impact on the environment and economically beneficial results for our stockholders. By executing our strategy, we aim to become both a producer of clean, geothermal electric power as well as a provider of electric and hybrid-electric vehicle technologies and products.

Liquidity

The accompanying condensed consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and the settlement of liabilities and commitments in the normal course of business. As reflected in the accompanying consolidated financial statements, as of September 30, 2009, we had approximately $3.8 million in cash and cash equivalents on hand and restricted cash and marketable securities of approximately $16.8 million and accounts payable and accrued liabilities of $15.5 million. Cash used in operations totaled approximately $24.7 million for the nine months ended September 30, 2009 and our accumulated deficit totaled $103.7 million. We have incurred substantial losses since inception, and we are not operating at cash breakeven.

Our ability to secure liquidity in the form of additional financing or otherwise is crucial for the execution of our plans and our ability to continue as a going concern. Our current cash balance, together with cash anticipated to be provided by operations, will not be sufficient to satisfy our anticipated cash requirements for normal operations and capital expenditures for the foreseeable future. During 2008 and 2009, economic conditions have weakened significantly and global financial markets have experienced significant liquidity challenges. Despite these challenges, we were able to obtain a limited amount of financing during 2009. Earlier in the year, we established an Unsecured Line of Credit Agreement and Promissory Note, dated January 27, 2009 and amended on July 22, 2009 (the “Line of Credit”), among Radion Energy, LLC (“Radion”), Ocean Fund, LLC (“Ocean Fund”), Primary Colors, LLC (“Primary Colors”) and R. Thomas Bailey, an individual (collectively, the “LOC Lenders”). During the year we borrowed a total of $13.4 million under the Line of Credit. In July 2009, we completed a $25.5 million registered direct offering In October 2009, we sold shares of our common stock and warrants to acquire shares of our common stock to three of the LOC Lenders for a total purchase price of $5.4 million. We received the purchase price in the form of promissory notes, which were then used as an offset to settle our outstanding obligations to the participating LOC Lenders under the Line of Credit and reduce our outstanding borrowings under the Line of Credit to $5.3 million. This transaction reduced our liabilities, but did not change our available cash. Although the outstanding borrowings under the Line of Credit of $5.3 million is due in July 2010, the remaining LOC Lender is a related party and has informed us that he does not intend to exert further pressure on our liquidity situation.

Although we were able to obtain limited financing through the sources described above, these sources of funding alone will be insufficient for us to properly execute our current business plan. We have substantial short-term and long-term obligations, and need to obtain additional financing to meet these obligations. However, the current economic environment makes it challenging for us to obtain the financing that we need, on terms acceptable to us.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

The cost of raising capital in the debt and equity capital markets has increased substantially while the availability of funds from those markets generally has diminished significantly. Also, as a result of concerns about the stability of financial markets generally and the solvency of counterparties, the cost of obtaining money from the credit markets generally has increased as many lenders and institutional investors have increased interest rates, enacted tighter lending standards, refused to refinance existing debt at maturity on terms that are similar to existing debt, and reduced, or in some cases ceased, to provide funding to borrowers. If we are unable to secure adequate funds on a timely basis on terms acceptable to us, we will be unable to satisfy our existing obligations, or execute our plans. In such case, we would be required to curtail or cease operations, liquidate or sell assets, modify our current plans for plant construction, well field development and other development activities, or extend the time frame over which these activities will take place, or pursue other actions that could adversely affect future operations. Federal and state governments have recognized the financing challenges faced by many businesses and have established programs to help companies engaged in the development of renewable energy projects. These programs include loan guarantee, government grant and other programs. As a result, part of our short-term strategy to obtain additional funding includes applications for loan guarantees and government grants. For example, we have made or are in the process of making applications for funding under several stimulus programs established by the American Recovery and Reinvestment Act of 2009 (the “Recovery Act”) and other pre-existing programs. However, one of our applications for loan guarantees was denied, and we were not awarded three small grants that were applied for in connection with innovative exploration activities. We cannot predict whether we will be able to successfully obtain loan guarantees or grants under government programs.

We intend to continue to seek financing arrangements to fund our development activities from a variety of sources, which may include the issuance of debt, preferred stock, equity or a combination of these instruments. We also continue to evaluate a variety of alternatives to finance the development of our geothermal power projects. These alternatives include project financing and tax equity financing, government funding from grants, loan guarantees or private activity bonds, joint ventures, the sale of one or more of our projects or interests therein, entry into prepaid power purchase agreements with utilities or municipalities, or a merger and/or other transaction, a consequence of which could include the sale or issuance of stock to third parties. The amount and timing of our future capital needs will depend on many factors, including the timing of our development efforts, opportunities for strategic transactions, and the amount and timing of any cash flows we are able to generate. We cannot be certain that funding will be available to us on reasonable terms or at all.

Revenue and cost of revenue

Revenue is primarily related to sale of electricity from our Thermo No. 1 geothermal power plant to the City of Anaheim. Revenue related to the sale of electricity is recorded based upon output delivered at rates specified under relevant contract terms when incurred. The power purchase agreement with the City of Anaheim is exempt from derivative treatment due to the normal purchase and sale exception.

Cost of revenue includes direct costs attributable to our operating geothermal power plant including operation and maintenance expenses such as depreciation and amortization, salaries and related employee benefits, equipment expenses, costs of parts and chemicals, costs related to third-party services, lease expenses, royalties, startup and auxiliary electricity purchases, property taxes, insurance and certain transmission charges. Payments made to government agencies and private entities on account of site leases where plants are located are also included in cost of revenue. Royalty payments, included in cost of revenue, are made as compensation for the right to use certain geothermal resources and are paid as a percentage of the revenue derived from the associated geothermal rights.

Derivative Financial Instruments

During the normal course of business, from time to time, we issue warrants and options to vendors as consideration to perform services or settle outstanding debt. We may also issue warrants as part of a debt or equity placement offering. We do not enter into any derivative contracts for speculative purposes.

We recognize all derivatives as assets or liabilities measured at fair value with changes in fair value of derivatives reflected as current period income or loss unless the derivatives qualify as hedges of future cash flows and are accounted for as such. As a result, certain warrants are accounted for as derivatives. See Note D. “Warrants” and Note I. “Fair Value Measurements.”

New Accounting Pronouncements Effective January 1, 2009

Effective January 1, 2009, we adopted new accounting guidance relating to disclosures about derivative instruments and hedging activities. The new accounting standard is intended to improve financial reporting about derivative instruments and hedging activities by requiring enhanced disclosures to enable investors to better understand their effects on an entity’s financial position, results of operations and cash flows. The new standard also improves transparency about how and why a company uses derivative

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

instruments and how derivative instruments and related hedged items are accounted for under the Derivatives and Hedging Topic of the FASB Accounting Standards Codification. The effect of adopting this new accounting standard was to increase certain derivative footnote disclosures.

Effective January 1, 2009, we adopted new accounting standards relating to non-controlling interests in consolidated financial statements. The new accounting guidance established accounting and reporting standards that require non-controlling interests to be reported as a component of equity, changes in a parent’s ownership interest while the parent retains its controlling interest to be accounted for as equity transactions, and any retained non-controlling equity investment upon the deconsolidation of a subsidiary to be initially measured at fair value. The adoption of this new accounting guidance primarily resulted in moving the presentation of non-controlling interest to the “Stockholders’ equity” section of our condensed consolidated balance sheets.

We also adopted new accounting guidance that revised the classification and measurement of redeemable securities. The revisions require that securities with redemption features that are not solely within the control of the company should be classified outside of permanent equity as temporary equity. We adopted the revisions effective January 1, 2009. As a result of the adoption, we classified “non-controlling interest” as temporary equity outside of the permanent equity section.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

Effective January 1, 2009, we adopted new accounting guidance that prescribes the accounting for parties of a collaborative arrangement to present the results of activities for the party acting as the principal on a gross basis and report any payments received from (made to) other collaborators based on other applicable GAAP or, in the absence of other applicable GAAP, based on analogy to authoritative accounting literature or a reasonable, rational, and consistently applied accounting policy election. Further, the new accounting guidance clarified the determination of whether transactions within a collaborative arrangement are part of a vendor-customer (or analogous) relationship. The adoption of this new accounting guidance had no material effect on our financial position or results of operations.

Effective January 1, 2009, we adopted new accounting guidance relating to determining whether a financial instrument is indexed to an entity’s own stock. The new accounting guidance provides that an entity should use a two-step approach to evaluate whether an equity-linked financial instrument (or embedded feature) is indexed to its own stock, including evaluating the instrument’s contingent exercise and settlement provisions. It also clarifies the impact of foreign currency denominated strike prices and market-based employee stock option valuation instruments on the evaluation. The adoption of this new accounting guidance resulted in our warrants with anti-dilutive provisions being classified as derivatives as required by the Derivatives and Hedging Topic of the FASB Accounting Standards Codification. For further discussion of the adoption of this new accounting pronouncement, please refer to Note D. “Warrants” and Note I. “Fair Value Measurements” below.

Effective April 1, 2009, we adopted new accounting guidance which provides additional guidance for estimating fair value in accordance when the volume and level of activity for an asset or liability have significantly decreased, and also includes guidance on identifying circumstances that indicate a transaction is not orderly. The new accounting guidance amends the other-than-temporary impairment guidance in U.S. GAAP for debt securities to make the guidance more operational and to improve the presentation and disclosure of other-than-temporary impairments on debt and equity securities in the financial statements. The new accounting guidance also amends certain disclosures about Fair Value of Financial Instruments to require disclosures about fair value of financial instruments for interim reporting periods of publicly traded companies as well as in annual financial statements. This new accounting guidance also requires those disclosures in summarized financial information at interim reporting periods. The adoption of this new accounting guidance increased financial statement disclosure surrounding the fair value of our financial debt instruments that were previously disclosed annually.

Effective April 1, 2009, we adopted new accounting guidance which establishes general standards of accounting for disclosure of events that occur after the balance sheet date but before financial statements are issued or available to be issued. It requires the disclosure of the date through which an entity has evaluated subsequent events and whether that date represents the date the financial statements were issued or were available to be issued. We implemented this guidance on April 1, 2009, and it did not have a material impact on our financial condition, results of operations, or cash flows.

Effective April 1, 2009, we adopted new accounting guidance which establishes general standards of accounting and requires disclosures of events that occur after balance sheet dates but before financial statements are issued or are available to be issued. The adoption of the new accounting guidance did not have a material effect on our financial statements.

No other new accounting pronouncement that will take effect with respect to 2009 or any interim period during 2009 had or is expected to have a material impact on our condensed consolidated financial statements.

Concentration of Credit Risk

During the quarter ended September 30, 2009, we sold electricity generated by our Thermo No. 1 geothermal power plant to the City of Anaheim in accordance with our power purchase agreement. In accordance with the power purchase agreement, we invoice the City of Anaheim within 15 days after each month end for the previous month’s activity. The City of Anaheim is required to remit payment to us within 15 days after receiving the invoice. We do not believe that we are exposed to any significant credit risks relating to collecting payments in accordance with our power purchase agreement.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

B. Geothermal Property, Plant and Equipment

The Thermo No. 1 power plant was placed in service during the first quarter of 2009. Accordingly, we reclassified our related power project lease acquisition costs from the “Power project leases and prepaid delay rentals” account, well field drilling costs from the “Geothermal well field development-in-progress” account and power plant construction and transmission equipment costs from the “Power project construction-in-progress” account to the “Geothermal property, plant and equipment” account in accordance with our company policy.

Accordingly, we began to amortize the capitalized costs related to the power plant over the estimated useful life of the Thermo No. 1 geothermal power plant in the second quarter of 2009. The useful life of the Thermo No. 1 plant is estimated to be 35 years.

The table below sets forth the capitalized costs relating to our geothermal property, plant and equipment as of September 30, 2009:


	September 30, 2009
Thermo No. 1 Geothermal Power Plant:
Power project lease acquisitions	$	2,376,751
Well field drilling costs		42,419,586
Power plant		60,003,521
Transmission equipment		4,347,406
Accumulated depreciation		(1,438,345	)

Net geothermal property, plant and equipment	$	107,708,919

At our Thermo No. 1 project, as of September 30, 2009, we had completed the drilling of five wells that had been identified as production wells, two wells that had been identified as reinjection wells, one cold water well that is utilized for the cooling towers, and two wells that we have determined to be non-commercial wells. These two non-commercial wells were expensed. As of September 30, 2009, we had finished drilling two additional wells that we expect to use as production wells, pending the completion of testing. No additional wells were being drilled at September 30, 2009. Capitalized interest included in the costs of the Thermo No. 1 geothermal property, plant and equipment totaled $1,468,279.

The following table is a roll forward of the capitalized well costs for pending wells at the Thermo No. 1 project for the nine months ending September 30, 2009:


	Thermo No. 1 Project
Balance at December 31, 2008	$	1,898,677
2009 Activity:
Additions to capitalized well costs for pending wells		1,052,862
Wells charged to expense		—
Reclassification of capitalized well costs from pending wells to wells used in production		—

Balance at March 31, 2009	$	2,951,539
Additions to capitalized well costs for pending wells		2,372,177
Wells charged to expense		—
Reclassification of capitalized well costs from pending wells to wells used in production		—

Balance at June 30, 2009	$	5,323,716
Additions to capitalized well costs for pending wells		3,560,313
Wells charged to expense		—
Reclassification of capitalized well costs from pending wells to wells used in production		—

Balance at September 30, 2009	$	8,884,029

C. Short-Term and Long-Term Debt

On January 27, 2009, we entered into the Line of Credit with the LOC Lenders party thereto. Pursuant to the Line of Credit, we could borrow up to $15.0 million, subject to the final approval of each advance by the LOC Lenders. Radion, one of the LOC Lenders, is controlled by the Chairman of our Board of Directors, Kraig Higginson. The commitment amounts under the Line of Credit from each of the LOC Lenders were as follows: $7.2 million from Radion; $5.3 million from Ocean Fund; $2.0 million from Primary Colors; and $500,000 from Mr. Bailey. Under the Line of Credit, advances are subject to the final approval of the LOC Lenders, and

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

amounts borrowed under the Line of Credit accrue interest at the rate of 10% per annum. Under the Line of Credit, each LOC Lender receives warrants (the “LOC Warrants”) to purchase our common stock for each advance of funds made under the Line of Credit. The number of shares underlying each LOC Warrant is equal to 50% of the total amounts funded by the applicable LOC Lender divided by the closing price of our common stock on the date of the advance. The LOC Warrants have an exercise price of $6.00 per share. As of June 30, 2009, we had borrowed $13.4 million of the Line of Credit, and the LOC Lenders had received LOC Warrants to acquire approximately 1,755,048 shares of our common stock at a strike price of $6.00 per share as a result of the amount borrowed. On July 22, 2009, we amended the Line of Credit agreement with the LOC Lenders. Under the amendment, we paid $2.9 million of the loan principal and approximately $0.4 million of accrued interest. In connection with the amendment, the due date of the remaining principal balance was extended until July 31, 2010, without an early payment penalty. However, LOC Lenders have the right to demand early repayment of all or part of the outstanding balance at any time after November 15, 2009. The principal balance, and any accrued interest thereon, can be paid in the form of cash or equity securities at our sole discretion. At September 30, 2009, the amount of principal and accrued interest outstanding on the Line of Credit totaled $10.7 million.

On October 19, 2009, we sold shares of our common stock and warrants to three of the LOC Lenders in consideration for $5.4 million in promissory notes (for further discussion of the registered offering see Note D. “Warrants” and Note G. “Common Stock” below). On October 23, 2009, we entered into agreements with the three LOC Lenders to cancel the $5.4 million promissory notes as an offset to settle the equivalent amount owed to the participating LOC Lenders for their respective portions of the outstanding Line of Credit balance on that date.

D. Warrants

Derivative Liability Warrants

Effective January 1, 2009, we adopted the provisions of a new accounting pronouncement, which applies to any freestanding financial instruments or embedded features that have the characteristics of a derivative and to any freestanding financial instruments that are potentially settled in an entity’s own common stock. As a result, certain of our issued and outstanding warrants previously treated as equity pursuant to the derivative treatment exemption are no longer considered exempt. Accordingly, effective January 1, 2009, we reclassified the fair value of the warrants described below, which have exercise price reset features, from equity to liability status as if these warrants had been treated as a derivative liability since the date they were issued.

Fletcher Warrants

As part of a $20.0 million private placement to Fletcher International Limited (“Fletcher”) in November of 2008, we issued to Fletcher warrants to acquire shares of our common stock in an aggregate value of up to $20.0 million (the “Fletcher Warrants”). The number of shares issued pursuant to the Fletcher Warrants may not exceed 7,458,532 shares of our common stock. The Fletcher Warrants had an original strike price per share equal to the lesser of (i) six dollars ($6.00) or (ii) a price equal to the weighted-average of the daily market prices of our common stock for the forty (40) business days ending on the third business day prior to the exercise of the Fletcher Warrants, less $0.60, subject to certain adjustments (see “Fletcher Warrants Price Reset Feature” below). In addition, our agreement with Fletcher requires us to issue additional shares to Fletcher if, prior to the first-year anniversary of the 2008 private placement transaction or any exercise of the Fletcher Warrants by Fletcher, we engage in a public disclosure of our intention or agreement to engage in a sale or issuance of any shares of, or securities convertible into, exercisable or exchangeable for, or whose value is derived in whole or in part from, any shares of any class of our capital stock. As a result of the issuance of the units in the July 2009 registered direct offering, we issued 445,901 additional shares of common stock to Fletcher in August 2009. Accordingly, as of September 30, 2009, the number of shares that may be issued pursuant to the Fletcher Warrants was reduced by the amount of additional shares issued and may not exceed 7,012,631. Furthermore, as a result of the issuance of additional units in the October 2009 registered offering to the participating LOC Lenders, we are also required to issue 136,219 additional shares of our common stock to Fletcher which further reduced the maximum number of shares that may be issued pursuant to the Fletcher Warrants to not exceed 6,876,412.

At September 30, 2009, based upon an exercise price equal to the weighted average of the daily market prices of our common stock for the forty (40) business days ending on the third business day prior to the exercise of the Fletcher Warrants, less $0.60 on that date, the Fletcher Warrants would have been exercisable for a total of 7,012,631 shares of our common stock. The Fletcher Warrants expire on November 14, 2018. The Fletcher Warrants would generate proceeds totaling $20.0 million, if all of the Fletcher Warrants are exercised unless Fletcher decides to exercise the Fletcher Warrants through a cashless exercise.

Fletcher Warrants Price Reset Feature

As described above, the Fletcher Warrants, issued in November of 2008, would have been exercisable for a total of 5,861,622 shares of our common stock at June 30, 2009. The Fletcher Warrants contain an exercise price reset feature that may be triggered upon certain events, such as the issuance of shares of common stock at a price below the maximum Fletcher Warrant exercise price. If triggered, the exercise price reset feature results in a downward adjustment to the original maximum Fletcher Warrant exercise price of $6.00 per share to an amount equal to the average of the then current maximum exercise price and the lowest price at which shares are issued on the date when the event occurred. On July 6, 2009, we closed a $25.5 million registered direct offering that triggered a

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

price reset with respect to the Fletcher Warrants. Pursuant to the registered direct offering, we sold units of one share of our common stock and one warrant to acquire 0.50 share of our common stock (the “July 2009 Warrants”) for a negotiated price of $2.98 per unit. The per share exercise price of the July 2009 Warrants is $4.62. The issuance of the units in connection with the July 2009 registered direct offering triggered a price reset with respect to the Fletcher Warrants, resulting in a maximum exercise price of $3.99 for the Fletcher Warrants as of September 30, 2009.

On October 22, 2009, we closed a $5.4 million registered offering that triggered another price reset with respect to these warrants. Pursuant to the registered offering, we sold units that included one share of our common stock and one warrant to acquire 0.50 share of our common stock (the “October 2009 Warrants”) for a negotiated price of $1.68 per unit. The per share exercise price of the October 2009 Warrants associated with the units is $1.61. The issuance of the units in connection with the October 2009 registered offering triggered a price reset with respect to the Fletcher Warrants, resulting in a current maximum exercise price of $2.56 for the Fletcher Warrants.

Contingent Warrants

On January 16, 2008, we granted to Merrill Lynch warrants to acquire up to 3,700,000 shares of our common stock, subject to vesting requirements associated with the financing of our geothermal power plants (the “Contingent Warrants”). The Contingent Warrants expire on January 16, 2015 and would generate proceeds totaling $44.8 million if all of the warrants vest and are exercised. On August 31, 2008, the Contingent Warrants to acquire 1,350,000 shares of our common stock vested in connection with the closing of the project financing arrangements for the Thermo No. 1 project. These Contingent Warrants are immediately exercisable and had an exercise price of $11.65 as of September 30, 2009.

Contingent Warrant Price Reset Feature

The Contingent Warrants will vest and become exercisable in increments over the term of the financing commitment based on the actual funding provided. In accordance with the anti-dilution provisions included in the Contingent Warrants, the issuance of the Convertible Notes, the issuance of common stock during the third and fourth quarters of 2008, the issuance of the LOC Warrants in connection with the Line of Credit during the second quarter of 2009, resulted in a reduction of the original strike prices of the Contingent Warrants from a range of $14.98 to $19.71 to a range of $13.07 to $16.64. The issuance of units in connection with the July 2009 registered direct offering, as described above, and subsequent issuance of shares to Fletcher International also in connection with July 2009 registered direct offer, resulted in a further reduction of the strike prices to a range of $11.65 to $14.69 Subsequent to September 30, 2009, the issuance of units in connection with the October 2009 registered offering resulted in an additional reduction of the strike prices to a range of $11.09 to $13.96.

The terms of the Contingent Warrants provide for anti-dilution protection, which adjusts the exercise price of each Contingent Warrant, from time to time upon the occurrence of certain events, including stock splits, dividends, recapitalizations and similar events. Upon the occurrence of such events, the exercise price of the Contingent Warrants will be appropriately adjusted.

The above warrants that are classified as a derivative liability do not qualify for hedge accounting, and as such, all future changes in the fair value of these warrants will be recognized currently in earnings until such time as the warrants are exercised or expire. In addition, these warrants do not trade in an active securities market, and as such, we estimate the fair value of these warrants using either a Binomial Lattice valuation model or the Black-Scholes option pricing model, whenever appropriate. The fair values of the warrants treated as derivatives were computed using the following assumptions:


	September 30, 2009		January 1, 2009
Risk-free interest rate	0.06 – 3.25	%	0.32 – 2.23	%
Expected dividend yield	0.0	%	0.0	%
Volatility	104 – 105	%	105 – 106	%
Time to maturity (in years)	0.02 – 9.25		0.75 – 10.0

The risk-free interest rate is based on a yield curve of interest rates at the time of the grant based on the contractual life of the option. Expected dividend yield is based on our dividend history and anticipated dividend policy. Expected volatility is based on historical volatility for our common stock. We currently have no reason to believe future volatility over the expected remaining life of these warrants is likely to differ materially from historical volatility. The expected life is based on the remaining term of the warrants.

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Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

Detachable Warrants

July 2009 Warrants

On July 6, 2009, we closed our $25.5 million registered direct offering in which we sold an aggregate of 8,550,339 units primarily to institutional investors. Each unit consisted of one share of our common stock, and one warrant to purchase 0.50 share of our common stock pursuant to a Warrant to Purchase Common Stock. The July 2009 Warrants have an exercise price of $4.62 per share and expire on July 6, 2014.

There is no anti-dilution or pricing reset feature associated with the July 2009 Warrants. As of September 30, 2009, none of the July 2009 Warrants had been exercised.

October 2009 Warrants

On October 22, 2009, we completed our registered offering in which we sold an aggregate of 3,201,526 Units to certain of the LOC Lenders in connection with the settlement of $5.4 million of the outstanding Unsecured Line of Credit. Each unit consisted of one share of our common stock, and one warrant to purchase 0.50 share of our common stock pursuant to a Warrant to Purchase Common Stock. The October 2009 Warrants have an exercise price of $1.61 per share and expire on October 19, 2019.

There is no anti-dilution or pricing reset feature associated with the October 2009 Warrants.

The following table summarizes the warrants outstanding and exercisable at September 30, 2009:


	Series B Warrants		Contractor Warrants		Contingent Warrants
Grant dates		September 2004		Oct. 2007-Mar. 2009		January 2008
Exercise price	$	3.53	$	5.35 -12.06	$	11.65 -14.69
Expiration date		October 5, 2009		Oct. 2011-Mar. 2014		January 15, 2015
Warrants outstanding		25,243		137,603		3,700,000
Warrants exercisable		25,243		137,603		1,350,000
Proceeds if exercised	$	89,108	$	836,826	$	15,727,500

	Contingent Contractor Warrants		Fletcher Warrants		Line of Credit Warrants
Grant dates		April 2009		November 2008		January 2009
Exercise price	$	4.00	$	3.99 to 2.85	$	6.00
Expiration date		April 6, 2014		November 14, 2018		January 27, 2019
Warrants outstanding		50,000		7,012,631		1,755,048
Warrants exercisable		0		7,012,631		1,755,048
Proceeds if exercised	$	0	$	20,000,000	$	10,530,288

	July 2009 Warrants
Grant dates		July 2009
Exercise price	$	4.62
Expiration date		July 6, 2014
Warrants outstanding		4,275,170
Warrants exercisable		4,275,170
Proceeds if exercised	$	19,751,285

The Series B Warrants expired unexercised on October 5, 2009.

E. Contingencies and Commitments

Guarantees

On August 31 2008, we finalized the project financing arrangements for the Thermo No. 1 project and entered into and entered into various definitive agreements (the “Thermo Financing Agreements”). The Thermo Financing Agreements included an equity capital contribution agreement (the “ECCA”) between Thermo No. 1 BE-01, LLC (“Thermo Subsidiary”) and Merrill Lynch LP. Holdings, Inc., the minority member of the Thermo Subsidiary (the “Class A Member”). Pursuant to the ECCA, our Thermo

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

Subsidiary agreed to fund any drilling costs in excess of the original drilling account escrow of $5.7 million established to complete the well field drilling of the Thermo No. 1 project (the “Drilling Escrow Top Up”). Through September 30, 2009, we have contributed an additional $16.3 million to the drilling account escrow for completion of the well field.

The Thermo Financing Agreements include a guaranty agreement dated August 31, 2008 among our Thermo Subsidiary, the Class A Member, and us (the “Guaranty Agreement”). Under the Guaranty Agreement, we guarantee the full payment of the Drilling Escrow Top Up. Our liability under the Guaranty Agreement will continue until the guaranteed obligation is satisfied in full. We expect to complete our well drilling at the Thermo No. 1 project during the fourth quarter of 2009; however, the maximum potential future payments may be unlimited if our wells cannot produce sufficient resource (both heat and flow) so that the Thermo No. 1 geothermal power plant can achieve the designated level of electricity generation.

The Thermo Financing Agreements also include an engineering, procurement and construction agreement (the “EPC Agreement”) with our Thermo Subsidiary. Pursuant to the EPC Agreement, we agreed to oversee the engineering, procurement and construction of the geothermal power plant for the Thermo No. 1 project. In addition, we guaranteed the completion of the geothermal power plant construction and the payment of all services performed by the subcontractors. We expect to make the payments to the subcontractors, including cost overruns, if any, in the ordinary course of business. All intercompany transactions related to the EPC Agreement are eliminated in consolidation of the financial statements. Our liability under this agreement will continue until the guaranteed obligation is satisfied in full. We expect to complete our construction phase at the Thermo No. 1 project during the fourth quarter of 2009.

In connection with the Thermo Financing Agreements, we also entered into an amended and restated purchase contract (the “Amended and Restated Purchase Contract”) with UTC Power (“UTCP”) relating to the purchase of generating units for the Thermo No. 1 project. The agreements relating to the purchase of the power generating units have since been assigned from UTCP to Pratt & Whitney Power Systems (“PWPS”). Under the terms of the Amended and Restated Purchase Contract, PWPS is required to allow us to retain a certain portion of the purchase price of the generating units pending the successful completion of the Thermo No. 1 project. If the Thermo No. 1 project is not successfully completed as a result of a problem with the generating units, then we will keep the retained portion of the purchase price as a liquidated damages payment. If the Thermo No. 1 project is not successfully completed as a result of any other reason, we will reimburse PWPS for any liquidated damages paid by PWPS. To secure payment of our obligations to reimburse PWPS under the Amended and Restated Purchase Contract, we provided a security interest to PWPS in five patents relating to our Transportation & Industrial segment. We believe that the likelihood that we will be obligated to reimburse PWPS for liquidated damages under the Amended and Restated Purchase Contract is “remote.” Accordingly, we estimate the maximum potential obligation and the related fair value of the obligation under the Amended and Restated Purchase Contract to be immaterial at this time. Therefore, no liability was recorded at September 30, 2009.

The Thermo Financing Agreements also contain a conditional redemption provision whereby the Thermo No. 1 geothermal power plant must achieve “Final Completion” as defined in the Thermo Financing Agreements, by June 15, 2009. We have, however, extended the deadline several times. We are working with the debt holder and the Class A Member of the Thermo No. 1 plant to restructure the tax equity ownership of the Thermo Subsidiary in an attempt to obtain certain benefits under the Recovery Act, which could include grants from the United States Treasury Department of up to 30% of the cost of construction and certain drilling costs for the Thermo plant in lieu of receiving production tax credits for the production of electricity. As part of these restructuring discussions, we intend to seek to extend the deadline for Final Completion or otherwise renegotiate the applicability of the additional penalties. The current deadline is November 30, 2009. Final Completion is achieved when the facility successfully completes a 10-day production test to verify its operating capacity. If the Thermo No. 1 geothermal power plant fails to achieve certain levels of production, either the Class A Member or the debt holder could exercise its rights to require us to make a buy-down payment to the debt holder and the Class A Member. The buy-down payment is based upon a calculation that effectively gives the debt holder and the Class A Member the same economic return as if the facility were operating at full capacity. Any amounts payable under the buy-down provision to the debt holder or the Class A Member would be disbursed from cash in an escrowed account maintained at our Thermo Subsidiary totaling $2.9 million and amounts held back from the purchase price of the PWPS generating units under the terms of the Amended and Restated Purchase Contract between the Thermo Subsidiary and PWPS totaling $4.3 million and any amounts expected to be received from the United States Treasury Department grants under the Recovery Act. We expect the grant to be in the range of $30 – 34 million.

As part of the grant application process, we will provide a certificate from an independent accountant which will certify the qualified expenses incurred on the project. We have completed our review of the project expenses and preparation of this certificate is nearly complete. We will also submit a certificate from an independent engineer that describes that the project was placed in service in 2009. Preparation of this certificate is also underway. Once these final certificates are ready, and the restructuring is complete, we will submit the grant application. The United States Department of Treasury must fund the grant within 60 days of when an application is deemed complete. To date, many of these United States Department of Treasury grants have been funded in less than the mandatory 60 days and we are hopeful that they will do the same with our application.

If the buy-down payment is greater than these amounts, we would have to make up the difference out of general corporate funds. During November of 2009, management assessed the likelihood of successfully achieving Final Completion by November 30, 2009 and determined that it is probable that the Thermo No. 1 plant will not achieve Final Completion by November 30, 2009. This assessment is based upon delays we have experienced in completing drilling and other related items. The transaction documents provide for various payments in penalties in the event that Final Completion is not achieved by November 30, 2009. As part of the broader restructuring, however, we expect to further extend the November 30, 2009 date until the 1st quarter of 2010.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

We estimate that the failure to achieve Final Completion by November 30, 2009, would result in additional penalties of between $2.0 million to $3.0 million. However, we are working with the debt holder and the Class A Member to restructure the tax equity ownership of the Thermo Subsidiary in an attempt to obtain certain benefits under the Recovery Act, which could include grants from the United States Treasury Department of up to 30% of the cost of construction and certain drilling costs for the Thermo plant in lieu of receiving production tax credits for the production of electricity. As part of these restructuring discussions, we intend to seek to extend the deadline for Final Completion or otherwise renegotiate the applicability of the additional penalties. Given our past history and positive working relationship with the debt holders and the Class A Member, we believe that the likelihood of incurring additional penalties is only “reasonably possible” and not “probable” as defined by ASC Subtopic 450-20 “Contingencies-Loss Contingencies”. Accordingly, no liability was recorded relating to the estimated penalties at September 30, 2009. We cannot be certain, however, that we will be able to restructure the tax equity ownership of the Thermo Subsidiary in a manner that allows us to avoid incurring these penalties.

As of September 30, 2009, we did not have any letters of credit or repurchase obligations.

Legal Proceedings

On August 17, 2009, Kay Mendenhall (“Mendenhall”), an individual, and Spindyne, Inc. (“Spindyne”), a Utah corporation, filed a complaint in Fourth Judicial District Court, Utah County, Utah against Jack H. Kerlin, an individual, Kraig Higginson, an individual, and Raser Technologies, Inc. Mendenhall and Spindyne allege that, around the time that Raser was formed, Kerlin, on behalf of Spindyne, assigned to Raser the rights to use certain proprietary technology that was owned by Spindyne. Mendenhall and Spindyne allege that they were not properly compensated for that technology. In general, the complaint alleges, among other claims, breach of contract, breach of implied covenant of good faith and fair dealing, and intentional interference with contract and prospective economic relations. The complaint seeks damages in an amount to be determined at trial for the value of the alleged technology. Neither Spindyne nor Mendenhall have any relationship with us or Mr. Higginson, our Chairman. The alleged technology at issue in the complaint is not currently in use and has never been used by us or Mr. Higginson. We believe the complaint to be completely without merit and are vigorously defending it.

On May 26, 2009, Bakersfield Pipe and Supply, Inc. (“Bakersfield”) filed a complaint in Fifth Judicial District Court, Beaver County, Utah against Thermo No. 1 BE-01, LLC, Intermountain Renewable Power, LLC and Raser Technologies, Inc., alleging breach of contract and attempting to foreclose on a mechanic’s lien. The complaint seeks monetary damages of approximately $1.07 million plus interest and fees. We have accrued for these amounts and are in final stages of settlement negotiations with Bakersfield.

Contingently Vesting Warrants

See discussion of Contingent Warrants in Note D. Warrants.

F. Non-controlling Interest

On August 31, 2008 and in conjunction with the Thermo No. 1 project financing, our Thermo Subsidiary issued new member units to the Class A Member, which contributed $24.5 million in exchange for an equity interest. We received $3.7 million of the total contribution on September 8, 2008 and the remaining balance of $20.8 million was received on October 20, 2008.

The Thermo Financing Agreements provide for the allocation of 99% of profits and losses to the Class A Member until the Class A Member earns a target internal rate of return of 15%. 100% of the intangible drilling costs are allocated directly to us. Upon reaching the target internal rate of return, the Class A Member’s allocation of profits and losses will automatically be reduced to 5.00%.

Because we maintain a 75% voting interest in the Thermo Subsidiary, we will continue to consolidate 100% of the assets and liabilities of the Thermo Subsidiary. The Class A Member’s interest in the Thermo Subsidiary is reflected as “Non-controlling interest” in our consolidated balance sheet and statement of operations.

The Thermo Financing Agreements also contain certain complex liquidation preference provisions that require certain distributions to each of the members of the Thermo Subsidiary in the event of a liquidation. According to the Thermo Financing Agreements, upon liquidation of the Thermo Subsidiary and after payment of all outstanding debt, any remaining funds would be distributed in the following manner: (i) first, to both the Class A Member and the Company in the amount of the agreed upon initial capital contributions for tax purposes, (ii) second, to the Class A Member so that any shortfall in achieving its target internal rate of return of 15% would be achieved, and (iii) third, to both the Class A Member and the Company with an allocation of 5% to the Class A Member and 95% to the Company. To determine the non-controlling interest, we utilize a hypothetical liquidation at book value methodology at each balance sheet date. For the period ending March 31, 2009, we modified our hypothetical liquidation at book value methodology to include the recast-financial-statements approach. Under the hypothetical liquidation methodology, we utilize the recast-financial-statements approach which captures the initial relevant fair values of the assets and liabilities and follows generally accepted accounting principles for any additional transactions. We believe that the recast-financial-statements approach closely reflects the Class A Member’s claim on the Thermo Subsidiary’s book value at each balance sheet date because the tax equity financing documents with the Class A Member contain a liquidation preference. According to the recast-financial-statements approach, upon the initial sale of the membership interests, the assets and liabilities are hypothetically liquidated at the recast book value at the end of each period and the portions of the Class A Member’s claim relating to liquidation preferences are recorded as gains or losses. Because we have modified our hypothetical liquidation at book value methodology for the period ended March 31, 2009, certain differences result in the “Non-controlling interest” balance at March 31, 2009 as compared to the balance at December 31, 2008 and September 30, 2008. We treated these differences as a correction of an error in the first quarter of 2009. Based on our projected results for 2009, we do not believe that the correction of the error from the first quarter of 2009 will be material to our overall results for 2009. We will continue to monitor the materiality of this correction of an error through the fourth quarter of 2009.

Effective January 1, 2009, we adopted a new accounting pronouncement whereby the FASB established accounting and reporting standards that require non-controlling interests to be reported as a component of equity. Changes in a parent’s ownership interest while the parent retains its controlling interest are to be accounted for as equity transactions. Operating gains or losses attributable to non-controlling interests are excluded from the net profit and loss calculation but included in the earnings and loss per share computations.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

Non-controlling interest totaled $27.9 million and $28.0 million at September 30, 2009 and December 31, 2008, respectively. Changes in non-controlling interest during the nine months ended September 30, 2009 are set forth below:


Non-controlling Interest	Quarter ended September 30, 2009
Balance at January 1, 2009	$	28,025,116
Correction of error from prior period		(2,079,402	)
Increase in non-controlling interest from operating losses and liquidation preferences		819,470
Increase in non-controlling interest from additional parent capital contributions		65,576

Balance at March 31, 2009	$	26,830,760
Non-controlling interest from operations and liquidation preferences		204,960
Non-controlling interest from additional parent capital contributions		100,050

Balance at June 30, 2009	$	27,135,770
Non-controlling interest from operations and liquidation preferences		332,458
Non-controlling interest from additional parent capital contributions		382,028

Balance at September 30, 2009	$	27,850,256

From time to time, we are required to pay operating expenses on behalf of the Thermo Subsidiary, which result in decreases to the non-controlling interest. The payment of these operating expenses on behalf of the Thermo Subsidiary is not reimbursable to us under the Thermo Subsidiary operating agreements.

In accordance with the FASB Accounting Standards Codification, we classified “Non-controlling interest” outside of permanent equity because the Thermo Financing Agreements contain a conditional redemption provision that is based upon the occurrence of an event that is not solely within our control (see Note E. “Contingencies and Commitments” above). Upon satisfaction of the conditional redemption provision, the “Non-controlling interest” will be classified as permanent equity.

G. Common Stock

2009 Registered Direct Offering

On June 30, 2009, we entered into a Placement Agent Agreement (the “Placement Agent Agreement”) in which Calyon Securities (USA) Inc., RBC Capital Markets Corporation and JMP Securities LLC served as placement agents relating to a registered direct offering by us of up to an aggregate of 8,550,339 units (“Units”) primarily to institutional investors. Each Unit consists of one share of our common stock, and one warrant to purchase 0.50 share of the Common Stock pursuant to a Warrant to Purchase Common Stock. The sale of the Units was made pursuant to Subscription Agreements, dated June 30, 2009 (the “Subscription Agreements”), with each of the investors. The per share exercise price of the July 2009 Warrants is $4.62 (see Note D. Warrants for further discussion of the July 2009 Warrants).

The investors purchased the Units for a negotiated price of $2.98 per Unit, resulting in gross proceeds to us of approximately $25.5 million, before deducting placement agents’ fees and offering expenses totaling $1.7 million. We closed the registered direct offering on July 6, 2009 and received the net offering proceeds from the sale of the Units, after deducting the placement agents’ fees and other offering expenses totaling approximately $23.8 million.

Stock-Based Compensation Plans

Options and warrants granted to employees and contractors are valued by applying the fair value based method to stock-based compensation in each period utilizing the Black-Scholes option pricing model, a generally accepted valuation model for determining the fair value of options. The maximum term of each option is ten years. With respect to stock options granted and warrants issued during the nine months ended September 30, 2009 and 2008, the assumptions used in the Black-Scholes option-pricing model computations were as follows:


	Three months ended September 30,				Nine months ended September 30,
	2009		2008		2009		2008
Risk-free interest rate	3.01	%	2.71 – 3.66	%	1.76 – 3.01	%	2.67 – 3.66	%
Expected dividend yield	0.0	%	0.0	%	0.0	%	0.0	%
Volatility	106	%	98 – 99	%	106	%	98 – 99	%
Expected exercise life (in years)	6.5		6.0		6.5		6.0

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

The risk-free interest rate is based on a yield curve of interest rates at the time of the grant based on the contractual life of the option. Expected dividend yield is based on our dividend history and anticipated dividend policy. Expected volatility is based on historical volatility for our common stock. Expected exercise life is based on management estimates of future attrition and early exercise rates, giving consideration to employee exercise behavior since filing of our initial S-8 registration statement for our Amended and Restated 2004 Long Term Incentive Plan on March 3, 2005.

Third Party Share Grants

During the nine months ended September 30, 2009, in settlement of an outstanding promissory note and outstanding payables to various vendors, we issued 142,013 restricted shares and 3,278,748 unrestricted shares of our common stock to settle outstanding debt totaling $9,269,800. As a result, we incurred a gain on the extinguishment of debt totaling $68,588.

Contingent and Non-contingent Warrants Issued

See discussion of contingently vesting warrants and non-contingently vesting warrants issued during 2009 and 2008 in Note D. “Warrants” above.

The activity for stock options and warrants during the nine months ended September 30, 2009 is summarized as follows:


	Number of Options and Warrants		Weighted Average Exercise Price		Aggregate Intrinsic Value
Outstanding at January 1, 2009:	14,552,558		$	8.57
Granted	1,326,475			5.80
Exercised	—			—
Expired or forfeited	(50,850	)		7.63

Outstanding at March 31, 2009:	15,828,183		$	6.77	$	4,872,767
Granted	676,176			3.61
Exercised	—			—
Expired or forfeited	(183,375	)		11.91

Outstanding at June 30, 2009:	16,320,984		$	6.63	$	895,024
Granted	4,285,170			4.62
Exercised	—			—
Reduction in Maximum Fletcher Warrants	(445,901	)		2.85
Expired or forfeited	(375,875	)		10.25

Outstanding at September 30, 2009:	19,784,378		$	6.00	$	—

Exercisable at March 31, 2009:	12,036,478		$	5.01	$	4,807,347

Exercisable at June 30, 2009:	12,759,413		$	5.08	$	895,024

Exercisable at September 30, 2009:	16,634,369		$	4.99	$	—

The following tables summarize certain stock option and warrant information at September 30, 2009:

Outstanding Options and Warrants Fully Vested and/or Expected to Vest


Range of exercise price	Number	Weighted average contractual life	Weighted average exercise price		Intrinsic value
$ 2.28 – $5.75	12,769,747	7.23	$	3.60	$	—
$ 6.00 – $11.00	2,767,948	8.62		6.82		—
$ 11.01 – $17.20	4,213,350	5.47		12.55		—
$25.95	33,333	5.55		25.95		—

Total	19,784,378	7.05	$	6.00	$	—

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

Outstanding Options and Warrants Fully Vested and Exercisable


Range of exercise price	Number	Weighted average contractual life	Weighted average exercise price		Intrinsic value
$ 2.28 – $5.75	12,475,838	8.54	$	3.59	$	—
$ 6.00 – $11.00	2,345,098	8.77		6.55		—
$ 11.01 – $17.20	1,780,100	5.58		12.42		—
$25.95	33,333	5.55		25.95		—

Total	16,634,369	8.15	$	4.99	$	—

The following table summarizes the non-vested stock options at September 30, 2009:

Non-Vested Option Grants


	Number of Options		Weighted average per option fair market value
Non-vested at January 1, 2009	1,624,204		$	7.34
Granted	63,000			2.53
Vested	(194,649	)		5.94
Forfeited	(50,850	)		6.19

Non-vested at March 31, 2009:	1,441,705		$	7.36
Granted	12,000			3.41
Vested	(108,759	)		7.95
Forfeited	(183,375	)		9.88

Non-vested at June 30, 2009:	1,161,571		$	6.87
Granted	10,000			1.91
Vested	(45,686	)		6.82
Forfeited	(375,875	)		8.15

Non-vested at September 30, 2009:	750,010		$	6.16

The following table summarizes the non-vested stock awards at September 30, 2009:

Non-Vested Share Awards


	Number of Shares		Weighted average per share fair market value
Outstanding at January 1, 2009:	30,084		$	10.07
Granted	1,712,956			3.10
Vested	(1,336,264	)		3.24
Forfeited	(500	)		6.60

Outstanding at March 31, 2009:	406,276		$	3.18
Granted	408,681			3.89
Vested	(684,957	)		3.51
Forfeited	—			—

Outstanding at June 30, 2009:	130,000		$	3.66
Granted	1,483,705			2.05
Vested	(1,483,705	)		2.05
Forfeited	—			—

Outstanding at September 30, 2009:	130,000		$	3.66

On August 5, 2009, Brent Cook resigned as our Chief Executive Officer. As part of his final compensation agreement, Mr. Cook is entitled to receive a number of unrestricted shares of our common stock on January 4, 2010 based upon a predetermined formula. The number of shares will be computed based upon the aggregate fair market value of $145,833 divided by a 30-day volume weighted average price effective December 31, 2009.

As of September 30, 2009, we had $7,363,208 of unrecognized compensation expense related to non-vested stock option grants and $356,850 of unrecognized compensation expense related to non-vested stock award grants. These expenses are expected to be recognized over a weighted average period of 1.73 years. As of September 30, 2009, the following table summarizes the unrecognized compensation expense expected to be recognized in future periods.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)


	Stock-based compensation expense (pre-tax)
Remainder of 2009:	$	1,017,663
2010		3,532,888
2011		1,633,827
2012		1,177,166
2013		346,752
2014		11,762

Total:	$	7,720,058

H. Net Loss Per Common Share

The following table sets forth the number of shares that would be outstanding if outstanding securities convertible into common stock were converted into common stock, whether the convertible securities were “in the money” or “out of the money” based upon the closing market price on September 30, 2009:


	“In the Money”	“Out of the Money”
Warrants granted	—	16,955,696
Vested employee options	—	2,078,673
Unvested employee options	—	570,010
Vested contractor options	—	85,000
Unvested contractor options	—	95,000


	“In the Money”	“Out of the Money”
Warrants granted	25,243	3,715,000
Vested employee options	1,023,800	503,408
Unvested employee options	704,650	922,925
Vested contractor options	75,000	35,000

Unvested stock grants totaling 130,000 and 30,750 were outstanding on September 30, 2009 and 2008, respectively. Since these shares were granted to employees and Board of Directors, and fully vest upon a “change in control” as defined by the share grant agreements, they were included in the net loss per share computation. These warrants and options were not included in the calculation of diluted net loss per share because their effect was anti-dilutive. Our common stock underlying the call spread option transaction and forward stock purchase transaction would be recorded as treasury stock when delivered and; therefore, would be excluded from the calculation of diluted net loss per share because their effect is anti-dilutive.

I. Fair Value Measurements

Effective January 1, 2008, we adopted the new accounting guidance relating to fair value measurements as required by the Fair Value Measurement Topic of the FASB Accounting Standards Codification, for financial instruments measured at fair value on a recurring basis. The new accounting guidance defines fair value, establishes a framework for measuring fair value in accordance with accounting principles generally accepted in the United States and expands disclosures about fair value measurements.

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Accounting Standards Codification Topic 820 establishes a three-tier fair value hierarchy which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurements) and the lowest priority to unobservable inputs (level 3 measurements). These tiers include:

•

Level 1, defined as observable inputs such as quoted prices for identical instruments in active markets;

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

•

Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable such as quoted prices for similar instruments in active markets or quoted prices for identical or similar instruments in markets that are not active; and

•

Level 3, defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions, such as valuations derived from valuation techniques in which one or more significant inputs or significant value drivers are unobservable.

Warrants

Effective January 1, 2009, we adopted the new accounting guidance relating to determining whether a financial instrument is indexed to its own stock as required by the Derivatives and Hedging Topic of the FASB Accounting Standards Codification. The adoption of the new accounting guidance can affect the accounting for warrants and many convertible instruments with provisions that protect holders from a decline in the stock price (“down round” provisions). For example, warrants with such provisions will no longer be recorded in equity. Down round provisions reduce the exercise price of a warrant or convertible instrument if a company either issues equity shares for a price that is lower than the exercise price of those instruments or issues new warrants or convertible instruments that have a lower exercise price. We evaluated whether warrants to acquire shares of our common stock contain provisions that protect holders from declines in the stock price or otherwise could result in modification of the exercise price and/or shares to be issued under the respective warrant agreements based on a variable that is not an input to the fair value of a “fixed-for-fixed” option. Accordingly, we determined that the following warrants contained such provisions, thereby concluding they were not indexed to our common stock:

•

Series B Warrants, exercisable for 25,243 shares of our common stock, that expired unexercised on October 5, 2009

•

Contingent Warrants issued to Merrill Lynch, exercisable for 1,350,000 shares of our common stock, that expire January 16, 2015

•

Fletcher Warrants to acquire shares of our common stock in an aggregate value of up to $20.0 million that may not exceed 7,012,631 shares of our common stock, exercisable at September 30, 2009 for 7,012,631 shares of our common stock, that expire November 14, 2018.

For further discussion of these financial instruments, refer to Note D. “Warrants” and Note G. “Common Stock.”

Beginning January 1, 2009, we recognized these warrants as liabilities at their respective fair values on each reporting date. The cumulative effect of the change in accounting for these warrants of $7.2 million was recognized as an adjustment to the opening balance of accumulated deficit at January 1, 2009. The cumulative effect adjustment was the difference between the amounts recognized in the consolidated balance sheet before January 1, 2009 and the amounts recognized in the consolidated balance sheet after January 1, 2009. The amounts recognized in the consolidated balance sheet on January 1, 2009 were determined based on the amounts that would have been recognized if the change had been applied from the issuance date of the warrants. We measured the fair value of these warrants as of March 31, 2009, and recorded a $0.9 million loss on derivatives and recorded the liabilities associated with these warrants at their respective fair values as of March 31, 2009. For the quarter ended June 30, 2009, we measured the fair value of these warrants as of June 30, 2009, and recorded a $7.9 million gain on derivatives. We also recorded the liabilities associated with these warrants at their respective fair values as of June 30, 2009. We also measured the fair value of these warrants as of September 30, 2009, and recorded a $5.9 million gain on derivatives for the quarter ended September 30, 2009 and recorded the liabilities associated with these warrants at their respective fair values as of September 30, 2009. We determined the fair values of these securities using the Binomial Lattice and Black Scholes valuation models when appropriate.

We measure certain financial instruments at fair value on a recurring basis. Financial assets measured at fair value on a recurring basis are as follows at September 30, 2009:


	Level 1		Level 2		Level 3		Total
Cash and cash equivalents	$	3,817,632	$	0	$	0	$	3,817,632
Restricted cash		12,387,611		76,921		0		12,464,532

Total assets	$	16,205,243	$	76,921	$	0	$	16,282,164

Series B Warrants	$	0	$	0	$	0	$	0
Merrill Lynch 2008 Contingent Warrants		0		0		1,013,710		1,013,710
Fletcher Warrants		0		0		13,240,549		13,240,549

Total liabilities	$	0	$	0	$	14,254,259	$	14,254,259

Cash and cash equivalents and restricted cash measured using Level 1 inputs consist primarily of money market accounts that are traded on active exchange markets. Valuations are obtained from readily available pricing sources for market transactions involving identical instruments.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

Restricted cash measured using Level 2 inputs consist of certificates of deposit. Valuations are generally obtained from third party pricing services for or comparable instruments (and validated through back testing to trade data or confirmation that the pricing service’s significant inputs are observable) or determined through use of valuation methodologies using observable market inputs such as market interest rates.

We determined the fair value of the Contingent Warrants and the Fletcher Warrants using a Binomial Lattice valuation model that considered their down round provisions that reduce the exercise price if we issues new warrants or equity at a lower price. The model considered the historical volatility of our stock price. See discussion of variable inputs to the valuations of these warrants in Note D. “Warrants” above.

Recurring Level 3 Activity, Reconciliation and Basis for Valuation

The table below provides a reconciliation of the beginning and ending balances for the major classes of assets and liabilities measured at fair value using significant unobservable inputs (Level 3). The table reflects gains and losses for the quarter for all financial assets and liabilities categorized as Level 3 as of September 30, 2009.

Fair Value Measurements Using Significant Unobservable Inputs (Level 3) (in thousands):


	Total
Assets:
Balance as of January 1, 2009	$	—
Total realized and unrealized gains (losses)		—

Balance as of March 31, 2009	$	—
Total realized and unrealized gains (losses)		—

Balance as of June 30, 2009	$	—
Total realized and unrealized gains (losses)		—

Balance as of September 30, 2009	$	—
Liabilities:
Balance as of January 1, 2009	$	27,171,713
Increase in fair value of derivative warrants (unrealized gain)		942,839

Balance as of March 31, 2009	$	28,114,552
Decrease in fair value of derivative warrants (unrealized loss)		(7,942,193	)

Balance as of June 30, 2009	$	20,172,359
Decrease in fair value of derivative warrants (unrealized loss)		(5,918,100	)

Balance as of September 30, 2009	$	14,254,259

The carrying amounts reported in the accompanying consolidated financial statements for cash and cash equivalents, accounts receivable, notes receivable, interest receivable, accounts payable and accrued liabilities approximate fair values because of the immediate or short-term maturities of these financial instruments.

The carrying value and estimated fair value of our debt instruments at September 30, 2009 were as follows:


	September 30, 2009
	Estimated Fair Value		Carrying Value
Short-term 10.0% amended unsecured line of credit*	$	10,673,800	$	10,673,852
Long-term 9.5% senior secured note**		26,470,000		30,326,240
Long-term 8.0% convertible senior notes		29,150,000		57,197,726

Total liabilities	$	66,293,800	$	98,197,818

Due to the original issue discount, cash proceeds of debt are less than the face value of the debt. Therefore, the effective interest rate of 9.5% is greater than the 7.0% stated rate.

*	Represents face value of debt without consideration of the deferred financing costs of $462,403 as of September 30, 2009.

**	Represents face value of debt without consideration of the original issue discount of $4,575,832 as of September 30, 2009.

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

J. Business Segments

The basis for presenting segment information results generally is consistent with our overall operating practices. We report operating segment information as required by the Business Segment Topic of the FASB Accounting Standards Codification, which establishes reporting standards for disclosure of operating segments. All consolidating items and corporate administrative costs are included in Corporate and Other.

Accordingly, the presentation below comprises financial information relating to our segments for the three and nine months ended September 30, 2009 and 2008, respectively:


As of and for the Three Months Ended September 30, 2009	Transportation & Industrial			Power Systems			Corporate and Other			Total
Revenues	$	—		$	845,265		$	—		$	845,265
Segment Operating Loss		(399,774	)		(3,286,362	)		(2,317,395	)		(6,003,531	)
Depreciation, Amortization and Accretion		39,906			801,822			22,386			864,114
Interest Expense		—			759,060			2,722,105			3,481,165
Fixed Asset Purchases		—			21,565			—			21,565
Geothermal Well Field Drilling Purchases		—			4,119,709			—			4,119,709
Power Project Construction Purchases		—			4,127,302			—			4,127,302
Total Assets	$	497,397		$	147,098,519		$	10,562,731		$	158,158,647

As of and for the Three Months Ended September 30, 2008	Transportation & Industrial			Power Systems			Corporate and Other			Total
Revenues	$	—		$	30,000		$	—		$	30,000
Segment Operating Loss		(978,844	)		(3,202,729	)		(2,439,959	)		(6,621,532	)
Depreciation, Amortization and Accretion		52,018			5,427			17,483			74,928
Interest Expense		—			161,091			916,604			1,077,695
Fixed Asset Purchases		11,226			—			30,848			42,074
Geothermal Well Field Drilling Purchases		—			14,860,086			—			14,860,086
Power Project Construction-in-Progress Purchases		—			29,605,575			—			29,605,575
Total Assets	$	700,057		$	114,109,968		$	23,792,548		$	138,602,573

As of and for the Nine Months Ended September 30, 2009	Transportation & Industrial			Power Systems			Corporate and Other			Total
Revenues	$	—		$	1,252,506		$	—		$	1,252,506
Segment Operating Loss		(1,711,832	)		(9,985,920	)		(7,514,235	)		(19,211,987	)
Depreciation, Amortization and Accretion		144,872			1,635,841			68,736			1,849,449
Interest Expense		—			1,925,406			6,788,704			8,714,110
Fixed Asset Purchases		—			262,118			73,686			335,804
Geothermal Well Field Drilling Purchases		—			11,887,887			—			11,887,887
Power Project Construction-in-Progress Purchases		—			11,984,002			—			11,984,002
Total Assets	$	497,397		$	147,098,519		$	10,562,731		$	158,158,647

As of and for the Nine Months Ended September 30, 2008	Transportation & Industrial			Power Systems			Corporate and Other			Total
Revenues	$	136,423		$	30,000		$	—		$	166,423
Segment Operating Loss		(3,095,230	)		(8,091,820	)		(7,429,889	)		(18,616,939	)
Depreciation, Amortization and Accretion		147,069			15,417			62,479			224,965
Interest Expense		—			181,924			1,999,052			2,180,976
Fixed Asset Purchases		82,510			23,522			74,647			180,679
Geothermal Well Field Drilling Purchases		—			30,117,913			—			30,117,913
Power Project Construction-in-Progress Purchases		—			48,640,710			—			48,640,743
Total Assets	$	700,057		$	114,109,968		$	23,792,548		$	138,602,573

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

K. Supplemental Cash Information

For the nine months ended September 30, 2009

•

We paid $3,807,734 for interest and $400 for income taxes.

•

We recorded five non-cash payments totaling $40,000 for 11,035 shares of our common stock issued to settle outstanding invoices from two service providers for consulting relating to our PHEV project. The non-cash payments were equal to the fair market value of the shares on the date the shares were granted.

•

We recorded a $150,000 non-cash payment for 34,483 shares of our common stock issued to settle an outstanding invoice from a service provider for construction of our Thermo No. 1 geothermal power plant. The non-cash payment was equal to the fair market value of the shares on the date the shares were granted.

•

We recorded a $2,000,000 non-cash payment for 574,713 shares of our common stock issued to settle an outstanding invoice from a service provider for construction of our Thermo No. 1 geothermal power plant. The non-cash payment approximated the fair market value of the shares on the date the shares were granted.

•

We recorded a $950,000 non-cash payment for 263,108 shares of our common stock issued to settle a promissory note with a former merger candidate that was settled on January 27, 2009. The non-cash payment resulted in a gain on extinguishment of debt totaling $68,588.

•

We recorded five non-cash payments totaling $3,500,000 for 70,197 restricted shares of our common stock, 1,004,094 unrestricted shares of our common stock, and 122,603 warrants to acquire shares of our common stock issued to settle an outstanding invoice from a service provider for construction of our Thermo No. 1 geothermal power plant. The non-cash payment approximated the fair market value of the shares on the date the shares were granted.

•

We recorded two non-cash payments totaling $96,900 for 20,000 restricted shares of our common stock and 31,246 unrestricted shares of our common stock issued to settle outstanding invoices from two service providers for consulting relating to our investor relations and expansion of our geothermal operations. The non-cash payment approximated the fair market value of the shares on the date the shares were granted.

•

We recorded eighteen non-cash payments totaling $2,930,200 for 1,425,894 shares of our common stock to settle outstanding invoices from the service providers for construction of our Thermo No. 1 geothermal power plant. The non-cash payments approximated the fair market value of the shares on the date the shares were granted.

For the nine months ended September 30, 2008:

•

No cash was paid for interest and $400 was paid for income taxes.

•

We recorded in accrued liabilities certain capitalized well field development expenditures that were not paid as of September 30, 2008. These accrued capitalized costs included both tangible and intangible drilling costs and were omitted from the statement of cash flows as non-cash items totaling $5,987,546.

•

We recorded in accrued liabilities and accounts payable certain capitalized power systems equipment and contractor fees that were not paid as of September 30, 2008. These accrued expenses included equipment such as pumps, cooling towers, generating units and related construction costs for a geothermal power plant under construction. These accrued capitalized costs were omitted from the statement of cash flows as non-cash items totaling $24,504,780.

•

We recorded a $450,000 non-cash payment for 45,732 shares of our common stock issued to settle an outstanding invoice from a service provider for design and engineering services relating to construction of a geothermal power plant. The non-cash payment was equal to the fair market value of the shares on the date the shares were granted.

•

We recorded a $419,000 non-cash payment for 100,000 shares of our common stock issued to settle a portion of an outstanding invoice from a service provider for design and engineering services relating to construction of a geothermal power plant. The non-cash payment was equal to the fair market value of the shares on the date the shares were granted.

•

We recorded a $318,814 non-cash payment for 22,217 shares of our common stock issued to settle an outstanding invoice from a service provider for design and engineering services relating to construction of a geothermal power plant. The non-cash payment was equal to the fair market value of the shares on the date the shares were granted.

•

We recorded a $51,158 non-cash payment for 3,565 shares of our common stock issued to settle an outstanding invoice for professional services related to obtaining the proper permits that enable us to drill for geothermal resources. The non-cash payment was equal to the fair market value of the shares on the date the shares were granted.

•

We recorded a $9,930 non-cash payment for 1,000 shares of our restricted common stock issued to acquire geothermal mineral rights on properties in Nevada. The non-cash payment was equal to the fair market value of the shares on the date the 10-year geothermal leases were signed.

L. Recently Issued Accounting Pronouncements

In July 2009, the Financial Accounting Standards Board (“FASB”) established the FASB Accounting Standards Codification (“ASC”) as the source of authoritative accounting principles recognized by the FASB to be applied by nongovernmental entities in the preparation of financial statements in conformity with GAAP. Rules and interpretive releases of the Securities and Exchange

RASER TECHNOLOGIES, INC. AND SUBSIDIARIES

Notes to Condensed Consolidated Financial Statements—(Continued)

(Unaudited)

Commission (“SEC”) under authority of federal securities laws are also sources of authoritative GAAP for SEC registrants. The ASC supersedes all existing non-SEC accounting and reporting standards and is not intended to change GAAP. The use of the ASC was effective for financial statements issued for periods ending after September 15, 2009. We implemented this guidance on July 1, 2009, and it had no material impact on our financial condition, results of operations, or cash flows.

In July 2009, the FASB issued new accounting guidance to improve financial reporting by enterprises involved with variable interest entities and to provide more relevant and reliable information to users of financial statements. This new accounting guidance is effective as of the beginning of each reporting entity’s first annual reporting period that begins after November 15, 2009, for interim periods within that first annual reporting period, and for interim and annual reporting periods thereafter. Based upon current assumptions, we believe that adoption of this new accounting guidance will not immediately change the designation of our Thermo Subsidiary from being a consolidated entity for financial statement purposes. However, we will continue to evaluate events under this new pronouncement that may result in the deconsolidation of the Thermo Subsidiary as they arise.

In August 2009, the FASB issued new accounting guidance to provide clarification on measuring liabilities at fair value when a quoted price in an active market is not available. This new guidance became effective on July 1, 2009. We implemented this guidance on July 1, 2009, and it had no material impact on our financial condition, results of operations, or cash flows.

In September 2009, the FASB issued new accounting guidance to provide implementation guidance for uncertainty in income taxes for “pass through entities”. The amendments clarify that management’s determination of the taxable status of the entity is a tax position subject to the standards required for accounting for uncertainty in income taxes. This new guidance became effective on July 1, 2009. We implemented this guidance on July 1, 2009, and it had no material impact on our financial condition, results of operations, or cash flows.

In January 2009, the Securities and Exchange Commission issued Release No. 33-9002, “Interactive Data to Improve Financial Reporting.” The final rule requires companies to provide their financial statements and financial statement schedules to the Securities and Exchange Commission in interactive data format using the eXtensible Business Reporting Language (“XBRL”). The rule was adopted by the Securities and Exchange Commission to improve the ability of financial statement users to access and analyze financial data. The Securities and Exchange Commission adopted a phase-in schedule indicating when registrants must furnish interactive data. Under this schedule, we will be required to submit filings with financial statement information using XBRL commencing with our June 30, 2011 quarterly report on Form 10-Q. We are furnishing financial information in XBRL format starting with this quarterly report on Form 10-Q. As an earlier XBRL adopter, we may choose to discontinue furnishing XBRL data in the future until the required compliance date of June 30, 2011.

M. Subsequent Events

Events subsequent to September 30, 2009, were evaluated until the time of the Form 10-Q filing with the Securities and Exchange Commission on November 9, 2009.

October 2009 Registered Offering

On October 19, 2009, we sold 3,201,526 shares of our common stock and warrants to acquire up to 1,600,763 shares of our common stock to three of the LOC Lenders in consideration for $5.4 million in promissory notes. The common stock and warrants were sold as units (the “Units”), with each Unit consisting of one share of common stock and one warrant to acquire 0.50 shares of our common stock (each, a “Warrant” and collectively, the “Warrants”) at an exercise price of $1.61 per share. The October 2009 Warrants expire on October 19, 2019. Each Unit was sold at a negotiated price of $1.68 per unit. On October 23, 2009, we entered into agreements with the three participating LOC Lenders to cancel the $5.4 million promissory notes as an offset to settle the equivalent amount owed to the participating LOC Lenders for their respective portions of the outstanding Line of Credit balance on that date.

Pursuant to the registered offering, we sold 3,201,526 Units to three of the LOC Lenders, each of whom had advanced funds to us pursuant to the Line of Credit. We did not offer Units to the one lender under the Line of Credit that is controlled by our Chairman of the Board, Kraig Higginson, due to certain regulatory restrictions relating to the sale of Units to an officer of the Company. The proceeds from the sale of these units to the three participating LOC Lenders totaled $5.4 million, before deducting estimated offering expenses of approximately $75,000. We accepted promissory notes totaling $5.4 million from the three participating LOC Lenders for the 3,201,526 Units sold.

In addition to the sale of the Units to the three participating LOC Lenders, we also offered an aggregate of 1,120,526 additional Units to certain stockholders and former stockholders of our Company (the “Participation Rights Holders”) pursuant to agreements dated June 30, 2009 between us and the Participation Rights Holders. Each of the Participation Rights Holders was entitled to purchase a number of Units equal to at least its pro rata portion of 35% of the Units offered on the same terms and conditions as the three participating LOC Lenders. None of the Participation Rights Holders elected to participate in this offering.

Item 2.

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

SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

Certain information set forth in this report contains “forward-looking statements” within the meaning of the federal securities laws. Forward-looking statements include statements concerning our plans, objectives, goals, strategies, future events, future revenues or performance, capital expenditures, financing needs, plans or intentions relating to acquisitions or dispositions and other information that is not historical information. In some cases, forward-looking statements can be identified by terminology such as “believes,” “expects,” “may,” “will,” “should,” “anticipates” or “intends” or the negative of such terms or other comparable terminology, or by discussions of strategy. We may also make additional forward-looking statements from time to time. All such subsequent forward-looking statements, whether written or oral, by us or on our behalf, are also expressly qualified by these cautionary statements.

All forward-looking statements, including without limitation management’s examination of historical operating trends, are based upon our current expectations and various assumptions. Our expectations, beliefs and projections are expressed in good faith and we believe there is a reasonable basis for them, but there can be no assurance that management’s expectations, beliefs and projections will result or be achieved. All forward-looking statements apply only as of the date made. We undertake no obligation to publicly update or revise forward-looking statements which may be made to reflect events or circumstances after the date made or to reflect the occurrence of unanticipated events.

There are a number of risks and uncertainties that could cause our actual results to differ materially from the forward-looking statements contained in or contemplated by this report. Any forward-looking statements should be considered in light of the risks set forth in Part II “Item 1A. Risk Factors” and elsewhere in this report.

Unless the context requires otherwise, all references in this annual report to “Raser,” “the Company,” “we,” “us,” “our company,” “Raser Technologies” or “our” refer to Raser Technologies, Inc. and its consolidated subsidiaries.

Overview

Our Company

We are incorporated in Delaware. We are the successor to Raser Technologies, Inc., a Utah corporation, which was formerly known as Wasatch Web Advisors, Inc. Wasatch Web Advisors acquired 100% of our predecessor corporation in a reverse acquisition transaction in October of 2003. Prior to that transaction, our predecessor corporation was a privately-held company.

We have initiated the development of eight geothermal projects in our Power Systems segment to date, and we are currently in the development stage of well drilling and geothermal power plant construction to further develop viable geothermal resources. We have accumulated a large portfolio of geothermal interests in four western continental states and a geothermal concession in Indonesia. These geothermal interests are important to our ability to develop geothermal power plants. We continue to seek and accumulate additional interests in geothermal resources for potential future projects.

We have incurred substantial losses since inception and we are not operating at cash breakeven. Our continuation as a going concern is dependent on efforts to secure additional funding, increase revenues, reduce expenses, and ultimately achieve profitable operations, any of which may be challenging given the current economic environment. If substantial losses continue, or if we are unable to secure sufficient additional funding on reasonable terms, liquidity concerns may require us to curtail or cease operations, liquidate or sell assets or pursue other actions that could adversely affect future operations.

Liquidity, Capital Requirements and Market Conditions

Our ability to secure liquidity in the form of additional financing or otherwise remains crucial for the execution of our business plans and our ability to continue as a going concern. Our current cash balance, together with cash anticipated to be provided by operations, will not be sufficient to satisfy our anticipated cash requirements for normal operations, accounts payable and capital expenditures for the foreseeable future. Obligations that may exert further pressure on our liquidity situation include the obligation to repay the remaining amounts borrowed under our Unsecured Line of Credit Agreement and Promissory Note, dated January 27, 2009 and amended on July 22, 2009 (the “Line of Credit”), among Radion Energy, LLC (“Radion”), Ocean Fund, LLC (“Ocean Fund”), Primary Colors, LLC (“Primary Colors”) and R. Thomas Bailey, an individual (collectively, the “LOC Lenders”), which are due in July 2010 but may need to be repaid as early as November 2009. The principal balance of the Line of Credit and any accrued interest

thereon, can be paid in the form of cash or equity securities at our sole discretion, subject to any regulatory limitations on our ability to satisfy these obligations through the issuance of equity securities. Although the outstanding borrowings under the Line of Credit of $5.3 million is due in July 2010, the remaining LOC Lender is a related party and has informed us that he does not intend to exert further pressure on our liquidity situation. In addition to our obligations under the Line of Credit, if we fail to achieve “Final Completion,” as defined in the Thermo Financing Agreements, of our Thermo No. 1 geothermal power plant by November 30, 2009, we may incur penalties of between $2.0 million to $3.0 million would be payable immediately to our debt and tax equity providers. However, given our past history and positive working relationship with the debt holders and the Class A Member, we believe that the likelihood of incurring additional penalties is only “reasonably possible” and not “probable” as defined by ASC Subtopic 450-20 “Contingencies-Loss Contingencies”. Accordingly, no liability was recorded relating to the estimated penalties at September 30, 2009.

During 2008 and 2009, economic conditions have weakened significantly and global financial markets have experienced significant liquidity challenges. Despite these challenges, we were able to obtain a limited amount of financing during 2009. Earlier in the year, we established the Line of Credit. During the year, we borrowed a total of $13.4 million under the Line of Credit. In July 2009, we completed a $25.5 million registered direct offering. In October 2009, we sold shares of our common stock and warrants to acquire shares of our common stock to three of the LOC Lenders for a total purchase price of $5.4 million. We received the purchase price in the form of promissory notes, which were then used as an offset to settle our outstanding obligations to the participating LOC Lenders under the Line of Credit and reduce our outstanding borrowings under the Line of Credit to $5.3 million. This transaction reduced our liabilities, but did not change our available cash. Although the outstanding borrowings under the Line of Credit of $5.3 million is due in July 2010, the remaining LOC Lender is a related party and has informed us that he does not intend to exert further pressure on our liquidity situation.

The cost of raising capital in the debt and equity capital markets has increased substantially while the availability of funds from those markets generally has diminished significantly. Also, as a result of concerns about the stability of financial markets generally and the solvency of counterparties, the cost of obtaining money from the credit markets generally has increased as many lenders and institutional investors have increased interest rates, enacted tighter lending standards, refused to refinance existing debt at maturity on terms that are similar to existing debt, and reduced, or in some cases ceased, to provide funding to borrowers. If we are unable to secure adequate funds on a timely basis on terms acceptable to us, we will be unable to satisfy our existing obligations, or to execute our plans. In such case, we would be required to curtail or cease operations, liquidate or sell assets, modify our current plans for plant construction, well field development and other development activities, or extend the time frame over which these activities will take place, or pursue other actions that could adversely affect future operations. We intend to continue to seek financing arrangements from a variety of sources to fund our development activities, which may include the issuance of debt, preferred stock, equity or a combination of these instruments. We also continue to evaluate a variety of alternatives to finance the development of our geothermal power projects. These alternatives could include project financing and tax equity financing, government funding from grants, loan guarantees or private activity bonds, joint ventures, the sale of one or more of our projects or interests therein, entry into prepaid power purchase agreements with utilities or municipalities, or a merger and/or other transaction, a consequence of which could include the sale or issuance of stock to third parties.

Federal and state governments have recognized the financing challenges faced by many businesses and have established programs to help companies engaged in the development of renewable energy projects. These programs include loan guarantee, government grant and other programs. As a result, part of our short-term strategy to obtain additional funding includes applications for loan guarantees and various government grants. For example, we have made or are in the process of making applications for funding under several stimulus programs established by the American Recovery and Reinvestment Act of 2009 (the “Recovery Act”) and other pre-existing programs. However, one of our applications for loan guarantees was denied. In addition, we were not awarded three small grants for innovative exploration activities. We cannot predict whether we will be able to successfully obtain loan guarantees or grants under these new government programs.

The amount and timing of our future capital needs will depend on many factors, including the timing of our development efforts, opportunities for strategic transactions, and the amount and timing of any cash flows we are able to generate. We cannot be certain that funding will be available to us on reasonable terms or at all.

Current Geothermal Power Projects

We have initiated the development of eight geothermal projects in our Power Systems segment to date. In April 2009, we began selling electricity generated by the Thermo No. 1 geothermal power plant to the City of Anaheim pursuant to a power purchase agreement we previously entered into with Anaheim, and we have either obtained or are in the process of obtaining permits for the development of the other seven geothermal power projects we have initiated. The current status of development for each of these eight projects is described below. Other than certain permitting activities and engineering work currently being performed, the continued development of each of our projects is dependent on additional financing. While we would expect to seek project-specific financing arrangements for plant construction at these projects, including the forms of financing described above, we anticipate that we will need to fund some or all of our well field development activities from general corporate funds, which would typically be obtained through financing at the parent company level, if available. Due to uncertainties associated with the current economic environment, we cannot be certain that financing will be available to us on reasonable terms or at all. As a result, the timing for continued development at each of our projects is highly uncertain.

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Thermo No. 1 Plant (Utah): We completed major construction of the cooling towers and transmission lines and installed the power generating units at the Thermo No. 1 geothermal power plant, located in Beaver County, Utah, in the fourth

quarter of 2008. We completed the commissioning of the plant in the first quarter of 2009. In April 2009, we began selling electricity generated by the Thermo No. 1 geothermal power plant to the City of Anaheim pursuant to a power purchase agreement we previously entered into with Anaheim. For more information regarding the background, geological studies, geothermal leases and geothermal resources relating to the Thermo No. 1 power plant, please see our Annual Report on Form 10-K for the year ended December 31, 2008.

During the second and third quarters of 2009, we delivered 14,695 MW hours of electricity to the City of Anaheim. The Thermo No. 1 plant is currently producing and transmitting approximately 5 MW of electricity, which represents approximately half of the plant’s designed capacity. Thus far, we have been unable to operate the plant at full capacity due to insufficient heat and flow from the production wells that provide geothermal water to the plant. As more fully described below, we believe that additional wells we have drilled, together with some of the existing wells we are reworking, have the potential to increase the net power production to full capacity by the end of the fourth quarter of 2009. However, we have not completed all of the necessary drilling, stimulation work and testing, and we cannot be certain the additional wells will allow us to operate the Thermo No. 1 plant at full capacity. While we expect the plant to be generating power at or near full capacity of 10 megawatts available for sale by the end of this year, we do not expect to complete all of the steps necessary to achieve “Final Completion” under the Thermo Financing Agreements until the first quarter of 2010.

The net power produced by the Thermo No. 1 plant is purchased by the City of Anaheim, California pursuant to a renewable power purchase and sale agreement (the “Thermo PPA”), which we entered into on March 10, 2008, before the plant was constructed. Subject to certain conditions, the Thermo PPA provides for the delivery by the Thermo No. 1 plant of up to 11 megawatts of geothermal renewable power for 20 years. The Thermo PPA provides for a selling price of $78 per megawatt hour with a two percent per annum increase over the term of the Thermo PPA. Under the Thermo PPA, the City of Anaheim is also obligated to pay for the “wheeling costs,” or cost for transmission, of the electricity from the Thermo No. 1 power plant to the City of Anaheim. The is no penalty under the Thermo PPA for delivering less than 11 megawatts of geothermal renewable power.

As noted above, we completed the major construction of the cooling towers, transmission lines and setting of the power generating units at the Thermo No. 1 geothermal power plant in October of 2008. Commissioning testing of the power generating units was completed in the first quarter of 2009 using two production wells and one reinjection well that we had connected to the plant. Once a plant has been placed in service, we reclassify the cost of the related leases, wells, transmission lines and substations and construction in progress as “Geothermal property, plant and equipment” on the balance sheet. Since our Thermo No. 1 geothermal power plant was placed into service in the first quarter of 2009, we reclassified these costs as “Geothermal property, plant and equipment” accordingly.

At September 30, 2009, the total capitalized costs of the Thermo No. 1 project were $107.7 million, consisting of $64.3 million in plant construction and transmission line and interconnection costs, $42.4 million in well field development costs, $2.4 million in land and lease acquisition costs and accumulated depreciation totaling $1.4 million. These costs will be amortized over the estimated useful life of the geothermal power plant, which is expected to be approximately 35 years. Amortization of the Thermo No. 1 geothermal power plant began in the second quarter of 2009. We have assessed the additional construction and drilling costs that we expect to incur so that the power plant will be able to operate at or near full capacity to be approximately $8.0 million.

We have drilled five production wells and two reinjection wells that we expect to utilize for the plant when it is operating at full capacity. We recently finished drilling two additional wells and we expect to use at least one of these wells as a production well pending the completion of well testing. We believe that when the plant is operating at full capacity, it will utilize five to six production wells and two to three injection wells at the Thermo No. 1 geothermal power plant. In addition to the completion of drilling, stimulation work and testing of these two newest wells, we expect to rework some of the existing wells in order to isolate cooler waters that may be entering the wells.

The expected production wells have demonstrated flow temperatures in commercially productive ranges of approximately 240 degrees Fahrenheit to 300 degrees Fahrenheit, with bottom-hole temperatures in excess of 350 degrees Fahrenheit. The geothermal resources utilized by the plant are believed to be renewable so long as; (i) the plant is operated at or below the maximum level studies indicate that the resource will support, (ii) all of the geothermal fluids are recycled without losses, and (iii) the hydrological balance of the geothermal resource is properly maintained.

In addition to the wells described above, we have drilled two wells that we, in consultation with our drilling and geothermal consultants, have determined to be non-commercial wells. However, we may conduct further testing of one of these wells in the future to determine whether it can be stimulated to increase its production through a variety of commonly-used well stimulation techniques. We may also use one of these wells as a reinjection well.

Our ability to operate the Thermo No. 1 plant at full capacity depends significantly on the characteristics of the additional production wells we expect to use for the plant. The wells need to provide sufficient heat at flow rates that can be maintained without a significant increase in the parasitic load associated with the plant. The parasitic load refers to the amount of electricity used by the plant to maintain operations and typically refers to loads associated with cooling towers, cooling water pumps, turbine pumps, and other plant loads. This type of parasitic load is satisfied by utilizing power generated by the plant itself. A significant load can also result from geothermal well pumps and other equipment used to maintain the flow of geothermal water from the earth through the plant and back into the earth through reinjection wells. Generally, water with a higher temperature will allow the plant to operate with a lower rate of flow, which results in a decrease in the parasitic load because less electricity is required to maintain the necessary flow rate. Water with lower temperatures, on the other hand, requires a higher flow rate to operate the plant, which increases the parasitic load. Unless the water produced by a well is hot enough to increase the amount of power generated by the plant and available for sale, and the increase is sufficient to compensate for the cost of purchasing power to satisfy any resulting increase in parasitic load, the well will not result in a net increase in the revenue from the plant. Therefore, the overall temperature of the water produced by the production wells is critical to our ability to operate the plant at full capacity.

We satisfy the power requirements of the geothermal well pumps at the Thermo No. 1 plant by purchasing electricity from the local electrical utility. We are able to purchase this power at rates lower than the rates we are able to sell the power generated by the plant under the applicable Thermo PPA. This allows us to economically sell all of the power resulting from an increase in the amount of power generated by the Thermo No. 1 plant as long as the value of that power exceeds the value of the power we purchase to satisfy any related increase in the parasitic load. We are also limited by the amount of water our reinjection wells can return to the earth. Additional reinjection wells may be required if the current wells exceed their capacity to reinject water to the geothermal source. While we believe the additional production wells we expect to use for the plant have the potential to increase the net production at the plant to full capacity, we cannot be certain that the wells will increase net production until the wells are brought online and the impact to the parasitic load at the plant has been determined. Similarly, we may elect to rework marginal wells where we estimate we may be able to increase the temperature by blocking off zones where the water is cooler. We cannot be certain that this rework will generate an economic return and net production increase until the wells are brought online and the impact to the parasitic load has been determined.

Assuming we are able to increase production at the Thermo No. 1 plant to full capacity, we are also currently evaluating the expansion of the Thermo No. 1 plant by including a bottom-cycling operation. In the bottom cycling operation, the discharged geothermal water from the main plant would be cascaded through a second set of power generating units, extracting more heat to generate additional power. The expanded project is referred to as the Thermo No. 1A project. The economics of the Thermo No. 1A project would benefit from the transmission infrastructure, cooling towers and established well field already in place at the Thermo No. 1 plant. The Thermo No. 1A project may be able to generate up to an additional 5 MW of power. We expect that, if feasible, Thermo No. 1A will enhance the economics of Thermo No. 1 because of project cost savings from eliminating drilling, transmission upgrades, and cooling tower costs. Unless we are able to increase the production of Thermo No. 1 to full capacity, however, it is unlikely that the bottom cycling operation will be viable.

We have experienced certain delays and cost overruns on the Thermo No. 1 project. The Thermo No. 1 geothermal power plant is the first ever large-scale commercial application of the Pratt & Whitney Power Systems (“PWPS”) Pure-Cycle power generating units and the first plant built under our rapid-deployment approach so such delays and overruns are not entirely unexpected. Some of the key drivers of the delays and cost overruns are as follows:

Well Field Development:

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Increased costs to broaden previous well field plans.

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Complications encountered by drilling contractors.

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High demand for drilling services and related materials due to the rapid increase in the price of oil.

Construction:

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Wider than necessary step-outs for injection wells, which increased piping costs, due to concerns of lenders.

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Additional costs incurred relating to establishing the greater Thermo area.

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Increased prices for steel, concrete and other commodities due to high demand.

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Payment of overtime and other additional costs in order to accelerate the construction schedule.

Equipment:

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Expenses associated with installing PWPS power generating units for the first time, which allowed us to identify design changes for the benefit of future plants.

Transmission:

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In anticipation of future plants, we built a larger transmission infrastructure.

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Lightning Dock Plant (New Mexico): We acquired the Lightning Dock project in 2007 in an acquisition transaction. Pursuant to the transaction, we purchased a United States Bureau of Land Management (“BLM”) lease and other miscellaneous assets totaling $4,140,000 (the “Purchase”). Numerous exploratory wells and two production wells were drilled prior to our acquiring the site. Subject to obtaining adequate financing, we intend to build a geothermal power plant at Lightning Dock with an estimated generating capacity of approximately 10 to 15 MW. For more information regarding the background, geological studies, geothermal leases and geothermal resources relating to the Lightning Dock project, please see our Annual Report on Form 10-K.

We are in the process of obtaining the final, necessary permits for the Lightning Dock plant. We have received the bulk of the permits we need for the project and are in the process of finalizing the last few permitting items. However, to date, we have not drilled production or reinjection wells on this site. We are awaiting final approval to proceed with the final permits from the local government officials, pending a ruling relating to a protest filed by a nearby land owner.

The power generated from the facility is expected to be sold to the Salt River Project Agricultural Improvement and Power District (“SRP”) in Phoenix, Arizona pursuant to a 20-year power purchase agreement.

We are evaluating various generating equipment for the Lightning Dock project. We anticipate that the Lightning Dock project will produce between 15 and 20 MW of power for sale to SRP. We estimate that the total costs of the completed Lightning Dock geothermal power plant will range from $75 to $85 million, including the costs of well field development and transmission line construction, depending on the equipment selected. Continued development of the Lightning Dock plant, other than the permitting work currently performed, will be dependent on additional financing.

The initial lease term of the assigned BLM lease began in January 1979 and has been extended based upon certain conditions in the lease until January 2024. Annual delay rental payments of $5,000 are required on each anniversary date until geothermal power production has begun. If a geothermal power plant is constructed which utilizes geothermal resources covered by the lease, royalties are owed to the BLM based on a percentage of electrical sales from the plant. We have capitalized certain legal fees directly associated with completing the Purchase and obtaining the BLM lease. We also capitalized the obligations we assumed to plug certain abandoned wells located on the property.

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Thermo No. 2 and No. 3 Plants (Utah): In March of 2008 we concluded with a high degree of confidence that the Thermo area contained a commercially viable geothermal resource which could support additional power plants. When it became clear that the geothermal resource located on our leased lands in the Thermo area could support more than just the Thermo No. 1 project, we began preliminary planning for the Thermo No. 2 and Thermo No. 3 projects including preparing permit applications, securing water rights, filing for transmission interconnection, securing rights of way for the expected new transmission line, and beginning environmental work. These permits include, among others, air quality permits, hazardous materials permits, and storm water discharge permits. While construction of the Thermo No. 1 geothermal power plant has been ongoing, we have begun obtaining the necessary permits for the Thermo No. 2 project and the Thermo No. 3 project. The Thermo No. 2 geothermal power plant is expected to be located on an approximately 480 acre portion of a 11,000 acre private lease and the Thermo No. 3 geothermal power plant is expected to be located on an approximately 480 acre parcel owned by the Utah School and Institutional Trust Lands Administration. For more information regarding the background, geological studies, geothermal leases and geothermal resources relating to the Thermo No. 1 power plant, please see our Annual Report on Form 10-K.

As of September 30, 2009, we had not entered into power purchase agreements for the sale of the power to be generated from the Thermo No. 2 and Thermo No. 3 geothermal power plants, but have signed a term sheet with the Southern California Public Power Authority (“SCPPA”) that, if the final Power Purchase Agreement is executed, will facilitate the financing for the development of both Thermo No. 2 and Thermo No. 3.

Continued development of the Thermo No. 2 and Thermo No. 3 plants, other than the permitting and engineering work currently being performed, will be dependent on additional financing.

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Klamath Falls Plant (Oregon): We have obtained the necessary zoning permit and drilling permit to drill the first well at our Klamath Falls project. We are in the process of obtaining the necessary water change permit for reinjecting water into the ground, along with permits for construction, air quality and other permits necessary to begin construction of our geothermal power plant. We have performed some preparations at the site, but have not begun drilling activities. Continued development of the Klamath Falls plant, other than the permitting work currently being performed, will be dependent on additional financing. For more information regarding the background, geological studies, geothermal leases and geothermal resources relating to the Klamath Falls project, please see our Annual Report on Form 10-K for the year ended December 31, 2008.

Annual delay rental payments of $1,000 are due on each anniversary date until production begins. If a geothermal power plant is constructed which utilizes geothermal resources covered by the lease, royalties are owed to the landowner based on a percentage of electrical sales from the plant.

In addition to the lease acquisition costs for the Klamath Falls project totaling $10,000, we have incurred permitting costs totaling $76,900.

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Truckee Plant (Nevada): We have obtained the drilling, construction, air quality, water reinjection, water quality and other permits that are necessary to begin drilling at the Truckee site. We are in the process of obtaining the environmental assessment from the BLM that will enable us to construct the Truckee plant. We drilled the first well at this site in the fourth quarter of 2007. However, the results of the first well have been inconclusive. We will have additional independent geologic studies performed before we proceed with any additional drilling. With other projects showing greater geothermal resources, we expect to seek funding to continue the development of our other projects ahead of the Truckee project. Further development on the Truckee resource will be dependent upon more positive geological studies and the availability of financing for the resource. For more information regarding the background, geological studies, geothermal leases and geothermal resources relating to the Truckee project, please see our Annual Report on Form 10-K for the year ended December 31, 2008.

Pursuant to the terms of the BLM leases, annual delay rental payments of $15,000 are due each year until production begins. If a geothermal power plant is constructed which utilizes geothermal resources covered by the lease, royalties are owed to the BLM based on a percentage of electrical sales from the plant.

As of December 31, 2008, we performed an impairment review of the Truckee well and determined that it should be impaired. The circumstances that led to the impairment of the Truckee well are primarily due to the current world-wide economic conditions that have led to tightening credit markets. Because of the tightening credit markets, we determined that our access to capital may be constrained in the future. Accordingly, we prioritized our cash uses, concentrating our efforts on our largest known resources. As a result, the future undiscounted cash flows from the Truckee well have become uncertain because of the re-prioritization of our projects based upon the changing economic conditions. Therefore, we considered our ability to secure sufficient financing necessary to continue drilling at the Truckee project and determined it was uncertain if we would be able to finance continued drilling at the Truckee project in the near term in addition to our other projects of higher priority. Because of this uncertainty, we expensed $3.0 million in the Power Systems segment in the fourth quarter of 2008. However, management believes that the Truckee well could still be used in the production of electricity as either a production or reinjection well in the future should the appropriate financing be obtained.

In addition to the lease acquisition costs for the Truckee project totaling $734,500, we incurred drilling costs totaling $3.0 million. As of December 31, 2008, we determined that the value of this well had been impaired due to our current cash requirements and the need to raise additional capital to continue with the Truckee project. Accordingly, the $3.0 million of costs were expensed at December 31, 2008. However, if we are able to secure additional financing and continue development of the Truckee project, we believe it is likely that the Truckee well will be suitable as a reinjection well, but until more detailed testing is performed on the well we will not know if it will be a production well, a reinjection well or will be abandoned.

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Devil’s Canyon Plant (Nevada): We have obtained drilling permits for up to eight production wells and three reinjection wells at our Devil’s Canyon project. We are in the process of obtaining the necessary environmental assessment permit from the BLM, water change permit for reinjecting water into the ground, construction, air quality, environmental and other permits necessary to begin construction of our geothermal power plant. We have not yet begun drilling activities. Continued development of the Devil’s Canyon plant, other than the permitting work currently being performed, will be dependent on additional financing. For more information regarding the background, geological studies, geothermal leases and geothermal resources relating to the Devil’s Canyon project, please see our Annual Report on Form 10-K for the year ended December 31, 2008.

Annual delay rental payments of $20,000 are due on each anniversary date of the geothermal leases relating to the Devil’s Canyon project until production begins.

Our Devil’s Canyon geothermal leases are located on ranches that contain a shed with no other structures.

In addition to the lease acquisition costs for the Devil’s Canyon project totaling $45,600, we incurred permitting costs totaling $123,700.

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Trail Canyon Plant (Nevada): We are in the process of obtaining the necessary environmental assessment permit from the BLM, and are moving forward with drilling permits, the water change permit for re-injecting water into the ground, construction, air quality and other permits and rights of way necessary to begin construction of our geothermal power plant. Accordingly, we have not yet begun drilling activities. Continued development of the Trail Canyon plant, other than the permitting work currently being performed, will be dependent on additional financing. For more information regarding the background, geological studies, geothermal leases and geothermal resources relating to the Trail Canyon project, please see our Annual Report on Form 10-K for the year ended December 31, 2008.

Annual delay rentals with respect to the leases total $635 on each anniversary date until production of electricity begins. If a geothermal power plant is constructed which utilizes geothermal resources covered by these leases, royalties are owed to the respective landowners based on a percentage of electrical sales from the plant.

In addition to the lease acquisition costs for the Trail Canyon project totaling $179,600, we incurred permitting costs totaling $224,100.

The timing for construction and completion of each of the projects described above will depend on a number of factors, including the receipt of necessary permits, timely granting of interconnection and transmission access, and the ability to obtain adequate financing for both the well-field development phase and the plant construction phase of each project. Uncertainties associated with these factors could result in unexpected delays. In addition, the feasibility of certain of the projects described above is still subject to further geological testing and/or drilling to determine whether an adequate geothermal resource exists to support a geothermal power plant.

In addition to the projects currently under development, we intend to initiate the development of additional projects. However, our ability to initiate new projects will depend on a number of factors, including the availability of adequate financing, the availability of adequate geothermal resources, the demand for renewable power, the number of projects we have under development, and our available resources to devote to our project development efforts.

Results of Operations

We completed the major construction of the cooling towers and transmission lines and installed the PWPS power generating units at our Thermo No. 1 project in October 2008. The Thermo No. 1 power plant began generating nominal quantities of “test” electricity in December 2008. We began delivering electricity generated by the Thermo No. 1 geothermal power plant to the City of Anaheim in April 2009 pursuant to the Thermo PPA. Subject to the risks and uncertainties described elsewhere in this report, we expect the plant to become operational at or near full capacity in the fourth quarter of 2009. Although Thermo No. 1 BE-01, LLC (“Thermo Subsidiary”) began generating revenues under the Thermo PPA during 2009, the expected revenues and cash flows received by Raser, the parent company of Thermo No. 1 will not have a material effect on our liquidity or our needs for additional financing.

Our Transportation & Industrial segment expects to begin to generate modest revenues in the future from contracts we have entered into, or expect to enter into, for the development of extended range Plug-in Hybrid Electric Vehicle (“PHEV”) demonstration vehicles. Our Transportation & Industrial segment will not generate significant revenues or cash flows unless we are able to license our Symetron ^TM technologies to third parties. Although progress is being made by each of our business segments, significant revenues may not be generated as expected by either of our segments, if at all. We are currently evaluating the possibility of further dividing the Transportation and Industrial and Power Systems segments or otherwise spinning off the Transportation and Industrial business segment in a manner that would be beneficial to our shareholders.

We have incurred significant losses since our inception. As of September 30, 2009, we had incurred an accumulated deficit of approximately $103.7 million on cumulative revenues since inception of approximately $2.3 million. Our net losses applicable to common stockholders for the nine months ended September 30, 2009 and 2008 totaled $14.2 million and $12.9 million, respectively.

During the nine months ended September 30, 2009, our average monthly cash expenditure rate for operations decreased to approximately $1.3 million from approximately $1.8 million per month for the nine months ended September 30, 2008. The current spending rate primarily comprises lower professional services associated with power plant design, financing and tax structures and general engineering totaling $0.5 million per month. This decrease was offset by increased payroll costs, certain expenses related to the construction of the Thermo No. 1 geothermal power plant, and miscellaneous fees incurred as a result of our deposit refund from PWPS totaling $0.2 million per month. In addition, the current spending rate has decreased primarily due to lower payroll and consulting costs relating to our research and development engineering costs of our PHEV project totaling $0.2 million per month. Provided we have sufficient cash available, we expect that our average monthly cash expenditure rate will begin to increase again as we implement our plans to develop additional geothermal power plants. For the third quarter of 2009, our average monthly cash expenditure rate decreased to $0.9 million per month as a result of management’s decision to reduce administrative costs and focus corporate efforts and resources on completing the Thermo No. 1 plant. We expect the expenditure rate to remain at this level or continue to decrease until we secure additional financing.

For the nine months ended September 30, 2009, our operating expenses consisted primarily of cost of sales, general and administrative expenses, power project development expenses and research and development expenses. Cost of revenue incurred for the current year periods presented primarily includes the direct costs of operating our Thermo No. 1 geothermal power plant such as the wheeling costs (wheeling costs are reimbursed by the City of Anaheim), commissions, royalties, costs of electricity (referred to as parasitic load) to operate well pumps and equipment, geothermal engineering consulting, depreciation and other direct overhead related costs. Cost of revenue incurred during prior periods also includes the direct labor, materials and overhead expenses required to perform work on research and development subcontracts which have now been completed.


	Three months ended September 30,						Nine months ended September 30,
	2009			2008			2009			2008
Revenue	$	845,265		$	30,000		$	1,252,506		$	166,423
Cost of revenue
Direct costs		2,150,652			—			3,283,296			74,112
Depreciation and amortization		735,126			—			1,445,900			—

Gross margin		(2,040,513	)		30,000			(3,476,690	)		92,311

Operating expenses
General and administrative		2,352,612			2,447,878			7,633,943			7,562,902
Power project development		1,245,849			3,232,729			6,509,230			8,012,210
Research and development		364,557			970,925			1,592,124			3,134,138

Total operating expenses		3,963,018			6,651,532			15,735,297			18,709,250

Operating loss		(6,003,531	)		(6,621,532	)		(19,211,987	)		(18,616,939	)
Interest income		33,538			94,030			122,342			265,306
Interest expense		(3,481,165	)		(1,077,695	)		(8,714,110	)		(2,180,976	)
Gain on derivative instruments		5,918,100			—			12,917,454			—
Other		—			—			(131,442	)		75,775

Loss before income taxes		(3,533,058	)		(7,605,197	)		(15,017,743	)		(20,456,834	)
Tax benefit (expense)		—			—			—			—

Net loss	$	(3,533,058	)	$	(7,605,197	)	$	(15,017,743	)	$	(20,456,834	)
Non-controlling interest in the Thermo No. 1 subsidiary		(248,513	)		(1,226,070	)		806,458			(1,226,070	)

Net loss applicable to common stockholders	$	(3,781,571	)	$	(8,831,267	)	$	(14,211,285	)	$	(21,682,904	)

Loss per common share-basic and diluted	$	(0.05	)	$	(0.15	)	$	(0.21	)	$	(0.38	)

Weighted average common shares-basic and diluted		74,881,000			57,785,000			68,321,000			56,646,000

Comparison of Three Months Ended September 30, 2009 and 2008

Revenue

During the three months ended September 30, 2009, we recognized revenue totaling $0.8 million as compared to $30,000 during the same period in 2008. During the second quarter of 2009, we began selling electricity generated by our Thermo No. 1 geothermal power plant to the City of Anaheim. During the third quarter, we generated and sold approximately 9,819 MW hours of electricity.

Cost of revenue. Cost of revenue for the three months ended September 30, 2009 totaled $2.9 million compared to zero for the same period in 2008. The increase in cost of sales for 2009 was primarily due to sales of electricity from the Thermo No. 1 power plant during the third quarter of 2009. Cost of revenue includes depreciation expense totaling $0.7 million, parasitic load costs totaling $0.5 million, the annual property tax assessments totaling $0.8 million that had not been accrued previously; consulting and insurance costs totaling $0.3 million; maintenance costs for the Thermo No. 1 power generating units totaling $0.2 million; and payroll related costs totaling $0.1 million. Although, the gross margin was negative for the quarter ended September 30, 2009, we anticipate that as the Thermo No. 1 plant reaches full capacity, certain consulting expenses and parasitic load costs will decline and we expect the revenue generated from the sale of electricity under the current PPA to exceed the cost of revenue.

Operating Expenses

General and Administrative. General and administrative expenses remained relatively flat at approximately $2.4 million for the three months ended September 30, 2009 as compared to the three months ended September 30, 2008. Employment related costs increased approximately $0.2 million due to cash and equity based compensation relating to severance payments to certain former employees. Office related expenses increased approximately $0.1 million due to our general expansion of office space at the beginning of the current year. These increases are offset by decreased professional services during the third quarter of 2009 from the third quarter of 2008 totaling $0.4 million reflecting decreased legal and consulting fees associated with tax equity financing activities during the prior year third quarter.

Power Project Developments. Power project development expenses during the three months ended September 30, 2009 totaled $1.2 million as compared to $3.2 million for the three months ended September 30, 2008. During the third quarter of 2009, professional services decreased by approximately $2.0 million due to costs incurred during the third quarter of 2008 relating to geological engineering consulting, transmission line capacity studies and legal fees associated with debt and tax equity financing structures contemplated by financing commitments under our commitment letter with Merrill Lynch (the “Commitment Letter”) that were not incurred during the third quarter of 2009. These fees were higher during the 2008 period due to the negotiation of the Commitment Letter we obtained from Merrill Lynch and the financing we obtained for the Thermo No. 1 plant. Employment related and other operating costs remained relatively flat as compared to the third quarter of 2008. Equity-based non-cash employee and contractor compensation for the three months ended September 30, 2009 also remained relatively flat as compared to the third quarter of 2008.

Research and Development. Research and Development expense decreased from $1.0 million in the three months ended September 30, 2008 to $0.4 million for the three months ended September 30, 2009. Equity based non-cash employee compensation remained relatively flat during the three months ended September 30, 2009 compared to the same period in 2008. This was due primarily to offsetting factors relating to decreasing headcount from the prior year while issuing stock grants to employees as part of their severance agreements during the current year as a result our decision to reduce the cash requirements at our design center. Because we reduced our employment levels at the design center, cash based employee compensation decreased $0.3 million during the three months ended September 30, 2009 from the third quarter of 2008. Professional services decreased by approximately $0.2 million during the three months ended September 30, 2009 compared to the same period in 2008 due primarily to the substantial completion of the consulting work relating to the PHEV early in 2009. The portion of engineering expenses relating to testing of materials decreased during the three months ended September 30, 2009 over the comparable 2008 period by approximately $0.1 million.

Interest and Other Income.

Interest income for the three months ended September 30, 2009 decreased approximately $0.1 million compared to the same period in 2008 reflecting relatively lower average monthly cash balances and interest rates due to the current economic environment. Interest expense during the three months ended September 30, 2009 increased $2.4 million over the three months ended September 30, 2008 primarily due to placing the Thermo No. 1 plant into service during the first quarter of 2009. Once the plant was placed into service, we no longer capitalized interest expense associated with the financing for the construction of the plant. Gain on derivative increased $5.9 million during the three months ended September 30, 2009 compared to the third quarter of 2008 due primarily to a decrease in the fair value of outstanding warrants that contain anti-dilutive features.

Non-controlling Interest.

Comparison of Nine Months Ended September 30, 2009 and 2008

Revenue

During the nine months ended September 30, 2009, we recognized revenue totaling $1.3 million compared to $0.2 million during the same period in 2008. During the second quarter of 2009, we began selling electricity generated by our Thermo No. 1 geothermal power plant to the City of Anaheim. During the second and third quarters, we generated approximately 14,695 MW hours of electricity.

Cost of revenue. Cost of revenue for the nine months ended September 30, 2009 and 2008 totaled $4.7 million compared to $0.1 million for the same period in 2008. The increase in cost of sales for 2009 was due primarily to sales of electricity from Thermo No. 1 during the second and third quarters of 2009. Cost of revenue includes depreciation expense totaling $1.4 million, parasitic load costs totaling $0.7 million, the annual property tax assessments totaling $0.8 million that had not been accrued previously, consulting and insurance costs totaling $0.5 million, maintenance cost for the Thermo No. 1 generating units totaling $0.7 million and payroll related costs totaling $0.2 million. Although, the gross margin was negative for the nine months ended September 30, 2009, we anticipate that as the Thermo No. 1 plant reaches full capacity, certain consulting expenses and parasitic load costs will decline and we expect the revenue generated from the sale of electricity under the current PPA to exceed the cost of revenue.

Operating Expenses

General and Administrative. General and administrative expenses remained relatively flat at $7.6 million for the nine months ended September 30, 2009 compared to the nine months ended September 30, 2008. Equity-based non-cash employee and service provider compensation expenses increased by approximately $0.2 million as a result of severance payments, in the form of our common stock, granted to certain former employees. Cash based employee compensation also increased by approximately $0.2 million as a result of severance payments to certain employees whose employment was terminated during the nine months ended September 30, 2009. Office expenses also increased by approximately $0.5 million over the same prior year period due primarily to increases in franchise taxes in the State of Delaware, fees to Merrill Lynch and Prudential that were incurred to extend the substantial completion date for the Thermo No. 1 plant, and additional rent expense in 2009 associated with extending the lease for our corporate office space. These increases were partially offset by decreases of approximately $0.7 primarily in professional services during the nine months ended September 30, 2009. These professional fees were higher during the 2008 period due to the overall design of our tax equity transactions and negotiation of the Commitment Letter we obtained from Merrill Lynch and the financing we obtained for the Thermo No. 1 plant.

Power Project Developments. Power project development expenses during the nine months ended September 30, 2009 totaled $6.5 million as compared to $8.0 million for the nine months ended September 30, 2008. This decrease was due primarily to employment related costs of $0.7 million resulting from increased power project development employment levels to execute our business plan. Equity-based non-cash employee and contractor compensation for the nine months ended September 30, 2009 increased $0.2 million over the nine months ended September 30, 2008 as a result of stock option grants to new employees and stock grants to a consultant who provided services in connection with our Lightning Dock project. Miscellaneous expenses also increased during the nine months ended September 30, 2009 by approximately $1.6 million over the same period in 2008. The increase was due primarily to a cancellation fee relating to a deposit refund from PWPS. These increases were offset by a decrease in professional services of approximately $4.4 million during the nine months ended September 30, 2009 compared to the third quarter of 2008. The decrease in professional services was due primarily to a decrease in geological engineering services resulting from the completion of certain phases of construction at Thermo No. 1 during the prior year. In addition, during the second and third quarters of 2009 we expensed $0.1 million of testing costs relating to a well at our Thermo No. 1 project. We had previously determined that this well had been impaired and, accordingly, all subsequent testing costs were expensed rather than capitalized.

Research and Development. Research and Development expense decreased from $3.1 million in the nine months ended September 30, 2008 to $1.6 million for the nine months ended September 30, 2009. Equity based non-cash employee compensation increased by approximately $0.1 million during the nine months ended September 30, 2009 as compared to the same period in 2008. This increase was due primarily to issuing stock grants to employees as part of their severance agreements as a result of our decision to reduce the cash requirements at our design center. Because we reduced our employment levels at the design center during the latter part of the second quarter of 2009, cash based employee compensation decreased approximately $0.5 million from the nine months ended September 30, 2008. Professional services decreased by approximately $0.7 million during the nine months ended September 30, 2009 compared to the same period in 2008 due primarily to the substantial completion of the consulting work relating to the PHEV early in 2009. The portion of engineering expenses that could be attributed to cost of sales decreased by approximately $0.5 million during the nine months ended September 30, 2009 over the comparable 2008 period due to a decrease in the amount of materials consumed in testing.

Interest and Other Income.

Interest income for the nine months ended September 30, 2009 decreased approximately $0.1 million compared to the same period in 2008 reflecting a decrease in average monthly cash balances and related interest rates. Interest expense increased $6.5 million during the nine months ended September 30, 2009 over the nine months ended September 30, 2008 primarily due to placing the Thermo No. 1 plant into service during the first quarter of 2009. Once the plant was placed in service, we could no longer capitalize interest expense associated with the financing for the construction of the plant. Gain on derivatives increased $12.9 million during the nine months ended September 30, 2009 compared to the third quarter of 2008 due primarily to the decrease in the fair value of outstanding warrants that contain anti-dilutive features.

Non-controlling Interest.

Non-controlling interest represents the non-controlling tax equity partner’s claim on the assets of Thermo No. 1. In previous filings, non-controlling interest was referred to as minority interest. Non-controlling interest increased by approximately $2.0 million during the nine months ended September 30, 2009 over the same period in 2008. Non-controlling interest for the nine months ended September 30, 2009 includes an adjustment resulting from a correction of an error from a prior period that resulted from modifying our hypothetical liquidation at book value computation to include a basis difference that arises under the recast-financial-statements approach. Such modification resulted in a decrease in non-controlling interest occurred in the first quarter of 2009 totaling $2.1 million. Non-controlling interest also decreased during the nine months ended September 30, 2009 due to certain operating expenditures that we paid on the Thermo Subsidiary’s behalf totaling $0.4 million. This decrease was offset by an increase due to liquidation preferences in accordance with the Thermo Financing Agreements during the nine months ended September 30, 2009 totaling $1.5 million.

Liquidity and Capital Resources


Cash and Cash Equivalents	September 30, 2009		December 31, 2008
Cash	$	3,455,851	$	59,492
Money Market Account		361,781		1,475,328

Total	$	3,817,632	$	1,534,820

Restricted Cash		12,464,532		20,975,839
Restricted Marketable Securities		4,382,258		6,521,347

Total	$	16,846,790	$	27,497,186

Liquidity and Certain Commitments

At September 30, 2009, we had approximately $3.8 million in cash and cash equivalents and restricted cash and marketable securities of approximately $16.8 million. Our operating activities used approximately $24.7 million and $10.1 million of cash during the nine months ended September 30, 2009 and 2008, respectively. We have incurred substantial losses since inception, and we are not operating at cash breakeven. Subsequent to September 30, 2009, we completed a $5.4 million offering of shares of our common stock and warrants to purchase shares of our common stock in connection with the settlement of $5.4 million of outstanding borrowings under our Line of Credit. This transaction reduced our liabilities, but did not increase our available cash.

Of our restricted cash balance at September 30, 2009, $12.4 million will be used to complete the well field drilling, stimulation work and testing for the Thermo No. 1 plant, to pay the remaining balance owed to PWPS for the power generating units and for distribution of development fees after Final Completion is achieved. $0.1 million has been invested in a certificate of deposit for the sole purpose of covering the credit limit of our corporate credit card to minimize the credit risk to our bank. Approximately $4.3 million relating to the marketable securities will be used to pay interest payments for our Convertible Notes upon each of the maturity dates of the marketable securities.

At September 30, 2009, we had approximately $15.5 million in accounts payable and accrued expenses, which reflects a decrease in accounts payable and accrued expenses of approximately $48.9 million from December 31, 2008. The decrease in accounts payable and accrued expenses during the nine month period was due primarily to an agreement we entered into with PWPS (the “PWPS Agreement”), Trail Canyon Geothermal No. 1 SV-02, LLC and Raser Power Systems, LLC pursuant to which we and PWPS agreed to terminate certain agreements that had been assigned to PWPS from UTC Power (“UTCP”) relating to the purchase of power generating units. Under the terms and conditions of the PWPS Agreement, we agreed to transfer title for 113 power generating units to PWPS. We had previously taken delivery of the power generating units, and the cost of the units was previously capitalized and included in accounts payable and accrued expenses. The PWPS Agreement eliminated our obligation to pay for these units, resulting in a reduction to our accounts payable and accrued expenses. Accounts payable and accrued expenses have also decreased through issuance of our common stock to settle outstanding payables totaling $9.3 million.

Approximately $4.3 million of the $15.5 million of accounts payable and accrued expenses represents the remaining balance owed to PWPS for power generating units purchased for our Thermo No. 1 plant. $3.3 million of the amount owed to PWPS is expected to be paid from our restricted cash balances, which totaled $12.4 million at September 30, 2009, upon successful completion of tests to be performed on the units. The remaining balance of the accounts payable and accrued expenses consists of amounts owed for well field development, other equipment and construction costs for the Thermo No. 1 project and for general and administrative costs. The remaining $1.0 million of the amount owed to PWPS for the power generating units purchased for the Thermo No. 1 plant is expected to be paid by us upon successful completion of tests to be performed on the units.

Our ability to secure liquidity in the form of additional financing or otherwise remains crucial for the execution of our plans and our ability to continue as a going concern. Our current cash balance, together with cash anticipated to be provided by operations, will not be sufficient to satisfy our anticipated cash requirements for normal operations, accounts payable and capital expenditures for the foreseeable future. Obligations that may exert further pressure on our liquidity situation include the obligation to repay the remaining balance of $5.3 million borrowed under our Line of Credit, which are due in July 2010 but may need to be repaid as early as November 2009. The principal balance, and any accrued interest thereon, can be paid in the form of cash or equity securities, at our sole discretion, subject to regulatory limitations on our ability to satisfy these obligations through the issuance of equity securities. Although the outstanding borrowings under the Line of Credit of $5.3 million is due in July 2010, the remaining LOC Lender is a related party and has informed us that he does not intend to exert further pressure on our liquidity situation. In addition, if we fail to achieve Final Completion of our Thermo No. 1 geothermal power plant by November 30, 2009 or further extend the Final Completion deadline, we may incur penalties of between $2.0 million to $3.0 million immediately payable to our debt and tax equity providers.

During 2008 and continuing through the third quarter of 2009, economic conditions have weakened significantly and global financial markets have experienced significant liquidity challenges. Despite these challenges, we were able to obtain a limited amount of financing during 2009. Earlier in the year, we established the Line of Credit. During the year, we borrowed a total of $13.4 million under the Line of Credit. In July 2009, we completed a $25.5 million registered direct offering. In October 2009, we sold shares of our common stock and warrants to acquire shares of our common stock to three of the LOC Lenders for a total purchase price of $5.4 million. We received the purchase price in the form of promissory notes, which were then used as an offset to settle our outstanding obligations to the participating LOC Lenders under the Line of Credit and reduce our outstanding borrowings under the Line of Credit to $5.3 million.

Our independent registered public accounting firm’s report on our financial statements as of December 31, 2008 expressed doubt about our ability to continue as a going concern. The report includes an explanatory paragraph stating that there is substantial doubt about our ability to continue as a going concern due to our incurring significant losses, the use of significant cash in operations, and the lack of sufficient capital, as of the date the report was issued, to support our business plan through the end of 2009.

We are not currently generating significant revenues, and our cash and cash equivalents will continue to be depleted by our ongoing development efforts. Until we are in a position to generate significant revenues, we will need to continue to secure additional funds to continue operating as a going concern. We intend to continue to seek financing arrangements from a variety of sources to fund our development activities, which may include the issuance of debt, preferred stock, equity or a combination of these instruments. For example, in June 2009, we filed a universal shelf registration statement on Form S-3 that permits us, from time to time, to offer and sell various types of securities, including our common stock. We cannot be certain that future funding from any of these sources will be available on reasonable terms or at all.

In addition to funding for general corporate purposes, well field development and certain other general development expenses, we will need to finance each of the geothermal power projects we intend to develop. We intend to continue to evaluate a variety of alternatives to finance the development of our geothermal power projects. These alternatives could include project financing and tax equity financing, government funding from grants, loan guarantees and private activity bonds, joint ventures, the sale of one or more of our projects or interests therein, entry into pre-paid power purchase agreements with utilities or municipalities, or a merger and/or other transaction, a consequence of which could include the sale or issuance of stock to third parties. We cannot be certain that funding from any of these sources will be available on reasonable terms or at all.

Federal and state governments have recognized the financing challenges faced by many businesses and have established programs to help companies engaged in the development of renewable energy projects. These programs include loan guarantee, government grant and other programs. As a result, part of our short-term strategy to obtain additional funding includes applications for loan guarantees and government grants. For example, we have made or are in the process of making applications for funding under several stimulus programs established by the Recovery Act and other pre-existing programs. However, one of our applications for loan guarantees was denied and we were not awarded three small grants that we applied for in connection with innovative exploration activities. We cannot predict whether we will be able to successfully obtain loan guarantees or grants under government programs.

As more fully described below, we have obtained financing for the Thermo No. 1 project pursuant to our Commitment Letter with Merrill Lynch. The Commitment Letter remains in force and available for us to seek potential funding for additional projects in accordance with the terms and conditions of the Commitment Letter. However, since entering into the Commitment Letter, Merrill Lynch has experienced some significant changes in its operations, including the merger of its parent company with Bank of America Corporation, and we cannot be certain that financing under this agreement will be available to us. During this same period, we have established relationships with other investment banks, financial institutions, and other funding sources. We have lessened our overall involvement with Merrill Lynch, and the Recovery Act has provided for a grant in lieu of production tax credits, which may provide an incentive for us and Merrill Lynch to restructure the tax equity financing arrangements for the Thermo No. 1 project. While we cannot predict what our future relationship with Merrill Lynch will be, if the Commitment Letter is terminated, we will need to seek funding from other sources, which could adversely affect the timing and costs of our future projects. We intend to continue discussions with other potential sources of capital interested in investing in geothermal energy.

In order to seek funding for our projects in accordance with the Commitment Letter or other sources of project financing, we must first develop at least a portion of a well field and demonstrate that the well field is sufficient to support the planned power plant. Costs to develop a well field for our power plants can be significant. We anticipate that we will fund well field development activities from general corporate funds if available or other potential arrangements. We will need to obtain the necessary financing for well field development and develop adequate well fields to support one or more of our current projects before we will be in a position to seek financing under the Commitment Letter or other sources of project financing for the development of the applicable power plant. Due to uncertainties associated with the current economic environment, we cannot be certain that financing will be available to us on reasonable terms or at all. As a result, the timing for continued development at each of our projects is uncertain.

As part of our geothermal power project development efforts, we have made a variety of financial commitments. These commitments allow us to order and purchase generating units, transformers, pumps, cooling towers, transmission lines, power substations, fire safety equipment and other major electronic components for use in our geothermal power plants. We also have obligations to pay delay rentals and other expenses associated with the geothermal resources on properties in which we have acquired an interest. As of September 30, 2009, we were obligated to pay the vendors and the lessors of our geothermal leases approximately $11.7 million in 2009; $1.3 million in 2010; $1.4 million in 2011; $1.5 million in 2012; and $1.5 million in 2013.

Consolidated Statements of Cash Flows

Operating Activities. Cash consumed by operating activities for the nine months ended September 30, 2009 consisted primarily of a net loss of approximately $14.2 million, adjusted for approximately $3.0 million of stock-based compensation and stock issued for services, deferred financing amortization relating to raising capital through debt issuances totaling $4.9 million and depreciation, amortization and accretion expenses totaling $1.8 million. Accounts payable and accrued liabilities decreased $48.9 million to $15.5 million at September 30, 2009, which included a $26.4 million reduction in accounts payable as a result of the PWPS Agreement, as described above. Accounts receivable from the City of Anaheim increased by $0.3 million relating to the generation of electricity by our Thermo No. 1 plant. Other assets decreased by approximately $2.1 million due to applying certain deposits to the cost of the completed Thermo No. 1 transmission lines and delivery of the related transformers and receiving refunds of certain deposits due to completion of certain drilling activities. We also adjusted our net loss for the non-controlling interest in our Thermo No. 1 subsidiary totaling $0.8 million and recognized gain on derivatives totaling $12.9 million due to decreases in the fair value of our warrants that have been classified as liabilities due to price reset features contained in the warrants.

Cash consumed by operating activities for the nine months ended September 30, 2008 consisted primarily of a net loss of approximately $21.7 million, adjusted for approximately $2.6 million of stock-based compensation and stock issued for services. Accounts payable and accrued liabilities increased from $4.2 million at December 31, 2007 to $39.3 million at September 30, 2008 due primarily to accrued expenses for well field development, geothermal power plant construction, transmission line construction, and the purchase of power systems equipment. The portion of accrued liabilities relating to well field development, construction-in-progress and power systems equipment, totaling $30.5 million, has been reclassified as a non-cash item to decrease the change in accrued liabilities. Net accounts receivable increased $0.1 million reflecting the completion of the ARINC subcontract. Deferred revenues increased by approximately $0.2 million, reflecting a down payment received for our anticipated PHEV. Minority interest in operations of our subsidiary totaled $1.2 million at September 30, 2008, representing the allocated loss since the time a minority interest in the Thermo Subsidiary was acquired by a third party in connection with the equity financing arrangements for the Thermo No. 1 project.

Investing Activities. We purchase investments in marketable debt securities as a means of temporarily investing the proceeds from financings until the funds are needed for operating purposes. Due to the nature of these investments, we consider it reasonable to expect that their fair market values will not be significantly impacted by a change in interest rates, and that they can be liquidated for cash on short notice. Our investments are intended to establish a high-quality portfolio that preserves principal, meets liquidity needs, avoids inappropriate concentrations and delivers an appropriate yield in relationship to our investment guidelines and market conditions. Concentration of credit risk is normally managed by diversifying investments among a variety of high credit-quality issuers. As of September 30, 2009, we had $0.4 million of cash in our money market account, which was invested with AIM Funds earning 0.16 percent interest. Cash from our checking account is swept nightly into a variable rate interest bearing account earning 0.75 percent per annum. Our checking account balance totaled $3.4 million at September 30, 2009.

Investing activities used approximately $5.4 million of cash in the nine months ended September 30, 2009. During the nine months ended September 30, 2009, we also paid $12.0 million for construction costs relating to the Thermo No. 1 geothermal power plant and $11.9 million relating to drilling the Thermo No. 1 well field. As a result, these construction and well field expenses were primarily paid through our Thermo No. 1 restricted cash account currently totaling $12.4 million. We also purchased certain equipment for the operation of the Thermo No. 1 plant totaling $0.3 million and two new power project leases totaling $0.1 million in Oregon and Utah. Cash was provided from our marketable equity securities totaling $2.2 million that matured on March 31, 2009 that were used to pay the April 1, 2009 interest payment of the Convertible Notes (as defined below). Cash was also provided as a result of entering into the PWPS Agreement described above. Pursuant to the PWPS Agreement, we received $7.1 million as a net refund of deposits previously paid to UTCP.

Investing activities consumed approximately $75.9 million in the nine months ended September 30, 2008, reflecting deposits of $7.1 million for the purchase of electric generating units for use in the geothermal power plants we intend to develop in the future. During the first nine months of 2008, we also purchased $24.1 million of equipment for geothermal well field development projects, primarily in Utah, and we incurred construction costs on our first geothermal power plant totaling $19.4 million. We deposited approximately $3.2 million primarily with drilling vendors, transmission line contractors, and utilities to conduct transmission line capacity and routing studies on our behalf. We paid $1.8 million for land and $0.9 million for water rights in the Thermo No. 1 project area primarily for transmission line easements and for water use operations. We also paid $0.5 million in connection with the acquisition of leases and the exercise of certain options relating to interests in unproved geothermal properties in Oregon, Nevada and Utah. In connection with the issuance of the Convertible Notes, we invested a portion of the proceeds totaling $8.7 million into four discounted U.S. Treasury Strips that mature separately on each of the first four semi-annual interest payment dates of the Convertible Notes. The U.S. Treasury Strips were placed into an escrow account to secure the first four interest payments on the Convertible Notes. These expenditures were partially offset by cash provided by investing activities, including the net change in the notes receivable totaling $0.4 million. In connection with the Thermo Financing Agreements, the funds received through the financing were deposited into restricted money market fund accounts for the purposes of paying for the well field costs to complete the drilling and certain equipment costs to complete the construction of the geothermal power plant. We prepaid commissions arising from entering into the City of Anaheim power purchase agreement totaling $0.4 million. We have also made deposits to manufacture prototypes of our Transportation and Industrial Technology segment designs totaling $0.2 million. At September 30, 2008, our restricted cash totaled $9.7 million.

Financing Activities. Financing activities provided approximately $33.6 million and $85.5 million of cash in the nine months ended September 30, 2009 and 2008, respectively.

During the nine months ended September 30, 2009, we obtained the Unsecured Line of Credit to provide working capital for general corporate purposes. As of September 30, 2009, we had borrowed a total of $13.4 million under the Line of Credit. We also completed a registered direct offering in July of 2009 of 8,550,339 units (“Units”) primarily to institutional investors. Each Unit consisted of one share of our common stock, and one warrant to purchase 0.5 shares of our common stock. The investors agreed to purchase the Units for a negotiated price of $2.98 per Unit, resulting in net proceeds, after deducting placement agents’ fees and estimated offering expenses, totaling $23.6 million. During the nine months ended September 30, 2009, we made principal payments of $2.9 million on the Line of Credit balance and our Thermo Subsidiary also made principal payments of $0.5 million on the 7.00% senior secured note (non-recourse).

We completed the issuance of the Convertible Notes and the related overallotment option totaling $55.0 million on April 1, 2008. In connection with the sale of the Convertible Notes, we incurred financing fees of $2.2 million, which were paid to Merrill Lynch. We also entered into a call spread option transaction and a forward stock purchase transaction totaling $5.9 million and $15.0 million, respectively. We used the remaining net proceeds from the offering for general corporate purposes and to continue well field and other development activities for our geothermal power projects. In connection with the purchase of a BLM lease in New Mexico, we entered into a promissory note payable and received cash for $0.9 million in February 2008. On June 17, 2008, we entered into an ATM Equity Offering Sales Agreement with Merrill Lynch & Co., Merrill Lynch, Pierce, Fenner & Smith Incorporated, pursuant to which we were able to offer and sell through Merrill Lynch, as our sales agent, from time to time, shares of our common stock with an aggregate sales price of up to $25.0 million. During the third quarter of 2008, we raised net proceeds totaling $24.2 million from our participation in the ATM equity program. In addition, during the third quarter of 2008, pursuant to the Thermo Financing Agreements, we received a capital contribution for minority interest in our Thermo Subsidiary totaling $3.7 million. Under the same Thermo Financing Agreements, we also entered into an 18-year permanent non-recourse senior secured note bearing annual interest at 7.00% and received net proceeds totaling $26.1 million. We incurred deferred financing costs related to the execution of the Thermo Financing Agreements totaling $4.2 million. During the nine months ended September 30, 2008, we also received approximately $0.7 million from the exercise of other outstanding stock options and warrants.

As of September 30, 2009, we had stockholders’ equity of approximately $4.5 million, approximately $3.8 million in cash and cash equivalents and restricted cash and marketable securities of approximately $16.8 million. Our cash balance, together with cash anticipated to be provided by our operations, will not be sufficient to satisfy our anticipated cash requirements for normal operations and capital expenditures for the next twelve months ending September 30, 2010. To strengthen our financial position, we intend to seek additional funding to be used for general corporate purposes, as well as geothermal development activities, including advancing well field development activities and project permitting. We intend to seek

funding for our capital needs through the issuance of debt, preferred stock, equity, government grants, loan guarantees, prepaid power purchase agreements with utilities or municipalities, or a combination of these instruments. We may also seek to obtain financing through private activity bonds, joint ventures, the sale of one or more of our projects or interests therein, or a merger and/or other transaction, a consequence of which could include the sale or issuance of stock to third parties. We expect that we will be able to secure sufficient financing to satisfy our anticipated cash requirements for normal operations and capital expenditures through at least September 30, 2010, although current economic and market conditions will make it challenging for us to do so. We intend to seek separate financing commitments with respect to each geothermal power project we intend to develop in order to fund construction and other development costs. We cannot be certain that we can obtain financing on terms acceptable to us or at all. If we are not able to raise additional capital, we will not have sufficient cash to fund our operations. In such case, we would be required to curtail or cease operations, liquidate or sell assets, modify our current plans for plant construction, well field development and other development activities, or extend the time frame over which these activities will take place, or pursue other actions that would adversely affect future operations.

Dividends. No dividends have been paid relating to either common stock or preferred stock during the nine months ending September 30, 2009. We do not expect to pay dividends on either common stock or preferred stock in the near future.

Recent Financing Activities

Since inception, we have funded our operations primarily through the sale of equity instruments, borrowings and project financing arrangements. Most recently, on October 19, 2009, we completed a $5.4 million registered offering whereby we sold shares of our common stock and warrants to acquire shares of our common stock in consideration for promissory notes delivered by the participating LOC Lenders. On October 23, 2009, we agreed with the participating LOC Lenders to cancel the $5.4 million promissory notes as an offset to settle the equivalent outstanding amount owed to the participating LOC Lenders for their portion of the Line of Credit balance on that date. We also offered to the participation right holders from our July 6, 2009 registered direct offering, the pro rata share of up to 35% of the same units offered to the LOC Lenders. The participation rights holders declined to participate in the October 2009 registered offering. Our net proceeds from this October 2009 registered offering were approximately $5.3 million, after deducting fees and expenses.

Debt Obligations

Pursuant to the Line of Credit, we could borrow up to $15.0 million, subject to the final approval of each advance by the LOC Lenders. The commitment amounts under the Line of Credit from each of the LOC Lenders were as follows: $7.2 million from Radion; $5.3 million from Ocean Fund; $2.0 million from Primary Colors; and $500,000 from Mr. Bailey. Radion is controlled by the Chairman of our Board of Directors, Kraig Higginson.

We obtained the Line of Credit in order to provide working capital for general corporate purposes. Under the Line of Credit, advances were subject to the final approval of the LOC Lenders, and amounts borrowed under the Line of Credit accrued interest at the rate of 10% per annum. Under the Line of Credit, each LOC Lender received warrants (the “LOC Warrants”) to purchase our common stock for each advance of funds made under the Line of Credit. The number of shares underlying each LOC Warrant was equal to 50% of the total amounts funded by the applicable LOC Lender divided by the closing price of our common stock on the date of the advance. The LOC Warrants have an exercise price of $6.00 per share. As of September 30, 2009, we had borrowed $13.4 million of the Line of Credit, of which we had repaid $2.9 million of principal, and the LOC Lenders had received LOC Warrants to acquire approximately 1,755,048 shares of our common stock.

On July 22, 2009, we amended the Line of Credit agreement with the LOC Lenders. Under the amendment, we paid $2.9 million of the loan principal and approximately $0.4 million of accrued interest. After taking these payments into account, the remaining principal balance outstanding under the Line of Credit was $10.5 million. In connection with the amendment, the due date of the remaining principal balance was extended until July 31, 2010, without an early payment penalty. However, the LOC Lenders have the right to demand early repayment of all or part of the outstanding balance at any time after November 15, 2009. Pursuant to the terms of the amendment, the principal balance, and any accrued interest thereon, can be paid in the form of cash or equity securities at our sole discretion.

As noted above, on October 19, 2009, through a registered offering, we received promissory notes from the participating LOC Lenders to purchase units of one share of our common stock and one warrant to purchase 0.50 shares of our common stock for $1.68 per unit totaling $5.4 million. On October 23, 2009, we agreed with the participating LOC Lenders to cancel the $5.4 million promissory notes as an offset to settle the equivalent outstanding amount owed to the participating LOC Lenders for their portion of the Line of Credit balance on that date. After taking this transaction into account, the remaining principal balance outstanding plus accrued interest under the Line of Credit was $5.3 million.

On August 31, 2008, we finalized the project financing arrangements for the Thermo No. 1 project and entered into the Thermo Financing Agreements, including a non-recourse senior secured note that provided debt financing and tax equity capital for the Thermo No. 1 project. The project financing arrangements for the Thermo No. 1 project included approximately $31.2 million of permanent non-recourse debt financing for the Thermo No. 1 project with a fixed annual interest rate of 7.00% over 18 years. Our

Thermo Subsidiary received proceeds from the debt financing of approximately $26.1 million for construction of the Thermo No. 1 project after an original issue discount of approximately $5.0 million. After the effect of the original issue discount, the effective interest rate on the $26.1 million of debt financing proceeds is 9.50%. Pursuant to the Thermo Financing Agreements, the debt financing for the Thermo No. 1 project is held by our Thermo Subsidiary, which is responsible for debt service, all maintenance and operations expenses, and the payment of various fees and distributions to us and Merrill Lynch. Accordingly, if our Thermo Subsidiary defaults on the loan, there will be no recourse to us to pay the unpaid balance. As of September 30, 2009, our Thermo Subsidiary had made total principal payments of $0.8 million and total interest payments of $2.3 million on the 7.00% senior secured note.

On March 26, 2008, we sold $50.0 million aggregate principal amount of our 8.00% Convertible Notes due 2013 (the “Convertible Notes”) pursuant to the terms of purchase agreement, dated March 19, 2008 (the “Purchase Agreement”), between Merrill Lynch & Co., Merrill Lynch, Pierce, Fenner & Smith Incorporated (the “Initial Purchaser” or “Merrill Lynch”), and us. We granted the Initial Purchaser of the Convertible Notes a 30-day overallotment option to purchase up to an additional $5.0 million aggregate principal amount of the Convertible Notes. On April 1, 2008, we sold an additional $5.0 million aggregate principal amount of the Convertible Notes pursuant to the exercise of the Initial Purchaser’s overallotment option. The Convertible Notes were offered through the Initial Purchaser only to qualified institutional buyers in accordance with Rule 144A under the Securities Act of 1933, as amended. The net proceeds from the sale of the Convertible Notes, after deducting financing fees of $2.2 million, totaled $52.8 million. The $2.2 million of financing fees was capitalized as a deferred financing fee and is being amortized as additional interest expense over the five-year term of the Convertible Notes. On April 1, 2009, we paid the second semi-annual interest payment totaling $2.2 million to the current holders of the Convertible Notes. The Convertible Notes bear interest at a rate of 8.00% per annum, which is payable semi-annually. The Convertible Notes are convertible, at the holder’s option, at an initial conversion rate of 108.3658 shares of common stock per $1,000 principal amount of Convertible Notes, which represents a 20% conversion premium based on the last reported sale price of $7.69 per share of our common stock on March 19, 2008. Conversion of all Convertible Notes will result in the issuance of up to a maximum of 5,960,121 shares of our common stock. As of September 30, 2009, none of the Convertible Notes had been converted. The Convertible Notes are unsecured and rank on parity with all of our other existing and future unsecured indebtedness. In connection with the issuance of the Convertible Notes, we entered into a Pledge and Escrow Agreement with the Initial Purchaser that required us to use approximately $7.9 million of the proceeds from the issuance of the Convertible Notes to purchase low-risk government securities that were pledged to secure the first four interest payments on the Convertible Notes. The last interest payment secured by this pledge is due on April 1, 2010. Following that interest payment, our ability to make future interest payments on the Convertible Notes will depend on our available cash, which will likely depend on our ability to obtain additional financing. On October 1, 2009, we paid the third semi-annual interest payment totaling $2.2 million to the current holders of the Convertible Notes.

Our Commitment Letter with Merrill Lynch

On January 16, 2007, we, together with our wholly-owned subsidiary, Truckee Geothermal No. 1 SV-01, LLC, entered into the Commitment Letter with Merrill Lynch. The Commitment Letter sets forth general terms relating to the structuring and financing of up to 155 MW of geothermal power plants we intend to develop. We obtained financing commitments from Merrill Lynch to provide non-recourse financing for our Thermo No. 1 project in Utah, our Lighting Dock project in New Mexico, and our Truckee project in Nevada. During the third quarter of 2008, we finalized the project financing arrangements for the Thermo No. 1 project as described below. The financing commitments for the Lightning Dock and Truckee projects expired. However, we intend to seek new financing commitments for these projects either under the Commitment Letter or from other sources once sufficient development progress has been achieved at these projects. As described above, we cannot be certain that financing under the Commitment Letter will be available to us in the future. If the Commitment Letter is terminated, such a termination would not affect the financing already obtained for the Thermo No. 1 project, but it would terminate our ability to obtain financing under the Commitment Letter for any other projects, including the Lightning Dock and Truckee projects. If the Commitment Letter is terminated, we will need to secure funding from other sources, which could adversely affect the timing and costs of our future projects. We can also possibly substitute the United States Treasury Department grant of 30% of construction and certain drilling costs in lieu of production tax credits.

Each project funded under the Commitment Letter or other sources of project financing will be held in a special purpose entity. These entities will be responsible for the debt service, all maintenance and operations expenses and various fees and distributions to us.

The Thermo Financing

On May 16, 2008, pursuant to the Commitment Letter, we and our Thermo Subsidiary entered into a financing commitment letter (the “Thermo Commitment”) with Merrill Lynch relating to the project financing and tax equity funding for the Thermo No. 1 project. On August 31, 2008, we finalized the Thermo Financing Agreements that provide debt financing and tax equity capital for the Thermo No. 1 project.

Pursuant to the Thermo Financing Agreements, we have agreed to serve as the engineering, procurement and construction contractor and have guaranteed the completion of the construction of the Thermo No. 1 project. The useful life of the Thermo No. 1 project is expected to be approximately 35 years. The useful life of the geothermal resource is expected to be renewable and have a much longer life than the Thermo No. 1 project.

The Thermo No. 1 project is held by the Thermo Subsidiary, which is responsible for debt service, all maintenance and operations expenses, and the payment of various fees and distributions to us and Merrill Lynch. The following provides further details concerning the terms and conditions of the Thermo Financing Agreements:

•

The Thermo Financing Agreements provided for approximately $31.2 million of permanent non-recourse debt financing for the Thermo No. 1 project with a fixed annual interest rate of 7.00%. The Thermo Subsidiary received proceeds from the debt financing of approximately $26.1 million for construction of the Thermo No. 1 project after an original issue discount of approximately $5.0 million. After the effect of the original issue discount, the effective interest rate on the $26.1 million of debt financing proceeds is 9.50%. From the proceeds of the debt financing, we received approximately $14.1 million from the Thermo Subsidiary as repayment for construction costs at the Thermo No. 1 project that were incurred by us prior to closing the project financing. Thermo is responsible for debt service and is expected to retire the debt through sculpted principal payments over 18 years. The sculpted principal payments provide for larger principal payments than normal amortization in the earlier years when project cash flows are greatest. Merrill Lynch has the right to syndicate its debt obligations under the Commitment Letter and has done so for the debt associated with the Thermo No. 1 project.

•

Under the Thermo Financing Agreements, tax equity capital for the tax benefits associated with the Thermo No. 1 project was provided to the Thermo Subsidiary by the Class A Member, of which Merrill Lynch funded approximately $3.7 million, at the initial funding. The balance of the tax equity capital, totaling approximately $20.8 million, was funded in October 2008. Merrill Lynch has the right to the syndicate tax equity capital commitment under the Commitment Letter.

•

While approximately $2.9 million is currently escrowed for development distributions from the Thermo Subsidiary to us until we achieve Final Completion, it is not certain whether we will receive any portion of the escrowed amount. If we are able to achieve Final Completion of the Thermo No. 1 plant, 25% of the escrowed amount is to be paid to us on the first anniversary of the date the Thermo No. 1 project achieves Final Completion, with the balance to be due and payable 18 months after Final Completion.

•

We also expect to receive approximately $0.6 million annually from the Thermo Subsidiary for our services as managing member and operator of the Thermo No. 1 project.

•

Prior to the date when the Class A Member achieves its target rate of return (the “Flip Date”), we will be eligible to receive a management bonus if the Thermo No. 1 project performs better than expected.

•

Annual operating and maintenance costs for the Thermo No. 1 project are expected to be approximately $2.5 million and are expected to be paid by the Thermo Subsidiary from its operating revenues. These costs include a manufacturer’s guarantee and maintenance agreement provided by PWPS.

•

Any residual cash flows available after paying all expenses and debt service will be distributed 99% to Merrill Lynch and 1% to us prior to the equity Flip Date, which is anticipated to occur between the seventh and tenth year of operation, after which the distribution split will be 5% to Merrill Lynch and 95% to us. Post-Flip Date distributable cash flows are expected to average approximately $1.7 million per year until the debt service is completed in year eighteen and approximately $6.0 million per year after the eighteenth year for the rest of the useful life of the Thermo No. 1 project plus certain residual tax benefits.

•

Our equity contribution to the Thermo Subsidiary of approximately $29.0 million was comprised primarily of the well field.

In connection with the Thermo Financing Agreements and the Thermo No. 1 project financing, we and our affiliates have entered into certain other ancillary agreements, including a pledge agreement with Deutsche Bank to secure the payment and performance of the Thermo No. 1 project under the Credit Agreement (the “Pledge Agreement”). The Pledge Agreement grants Deutsche Bank a continuing security interest in and lien on certain membership interests or other interests in the Thermo No. 1 project. We have also entered into a Guaranty Agreement in favor of the Thermo No. 1 project and the Class A Member, pursuant to which we guarantee certain obligations of certain parties to the Thermo Financing Agreements.

As discussed above, certain changes made by the Recovery Act relating to the use of production tax credits have made it beneficial for us and the Thermo No. 1 financing providers to restructure the Thermo No. 1 financing arrangements. We are working with the debt holder and the Class A Member of the Thermo No. 1 plant to restructure the tax equity ownership of the Thermo Subsidiary in an attempt to obtain certain benefits under the Recovery Act, which could include grants from the United States Treasury Department of up to 30% of the cost of construction and certain drilling costs for the Thermo plant in lieu of receiving production tax credits for the production of electricity. As part of these restructuring discussions, we intend to seek to extend the deadline for Final Completion or otherwise renegotiate the applicability of the additional penalties.

Potential Additional Financing Commitments

The Commitment Letter gives Merrill Lynch the exclusive right to provide or arrange financing for up to 100 MW of substantially similar geothermal power plants we intend to develop, other than certain excluded financings. Merrill Lynch also has a right of first refusal with respect to the financing of an additional 55 MW of geothermal plants to be developed by us. If Merrill Lynch provides a financing commitment proposal with respect to any future projects, such financing commitment will be subject to satisfactory due diligence and certain other conditions and the execution of a separate commitment letter relating to such project. Until Merrill Lynch has financed 20 MW of geothermal power projects under the Commitment Letter, we are generally obligated to accept any financing commitment proposed by Merrill Lynch that has terms similar to or more favorable than the financing commitment relating to the Thermo No. 1 plant. After Merrill Lynch has financed 20 MW of geothermal power projects under the Commitment Letter, we may enter into certain excluded financings with parties other than Merrill Lynch. Prepaid power purchase agreements, government grants and joint venture funding arrangements are considered excluded financings to the Commitment Letter.

As described above, we cannot be certain that financing under the Commitment Letter will be available to us in the future. If the Commitment Letter is terminated, we will need to secure funding from other sources, which could adversely affect the timing and costs of our future projects.

The timing of construction for the geothermal power plants we intend to develop, as well as the specific sites we choose to develop and construct, will depend on a number of factors, including drilling results, permitting and our ability to obtain adequate financing.

Structuring Fees and Other Consideration

As part of the Commitment Letter, we have agreed to pay Merrill Lynch certain non-refundable structuring fees in connection with the closing of each funding transaction. The structuring fees will initially be 4%, but will decrease for future financings once the cumulative financing commitment under the Commitment Letter reaches certain levels.

As additional consideration, we granted Merrill Lynch warrants to acquire shares of our common stock. The warrants will vest and become exercisable in increments over the term of the Commitment Letter based on the actual funding provided. The exercise price of the warrants is subject to adjustment upon any dilutive issuance by us. In accordance with the anti-dilution protection included in the warrants, the issuance of the Convertible Notes during the first quarter of 2008, the issuance of common stock during the third quarter of 2008, the issuance of common stock in connection with our private placement during the fourth quarter of 2008, the issuance of warrants in connection with the line of credit borrowings during the second quarter of 2009, the issuance of common stock and warrants in connection with the $25.5 million registered direct offering and subsequent issuance of shares to Fletcher pursuant to the terms of our agreement with Fletcher during the third quarter of 2009, and the issuance of common stock and warrants to the participating LOC Lenders in connection with the repayment of certain balances owed under the Line of Credit resulted in a reduction of the original strike prices of the warrants from a range of $14.98 to $19.71 to a range of $11.09 to $13.96. On August 31, 2008, warrants to acquire 1,350,000 shares of our common stock vested in connection with the closing of the project financing arrangements for the Thermo No. 1 project.

In general, warrants that vest in connection with the funding of earlier projects will be greater in number and have a lower exercise price, and warrants that vest in connection with the funding of later projects will be fewer in number and have a higher exercise price. Under certain circumstances, a reduced percentage of the warrants will vest if we reject a Merrill Lynch funding proposal for a project and subsequently obtain funding for such project from another party or, in certain circumstances, from Merrill Lynch. Any vested warrants may be called for cancellation by us if certain conditions have been met, including minimum market price requirements relating to our common stock. We have agreed to grant additional warrants to Merrill Lynch upon funding of any of the additional 55 MW of geothermal power projects with respect to which Merrill Lynch has a right of first refusal. The exercise price of any such additional warrants will be based on the volume weighted average price of our common stock over a 20 consecutive trading day period prior to the issuance of such warrants. Pursuant to a registration rights agreement between us and Merrill Lynch, we have agreed to file one or more registration statements covering the resale of the warrants issued pursuant to the Commitment Letter, as well as the resale of the shares of common stock issuable pursuant to the exercise of such warrants. When a series of warrants vests, we are obligated to register these securities for resale and cause the registration statement to remain continuously effective until all vested warrants and the shares of common stock issuable upon exercise of the warrants covered by such registration statement have been sold or may be sold without restriction pursuant to Rule 144 of the Securities Act of 1933, as amended. Merrill Lynch agreed to permit us to defer our obligation to register the resale of the warrants that vested in connection with the funding of the Thermo No. 1 project until such registration is requested by Merrill Lynch.

Potential Obligations in Connection with Future Financing Arrangements

In order to execute our business strategy and continue our business operations, we will need to secure additional funding from other sources through the issuance of debt, preferred stock, equity or a combination of these instruments. Any issuance of securities by us could trigger additional obligations under our prior financing arrangements, such as adjustments to the exercise price of outstanding warrants or the issuance of additional shares of common stock.

The warrants we issued to Fletcher contain an exercise price reset feature that may be triggered upon certain events, such as the issuance of shares of common stock at a price below the maximum warrant exercise price. If triggered, the exercise price reset feature results in a downward adjustment to the maximum warrant exercise price to an amount equal to the average of the then current maximum exercise price and the lowest price at which shares are issued on the date when the event occurred. The units we issued in our registered direct offering on July 6, 2009 triggered a price reset with respect to the Fletcher warrants resulting in a reduction of the maximum exercise price from $6.00 to $3.99 per share. Subsequent to September 30, 2009, we also issued units in the October 2009 registered offering to the three participating LOC Lenders that triggered a price reset with respect to the Fletcher warrants resulting in a further reduction of the maximum exercise price from $3.99 to $2.56 per share.

In addition, our agreement with Fletcher requires us to issue additional shares to Fletcher if, prior to the first-year anniversary of the 2008 private placement transaction or any exercise of warrants by Fletcher, we engage in a public disclosure of our intention or agreement to engage in a sale or issuance of any shares of, or securities convertible into, exercisable or exchangeable for, or whose value is derived in whole or in part from, any shares of any class of our capital stock. As a result of the issuance of the units in the July 2009 registered direct offering, we issued 445,901 additional shares of common stock to Fletcher in August 2009. As a result of the issuance of units in the October 2009 registered offering to the three participating LOC Lenders, we are also required to issue 136,219 additional shares of our common stock to Fletcher. Any issuance of shares under this provision of the Fletcher agreement reduces share-for-share the maximum number of shares that may be issued to Fletcher under the warrants held by Fletcher.

The terms of the Merrill Lynch warrants provide for anti-dilution protection, which adjusts the exercise price of each warrant, from time to time upon the occurrence of certain events, including the issuance of shares of common stock at a price lower than the exercise price of the Merrill Lynch warrants, stock splits, dividends, recapitalizations and similar events. Upon the occurrence of such events, the exercise price of the warrants will be appropriately adjusted. The issuance of common stock and warrants in connection with the $25.5 million registered direct offering and issuance of shares to Fletcher, and the issuance of common stock and warrants to the three participating LOC Lenders in connection with the repayment of certain balances owed under the line of credit resulted in a further reduction of the strike prices to a range of $11.09 to $13.96.

In connection with the registered direct offering that we completed on July 6, 2009, we granted the investors the right, subject to certain exceptions, to participate in any future equity financing by us prior to December 30, 2010. The participation right allows the registered direct investors to purchase up to 35% of the securities offered. Although, the holders of these participation rights were eligible to participate in the October 19, 2009 registered offering and purchase their pro rata share of up to 35% of the units offered to the LOC Lenders as discussed above, none of the participation rights holders exercised their rights to participate in the registered offering which closed on October 22, 2009.

Off-Balance Sheet Arrangements

As of September 30, 2009, we had the following off-balance sheet arrangements as defined by Item 303(a)(4)(ii) of SEC Regulation S-K.

In connection with the Thermo Financing Agreements, we entered into an Amended and Restated Purchase Contract with UTCP relating to the purchase of generating units for the Thermo No. 1 project. The agreements relating to the purchase of the power generating units have since been assigned from UTCP to PWPS. Under the terms of the Amended and Restated Purchase Contract, PWPS is required to allow us to retain a certain portion of the purchase price of the generating units pending the successful completion of the Thermo No. 1 project. If the Thermo No. 1 project is not successfully completed as a result of a problem with the generating units, then we will keep the retained portion of the purchase price as a liquidated damages payment. If the Thermo No. 1 project is not successfully completed as a result of any other reason, we will reimburse PWPS for any liquidated damages paid by PWPS. To secure payment of our obligations to reimburse PWPS under the Amended and Restated Purchase Contract, we provided a security interest to PWPS in five patents relating to our Transportation & Industrial segment. We are unable to estimate the maximum potential obligation we may have for future reimbursement payments under the Amended and Restated Purchase Contract at this time. We believe that the likelihood that we will be obligated to reimburse PWPS for liquidated damages under the Amended and Restated Purchase Contract is “remote” and, accordingly, no liability was recorded for the quarter ended September 30, 2009.

Contractual Obligations and Commitments

We lease our corporate office located at 5152 North Edgewood Drive, Suite 200, Provo, Utah. Our corporate office lease expires on December 31, 2011. We also lease our Symetron™ testing facility in Utah County, Utah. Our testing facility lease expired on June 1, 2009. We are currently leasing the test facility on a month-to-month basis and evaluating whether to extend this lease. The corporate offices and facilities are well maintained and in good condition.

During 2008, we entered into an agreement with a private land owner adjacent to our geothermal leased property in Hidalgo County, New Mexico. Under the agreement, we are permitted to store our power generating units, cooling tower equipment, pumps and other equipment that have been delivered to New Mexico for construction of our Lightning Dock geothermal power plant. All equipment is stored outside and the agreement continues on a month-to-month basis until all equipment is removed from the property.

Total rent expense for all of our office space, testing facilities and outdoor storage site leases for the nine months ended September 30, 2009 and 2008, was approximately $343,600 and $231,000 respectively.

On April 21, 2008, our wholly-owned subsidiary entered into a Road Construction and Maintenance Agreement with Beaver County, Utah to post an improvement bond, or mutually agreed upon equivalent, in the amount of $100,000. We are currently in the process of securing the improvement bond.

The table below summarizes our operating lease obligations pursuant to our non-cancelable leases, our long-term debt and our executed purchase obligations as of September 30, 2009:


	Payments due by period
	Total		Less than 1 year		1 to 3 years		3 to 5 years		More than 5 years
Operating Lease Obligations	$	957,540	$	419,948	$	537,592	$	—	$	—
Long Term Debt (principal and interest)		137,058,651		17,976,896		14,798,850		65,200,817		39,082,088
Purchase Obligations		19,935,750		11,683,322		2,713,992		3,010,668		2,527,768

Total	$	157,951,941	$	30,080,166	$	18,050,434	$	68,211,485	$	41,609,856

The contractual purchase obligations set forth above are not recorded as liabilities in our consolidated financial statements. Our equipment purchase obligations are recorded as liabilities when the equipment is received by us or the risk of loss has been legally transferred to us. Amounts payable pursuant to our operating leases are expensed during the reporting period in which the amounts are due and payable. The operating lease obligations include operating leases for our corporate headquarters and our testing facility.

Our obligations to PWPS relate primarily to purchase agreements for the purchase of power generating units. In 2007 and 2008 we entered into a number of agreements with UTPC for the purchase of power generating units to be used in connection with the construction of our geothermal power plant at the Thermo No. 1 project and for future projects. These agreements were subsequently assigned to PWPS. In April 2009, we entered into the PWPS Agreement pursuant to which we and PWPS agreed to terminate certain agreements that had been assigned to PWPS from UTCP. Under the PWPS Agreement, we agreed to transfer title to 113 power generating units to PWPS, free and clear of all liens and encumbrances, which were previously delivered to us at our Thermo No. 1 project site and the Lightning Dock project site and which were being held for us at PWPS manufacturing facilities, thereby significantly reducing our total purchase obligations. We and PWPS also agreed that, until the earlier of April 9, 2012 and the date on which we have installed 200 power generating units (in addition to the power generating units installed at our Thermo No. 1 project site), PWPS will be the exclusive provider of heat-to-electricity equipment used for any merchant power plant project developed by us or any of our affiliates so long as PWPS can meet the needs of the particular project.

The purchase obligations set forth in the table above include a series of purchase and service agreements whereby certain vendors have agreed to provide certain equipment and services to us. As of September 30, 2009, we were obligated to pay the vendors approximately $11.7 million in 2009; $1.3 million in 2010; $1.4 million in 2011; $1.5 million in 2012; and $1.5 million in 2013, as reflected in the table above. Since our geothermal lease agreements are not considered to be operating leases the purchase obligations include delay rental payments that we have agreed to make in order to maintain our granted rights to the leased properties.

On August 31, 2008, we finalized the project financing arrangements which provided project financing and tax equity capital for the Thermo No. 1 project. Pursuant to the project financing arrangements, the Thermo Subsidiary received proceeds of approximately $29.8 million pursuant to the initial funding and the Thermo Subsidiary received approximately $20.8 million of additional proceeds on October 20, 2008. These proceeds have been restricted for use and which a portion of the proceeds will be used to for approximately $3.3 million of the $4.3 million outstanding purchase obligation relating to the generating units installed at the Thermo No. 1 power plant which is included in the purchase obligations reflected in the table above.

Recently Issued Accounting Pronouncements

In June 2009, the FASB issued new accounting guidance relating to codification of accounting principles and authoritative hierarchy. On the effective date of this Statement, the Codification superseded all existing non-SEC accounting and reporting standards. All other non-grandfathered, non-SEC accounting literature not included in the Codification will become non-authoritative. The new accounting guidance was effective for financial statements issued for interim and annual periods ending after September 15, 2009. We implemented this guidance on July 1, 2009, and it had no material impact on our financial condition, results of operations, or cash flows.

In June 2009, the FASB issued new accounting guidance to improve financial reporting by enterprises involved with variable interest entities and to provide more relevant and reliable information to users of financial statements. This new accounting guidance becomes effective as of the beginning of each reporting entity’s first annual reporting period that begins after November 15, 2009, for interim periods within that first annual reporting period, and for interim and annual reporting periods thereafter. Based upon current assumptions, we believe that adoption of this new accounting guidance will not immediately change the designation of our Thermo Subsidiary from being a consolidated entity for financial statement purposes. However, we will continue to evaluate events under this new pronouncement that may result in the deconsolidation of the Thermo Subsidiary as they arise.

In September 2009, the FASB issued new accounting guidance to provide implementation guidance for uncertainty in income taxes for “pass through entities.” The amendments clarify that management’s determination of the taxable status of the entity is a tax position subject to the standards required for accounting for uncertainty in income taxes. This new guidance became effective on July 1, 2009. We implemented this guidance on July 1, 2009, and it had no material impact on our financial condition, results of operations, or cash flows.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

Disclosures About Market Risk

In addition to the risks inherent in our operations, we are exposed to financial, market, political and economic risks. The following discussion provides information regarding our exposure to the risks of changing interest rates.

As of September 30, 2009, we had approximately $3.8 million in cash and cash equivalents and $12.5 million in restricted cash, that were invested primarily in low risk money market accounts and certificates of deposit until needed for operating and other activities. Current money market rates range from approximately 0.00% to 0.16%. The money market interest rates have declined from 1.32% over the last nine months. A review of our money market accounts indicated that no impairment occurred during the nine months ended September 30, 2009 and no write-down in fair value is considered necessary.

Concurrent with the issuance of the Convertible Notes, we entered into a call spread option transaction with an affiliate of Merrill Lynch for the cost of $5.9 million. The call spread option transaction was intended to reduce the potential dilution of our common stock upon conversion of the Convertible Notes. The Convertible Notes are convertible at any time prior to maturity at a conversion rate of 108.3658 shares per $1,000 principal amount of Convertible Notes, which represents a conversion price of $9.23 per share, subject to adjustment. The call spread option transaction allows us to receive up to 934,118 shares of our common stock at $9.23 per share from the call spread option transaction holder, equal to the amount of our common stock related to the excess conversion value that we would deliver to the holders of the Convertible Notes upon conversion. The number of shares that we would receive pursuant to the call spread option transaction declines after the market price exceeds $11.15 per share to reflect the aggregate market value of $10.4 million of our common stock. The call spread option transaction will terminate upon the earlier of the maturity date of the Convertible Notes or the first day all of the Convertible Notes are no longer outstanding due to conversion or otherwise. Our ability to receive the maximum aggregate market value of shares of our common stock pursuant to the call spread option transaction is dependent upon the performance of our stock price and the desire of holders to convert the Convertible Notes into shares of our common stock. If holders fail to convert the Convertible Notes into shares of our common stock prior to the due date in 2013, the call spread option transaction will expire without the shares of our common stock being delivered to us.

Concurrent with the issuance of the Convertible Notes, we entered into a forward stock purchase transaction with Merrill Lynch at a cost of $15.0 million. Pursuant to the forward stock purchase transaction we are entitled to receive from Merrill Lynch 1.95 million shares of our common stock on or about the maturity date of the Convertible Notes to reduce the potential dilution to our common stock upon conversion of the Convertible Notes. If the stock price falls below $7.69 per share on or about the maturity date of the Convertible Notes, the aggregate value of our common stock received would be less than the amount paid for the forward stock purchase transaction.

We are exposed to losses in the event of nonperformance by the counterparties on the instruments described above.

Item 4.

Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Our management, with the participation of our chief executive officer and chief financial officer, evaluated the effectiveness of our disclosure controls and procedures as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934 as of the end of the period covered by this Quarterly Report on Form 10-Q. In designing and evaluating the disclosure controls and procedures, our management recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of disclosure controls and procedures must reflect the fact that there are resource constraints and that management is required to apply its judgment in evaluating the benefits of possible controls and procedures relative to their costs. The design of any disclosure controls and procedures also is based in part upon certain assumptions about the likelihood of future events and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions.

Based on that evaluation, our principal executive officer and chief financial officer concluded that, as of September 30, 2009, our disclosure controls and procedures were, subject to the limitations noted above, effective to provide reasonable assurance that information we are required to disclose in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms, and that such information is accumulated and communicated to our management, including our principal executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control Over Financial Reporting

We continued to formalize documentation and perform testing of our financial processes during the period covered by this Quarterly Report on Form 10-Q. There was no change in our internal control over financial reporting that occurred during the third quarter of 2009, that materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1.

Legal Proceedings

Item 1A.

Risk Factors.

The following risk factors, among others, could cause our financial performance to differ significantly from the goals, plans, objectives, intentions and expectations expressed in this report. If any of the following risks and uncertainties or other risks and uncertainties not currently known to us or not currently considered to be material actually occur, our business, financial condition or operating results could be harmed substantially.

We will need to secure additional financing and if we are unable to secure adequate funds on terms acceptable to us, we will be unable to support our business requirements, build our business or continue as a going concern.

At September 30, 2009, we had approximately $3.8 million in cash and cash equivalents and $16.8 million in restricted cash and marketable securities. As such, our cash balances are not sufficient to satisfy our anticipated cash requirements for normal operations and capital expenditures for the foreseeable future. Our operating activities used approximately $22.9 million of cash for the year ended December 31, 2008 and approximately $24.7 million of cash during the nine months ended September 30, 2009. We have incurred substantial losses since inception and we are not operating at cash breakeven. Obligations that may exert further pressure on our liquidity situation include the obligation to repay remaining amounts borrowed under our Line of Credit, which are due in July 2010, but may need to be repaid as early as November 2009.

Our continuation as a going concern is dependent on efforts to secure additional funding, increase revenues, reduce expenses, and ultimately achieve profitable operations. The current economic environment will make it challenging for us to access the funds that we need, on terms acceptable to us, to successfully pursue our development plans and operations. The cost of raising capital in the debt and equity capital markets has increased substantially while the availability of funds from those markets generally has diminished significantly. If we are unable to raise sufficient, additional capital on reasonable terms, we may be unable to satisfy our existing obligations, or to execute our plans. In such case, we would be required to curtail or cease operations, liquidate or sell assets, modify our current plans for plant construction, well field development or other development activities, or pursue other actions that would adversely affect future operations. Further, reduction of expenditures could have a negative impact on our business. A reduction of expenditures would make it more difficult for us to execute our plans to develop geothermal power plants in accordance with our expectations. It would also make it more difficult for us to conduct adequate research and development and other activities necessary to commercialize our Symetron technologies.

From time to time, we have raised additional capital through the sale of equity and equity-related securities. Most recently, on October 19, 2009, we completed a $5.4 million registered offering to our line of credit lenders. Our net proceeds from this October 2009 registered offering were approximately $5.3 million, after deducting fees and expenses. We accepted $5.4 million in promissory notes from the line of credit lenders to pay for the shares and warrants purchased. On October 23, 2009, we agreed with the participating LOC Lenders to cancel the $5.4 million promissory notes as an offset to settle the equivalent outstanding amount owed to the participating LOC Lenders for their portion of the Line of Credit balance on that date.

In order to execute our business strategy and continue our business operations, we will need to secure additional funding from other sources through the issuance of debt, preferred stock, equity or a combination of these instruments. We may also seek to obtain financing through a joint venture, the sale of one or more of our projects or interests therein, entry into pre-paid power purchase agreements with utilities or municipalities, a merger and/or other transaction, a consequence of which could include the sale or issuance of stock to third parties. We cannot be certain that funding that we seek from any of these sources will be available on reasonable terms or at all.

Our Commitment Letter with Merrill Lynch sets forth certain general terms relating to the structure and financing of up to 155 MW of geothermal power plants we intend to develop. We also received financing commitments for two other projects, but these financing commitments subsequently expired. If Merrill Lynch elects to provide or arrange a financing commitment with respect to any additional projects, such financing commitment will be subject to satisfactory due diligence, the execution of a separate commitment letter relating to such project and certain other conditions.

The Commitment Letter remains in force and available for us to seek potential funding for additional projects in accordance with the terms and conditions of the Commitment Letter. However, since entering into the Commitment Letter, Merrill Lynch has experienced some significant changes in its operations, including the merger of its parent company with Bank of America Corporation, and we cannot be certain that financing under this agreement will be available to us. During this same period, we have established relationships with other investment banks, financial institutions, and other funding sources. We have lessened our overall involvement with Merrill Lynch, and the Recovery Act has provided for a grant in lieu of production tax credits, which gives us an alternative to Merrill Lynch tax credit equity. While we cannot predict our future relationship with Merrill Lynch, if the Commitment Letter is terminated, we will need to seek funding from other sources, which could adversely affect the timing and costs of our future projects.

Even if we are able to obtain funding for the development of additional projects pursuant to the Commitment Letter or other similar sources, we will need additional financing to cover general operating expenses and certain development expenses that are not covered by the Commitment Letter.

If we raise additional capital through the issuance of equity or securities convertible into equity, our stockholders may experience dilution. Any new securities we issue may have rights, preferences or privileges senior to those of the holders of our common stock, such as dividend rights or anti-dilution protections. We have previously issued warrants to acquire our common stock in connection with certain transactions. Some of these warrants continue to be outstanding and contain anti-dilution provisions. Pursuant to these anti-dilution provisions, the exercise price of the applicable warrants will be adjusted if we issue equity securities or securities convertible into equity securities at a price lower than the exercise price of the applicable warrants.

We may also seek to secure additional financing by incurring indebtedness. However, as a result of concerns about the stability of financial markets generally and the solvency of counterparties specifically, the cost of obtaining money from the credit markets generally has increased as many lenders and institutional investors have increased interest rates, enacted tighter lending standards, refused to refinance existing debt at maturity on terms that are similar to existing debt, and reduced, or in some cases ceased, to provide funding to borrowers. In addition, any indebtedness we incur could constrict our liquidity, result in substantial cash outflows, and adversely affect our financial health and ability to obtain financing in the future. Any such debt would likely contain restrictive covenants that may impair our ability to obtain future additional financing for working capital, capital expenditures, acquisitions, general corporate or other purposes, and a substantial portion of cash flows, if any, from our operations may be dedicated to interest payments and debt repayment, thereby reducing the funds available to us for other purposes. Any failure by us to satisfy our obligations with respect to these potential debt obligations would likely constitute a default under such credit facilities.

We have limited operating experience and revenue, and we are not currently profitable. We expect to continue to incur net losses for the foreseeable future, and we may never achieve or maintain profitability.

We have a limited operating history and, from our inception, we have earned limited revenue from operations. We have incurred significant net losses in each year of our operations, including a net loss applicable to common stockholders of approximately $45.5 million and $14.2 million for the year ended December 31, 2008 and the nine months ended September 30, 2009, respectively. As a result of ongoing operating losses, we had an accumulated deficit of approximately $103.7 million on cumulative revenues from inception of approximately $2.3 million as of September 30, 2009. In addition, at September 30, 2009, we had negative working capital totaling $19.0 million.

Under our current growth plan, we do not expect that our revenues and cash flows will be sufficient to cover our expenses unless we are able to successfully place a number of power plants in service. As a result, we expect to continue to incur substantial losses until we are able to generate significant revenues. Our ability to generate significant revenues and become profitable will depend on many factors, including our ability to:

•

secure adequate capital;

•

identify and secure productive geothermal sites;

•

verify that the properties in which we have acquired an interest contain geothermal resources that are sufficient to generate electricity;

•

acquire electrical transmission and interconnection rights for geothermal plants we intend to develop;

•

enter into power purchase agreements for the sale of electrical power from the geothermal power plants we intend to develop at prices that support our operating and financing costs;

•

enter into additional tax equity partner agreements with potential financing partners that will provide for the allocation of tax benefits to them and for the contribution of capital by them to our projects or to successfully utilize new incentive provisions being implemented by the United States government;

•

finance and complete the development of multiple geothermal power plants;

•

manage construction, drilling and operating costs associated with our geothermal power projects;

•

successfully license commercial applications of our motor, generator and drive technologies;

•

enforce and protect our intellectual property while avoiding infringement claims;

•

comply with applicable governmental regulations; and

•

attract and retain qualified personnel.

Our independent registered public accounting firm’s report on our 2008 financial statements questions our ability to continue as a going concern.

Our independent registered public accounting firm’s report on our financial statements as of December 31, 2008 and 2007 and for the three year period ended December 31, 2008 expresses doubt about our ability to continue as a going concern. Their report includes an explanatory paragraph stating that there is substantial doubt about our ability to continue as a going concern due to the lack of sufficient capital, as of the date their report was issued, to support our business plan through the end of 2009.

We will need to secure additional financing in the future and if we are unable to secure adequate funds on terms acceptable to us, we will be unable to support our business requirements, build our business or continue as a going concern. Accordingly, we can offer no assurance that the actions we plan to take to address these conditions will be successful. Inclusion of a “going concern qualification” in the report of our independent accountants or any future report may have a negative impact on our ability to obtain financing and may adversely impact our stock price.

The current worldwide political and economic conditions, specifically disruptions in the capital and credit markets, may materially and adversely affect our business, operations and financial condition.

Recently, general worldwide economic conditions have experienced a downturn due to the credit conditions resulting from the subprime-mortgage turmoil and other factors, slower economic activity, concerns about inflation and deflation, decreased consumer confidence, reduced corporate profits and capital spending, recent international conflicts, recent terrorist and military activity, and the impact of natural disasters and public health emergencies. If the current market conditions continue or worsen, our business, operations and financial condition will likely be materially and adversely affected.

The United States credit and capital markets have become increasingly volatile as a result of adverse conditions that have caused the failure and near failure of a number of large financial services companies. If the capital and credit markets continue to experience volatility and the availability of funds remains limited, our ability to obtain needed financing on favorable terms could be severely limited. In the current environment, lenders may seek more restrictive lending provisions and higher interest rates that may reduce our ability to obtain financing and increase our costs. Also, lenders may simply be unwilling or unable to provide financing. Although we may seek additional funding for our projects in accordance with our Commitment Letter with Merrill Lynch, we cannot predict whether Merrill Lynch’s ability or willingness to provide financing to us will be adversely affected if current market conditions continue or worsen.

Longer term disruptions in the capital and credit markets as a result of uncertainty, changing or increased regulation, reduced alternatives or failures of significant financial institutions could adversely affect our access to capital needed for our operations and development plans. If we are unable to obtain adequate financing, we could be forced to reduce, delay or cancel planned capital expenditures, sell assets or seek additional equity capital, or pursue other actions that could adversely affect future operations. Failure to obtain sufficient financing or a reduction of expenditures may cause delays and make it more difficult to execute our plans to develop geothermal power plants in accordance with our expectations. It would also make it more difficult to conduct adequate research and development and other activities necessary to commercialize our Symetron™ technologies.

The market price for our common stock has experienced significant price and volume volatility and is likely to continue to experience significant volatility in the future. Such volatility may cause investors to experience dramatic declines in our stock price from time to time, may impair our ability to secure additional financing and may otherwise harm our business.

The closing price of our common stock fluctuated from a low of $1.53 per share to a high of $4.71 per share from January 1, 2009 to September 30, 2009. Our stock price is likely to experience significant volatility in the future as a result of numerous factors outside of our control, including the level of short sale transactions. As a result, the market price of our stock may not reflect our intrinsic value. In addition, following periods of volatility in our stock price, there may be increased risk that securities litigation, governmental investigations or enforcement proceedings may be instituted against us. Any such litigation, and investigation or other procedures, regardless of merits, could materially harm our business and cause our stock price to decline due to potential diversion of management attention and harm to our business reputation.

In addition, if the market price for our common stock remains below $5.00 per share, our common stock may be deemed to be a penny stock, and therefore subject to rules that impose additional sales practices on broker-dealers who sell our securities. For example, broker-dealers must make a special suitability determination for the purchaser and have received the purchaser’s written consent to the transaction prior to sale. Also, a disclosure schedule must be delivered to each purchaser of a penny stock, disclosing sales commissions and current quotations for the securities. Monthly statements are also required to be sent disclosing recent price information for the penny stock held in the account and information on the limited market in penny stocks. Because of these additional conditions, some brokers may choose to not effect transactions in penny stocks. This could have an adverse effect on the liquidity of our common stock.

The volatility in our stock price could impair our ability to raise additional capital. Further, to the extent we do raise additional funds through equity financing, we may need to issue such equity at a substantial discount to the market price for our stock. This, in turn, could contribute to the volatility in our stock price. In addition, in connection with future equity financing transactions, we may be required to issue additional shares of stock to investors who purchased securities from us in prior transactions, and future equity financings may result in adjustments to the exercise price of our outstanding warrants. These factors could also contribute to volatility in our stock price.

The geothermal power production development activities of our Power Systems segment may not be successful.

We are devoting a substantial amount of our available resources to the power production development activities of our Power Systems segment. To date, we have placed one geothermal power plant in service, and we continue our efforts to ramp up production of that plant. However, our ability to successfully complete that plant and develop additional projects is uncertain.

In connection with our first power plant, Thermo No. 1, we have experienced unexpected difficulties and delays in developing a well field that will produce sufficient heat to operate the plant at full capacity. While we have gained valuable experience that could benefit future projects, we could experience similar unexpected difficulties at future projects, which could adversely affect the economics of those projects. As a result, we cannot be certain that we will be able to operate any of our plants at full capacity on an economic basis.

Our success in developing a particular geothermal project is contingent upon, among other things, locating and developing a viable geothermal site, negotiation of satisfactory engineering, procurement and construction agreements, negotiation of satisfactory power purchase agreements, receipt of required governmental permits, obtaining interconnection rights, obtaining transmission service rights, obtaining adequate financing, and the timely implementation and satisfactory completion of construction. We may be unsuccessful in accomplishing any of these necessary requirements or doing so on a timely basis. Generally, we must also incur significant expenses for preliminary engineering, permitting, legal fees and other expenses before we can even determine whether a project is feasible. Project financing is not typically available for these preliminary activities.

Financing needed to develop geothermal power projects may be unavailable.

A substantial capital investment will be necessary to develop each geothermal power project our Power Systems segment seeks to develop. Our continued access to capital through project financing or other arrangements is necessary for us to complete the geothermal power projects we plan to develop. We have had difficulty raising the capital we need in the current economic environment, and our future attempts to secure capital on acceptable terms may not be successful.

Market conditions and other factors may not permit us to obtain financing for geothermal projects on terms favorable to us. Our ability to arrange for financing on a substantially non-recourse or limited recourse basis, and the costs of such financing, are dependent on numerous factors, including general economic and capital market conditions, credit availability from banks, investor confidence, the success of our projects, the credit quality of the projects being financed, the political situation in the state in which the project is located and the continued existence of tax and securities laws which are conducive to raising capital. If we are not able to obtain financing for our projects on a substantially non-recourse or limited recourse basis, or if we are unable to secure capital through partnership or other arrangements, we may have to finance the projects using recourse capital such as direct equity investments, which would have a dilutive effect on our common stock. Also, in the absence of favorable financing or other capital options, we may decide not to pursue certain projects. Any of these alternatives could have a material adverse effect on our growth prospects and financial condition.

Other than certain excluded financings, the Commitment Letter gives Merrill Lynch the exclusive right to provide or arrange financing for up to 100 MW of substantially similar geothermal power plants we intend to develop and also has a right of first refusal with respect to the financing of an additional 55 MW of substantially similar geothermal power plants we intend to develop. Pursuant to the Commitment Letter, we have obtained project financing for our Thermo No. 1 project. Any determination on the part of Merrill Lynch to provide financing commitments is subject to the satisfaction of additional due diligence and other conditions, and the funding obligations pursuant to any existing financing commitment, are subject to the satisfaction of certain conditions precedent and various other factors, including but not limited to, satisfactory completion of due diligence, the absence of any material adverse change in our business, liabilities, operations, condition (financial or otherwise) or prospects, the execution of acceptable definitive documentation, receipt of customary legal opinions acceptable to Merrill Lynch, satisfactory market conditions and necessary approvals. Accordingly, there can be no assurance that Merrill Lynch will ultimately provide additional funding under the Commitment Letter. Further, Merrill Lynch’s rights under the Commitment Letter, including its right to generally match alternative financing proposals, may make it difficult for us to obtain financing proposals from other sources.

In addition, the tax benefits originating from geothermal power projects are anticipated to provide a significant portion of the funding of the geothermal projects. This tax equity has traditionally been driven by the tax liability of the major financial industry companies. Many of these companies are currently experiencing significantly reduced income or incurring substantial losses. As a result, they are seeking fewer tax-advantaged investments and this may reduce the amount of readily available tax credit equity available for our geothermal projects.

The United States Congress recently passed the Recovery Act that was subsequently signed into law by President Obama. The Recovery Act provides certain economic incentives, such as clean energy grants, that are designed to provide developers of geothermal and other clean energy projects with cash to help fund the projects. These incentives are designed, in part, to address some of the current problems in the tax equity markets and provide an alternative funding mechanism. Accordingly, part of our short-term strategy to obtain additional funding includes applications for loan guarantees and government grants. However, one of our applications for loan guarantees was denied, and we cannot predict whether we will be able to successfully obtain loan guarantees or grants under these new government programs.

In order to finance the development of our geothermal power projects, we may transfer a portion of our equity interest in the individual projects to a third party and enter into long-term fixed price power purchase agreements. Under generally accepted accounting principles, this may result in the deconsolidation of these subsidiaries, and the reflection of only our net ownership interests in our financial statements.

Each of the geothermal power projects our Power Systems segment develops will likely be owned by a separate subsidiary. The geothermal power projects developed by these subsidiaries will likely be separately financed. To obtain the financing necessary to develop the geothermal power projects, we may transfer a portion of our equity interest in the individual subsidiaries to a third party and enter into long-term fixed price power purchase agreements. Depending upon the nature of these arrangements and the application of generally accepted accounting principles, we may be required to deconsolidate one or more or all of these subsidiaries, which would result in our share of the net profits or loss generated by the deconsolidated entities being presented as a net amount in our financial statements. As a result, our financial statements would not reflect the gross revenues and expenses of the deconsolidated entities. However, we do not expect the effect of such deconsolidation, if required, to have an impact on our stockholders’ equity (deficit), net income/loss or income/loss per share.

The financial performance of our Power Systems segment is subject to changes in the legal and regulatory environment.

Our geothermal power projects will be subject to extensive regulation. Changes in applicable laws or regulations, or interpretations of those laws and regulations, could result in increased compliance costs and require additional capital expenditures. Future changes could also reduce or eliminate certain benefits that are currently available.

Federal and state energy regulation is subject to frequent challenges, modifications, the imposition of additional regulatory requirements, and restructuring proposals. We may not be able to obtain or maintain all regulatory approvals or modifications to existing regulatory approvals that may be required in the future. In addition, the cost of operation and maintenance and the financial performance of geothermal power plants may be adversely affected by changes in certain laws and regulations, including tax laws.

In order to promote the production of renewable energy, including geothermal energy, the federal government has created incentives within the United States Internal Revenue Code. These tax incentives are instrumental to our ability to finance and develop geothermal power plants by providing increased economic benefits. If the available tax incentives were reduced or eliminated, the economics of the projects would be reduced and there could be reductions in our overall profitability or the amount of funding available from tax equity partners. Some projects may not be viable without these tax incentives.

Available federal tax incentives include intangible drilling costs, accelerated depreciation, depletion allowances and the investment tax credit (“ITC”), all of which currently are permanent features of the Internal Revenue Code. In addition, the Recovery Act recently extended the availability of the production tax credit (“PTC”) for geothermal projects placed in service before 2014 and created a new grant program for certain projects that are placed in service in, or for which construction begins in, 2009 or 2010.

The ITC is claimed in the year in which the qualified project is placed in service, and the amount of the credit is a specified percentage (10% or 30%) of the eligible costs of the facility. The ITC is subject to recapture if the property eligible for the credit is sold or otherwise disposed of within five years after being placed in service. In lieu of claiming the ITC, a project owner generally can claim the PTC during the first ten years after the project is placed in service. The amount of the PTC is $21.00 (as adjusted for inflation) per megawatt hour of electricity produced from the facility and sold to unrelated parties. As extended by the Recovery Act, the PTC applies to qualifying facilities that are placed in service before 2014. Also pursuant to the Recovery Act, an owner may elect to receive a grant from the United States Treasury Department in lieu of claiming either the ITC or the PTC. The amount of the grant is 30% of the cost of qualifying geothermal property placed in service in 2009 or 2010, or placed in service before 2014 if construction begins in 2009 or 2010. Grants are to be paid 60 days after the later of the date of the application for the grant or the date the project is placed in service.

Owners of projects also are permitted to depreciate for tax purposes most of the cost of the power plant on an accelerated basis. Generally, that depreciation occurs over a five year period. Under the Recovery Act, property placed in service during 2009 generally is entitled to additional “bonus” depreciation in which 50% of the adjusted basis of the property is deducted in 2009 and the remaining 50% of the adjusted basis of the property is depreciated over the five-year accelerated tax depreciation schedule.

All of these programs are subject to review and change by Congress from time to time. In addition, several of the programs are currently scheduled to expire, and continuation of those incentives will require affirmative Congressional action. Moreover, there are ambiguities as to how some of the provisions of the Recovery Act will operate, including the grant program for which there is not yet administrative guidance.

Many of the tax incentives associated with geothermal power projects generally are beneficial only if the owners of the project have sufficient taxable income to utilize the deductions and credits. Due to the nature and timing of these tax incentives, it is likely that the tax incentives available in connection with our geothermal power plants will exceed our ability to efficiently utilize these tax benefits for at least several years of operations. Therefore, an important part of our strategy involves partnering with investors that are able to utilize the tax credits and other tax incentives to offset taxable income associated with their operations unrelated to our geothermal power plants. For example, a corporation in a different industry may be willing to finance the development of a geothermal power plant in consideration for receiving the benefit of the tax incentives, which it could then use to reduce the tax liability associated with its regular operations.

Tax reform has the potential to have a material effect on our business, financial condition, future results and cash flow. Tax reform could reduce or eliminate the value of the tax subsidies currently available to geothermal projects. Any restrictions or tightening of the rules for lease or partnership transactions, whether or not part of major tax reform, could also materially affect our business, financial condition, future results and cash flow. In addition, changes to the Internal Revenue Code could significantly increase the regulatory-related compliance and other expenses incurred by geothermal projects which, in turn, could materially and adversely affect our business, financial condition, future results and cash flow. Any such changes could also make it more difficult for us to obtain financing for future projects.

A significant part of our business strategy is to utilize the tax and other incentives available to developers of geothermal power generating plants to attract strategic alliance partners with the capital sufficient to complete these projects. Many of the incentives available for these projects are new and highly complex. There can be no assurance that we will be successful in structuring agreements that are attractive to potential strategic alliance partners. If we are unable to do so, we may be unable to complete the development of our geothermal power projects and our business could be harmed.

The exploration, development, and operation of geothermal energy resources by our Power Systems segment is subject to geological risks and uncertainties, which may result in decreased performance, increased costs, or abandonment of our projects.

Our Power Systems segment is involved in the exploration, development and operation of geothermal energy resources. These activities are subject to uncertainties, which vary among different geothermal resources. These uncertainties include dry holes, flow-constrained wells, uncontrolled releases of pressure and temperature decline, and other factors, all of which can increase our operating costs and capital expenditures or reduce the efficiency of our power plants. In addition, the high temperature and high pressure in geothermal energy resources requires special resource management and monitoring. Because geothermal resources are complex geological structures, we can only estimate their geographic area. The viability of geothermal projects depends on different factors directly related to the geothermal resource, such as the heat content (the relevant composition of temperature and pressure) of the geothermal resource, the useful life (commercially exploitable life) of the resource and operational factors relating to the extraction of geothermal fluids. Although we believe our geothermal resources will be fully renewable if managed appropriately, the geothermal resources we intend to exploit may not be sufficient for sustained generation of the anticipated electrical power capacity over time. Further, any of our geothermal resources may suffer an unexpected decline in capacity. In addition, we may fail to find commercially viable geothermal resources in the expected quantities and temperatures, which would adversely affect our development of geothermal power projects.

The operation of geothermal power plants depends on the continued availability of adequate geothermal resources. Although we believe our geothermal resources will be fully renewable if managed properly, we cannot be certain that any geothermal resource will remain adequate for the life of a geothermal power plant. If the geothermal resources available to a power plant we develop become inadequate, we may be unable to perform under the power purchase agreement for the affected power plant, which in turn could reduce our revenues and materially and adversely affect our business, financial condition, future results and cash flow. If we suffer degradation in our geothermal resources, our insurance coverage may not be adequate to cover losses sustained as a result thereof.

Our ability to operate a geothermal plant at full capacity depends significantly on the characteristics of the production wells we drill to use for the plant. The wells need to provide sufficient heat at flow rates that can be maintained without a significant increase in the parasitic load associated with the plant. The parasitic load refers to the amount of electricity used by the plant to maintain operations. A significant portion of the parasitic load results from pumps and other equipment used to maintain the flow of geothermal water from the earth through the plant and back into the earth through reinjection wells. Generally, water with a higher temperature will allow the plant to operate with a slower rate of flow, which results in a decrease in the parasitic load because less electricity is required to maintain the necessary flow rate. Water with lower temperatures, on the other hand, requires a higher flow rate to operate the plant, which increases the parasitic load. Unless the water produced by a well is hot enough to increase the amount of power generated by the plant without a corresponding increase to the parasitic load, the well will not result in a net increase in the amount of power available for sale from the plant. Therefore, the overall temperature of the water produced by the production wells is critical to our ability to operate the plant at full capacity. We cannot be certain whether wells will increase net production at a plant until the wells are brought online and the impact to the parasitic load at the plant has been determined.

Our Power Systems segment operations may be materially adversely affected if we fail to properly manage and maintain our geothermal resources.

Our geothermal power plants use geothermal resources to generate electricity. When we develop a geothermal power plant, we conduct hydrologic and geologic studies. Based on these studies, we consider all of the geothermal resources used in our power plants to be fully renewable.

Unless additional hydrologic and geologic studies confirm otherwise, there are a number of events that could have a material adverse effect on our ability to generate electricity from a geothermal resource and/or shorten the operational duration of a geothermal resource, which could cause the applicable geothermal resource to become a non-renewable wasting asset. These events include:

•

Any increase in power generation above the amount our hydrological and geological studies indicate that the applicable geothermal resource will support;

•

Failure to recycle all of the geothermal fluids used in connection with the applicable geothermal resource; and

•

Failure to properly maintain the hydrological balance of the applicable geothermal resource.

While we intend to properly manage and maintain our geothermal resources in order to ensure that they are fully renewable, our ability to do so could be subject to unforeseen risks and uncertainties beyond our control.

Our Power Systems segment may be materially adversely affected if we are unable to successfully utilize certain heat transfer technologies in our geothermal power projects.

Our Power Systems segment intends to utilize certain heat transfer technologies in its geothermal power projects. One of the providers of these heat transfer technologies is PWPS. PWPS’s heat transfer technologies are designed to enable the generation of power from geothermal resources that are lower in temperature than those resources used in traditional flash steam geothermal projects.

PWPS’s heat transfer technologies have a limited operating history and have only been deployed in a limited number of geothermal power projects. Although we are using these technologies in our Thermo No. 1 power plant, that power plant has only been operating for a short time. As a result, we cannot be certain that PWPS’s heat transfer technologies or other vendors’ heat transfer technologies can be successfully implemented. If we are not able to successfully utilize heat transfer technologies in our geothermal power projects and we are unable to utilize appropriate substitute technologies, we may be unable to develop our projects and our business, prospects, financial condition and results of operations could be harmed.

The costs of compliance with environmental laws and of obtaining and maintaining environmental permits and governmental approvals required for construction and/or operation of geothermal power plants are substantial, and any non-compliance with such laws or regulations may result in the imposition of liabilities, which could materially and adversely affect our business, financial condition, future results and cash flow.

Our geothermal power projects are required to comply with numerous federal, regional, state and local statutory and regulatory environmental standards. Geothermal projects must also maintain numerous environmental permits and governmental approvals required for construction and/or operation. Environmental permits and governmental approvals typically contain conditions and restrictions, including restrictions or limits on emissions and discharges of pollutants and contaminants, or may have limited terms. If we fail to satisfy these conditions or comply with these restrictions, or we fail to comply with any statutory or regulatory environmental standards, we may become subject to a regulatory enforcement action and the operation of the projects could be adversely affected or be subject to fines, penalties or additional costs.

The geothermal power projects developed by our Power Systems segment could expose us to significant liability for violations of hazardous substances laws because of the use or presence of such substances.

The geothermal power projects developed by our Power Systems segment will be subject to numerous federal, regional, state and local statutory and regulatory standards relating to the use, storage and disposal of hazardous substances. We may use industrial lubricants, water treatment chemicals and other substances at our projects that could be classified as hazardous substances. If any hazardous substances are found to have been released into the environment at or near the projects, we could become liable for the investigation and removal of those substances, regardless of their source and time of release. If we fail to comply with these laws, ordinances or regulations or any change thereto, we could be subject to civil or criminal liability, the imposition of liens or fines, and large expenditures to bring the projects into compliance. Furthermore, we can be held liable for the cleanup of releases of hazardous substances at other locations where we arranged for disposal of those substances, even if we did not cause the release at that location. The cost of any remediation activities in connection with a spill or other release of such substances could be significant.

Our Transportation & Industrial segment may be unable to successfully license our intellectual property.

A significant part of our long-term business strategy for our Transportation & Industrial segment is based upon the licensing of our Symetron^TM technologies to electric motor, controller, alternator and generator manufacturers, suppliers and system integrators. We expect the sales cycle with respect to the licensing of our technology to be lengthy, and there can be no assurance that we will achieve meaningful licensing revenues in the time frames that we expect.

Our Symetron^TMtechnologies are relatively new and commercially unproven. While we have completed some laboratory testing, our technologies have not yet been durability tested for long-term applications. We can provide no assurance that our technologies will prove suitable for our target business segments. Our potential product applications require significant and lengthy product development efforts. To date, we have not developed any commercially available products. It may be years before our technology is proven viable, if at all. During our product development process, we may experience technological issues that we may be unable to overcome. Superior competitive technologies may be introduced or potential customer needs may change resulting in our technology or products being unsuitable for commercialization. Because of these uncertainties, our efforts to license our technologies may not succeed.

We are currently focusing on commercializing our Symetron^TM technologies in the transportation and industrial markets. We cannot predict the rate at which market acceptance of our technologies will develop in these markets, if at all. Additionally, we may focus our product commercialization activities on a particular industry or industries, which may not develop as rapidly as other industries, if at all. The commercialization of our products or the licensing of our intellectual property in an industry or industries that are not developing as rapidly as other industries could harm our business, prospects, financial condition and results of operations.

The demand for our technologies may be dependent on government regulations and policies such as standards for Corporate Average Fuel Economy, or CAFE, Renewable Portfolio Standards, or RPS, the Clean Air Act and Section 45 of the Internal Revenue Code. Changes in these regulations and policies could have a negative impact on the demand for the power we plan to generate and our technologies. Any new government regulations or policies pertaining to our products or technologies may result in significant additional expenses to us and our potential customers and could cause a significant reduction in demand for our technologies and thereby significantly harm our Transportation & Industrial segment.

The recent economic downturn has had a dramatic, adverse effect on the automotive industry and other large industrial manufacturers that would be in a position to use and benefit from our technologies. As a result, we believe our ability to commercialize our Symetron™ technologies will be limited until economic conditions improve. We intend to evaluate the prospects for our Transportation & Industrial segment on an ongoing basis. If we believe there are attractive opportunities, we will devote the resources to pursue those opportunities to the extent we believe appropriate. If, on the other hand, we determine that the risks and uncertainties for this business segment are too great in light of the current economic climate, we may choose to further reduce the resources devoted to these efforts. We may also be required to develop a new long-term business strategy for the Transportation & Industrial segment or discontinue operating this business segment.

We may not be able to enforce or protect the intellectual property that our Transportation & Industrial segment is seeking to license.

The success of our Transportation & Industrial segment is dependent upon protecting our proprietary technology. We rely primarily on a combination of copyright, patent, trade secret and trademark laws, as well as confidentiality procedures and contractual provisions to protect our proprietary rights. These laws, procedures and provisions provide only limited protection. We have applied for patent protection on most of our key technologies. We cannot be certain that our issued United States patents or our pending United States and international patent applications will result in issued patents or that the claims allowed are or will be sufficiently broad to protect the inventions derived from our technology or prove to be enforceable in actions against alleged infringers. Also, additional patent applications that we may file for our current and future technologies may not be issued. We have received three trademark registrations in the United States and ten trademark registrations internationally. We have also applied for five additional trademark registrations in the United States and one additional trademark registration internationally which may never be granted.

The contractual provisions we rely on to protect our trade secrets and proprietary information, such as our confidentiality and non-disclosure agreements with our employees, consultants and other third parties, may be breached and our trade secrets and proprietary information may be disclosed to the public. Despite precautions that we take, it may be possible for unauthorized third parties to copy aspects of our technology or products or to obtain and use information that we regard as proprietary. In particular, we may provide our licensees with access to proprietary information underlying our licensed applications which they may improperly appropriate. Additionally, our competitors may independently design around patents and other proprietary rights we hold.

Policing unauthorized use of our technology may be difficult and some foreign laws do not protect our proprietary rights to the same extent as United States laws. Litigation may be necessary in the future to enforce our intellectual property rights or determine the validity and scope of the proprietary rights of others. Litigation could result in substantial costs and diversion of resources and management attention resulting in significant harm to our business.

If third parties assert that our current or future products infringe their proprietary rights, we could incur costs and damages associated with these claims, whether the claims have merit or not, which could significantly harm our business. Any future claims could harm our relationships with existing or potential customers. In addition, in any potential dispute involving our intellectual property, our existing or potential customers could also become the targets of litigation, which could trigger indemnification obligations under license and service agreements and harm our customer relationships. If we unsuccessfully defend an infringement claim, we may lose our intellectual property rights, which could require us to obtain licenses which may not be available on acceptable terms or at all.

We license patented intellectual property rights from third party owners. If such owners do not properly maintain or enforce the patents underlying such licenses, our competitive position and business prospects could be harmed. Our licensors may also seek to terminate our licenses.

We are a party to licenses that give us rights to third-party intellectual property that is necessary or useful to our business. Our success will depend in part on the ability of our licensors to obtain, maintain and enforce our licensed intellectual property. Our licensors may not successfully prosecute the patent applications to which we have licenses. Even if patents are issued in respect of these patent applications, our licensors may fail to maintain these patents, may determine not to pursue litigation against other companies that are infringing these patents, or may pursue such litigation less aggressively than we would. Without protection for the intellectual property we license, other companies might be able to offer substantially identical products for sale, which could adversely affect our competitive business position and harm our business prospects.

Our licensors may allege that we have breached our license agreement with them, and accordingly seek to terminate our license. If successful, this could result in our loss of the right to use the licensed intellectual property, which could adversely affect our ability to commercialize our technologies, products or services, as well as harm our competitive business position and our business prospects.

Our Transportation & Industrial segment could incur significant expenses if products built with our technology contain defects.

If our Transportation & Industrial segment successfully licenses our technology, products built with that technology may result in product liability lawsuits for any defects that they may contain. Detection of any significant defects may result in, among other things, loss of, or delay in, market acceptance and sales of our technology, diversion of development resources, injury to our reputation, or increased service and warranty costs. A material product liability claim could significantly harm our business, result in unexpected expenses and damage our reputation.

We face significant competition in each of our business segments. If we fail to compete effectively, our business will suffer.

Our Power Systems segment faces significant competition from other companies seeking to develop the geothermal opportunities available. Some of our competitors for geothermal projects have substantial capabilities and greater financial and technical resources than we do. As a result, we may be unable to acquire additional geothermal resources or projects on terms acceptable to us.

Our Power Systems segment also competes with producers of energy from other renewable sources. This competition may make it more difficult for us to enter into power purchase agreements for our projects on terms that are acceptable to us.

We believe our Transportation & Industrial segment will face significant competition from existing manufacturers, including motor, controller, alternator, and transportation vehicle companies. We may also face significant competition from our future partners. These partners may have better access to information regarding their own manufacturing processes, which may enable them to develop products that can be more easily incorporated into their products. If our potential partners improve or develop technology that competes directly with our technology, our business will be harmed.

In each of our business segments, we face competition from companies that have access to substantially greater financial, engineering, manufacturing and other resources than we do, which may enable them to react more effectively to new market opportunities. Many of our competitors may also have greater name recognition and market presence than we do, which may allow them to market themselves more effectively to new customers or partners.

We may pursue strategic acquisitions that could have an adverse impact on our business.

Our success depends on our ability to execute our business strategies. Our Power Systems segment is seeking to develop geothermal power plants. Our Transportation & Industrial segment is seeking to license our intellectual property to electric motor and controller manufacturers, suppliers and system integrators. Executing these strategies may involve entering into strategic transactions to acquire complementary businesses or technologies. In executing these strategic transactions, we may expend significant financial and management resources and incur other significant costs and expenses. There is no assurance that the execution of any strategic transactions will result in additional revenues or other strategic benefits for either of our business segments. The failure to enter into strategic transactions, if doing so would enable us to better execute our business strategies, could also harm our business, prospects, financial condition and results of operations.

We may issue company stock as consideration for acquisitions, joint ventures or other strategic transactions, and the use of common stock as purchase consideration could dilute each of our current stockholder’s interests. In addition, we may obtain debt financing in connection with an acquisition. Any such debt financing could involve restrictive covenants relating to capital-raising activities and other financial and operational matters, which may make it more difficult for us to obtain additional capital and pursue business opportunities, including potential acquisitions. In addition, such debt financing may impair our ability to obtain future additional financing for working capital, capital expenditures, acquisitions, general corporate or other purposes, and a substantial portion of cash flows, if any, from our operations may be dedicated to interest payments and debt repayment, thereby reducing the funds available to us for other purposes and could make us more vulnerable to industry downturns and competitive pressures.

If we are unable to effectively and efficiently maintain our controls and procedures to avoid deficiencies, there could be a material adverse effect on our operations or financial results.

As a publicly-traded company, we are subject to the reporting requirements of the Exchange Act and the Sarbanes-Oxley Act of 2002. These requirements may place a strain on our systems and resources. Our management is required to evaluate the effectiveness of our internal control over financial reporting as of each year end, and we are required to disclose management’s assessment of the effectiveness of our internal control over financial reporting, including any “material weakness” (within the meaning of Public Company Accounting Oversight Board, or PCAOB, Auditing Standard No. 5) in our internal control over financial reporting. On an on-going basis, we are reviewing, documenting and testing our internal control procedures. In order to maintain and improve the effectiveness of our disclosure controls and procedures and internal control over financial reporting, significant resources and management oversight will be required.

No material weaknesses were identified in connection with the audit of our 2008 financial statements. However, weaknesses or deficiencies could be identified in the future. If we fail to adequately address any deficiencies, it could have a material adverse effect on our business, results of operations and financial condition. Ultimately, if not corrected, any deficiencies could prevent us from releasing our financial information and periodic reports in a timely manner, making the required certifications regarding, and complying with our other obligations with respect to our consolidated financial statements and internal controls under the Sarbanes-Oxley Act. Any failure to maintain adequate internal controls over financial reporting and provide accurate financial statements may subject us to litigation and would cause the trading price of our common stock to decrease substantially. Inferior controls and procedures could also subject us to a risk of delisting by the New York Stock Exchange and cause investors to lose confidence in our reported financial information, which could have a negative effect on the trading price of our common stock.

If we fail to comply with the New York Stock Exchange listing standards and maintain our listing on the New York Stock Exchange, our business could be materially harmed and our stock price could decline.

Our shares of common stock are listed on the New York Stock Exchange. Pursuant to the Sarbanes-Oxley Act of 2002, national securities exchanges, including the New York Stock Exchange, have adopted more stringent listing requirements. We may not be able to maintain our compliance with all of the listing standards of the New York Stock Exchange. Any failure by us to maintain our listing on the New York Stock Exchange could materially harm our business, cause our stock price to decline, and make it more difficult for our stockholders to sell their shares.

We rely on key personnel and the loss of key personnel or the inability to attract, train, and retain key personnel could have a negative effect on our business.

We believe our future success will depend to a significant extent on the continued service of our executive officers and other key personnel. Of particular importance to our continued operations are our executive management and technical staff. We do not have key person life insurance for any of our executive officers, technical staff or other employees. If we lose the services of one or more of our current executive officers or key employees, or if one or more of them decide to join a competitor or otherwise compete directly or indirectly with us, our business could be harmed.

In recent years we have experienced turnover in certain key positions. Most recently, on August 5, 2009, our Chief Executive Officer resigned due to health reasons. Our board of directors is conducting a search for a permanent replacement for our Chief Executive Officer. Until a permanent replacement has been identified, it may be more difficult for us to effectively manage our operations, secure additional financing, execute our business plan or retain other key personnel.

Our future success also depends on our ability to attract, train, retain and motivate highly skilled technical and sales personnel. Since we have limited resources to attract qualified personnel, we may not be successful in recruiting, training, and retaining personnel in the future, which would impair our ability to maintain and grow our business.

Our limited cash resources have in the past required us to rely heavily on equity compensation to hire and retain key personnel, and we expect this to continue in the future. This practice may result in significant non-cash compensation expenses and dilution to our stockholders.

We may record impairment charges which would adversely impact our results of operations.

We review our intangible assets and long-lived assets for impairment annually and whenever events or changes in circumstances indicate that the carrying amounts of these assets may not be recoverable as required by generally accepted accounting principles.

One potential indicator of impairment is whether our fair value, as measured by our market capitalization, has remained below our net book value for a significant period of time. Whether our market capitalization triggers an impairment charge in any future period will depend on the underlying reasons for the decline in stock price, the significance of the decline, and the length of time the stock price has been trading at such prices.

In the event that we determine in a future period that impairment exists for any reason, we would record an impairment charge in the period such determination is made, which would adversely impact our financial position and results of operations.

The large number of shares eligible for public sale could cause our stock price to decline.

The market price of our common stock could decline as a result of the resale of shares of common stock that were previously restricted under Rule 144. In addition, if our officers, directors or employees sell previously restricted shares for tax, estate planning, portfolio management or other purposes, such sales could be viewed negatively by investors and put downward pressure on our stock price. Approximately 63.5 million shares were free of restrictive legend as of September 30, 2009, up from approximately 40.6 million as of December 31, 2008. The occurrence of such sales, or the perception that such sales could occur, may cause our stock price to decline.

Our reported financial results may be adversely affected by changes in United States generally accepted accounting principles.

United States generally accepted accounting principles are subject to interpretation by the Financial Accounting Standards Board, or FASB, the American Institute of Certified Public Accountants, the SEC, and various bodies formed to promulgate and interpret appropriate accounting principles. A change in these principles or interpretations could have a significant effect on our financial results. For example, prior to January 1, 2007, we were not required to record liabilities relating to uncertainties in our income tax positions until a determination was made by the IRS disallowing the deductions. However, for periods after January 1, 2007 we are required to determine whether it is more-likely-than-not that a tax position is sustainable and measure the tax position to recognize in the financial statements in accordance with recent accounting pronouncements.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

On September 24, 2009, we granted 20,000 unregistered shares of our common stock to a service provider of our investor relations activities. The fair value of the unregistered shares on the date of the grant totaled $34,400.

We believe that the offer and sale of the shares of common stock described above were exempt from the registration requirements of the Securities Act pursuant to Section 4(2) under the Securities Act and Rule 506 of Regulation D under the Securities Act.

Item 6.

Exhibits


Exhibit Number		Description of Document

4.1		Amendment No. 1 to Unsecured Line of Credit Agreement and Promissory Note, dated July 22, 2009, among Raser Technologies, Inc., Radion Energy, LLC, Ocean Fund, LLC, Primary Colors, LLC, and R. Thomas Bailey (incorporated by reference to Exhibit 4.1 to our current report on Form 8-K filed July 24, 2009)

4.2		Form of Warrant (incorporated by reference to Exhibit 4.1 to our current report on Form 8-K filed October 19, 2009)

10.1		Schedule Z Amendment, dated as of September 15, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc., Raser Power Systems, LLC, and Pratt & Whitney Power Systems (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed September 17, 2009)

10.2		Schedule Z Amendment, dated as of October 1, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc. and Raser Power Systems, LLC (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed October 5, 2009))

10.3		Schedule Z Amendment, dated as of October 16, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc. and Raser Power Systems, LLC (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed October 19, 2009)

10.4		Form of Subscription Agreement between the Company and the investor signatories thereto (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed October 19, 2009)

10.5		Schedule Z Amendment, dated as of November 2, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc. and Raser Power Systems, LLC (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed November 5, 2009)

31.1*		Certification of Co-Principal Executive Officer pursuant to Exchange Act Rule 13a-14(a)

31.2*		Certification of Chief Financial Officer pursuant to Exchange Act Rule 13a-14(a)

31.3*		Certification of Co-Principal Executive Officer pursuant to Exchange Act Rule 13a-14(a)

32.1*		Certification of Co-Principal Executive Officers and Chief Financial Officer pursuant to 18 U.S.C. Section 1350

*	To be filed herewith.

SIGNATURES

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


						RASER TECHNOLOGIES, INC.
						(Registrant)

November 9, 2009						/s/ RICHARD D. CLAYTON
						Richard D. Clayton
						Principal Executive Officer, General Counsel and Secretary

November 9, 2009						/s/ MARTIN F. PETERSEN
						Martin F. Petersen,
						Chief Financial Officer

EXHIBIT INDEX


Exhibit Number		Description of Document

4.1		Amendment No. 1 to Unsecured Line of Credit Agreement and Promissory Note, dated July 22, 2009, among Raser Technologies, Inc., Radion Energy, LLC, Ocean Fund, LLC, Primary Colors, LLC, and R. Thomas Bailey (incorporated by reference to Exhibit 4.1 to our current report on Form 8-K filed July 24, 2009)

4.2		Form of Warrant (incorporated by reference to Exhibit 4.1 to our current report on Form 8-K filed October 19, 2009)

10.1		Schedule Z Amendment, dated as of September 15, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc., Raser Power Systems, LLC, and Pratt & Whitney Power Systems (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed September 17, 2009)

10.2		Schedule Z Amendment, dated as of October 1, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc. and Raser Power Systems, LLC (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed October 5, 2009)

10.3		Schedule Z Amendment, dated as of October 16, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc. and Raser Power Systems, LLC (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed October 19, 2009)

10.4		Form of Subscription Agreement between the Company and the investor signatories thereto (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed October 19, 2009)

10.5		Schedule Z Amendment, dated as of November 2, 2009, among Thermo No. 1 BE-01, LLC, Deutsche Bank Trust Company Americas, The Prudential Insurance Company of America, Intermountain Renewable Power, LLC, Merrill Lynch, Pierce, Fenner and Smith Incorporated, Raser Technologies, Inc. and Raser Power Systems, LLC (incorporated by reference to Exhibit 10.1 to our current report on Form 8-K filed November 5, 2009)

31.1*		Certification of Co-Principal Officer pursuant to Exchange Act Rule 13a-14(a)

31.2*		Certification of Chief Financial Officer pursuant to Exchange Act Rule 13a-14(a)

31.3*		Certification of Co-Principal Executive Officer pursuant to Exchange Act Rule 13a-14(a)

32.1*		Certification of Co-Principal Officers and Chief Financial Officer pursuant to 18 U.S.C. Section 1350

*	To be filed herewith.

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