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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2011

or

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

For the transition period from ____________to ___________

Commission File Number: 001-34023

U.S. GEOTHERMAL INC.
(Exact Name of Registrant as Specified in Its Charter)

Delaware	84-1472231
(State or Other Jurisdiction of	(I.R.S. Employer
Incorporation or Organization)	Identification No.)
1505 Tyrell Lane
Boise, Idaho	3706
(Address of Principal Executive Offices)	(Zip Code)

208-424-1027
(Registrant’s Telephone Number, Including Area Code)

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

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

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

Large accelerated filer [ ]		Accelerated filer [X]
Non-accelerated filer [ ]	(Do not check if a smaller	Smaller reporting company [ ]
	reporting company)

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

Class	Shares Outstanding as of August 9, 2011
Common stock, par value	84,838,456
$ 0.001 per share

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U.S. Geothermal Inc.
Form 10-Q
For the Quarter Ended June 30, 2011
INDEX

PART I – Financial Information

Item 1 - Financial Statements (Unaudited)	4
Interim Consolidated Balance Sheets - June 30, 2011 and March 31, 2011	6
Interim Consolidated Statements of Operations – Three Months Ended June 30, 2011 and 2010	7
Interim Consolidated Statements of Cash Flow – Three Months Ended June 30, 2011 and 2010	8
Interim Consolidated Statement of Stockholders’ Equity – Year Ended March 31, 2011 and Three Months Ended June 30, 2011	9
Notes to Interim Consolidated Financial Statements	10
Item 2 - Management’s Discussion and Analysis of Financial Condition and Results of Operations	34
- General Background and Discussion	35
- Operating Results	42
- Off Balance Sheet Arrangements	45
- Liquidity and Capital Resources	45
- Potential Acquisitions	47
- Critical Accounting Policies	47
Item 3 – Quantitative and Qualitative Disclosures about Market Risk	48
Item 4 - Controls and Procedures	48
PART II – Other Information
Item 1 - Legal Proceedings	49
Item 1A - Risk Factors	49
Item 2 - Unregistered Sales of Equity Securities and Use of Proceeds	49
Item 3 - Defaults Upon Senior Securities	49
Item 4 – Removed and Reserved	49
Item 5 - Other Information	49
Item 6 - Exhibits	49

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Part I- Financial Information

Item 1 - Financial Statements

The financial statements included herein have been prepared by U.S. Geothermal Inc. (the “Company”), without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles may have been condensed or omitted. However, in the opinion of management, all adjustments (which include only normal recurring accruals) necessary to present fairly the financial position and results of operations for the periods presented have been made. These financial statements should be read in conjunction with the accompanying notes, and with the audited financial statements and notes to the financial statements included in the Company’s annual report on Form 10-K for the year ended, March 31, 2011. The results of operations for the three months ended June 30, 2011 are not necessarily indicative of the results to be expected for the fiscal year ending March 31, 2012.

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U.S. GEOTHERMAL INC.
________

Consolidated Financial Statements
June 30, 2011

 

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U.S. GEOTHERMAL INC.

CONSOLIDATED BALANCE SHEETS

(Stated in U.S. Dollars)

		(Unaudited)
		June 30, 2011			March 31, 2011
ASSETS
Current:
Cash and cash equivalents	$	9,603,798		$	8,098,905
Restricted cash (note 3)		745,000			645,000
Receivable from subsidiary		1,021,524			282,257
Trade accounts receivable		423,080			532,605
Other current assets		248,747			164,239
Total current assets		12,042,149			9,723,006
Deposit on mineral rights purchase		200,000			200,000
Note receivable from subsidiary (note 4)		818,149			-
Investment in equity securities (note 5)		110,697			178,486
Investment in subsidiaries (note 6)		17,936,361			17,968,651
Property, plant and equipment, net of accumulated depreciation (note 7)		62,725,037			40,295,117
Intangible assets, net of accumulated amortization (note 8)		16,888,827			16,957,708
Total assets	$	110,721,220		$	85,322,968
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Accounts payable and accrued liabilities	$	6,221,376		$	940,563
Related party accounts payable		2,057			2,338
Current portion of capital lease obligation		12,975			12,736
Promissory note payable, current (note 11)		230,000			230,000
Total current liabilities		6,466,408			1,185,637
Long-term Liabilities:
Capital lease obligation, less current portion		11,039			14,372
Stock compensation payable		278,713			1,527,829
Convertible loan payable		-			5,132,740
Retention payable (note 18)		886,589			-
Construction loans payable (note 12)		19,709,826			11,651,861
Total liabilities		27,352,575			19,512,439
Commitments and Contingencies (note 18)		-			-
STOCKHOLDERS’ EQUITY
Capital stock (authorized: 250,000,000 common shares with a $0.001           par value; issued and outstanding shares at June 30, 2011 and            March 31, 2011 were: 84,838,456 and 84,761,956; respectively)		84,838			84,762
Additional paid-in capital		92,146,201			90,283,987
Accumulated other comprehensive income		41,201			108,990
Accumulated deficit		(27,649,201	)		(25,308,177	)
		64,623,039			65,169,562
Non-controlling interest (note 19)		18,745,606			640,967
Total stockholders’ equity		83,368,645			65,810,529
Total liabilities and stockholders’ equity	$	110,721,220		$	85,322,968

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

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U.S. GEOTHERMAL INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

(Stated in U.S. Dollars)

		(Unaudited)
		For the Three Months Ended June 30,
		2011			2010
Operating Revenues:
Energy sales, San Emidio	$	623,731		$	571,646
Energy credit sales, San Emidio		38,339			-
Land, water, and mineral rights lease		45,012			45,012
Management fees		62,500			62,500
Gain from investment in subsidiary		38,677			73,089
Total operating revenues		808,259			752,247
Operating Expenses:
Consulting fees		2,062			11,678
Corporate administration		267,964			222,300
Professional and management fees		1,266,767			555,548
Salaries and wages		599,036			470,054
Stock based compensation		534,898			167,014
Travel and promotion		37,386			114,031
Plant operations, San Emidio		678,888			648,271
Lease and equipment repair		34,744			55,275
Total operating expenses		3,421,745			2,244,171
Loss from Operations		(2,613,486	)		(1,491,924	)
Other Income (Loss):
Foreign exchange loss		-			(4,786	)
Other income		-			1,561
Interest income		5,481			16,664
Total other income		5,481			13,439
Net Loss before accumulated change		(2,608,005	)		(1,478,485	)
Accumulated effect on prior period application of capitalization policy (note 20)		262,305			-
Net Loss		(2,345,700	)		(1,478,485	)
Net loss attributable to the non-controlling interest		4,676			3,925
Net Loss Attributable to U.S. Geothermal Inc.		(2,341,024	)		(1,474,560	)
Other Comprehensive Income:
Unrealized loss on investment in equity securities		(67,789	)		(13,372	)
Comprehensive Loss Attributable to U.S. Geothermal Inc.	$	(2,408,813	)	$	(1,487,932	)
Basic And Diluted Net Loss Per Share Attributable to U.S. Geothermal Inc.	$	(0.03	)	$	(0.02	)
Weighted Average Number of Shares Outstanding for Basic and Diluted Calculations		84,835,093			78,647,776

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

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U.S. GEOTHERMAL INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Stated in U.S. Dollars)

		(Unaudited)
		For the Three Months Ended June 30,
		2011			2010
Operating Activities:
Net loss	$	(2,345,700	)	$	(1,478,485	)
Add non-cash items:
Depreciation and amortization		291,014			280,458
Gain on operations of subsidiary		(38,677	)		(73,089	)
Foreign exchange loss		-			4,786
Loss on equity investment		-			4,964
Stock based compensation		534,898			167,014
Change in non-cash working capital items:
Accounts receivable		(653,167	)		(298,457	)
Accounts payable and accrued liabilities		1,210,672			176,462
Prepaid expenses & other		(84,508	)		1,207
Total cash used by operating activities		(1,085,468	)		(1,215,140	)
Investing Activities:
Purchases of property, plant and equipment		(9,637,639	)		(2,874,259	)
Deposit on mineral rights purchase		-			(200,000	)
Proceeds from the non-controlling interest		13,000,000			-
Issuance of note receivable from subsidiary		(818,149	)		-
Distributions received from subsidiary		70,967			-
Cash restricted by regulating entities		(100,000	)		-
Total cash used by investing activities		2,515,179			(3,074,259	)
Financing Activities:
Issuance of common stock, net of issuance costs		78,276			-
Principal payments on capital lease		(3,094	)		(2,873	)
Total cash provided by financing activities		75,182			(2,873	)
Decrease in Cash and Cash Equivalents		1,504,893			(4,292,272	)
Cash and Cash Equivalents, Beginning of Period		8,098,905			12,970,612
Cash and Cash Equivalents, End of Period	$	9,603,798		$	8,678,340
Supplemental Disclosures:
Non-cash investing and financing activities:
Purchase of property and equipment on account	$	4,069,860		$	101,146
Construction and development costs from construction loans		8,944,554			-
Debt converted to non-controlling interest		5,109,315			-
Other Items:
Interest paid		2,354			9,493

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

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U.S. GEOTHERMAL INC.

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

For the Three Months Ended June 30, 2011 and the Year Ended March 31, 2011

(Stated in U.S. Dollars)

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

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U.S. GEOTHERMAL INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - Unaudited

June 30, 2011

(Stated in U.S. Dollars)

NOTE 1 - ORGANIZATION AND DESCRIPTION OF BUSINESS

When U.S. Cobalt Inc. (“GTH” or the “Company”) completed a reverse take-over on December 19, 2003, the former stockholders of U.S. Geothermal Inc. (“GEO – Idaho”) a company incorporated on February 26, 2002 in the State of Idaho, U.S.A. acquired control of GTH. In connection with the transaction, U.S. Cobalt Inc. changed its name to U.S. Geothermal Inc. and consolidated its common stock on a one new to five old basis. All references to common shares in these financial statements have been restated to reflect the roll-back of common stock. The Company constructs and manages power plants that utilize geothermal resources to produce energy. The Company’s operations have been, primarily, focused in the Western United States of America.

All references to “dollars” or “$” are to United States dollars and all references to $ CDN are to Canadian dollars.

Basis of Presentation

These unaudited interim consolidated financial statements of the Company and its subsidiaries have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”). Such rules and regulations allow the omission of certain information and footnote disclosures normally included in financial statements prepared in accordance with generally accepted accounting principles in the United States of America, so long as such omissions do not render the financial statements misleading. Certain prior period amounts have been reclassified to conform to the current period presentation.

In the opinion of management, these financial statements reflect all adjustments that are necessary for a fair statement of the results for the periods presented. All adjustments were of a normal recurring nature. These interim financial statements should be read in conjunction with the annual financial statements of the Company included in its Annual Report on Form 10-K.

The Company consolidates subsidiaries that it controls (more-than-50% owned) and entities over which control is achieved through means other than voting rights. These consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries, as well as one controlling interest. The accounts of the following companies are consolidated in these financial statements:

	i)	U.S. Geothermal Inc. (incorporated in the State of Delaware);
	ii)	U.S. Geothermal Inc. (incorporated in the State of Idaho);
	iii)	Gerlach Geothermal LLC (organized in the State of Delaware);
	iv)	U.S. Geothermal Services, LLC (organized in the State of Delaware);
	v)	USG Nevada LLC (organized in the State of Delaware);
	vi)	USG Gerlach LLC (organized in the State of Delaware);
	vii)	USG Oregon LLC (organized in the State of Delaware)
	viii)	Oregon USG Holdings, LLC (organized in the State of Delaware); and
	ix)	U.S. Geothermal Guatemala, S.A.

All intercompany transactions are eliminated upon consolidation.

Raft River Energy I LLC, previously a 100% owned subsidiary, was consolidated through July 2006, after which the entity is recorded under the equity method.

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In cases where the Company owns a majority interest in an entity but does not own 100% of the interest in the entity it recognizes a non-controlling interest. The Company will recognize 100% of the assets and liabilities of the entity, and disclose the non-controlling interest. The statements of operations will consolidate the subsidiary’s full operations, and will separately disclose the elimination of the non-controlling interest’s allocation of profits and losses.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The following are summarized accounting policies considered to be significant by the Company’s management:

Accounting Method

The Company’s consolidated financial statements are prepared using the accrual basis of accounting in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and have been consistently applied in the preparation of the consolidated financial statements.

Use of Estimates

The preparation of consolidated financial statements in accordance with generally accepted accounting principles requires the use of estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities known to exist as of the date the consolidated financial statements are published, and the reported amounts of revenues and expenses during the reporting period. Uncertainties with respect to such estimates and assumptions are inherent in the preparation of the Company’s consolidated financial statements; accordingly, it is possible that the actual results could differ from these estimates and assumptions and could have a material effect on the reported amounts of the Company’s consolidated financial position and consolidated results of operations.

Cash and Cash Equivalents

The Company considers all unrestricted cash, short-term deposits, and other investments with original maturities of no more than ninety days when acquired to be cash and cash equivalents for the purposes of the statement of cash flows. Discussion regarding restricted cash is included in Note 3.

Trade Accounts Receivable Allowance for Doubtful Accounts

Management estimates the amount of trade accounts receivable that may not be collectible and records an allowance for doubtful accounts, accordingly. The allowance is an estimate based upon aging of receivable balances, historical collection experience, and the periodic credit evaluations of our customers’ financial condition. Receivable balances are written off when we determine that the balance is uncollectible. As of June 30, 2011 and March 31, 2011, there were no balances that were over 90 days past due and no balance in allowance for doubtful accounts was recognized.

Concentration of Credit Risk

The Company’s cash and cash equivalents, including restricted cash, consisted of commercial bank deposits, money market accounts, and petty cash. Cash deposits are held in commercial banks in Boise, Idaho and Portland, Oregon. Deposits are guaranteed by the Federal Deposit Insurance Corporation (“FDIC”) up to $250,000 per legal entity through December 31, 2013. At June 30, 2011, the Company’s total cash balance, excluding money market funds, was $4,992,518, and bank deposits amounted to $5,589,219. The difference was due to outstanding checks and deposits. Of the bank deposits, $4,454,478 was not covered by or was in excess of FDIC insurance guaranteed limits. At fiscal year end, the Company’s money market funds invested in government backed securities totaled $5,354,080, and were not subject to deposit insurance.

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Equity Securities

The Company determines the appropriate classification of marketable securities at the time of purchase and reevaluate this designation as of each balance sheet date. The Company classifies these securities as either held-to-maturity, trading, or available-for-sale. All marketable securities and restricted investments were classified as available-for-sale securities. The Company classifies its investments as “available for sale” because it does not intend to actively buy and sell for short-term profits. The Company's investments are subject to market risk, primarily interest rate and credit risk. The fair value of investments is determined using observable or quoted market prices for those securities.

Available-for-sale securities are carried at fair value, with unrealized gains and losses included as a component of accumulated other comprehensive income (loss). Realized gains and losses, declines in value judged to be other than temporary and interest on available-for-sale securities are included in net income. The cost of securities sold is based on the specific identification method.

Allocation of Profits and Losses from Subsidiaries with Complex Ownership Structures

For subsidiaries that have contractually complex ownership rights, benefits and obligations, the Company utilizes the hypothetical liquidation at book value method (“HLBV”) for allocating profits and losses. This method utilizes the specific terms outlined in the subsidiary’s operating agreement or other authoritative documents. These terms may include cash disbursement terms, associated financial instruments, debt arrangements, and rights to specific revenue streams.

According to the operating agreement, upon liquidation and, after payment of all outstanding debts, any remaining funds would be distributed to the Members in accordance to their positive capital account balance ratio. Certain contract provisions contain allocation of profit and loss items to arrive at the capital account balances. Since the Company is currently the minority member recording their investment in RREI under the equity method, we utilize a hypothetical liquidation at book value at each balance sheet date to value our investment.

For the Company’s investment in RREI, the investment will change based upon actual capital contributions, actual cash distributions, 70% of revenue from renewable energy credits, and 1% of all other profit and loss items. See Note 5.

Property, Plant and Equipment

Property, plant and equipment, including assets under capital lease, are recorded at historical cost. Costs of acquisition of geothermal properties are capitalized on a geothermal reservoir basis. If a geothermal reservoir is abandoned, the associated costs that have been capitalized are charged to income in the year of abandonment. Major improvements that significantly increase the useful lives and/or capabilities of the assets are capitalized. Expenditures for repairs and maintenance are charged to expense as incurred. Interest costs incurred during the construction period of defined major projects from debt that is specifically incurred for those projects are capitalized.

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Depreciation is calculated on a straight-line basis over the estimated useful life of the asset. Where appropriate, terms of property rights and revenue contracts can influence the determination of estimated useful lives. Estimated useful lives by major asset categories are summarized as follows:

Intangible Assets

All costs directly associated with the acquisition of geothermal and water rights are capitalized as intangible assets. These costs are amortized over their estimated utilization period. There are several factors that influence the estimated utilization periods as well as underlying fair value that include, but are not limited to, the following:

• contractual expiration terms of the right,
• contractual terms of an associated revenue contract (i.e., PPAs),
• compliance with utilization and other requirements, and
• hierarchy of other right holders who share the same resource.

Currently, amortization expense is being calculated on a straight-line basis over an estimated utilization period of 30 years for assets placed in service. If an intangible water or geothermal right is forfeited or otherwise lost, the remaining unamortized costs are expensed in the period of forfeiture. An impaired right is reduced to its estimated fair market value in the year the impairment is realized. Costs incurred that extend the term of an intangible right are capitalized and amortized over the new estimated period of utilization.

Impairment of Long-Lived Assets

The Company evaluates its long-term assets annually for impairment or when circumstances or events occur that may impact the fair value of the assets. An impairment loss would be recognized if the carrying amount of a capitalized asset is not recoverable and exceeds its fair value. Management believes that there have not been any circumstances that have warranted the recognition of losses due to the impairment of long-lived assets as of June 30, 2011.

Stock Options Granted to Employees and Non-employees

The Company follows financial accounting standards that require the measurement of the value of employee services received in exchange for an award of equity instrument based on the grant-date fair value of the award. For employees, directors and officers, the fair value of the awards are expensed over the vesting period. The current vesting period for all options is eighteen months.

Non-employee stock-based compensation is granted at the Board of Director’s discretion to reward select consultants for exceptional performance. Prior to issuance of the awards, the Company was not under any obligation to issue the stock options. Subsequent to the award, the recipient was not obligated to perform any services. Therefore, the fair value of these options was expensed on the grant date, which was also the measurement date.

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Under the fair value recognition provisions, share-based compensation cost is measured at the grant date based on the value of the award and is recognized as expense over the vesting period. Determining the fair value of share-based awards at the grant date requires judgment. In addition, judgment is also required in estimating the amount of share-based awards that are expected to be forfeited. If actual results differ significantly from these estimates, stock-based compensation expense and our results of operations could be materially impacted.

The Company has adopted a standard that states that if certain conditions are present surrounding the issuance of equity instruments as share based compensation, then circumstances may warrant the recognition of a liability for financial reporting purposes. One such condition is present when the Company issued stock options denominated in a foreign currency (Canadian dollars) to employees. Authors of the standard have reasoned that when a condition is present that creates a financial risk to the recipient in addition to normal market risks (i.e., foreign currency translation risk), then the instrument takes on the characteristics of a liability, rather than an equity item. As the underlying stock options are exercised or are forfeited, then the stock based compensation liability will be reduced. The Company’s financial statements reflect these changes in the consolidated balance sheet. As the value of the options change over the vesting periods, these changes will ultimately be reflected in the amount of expense charged to operations.

Stock Based Compensation Granted to Employees

The Company recognizes the value of common stock granted to employees and directors over the periods in which the services are received. The value of those services is based upon the estimated fair value of the common stock to be awarded. Estimated fair value is adjusted each reporting period. At the end of each vesting period, estimated fair value is adjusted to fair market value. The adjustment is reflected in the reporting period in which the vesting occurs.

Earnings Per Share

The Company follows financial accounting standards, which provides for calculation of "basic" and "diluted" earnings per share. Basic earnings per share includes no dilution and is computed by dividing net income available to common shareholders by the weighted average common shares outstanding for the period. Diluted earnings per share reflect the potential dilution of securities that could share in the earnings of an entity similar to fully diluted earnings per share. Although there were common stock equivalents outstanding at June 30, 2011 and March 31, 2011, they were not included in the calculation of earnings per share because their inclusion would have been considered anti-dilutive. Total common stock equivalents at June 30, 2011 and March 31, 2011 were 104,149,873 and 102,665,193; respectively.

Financial Instruments

The Company’s financial instruments consist of cash and cash equivalents, trade account and other receivables, refundable tax credits, and accounts payable and accrued liabilities. Unless otherwise noted, it is management’s opinion that the Company is not exposed to significant interest, currency or credit risks arising from these financial instruments. The fair values of these financial instruments approximate their carrying values, unless otherwise noted.

Refundable tax credit is comprised of Goods and Services Tax (“GST”) which is refundable from the Government of Canada and is included in other current assets.

The Company’s functional currency is the U.S. dollar. Monetary items are converted into U.S. dollars at the rate prevailing at the balance sheet date. Resulting gains and losses are generally included in determining net income for the period in which exchange rates change.

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Revenue

Revenue Recognition

The energy sales revenue is recognized when the power is produced and delivered to the customer under the terms defined in the Power Purchase Agreements. Revenues from energy credits sales are recognized when the Company has met the terms of certain energy sales agreements with a financially capable buyer and has met the applicable governing regulations. Management fee income is recognized when the services have been provided. Royalties and Lease revenues are recognized as the resource has been utilized and other contractual obligations have been met.

Revenue Source

All of the Company’s direct and indirect operating revenues originate from energy production from its interests in geothermal power plants located in the states of Idaho and Nevada. All of the management fees and royalty revenues are earned from its subsidiary located in South Eastern Idaho. All of the power sales are earned from a power plant located in North Western Nevada.

Recent Accounting Pronouncements

Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs

In May 2011, FASB issued Financial Accounting Standards Update No. 2011-04, Fair Value Measurement (Topic 820), Amendments to Achieve Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs (“Update 2011-04”). Update 2011-04 promotes the development of common requirements for measuring fair value and for disclosing information about fair value measurements in accordance with U.S. generally accepted accounting principles (“U.S. GAAP”) and International Financial Reporting Standards (“IFRSs”). This Update is effective during interim and annual periods beginning after December 15, 2011, and should be applied prospectively. Management expects that it will impact the presentation of the statements of financial position, statements of operations, and statements of changes in shareholders equity.

Presentation of Comprehensive Income

In June 2011, FASB issued Financial Accounting Standards Update No. 2011-05, Fair Value Measurement (Topic 820 Comprehensive Income (Topic 220), Presentation of Comprehensive Income (“Update 2011-05”). Update 2011-05 improves the comparability and consistency of financial reporting of items reported in other comprehensive income between U.S. GAAP and IFRSs. This Update is effective for fiscal years and interim periods within those years, beginning after December 15, 2011, and should be applied retrospectively. Management is still evaluating the impact of this update, and expects that it will impact the presentation of the statements of financial position, statements of operations, and statements of changes in shareholders equity.

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NOTE 3 – RESTRICTED CASH

The Company maintains cash balances that are restricted under Letter of Credit covenants for State and Federal well bonding requirements. These bonds renew on an annual basis. Restricted cash balances and explanations of the nature of the restrictions are summarized as follows:

These bonding requirements ensure that the Company has sufficient financial resources to construct, operate and maintain geothermal wells while safeguarding subsurface, surface and atmospheric resources from unreasonable degradation, and to protect ground water aquifers and surface water sources from contamination. Other future costs of environmental remediation cannot be reasonably estimated and have not been recorded.

NOTE 4 – LONG TERM NOTE RECEIVABLE FROM SUBSIDIARY

On May 17, 2011, Raft River I Holdings, LLC consented to a repair plan for both under performing wells utilized by Raft River Energy I, LLC (wells RRG-2 and RRG-7). A Repair Services Agreement was executed between U.S Geothermal Services, LLC (“USG Services”) and Raft River Energy I LLC, whereby USG Services will provide up to $1.65 million in funding and manage the well repairs. The cost of the repairs will be repaid preferentially from project cash flow at a rate of 90% of increased cash created by the repairs. A management fee of 12.75% of the actual repair cost incurred will be paid to USG Services. The outstanding balance of the repair cost will also earn USG Services interest income at the rate of 12.0 % per-annum. At June 30, 2011, the total loan balance was $818,149 and was considered to be long term.

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NOTE 5 – INVESTMENT IN EQUITY SECURITIES

Investments in equity securities (150,000 shares of a publicly traded geothermal corporation) activities consisted of the following:

NOTE 6 – INVESTMENT IN SUBSIDIARIES

Raft River Energy I is a joint venture between the Company and Raft River I Holdings, LLC a subsidiary of Goldman Sachs Group, Inc. An Operating Agreement governs the rights and responsibilities of both parties. RREI is a voting interest entity recorded on the financial records of the Company as an equity investment. For book and income tax purposes, Raft River I Holdings, LLC will receive a greater proportion of the share of losses and other income tax benefits. Additionally, during the initial years of operations Raft River I Holdings, LLC will receive a larger allocation of cash distributions.

RREI resulted from an August 9, 2006 agreement between the Company and Raft River Holdings, LLC, a subsidiary of the Goldman Sachs Group, for construction financing of Phase I of the Raft River project. To accommodate the construction financing, the Company sold 50% of its ownership in Raft River Energy to Raft River Holdings, LLC. As a result of the agreements, the Company was required to contribute cash and property sufficient to complete a power plant, and Raft River Holdings was required to contribute $34,170,100.

As of June 30, 2011, the Company has contributed $17,953,640 in cash and property to the project, while Raft River Holdings, LLC has contributed $34,170,100.

RREI’s latest financial information is summarized as follows:

		(Unaudited)			December 31,			December 31,
		June 30, 2011			2010			2009
Total current assets	$	914,019		$	808,084		$	808,084
Property and equipment		44,925,029			47,993,261			47,993,261
	$	45,839,048		$	48,801,345		$	48,801,345
Total liabilities	$	1,948,670		$	791,116		$	791,116
Total members’ equity		43,890,378			48,010,229			48,010,229
	$	45,839,048		$	48,801,345		$	48,801,345

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		(Unaudited)
		Six Months Ended			Year Ended			Year Ended
		June 30, 2011			December 31, 2010			December 31, 2009
Operating revenues	$	1,713,867		$	4,542,477		$	4,718,949
Operating loss		(2,322,625	)		(747,544	)		(2,278,806	)
Net loss		(2,322,625	)		(747,396	)		(2,270,718	)
U.S. Geothermal Inc., portion of net earnings	$	105,271		$	375,053		$	279,072

For the Company’s investment in RREI, the investment will change based upon actual capital contributions, actual cash distributions, 70% of revenue from renewable energy credits and 1% of all other profits and losses.

The Company’s investment in the RREI has changed since March 31, 2009 as follows:

NOTE 7 - PROPERTY, PLANT AND EQUIPMENT

During the quarter ended June 30, 2011, the Company was primarily focused on the development of the Neal Hot Springs, Oregon and San Emidio, Nevada projects. At Neal Hot Springs, well NHS #12 was substantially completed at a cost of approximately $3.4 million. Construction costs that amounted to over $9.6 million were incurred on the transmission line, office building, shop building, power plant and site preparation. The office and shop buildings are substantially complete. Costs incurred for power plant construction are primarily related to engineering and design. Power plant construction costs, at San Emidio amounted to approximately $8.1 million during the quarter. The foundations and chemical buildings were substantially completed. Construction activities are primarily focused on the cooling tower and transmission line.

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Property, plant and equipment, at cost, are summarized as follows:

For the three months ended June 30, 2011, the Company incurred interest costs of $256,935 of which $254,581 was capitalized as a component of the Neal Hot Springs and San Emidio projects. Interest costs incurred during the three months ended June 30, 2010 were not significant and no interest was capitalized.

Depreciation expense charged to operations for the three months ended June 30, 2011 and 2010 amounted to $222,133 and $211,577; respectively.

Changes in Construction in Progress for the periods ended June 30, 2011 and March 31, 2011, are summarized as follows:

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Construction in Progress, at cost, consisted of the following projects/assets by location at fiscal year ends, are as follows:

		June 30, 2011			March 31, 2011
Raft River, Idaho:
Unit II, power plant, substation and transmission lines	$	1,000,750		$	1,000,273
Unit II, well construction		2,888,870			2,888,972
Grant reimbursements		(791,688	)		(791,687	)
		3,097,932			3,097,558
San Emidio, Nevada:
Power plant (Re-power project)		20,222,430			12,104,457
Interconnection studies for transmission line		238,386			197,679
Well construction		3,569,573			3,396,408
Grant reimbursements		(508,886	)		(432,113	)
		23,521,503			15,266,431
Neal Hot Springs, Oregon:
Wells		17,178,360			12,546,127
Buildings and site preparation		13,073,024			4,064,074
Transmission lines and substation		988,519			327,519
		31,239,903			16,937,720
	$	57,859,338		$	35,301,709

NOTE 8 – INTANGIBLE ASSETS

Intangible assets, at cost, are summarized as follows:

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Estimated aggregate amortization expense for the next five fiscal years is as follows:

Amortization expense charged to operations for the three months ended June 30, 2011 and 2010 amounted to $68,881 and $68,881; respectively.

NOTE 9 – PROVISION FOR INCOME TAXES

Income taxes are provided based upon the liability method. Under this approach, deferred income taxes are recorded to reflect the tax consequences in future years of differences between the tax basis of assets and liabilities and their financial reporting amounts at each year-end. A valuation allowance is recorded against deferred tax assets if management does not believe the Company has met the “more likely than not” standard imposed by accounting standards to allow recognition of such an asset.

At June 30, 2011, the Company had net deferred tax assets calculated at an expected rate, noted in the table below, of approximately $7,785,000 (March 31, 2011 - $6,743,000). As management of the Company cannot determine that it is more likely than not that the Company will realize the benefit of the net deferred tax asset, a valuation allowance equal to the net deferred tax asset was recorded at June 30, 2011 and March 31, 2011.

The significant components of the net deferred tax asset calculated with the estimated effective income tax rate at June 30, 2011 and March 31, 2011 were as follows:

* - significant components of deferred assets and liabilities are considered to be long-term.

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The Company’s estimated effective income tax rate is summarized as follows:

At June 30, 2011, the Company had net income tax operating loss carry forwards of approximately $19,961,000 ($13,678,000 in March 31, 2011), which expire in the years 2023 through 2031. The change in the allowance account from March 31, 2011 to June 30, 2011 was $1,042,000.

Although Management believes that its estimates are reasonable, no assurance can be given that the final tax outcome of these matters will not be different than that which is reflected in our tax provisions. Ultimately, the actual tax benefits to be realized will be based upon future taxable earnings levels, which are very difficult to predict.

Accounting for Income Tax Uncertainties and Related Matters

The Company may be assessed penalties and interest related to the underpayment of income taxes. Such assessments would be treated as a provision of income tax expense on the financial statements. For the years ended June 30, 2011, 2010 and 2009, no income tax expense has been realized as a result of operations and no income tax penalties and interest have been accrued related to uncertain tax positions. The Company files income tax returns in the U.S. federal jurisdiction and in the States of Idaho and Oregon. These filings are subject to a three year statute of limitations. The Company’s evaluation of income tax positions included the fiscal years ended March 31, 2011, 2010, and 2009, could be subject to agency examinations as of June 30, 2011. No filings are currently under examination. No adjustments have been made to reduce the estimated income tax benefit at fiscal year end. Any valuations relating to these income tax provisions will comply with U.S. generally accepted accounting principles.

NOTE 10 - CAPITAL LEASE OBLIGATION

Effective November 10, 2008, the Company entered into a capital lease obligation for the purchase of a forklift that is payable in monthly payments of $1,193 including interest to Wells Fargo Equipment, Inc. The contract includes a purchase option of $5,345 at the end of the lease term scheduled for November 2012. At June 30, 2011, equipment under capital lease amounted to $53,450 ($27,616 accumulated amortization). The schedule of minimum lease payments is as follows:

NOTE 11 – PROMISORY NOTE PAYABLE

On July 7, 2009, the Company financed the purchase of 40 acres of land and a building on property adjacent to our San Emidio power plant facility with a promissory note. The note for $230,000, is payable in 24 successive monthly installments commencing on the second month following the date of disbursement. The first 23 payments consist of interest only on the outstanding principal at 3.25% per annum. The entire principal and the accrued interest are due on the final payment. The note is unsecured. In the event of an assignment for the benefit of creditors, application for the appointment of a receiver or filing of a voluntary or involuntary petition in bankruptcy by or against the Company, the holder may declare this note immediately due and payable in full. Currently, the Company is in compliance with the note requirements.

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NOTE 12 – CONSTRUCTION NOTES PAYABLE

Effective August 27, 2010, the Company’s wholly owned subsidiary (USG Nevada LLC) signed a construction loan agreement with Benham Constructors LLC (“Benham”). Benham will be the primary contractor in the relocation and replacement of the existing power plant. The new 8.6 net megawatt power plant is expected to cost approximately $25 million, and is expected to be completed October 2011. Upon completion, the Company will pay the debt in full within 30 days of receipt of the final statement prepared by Benham. Interest will accrue on outstanding balance at 9.5% per annum. When due, the Company expects to obtain funds to repay the loan balance with a long-term project loan. The loan is non-recourse and is secured by the Project’s assets. Title of all work and materials shall pass to the Company the later of delivery to the Site or upon payment in full.

NOTE 13 - CAPITAL STOCK

The Company is authorized to issue 250,000,000 shares of common stock. All shares have equal voting rights, are non-assessable and have one vote per share. Voting rights are not cumulative and, therefore, the holders of more than 50% of the common stock could, if they choose to do so, elect all of the directors of the Company.

On March 10, 2011, the Company issued 705,000 shares for the stock compensation plan (restricted shares) approved on September 10, 2010. The shares will be distributed to qualified recipients according to the approved vesting schedule. See note 15 for details.

On March 7, 2011, the Company issued 5,000,000 shares of Common Stock at a price of $1.00 per share. Each investor received a Common Stock Purchase Warrant exercisable for 50% of number of shares of Common Stock purchased. Each Warrant will entitle the holder to purchase one additional share of Common Stock for $1.075 per share. The Warrants expire March 3, 2012. The issue included a placement agent fee of 112,000 Common Shares and 56,000 Broker Warrants with the same terms.

During the year ended June 30, 2011, the Company issued 297,180 common shares to employees of the Company upon exercise of stock options. Common shares of 272,180 were issued at a strike price of $1.00 CDN and 25,000 were issued at $0.92.

NOTE 14 - STOCK BASED COMPENSATION

The Company has a stock incentive plan (the “Stock Incentive Plan”) for the purpose of attracting and motivating directors, officers, employees and consultants of the Corporation and advancing the interests of the Corporation. The Stock Incentive Plan is a 15% rolling plan approved by shareholders in December 2009, whereby the Company can grant options to the extent of 15% of the current outstanding common shares. Under the plan, all forfeited and exercised options can be replaced with new offerings. As of June 30, 2011, the Company can issue stock option grants totaling up to 12,725,768 shares. Options are granted for a term of up to five years from the date of grant. Stock options granted generally vest over a period of eighteen months, with 25% vesting on the date of grant and 25% vesting every six months thereafter.

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Effective April 1, 2007, all grants are stated in U.S. dollars. The Company recognizes compensation expense using the straight-line method of amortization. Historically, the Company has issued new shares to satisfy exercises of stock options and the Company expects to issue new shares to satisfy any future exercises of stock options. At June 30, 2011, the Company had 8,111,375 options granted and outstanding.

On June 3, 2011, the Company granted 2,590,000 stock options to employees exercisable at a price of $0.83 until June 3, 2016.

On April 12, 2011, 1,094,320 of the total 1,763,000 options issued and outstanding on April 12, 2006 at prices ranging from $0.85 CDN to $1.00 CDN, were forfeited due to expiration.

On September 10, 2010, the Company granted 1,300,000 stock options to employees exercisable at a price of $0.86 until September 10, 2015.

The following table reflects the summary of stock options outstanding at March 31, 2010 and changes during for the year ended March 31, 2011 and the three months ended June 30, 2011:

					Weighted
					Average			Weighted
		Number of			Exercise			Average			Aggregate
		shares under			Price Per			Fair			Intrinsic
		options			Share			Value			Value
Balance outstanding, March 31, 2010		5,729,875		$	1.49		$	0.92		$	5,296,029
Forfeited		(29,500	)		2.00			0.66			(19,597	)
Exercised		(297,180	)		0.99			0.99			(294,066	)
Granted		1,300,000			0.86			0.58			752,206
Balance outstanding, March 31, 2011		6,703,195			1.38			0.86			5,734,572
Forfeited		(1,105,320	)		1.00			1.02			(1,122,467	)
Exercised		(76,500	)		1.00			1.02			(77,868	)
Granted		2,590,000			0.83			0.49			1,269,100
Balance outstanding, June 30, 2011		8,111,375		$	1.26		$	0.72		$	5,803,519

The fair value of each option award is estimated on the date of grant using the Black-Scholes option-pricing model using the assumptions noted in the following table. Expected volatilities are based on historical volatility of the Company’s stock. The Company uses historical data to estimate option volatility within the Black-Scholes model. The expected term of options granted represents the period of time that options granted are expected to be outstanding, based upon past experience and future estimates and includes data from the Plan. The risk-free rate for periods within the expected term of the option is based upon the U.S. Treasury yield curve in effect at the time of grant. The Company currently does not foresee the payment of dividends in the near term.

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The fair value of the stock options granted was estimated using the Black-Scholes option-pricing model and is amortized over the vesting period of the underlying options. The assumptions used to calculate the fair value are as follows:

Changes in the subjective input assumptions can materially affect the fair value estimate and, therefore, the existing models do not necessarily provide a reliable measure of the fair value of the Company’s stock options.

The following table summarizes information about the stock options outstanding at June 30, 2011:

OPTIONS OUTSTANDING
					REMAINING			NUMBER OF
EXERCISE		NUMBER OF			CONTRACTUAL			OPTIONS
PRICE		OPTIONS			LIFE (YEARS)			EXERCISABLE			INTRINSIC VALUE
$ 1.15 CDN		78,750			0.08			78,750			86,626
1.40 CDN		157,500			0.56			157,500			139,271
2.41		652,500			1.06			652,500			460,975
2.22		1,465,000			1.88			1,465,000			1,786,417
1.78		95,000			2.24			95,000			81,172
0.92		1,704,625			2.90			1,704,625			1,204,713
1.58		68,000			3.23			68,000			26,435
0.86		1,300,000			4.20			650,000			376,103
0.83		2,590,000			4.93			647,500			317,275
$ 1.26		8,111,375			3.34			5,518,875		$	4,478,987

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The following table summarizes information about the stock options outstanding at March 31, 2011:

OPTIONS OUTSTANDING
					REMAINING			NUMBER OF
EXERCISE		NUMBER OF			CONTRACTUAL			OPTIONS
PRICE		OPTIONS			LIFE (YEARS)			EXERCISABLE			INTRINSIC VALUE
$ 1.00 CDN		1,170,820			0.03			1,170,820		$	1,188,983
1.15 CDN		78,750			0.33			78,750			86,626
1.40 CDN		157,500			0.81			157,500			139,271
2.41		652,500			1.31			652,500			460,975
2.22		1,465,000			2.13			1,465,000			1,786,417
1.78		95,000			2.49			95,000			81,172
0.92		1,715,625			3.15			1,715,625			1,212,487
1.58		68,000			3.48			68,000			26,435
0.86		1,300,000			4.45			650,000			376,103
$ 1.38		6,703,195			2.36			6,053,195		$	5,358,469

A summary of the status of the Company’s nonvested stock options outstanding at March 31, 2010 and changes during the year ended March 31, 2011 and the three months ended June 30, 2011 are presented as follows:

As of June 30, 2011, there was $807,444 of total unrecognized compensation cost related to nonvested share-based compensation arrangements granted under the Plan. That cost is expected to be recognized over a weighted-average period of 1.5 years. The total fair value of options vested at June 30, 2011 and March 31, 2011 was $461,656 and $167,014; respectively.

Stock Compensation Plan (Restricted Shares)

On September 10, 2010, the Company granted officers, directors and select employees 705,000 common shares that will be distributed in three six-month vesting periods. The recipients meet the vesting requirements by maintaining employment and good standing with the Company through the vesting periods. After vesting, there are no restrictions on the shares. On March 10, 2011, the 705,000 common shares were issued to the recipients and held by the Company. All of these shares were considered to be issued and outstanding. On March 11, 2011, 235,000 common shares vested valued at $0.99 per share, and the shares were released to the qualified recipients. The remaining vesting schedule is as follows:

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Stock Purchase Warrants

At June 30, 2011, the outstanding broker warrants and share purchase warrants consisted of the following:

NOTE 15 – FAIR VALUE MEASUREMENT

On April 1, 2008, the Company adopted the provisions related to its financial assets and liabilities measured at fair value on a recurring basis. Current U.S. generally accepted accounting principles establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement).

The three levels of the fair value hierarchy are as follows:

Level 1 – Quoted prices are available in active markets for identical assets or liabilities. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

Level 3 – Pricing inputs include significant inputs that are generally unobservable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. Level 3 instruments include those that may be more structured or otherwise tailored to the Company’s needs.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

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The following table discloses by level within the fair value hierarchy the Company’s assets and liabilities measured and reported on its Consolidated Balance Sheet as of June 30, 2011 at fair value on a recurring basis:

		Total			Level 1			Level 2			Level 3
Assets:
Money market accounts	$	5,354,080		$	5,354,080		$	-		$	-
Investment in equity securities		110,697			-			110,697			-
	$	5,464,777		$	5,354,080		$	110,697		$	-

As allowed by current financial reporting standards, the Company has elected not to implement fair value recognition and reporting for all non-financial assets and non-financial liabilities, except for those that are recognized or disclosed at fair value in the financial statements on a recurring basis, that is, at least annually.

There were no changes in Level 3 assets measured for the three months ended June 30, 2011 and 2010.

The equity securities purchased in June 2008 are actively traded on a stock exchange; however, the securities held by the Company are subject to trading restrictions. Therefore, the investment was moved from Level 3 to Level 2.

NOTE 16 - RELATED PARTY TRANSACTIONS

At June 30, 2011 and March 31, 2011 the amounts of $2,058 and $2,338; respectively, were payable to directors and officers of the Company for routine expense reimbursement. These amounts are unsecured and due on demand.

The Company’s subsidiary Raft River Energy I, LLC (“RREI”) owed the Company $1,839,673 and $282,257 at June 30, 2011 and March 31, 2011; respectively, for operating and maintenance expenses. The current receivable balance is comprised of unsecured demand obligations due within twelve months. See note 5 for the terms of the long term liability. The Company received the following revenues from RREI:

The Company’s equity investment in RREI is adjusted monthly for its share of the profit and loss based on various revenue stream and cost allocations. The Company’s share of the costs to RREI associated with the above noted management fees and lease and royalty revenues are deemed immaterial at this time, and related U.S. Geothermal, Inc.’s revenues and RREI costs have not been eliminated in the financial statements.

The Company paid directors fees in the amounts of $52,500 and $22,500 for the three months ended June 30, 2011 and 2010; respectively.

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NOTE 17 - DIFFERENCES BETWEEN IFRS AND U.S. GAAP

The Company’s consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“U.S. GAAP”). The material difference in respect to these financial statements between U.S. GAAP and International Financial Reporting Standards (“IFRS”) is reflected in the recording of Property, Plant and Equipment. Under IFRS, development and exploration costs associated with the Raft River project (property lease payments, geological consulting fees, well monitoring and permitting, etc.) were recorded as a capital asset. Under U.S. GAAP, these amounts are expensed. Under U.S GAAP, the value of stock options issued in a foreign currency must be reflected as stock compensation liability. This liability is not recognized for IFRSs.

As a result of the above, under IFRS the following line items in the consolidated balance sheets and income statements would have been presented as follows:

The Company continues to evaluate and identify the various elements of the financial statements for proper presentation in accordance with IFRS.

NOTE 18 - COMMITMENTS AND CONTINGENCIES

Operating Lease Agreements
The Company has entered into several lease agreements with terms expiring up to December 1, 2034 for geothermal properties in Washoe County Nevada; Neal Hot Springs, Oregon and adjoining the Raft River properties in Raft River, Idaho. The Company incurred total lease expenses for three months ended June 30, 2011 and 2010, totaling $67,459 and $63,897; respectively.

BLM Lease Agreements

Idaho
On August 1, 2007, the Company signed a geothermal resources lease agreement with the United States Department of the Interior Bureau of Land Management (“BLM”). The contract requires an annual payment of $3,502 including processing fees. The primary term of the agreement is 10 years. After the primary term, the Company has the right to extend the contract. BLM has the right to terminate the contract upon written notice if the Company does not comply with the terms of the agreement. The Company believes that it is in compliance with all of the lease terms.

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San Emidio
The lease contracts are for approximately 21,905 acres of land and geothermal rights located in the San Emidio Desert, Nevada. The lease contracts have primary terms of 10 years. Per federal regulations applicable for the contracts, the lessee has the option to extend the primary lease term another 40 years if the BLM does not need the land for any other purpose and the lessee is maintaining production at commercial quantities. The leases require the lessee to conduct operations in a manner that minimizes adverse impacts to the environment.

Gerlach
The Gerlach Geothermal LLC assets are comprised of two BLM geothermal leases and one private lease totaling 3,615 acres. Both BLM leases have a royalty rate which is based upon 10% of the value of the resource at the wellhead. The amounts are calculated according to a formula established by Minerals Management Service (“MMS”). One of the two BLM leases has a second royalty commitment to a third party of 4% of gross revenue for power generation and 5% for direct use based on BTUs consumed at a set comparable price of $7.00 per million BTU of natural gas. The private lease has a 10 year primary term and would receive a royalty of 3% gross revenue for the first 10 years and 4% thereafter.

Granite Creek
The Company has three geothermal lease contracts with the BLM for the Granite Creek properties. The lease contracts are for approximately 5,414 acres of land and geothermal water rights located in North Western Nevada. The lease contracts have primary terms of 10 years. Per federal regulations applicable for the contracts, the lessee has the option to extend the primary lease term another 40 years if the BLM does not need the land for any other purpose and the lessee is maintaining production at commercial quantities. The leases state annual lease payments of $5,414, not including processing fees, and expire October 31, 2012.

Office Lease
The Company signed in a one year lease contract January 2011 for general office space for the executive office located in Boise, Idaho. The contract includes two one year renewal options for the Company. The lease payments are due in monthly installments of $6,160. The Company incurred total office lease expenses under the current contract and the prior contract for quarter ended June 30, 2011 and 2010, totaling $18,480 and $17,942; respectively.

The following is the total contracted lease operating obligations (operating leases, BLM lease agreements and office lease) for the next five fiscal years:

Power Purchase Agreements

The Company has signed a power purchase agreement with Idaho Power Company for sale of power generated from its joint venture Raft River Energy I, LLC. The Company has also signed a transmission agreement with Bonneville Power Administration for transmission of the electricity from this plant to Idaho Power, and from the Phase Two plants to other purchasers. These agreements will govern the operational revenues for the initial phases of the Company’s operating activities.

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The Company signed a power purchase agreement on March 12, 2008 with Eugene Water and Electric Board for the planned Phase Two power plant at Raft River, Idaho. The agreement allows for variable output up to a maximum of 16 megawatts with a term of 25 years. The agreement is subject to successful drilling and resource development.

As a part of the purchase of the assets from Empire Geothermal Power, LLC and Michael B. Stewart acquisition (“Empire Acquisition”), a power purchase agreement with Sierra Pacific Power Company was assigned to the Company. The contract has a stated expected output of 3,250 kilowatts maximum per hour and extends through 2017. All power produced will be purchased and there are no penalties for not meeting or exceeding expected output levels.

In December of 2009, the Company’s subsidiary (USG Oregon LLC), signed a power purchase agreement with Idaho Power Company for the sale of power generated by the Neal Hot Springs, Oregon project. The agreement has a term of 25 years and provides for the purchase of power up to 25 megawatts (22 megawatt planned output level). Beginning 2012, the flat energy price is $96 per megawatt hour. The price escalates annually by 6 percent in the initial years and by 1.33 percent during the latter years of the agreement. The approximate 25-year levelized price is $117.65 per megawatt hour.

401(k) Plan
The Company offers a defined contribution plan qualified under section 401(k) of the Internal Revenue Code to all its eligible employees. All employees are eligible at the beginning of the quarter after completing 3 months of service. The plan requires the Company to match 25% of the employee’s contribution up to 6%. Employees may contribute up to the maximum allowed by the Internal Revenue Code.

Mineral Rights Option Agreement
On May 24, 2010, USG Oregon LLC (a subsidiary of the Company) entered into an option agreement that allows for exclusive purchase of all mineral rights associated with 2,110 acres of land located in Malheur County, Oregon. Per the terms of the agreement, the Company transferred $200,000 to the seller. To exercise the option agreement, the Company must pay an additional $200,000 prior to November 25, 2012. If the second payment is not made, the Company loses all rights associated with the agreement.

Retention Liability on USG Oregon LLC Construction Contracts
The Company signed contracts with several major contractors involved in construction activities for USG Oregon LLC. Contracts for two of these major contractors allow for the Company to retain a portion of incurred costs to guarantee certain performance specifications. The retainage levels generally amount to 10% of incurred costs. At June 30, 2011, the retention payable balance was $886,589. Currently, management does not have any performance concerns on these contracts.

NOTE 19 – JOINT VENTURES/NON-CONTROLLING INTEREST

Raft River Energy I LLC
Raft River Energy I is a joint venture between the Company and Raft River I Holdings, LLC a subsidiary of Goldman Sachs Group, Inc. An Operating Agreement governs the rights and responsibilities of both parties. At fiscal year end, the Company had contributed approximately $17.9 million in cash and property, and Raft River I Holdings, LLC has contributed approximately $34 million in cash. Profits and losses are allocated to the members based upon hypothetical liquidation at book value method. For income tax purposes, Raft River I Holdings, LLC will receive a greater proportion of the share of losses and other income tax benefits. This includes the allocation of production tax credits, which will be distributed 99% to Raft River I Holdings, LLC and 1% to the Company during the first 10 years of production. During the initial years of operations Raft River I Holdings, LLC will receive a larger allocation of cash distributions. During the initial term of the agreement, the Company accounts for its investment in this LLC under the equity method as a voting interest entity.

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Gerlach Geothermal LLC
On April 28, 2008, the Company formed Gerlach Geothermal, LLC (“Gerlach”) with our partner, Gerlach Green Energy, LLC (“GGE”). The purpose of the joint venture is the exploration of the Gerlach geothermal system, which is located in northwestern Nevada, near the town of Gerlach. Based upon the terms of the members’ agreement, the Company owns a 60% interest and GGE owns a 40% interest in Gerlach Geothermal, LLC. The agreement gives GGE an option to maintain its 40% ownership interest as additional capital contributions are required. If GGE dilutes to below a 10% interest, their ownership position in the joint venture would be converted to a 10% net profits interest. The Company has contributed $746,000 in cash and $300,000 for a geothermal lease and mineral rights; and the GGE has contributed $697,000 of geothermal lease, mineral rights and exploration data.

The consolidated financial statements reflect 100% of the assets and liabilities of Gerlach, and report the current non-controlling interest of GGE. The full results of Gerlach’s operations will be reflected in the statement of operations with the elimination of the non-controlling interest identified.

Oregon USG Holdings LLC
In September 2010, the Company’s subsidiary, Oregon USG Holdings LLC (“Oregon Holdings”), signed an Operating Agreement with Enbridge Inc. (“Enbridge”) for the right to participate in the Company’s project in the Neal Hot Springs project located in Malheur County, Oregon. The agreement provided for the issuance of a $5 million promissory note with a conversion option. After conversion and an additional capital contribution of $13.8 million, Enbridge would receive a 20% direct ownership interest in Oregon Holdings. At the Company’s election, the agreement allows for an additional payment obligation of up to $5 million that would increase Enbridge’s ownership by 1.5 percentage points for each $1 million contributed. Added to their base 20% ownership, additional payments could increase Enbridge’s ownership to a maximum of 27.5% .

In September 2010, Oregon Holdings received funding under the $5 million convertible promissory note. On April 11, 2011, the note ($5,109,315 including accrued interest) was converted to an equity interest. On that same date, Enbridge provided an additional equity investment of $13 million and received 20% direct ownership interest in Oregon Holdings. Subsequent to the fiscal quarter ended June 30, 2011, the remaining funds were provided to Oregon Holdings that totals the $18.8 million stipulated in the original Operating Agreement. The Company has contributed $13 million to Oregon Holdings and has an 80% ownership interest. Oregon Holdings has a 100% ownership interest in USG Oregon LLC.

The consolidated financial statements reflect 100% of the assets and liabilities of Oregon Holdings and USG Oregon LLC, and report the current non-controlling interest of Enbridge. The full results of Oregon Holdings and USG Oregon LLC’s operations will be reflected in the statement of operations with the elimination of the non-controlling interest identified.

NOTE 20 – CUMULATIVE CHANGE IN ACCOUNTING ESTIMATE CAPITALIZATION POLICY

During the quarter ended June 30, 2011, it was noted by Company management that certain costs related to development activities incurred for USG Oregon LLC had been expensed in the prior period according to the capitalization policies instituted at that time that have been amended to match policies recommended by the external federal agency that is providing assistance for the Neal Hot Springs, Oregon project. The change in estimate adjustment capitalizes $262,305, which was previously reported as corporate administration, professional fees, and lease and equipment repairs that amounted to $2,498, $162,886, and $96,920; respectively.

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NOTE 21 – SUBSEQUENT EVENT

The Company has evaluated events and transactions that have occurred after the balance sheet date through August 9, 2011, which is considered to be the issuance date. The following event was identified for disclosure:

Oregon USG Holdings LLC Funding Completion
On July 6, 2011, Enbridge Inc. provided Oregon USG Holdings LLC the remaining funding of $690,685 (reduced by accrued interest) to total the $18.8 million outlined in the Operating Agreement. See Note 20 for additional contract and equity information.

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

INFORMATION REGARDING FORWARD LOOKING STATEMENTS

This document contains “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements involve a number of risks and uncertainties. We caution readers that any forward-looking statement is not a guarantee of future performance and that actual results could differ materially from those contained in the forward-looking statement. These statements are based on current expectations of future events. You can find many of these statements by looking for words like “believes,” “expects,” “anticipates,” “intend,” “estimates,” “may,” “should,” “will,” “could,” “plan,” “predict,” “potential,” or similar expressions in this document or in documents incorporated by reference in this document. Examples of these forward-looking statements include, but are not limited to:

• our business and growth strategies;
• our future results of operations;
• anticipated trends in our business;
• the capacity and utilization of our geothermal resources;
• our ability to successfully and economically explore for and develop geothermal resources;
• our exploration and development prospects, projects and programs, including construction of new projects and expansion of existing projects;
• availability and costs of drilling rigs and field services;
• our liquidity and ability to finance our exploration and development activities;
• our working capital requirements and availability;
• our illustrative plant economics;
• market conditions in the geothermal energy industry; and
• the impact of environmental and other governmental regulation.

These forward-looking statements are based on the current beliefs and expectations of our management and are subject to significant risks and uncertainties. If underlying assumptions prove inaccurate or unknown risks or uncertainties materialize, actual results may differ materially from current expectations and projections. The following factors, among others, could cause actual results to differ from those set forth in the forward-looking statements:

• the failure to obtain sufficient capital resources to fund our operations;
• unsuccessful construction and expansion activities, including delays or cancellations;
• incorrect estimates of required capital expenditures;
• increases in the cost of drilling and completion, or other costs of production and operations;
• the enforceability of the power purchase agreements for our projects;
• impact of environmental and other governmental regulation, including delays in obtaining permits;
• hazardous and risky operations relating to the development of geothermal energy;
• our ability to successfully identify and integrate acquisitions;

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• our dependence on key personnel;
• the potential for claims arising from geothermal plant operations;
• general competitive conditions within the geothermal energy industry; and
• financial market conditions.

All subsequent written or oral forward-looking statements attributable to us or any person acting on our behalf are expressly qualified in their entirety by the cautionary statements contained or referred to in this section. We do not undertake any obligation to release publicly any revisions to these forward-looking statements to reflect events or circumstances after the date of this document or to reflect the occurrence of unanticipated events, except as may be required under applicable U.S. securities law. If we do update one or more forward-looking statements, no inference should be drawn that we will make additional updates with respect to those or other forward-looking statements.

The U.S. dollar is the Company’s functional currency; however some transactions involved the Canadian dollar. All references to “dollars” or “$” are to United States dollars and all references to $ CDN are to Canadian dollars.

General Background and Discussion

The following discussion should be read in conjunction with our unaudited consolidated financial statements for the quarter ended June 30, 2011 and notes thereto included in this report.

U.S. Geothermal Inc. (“the Company”) is a Delaware corporation. The Company’s common stock trades on the Toronto Stock Exchange under the symbol “GTH” and on the NYSE Amex LLC under the trade symbol “HTM.”

For the quarter ended June 30, 2011, the Company was focused on:

	1)	Constructing the new San Emidio Unit 1 power plant in Nevada;
	2)	Drilling injection wells and start of construction for the Neal Hot Springs project;
	3)	Preparing for and starting the repair of two wells at the Raft River project in Idaho (“Raft River Unit I”;
	4)	Permitting and preparation of a drilling plan and schedule for expansion of the San Emidio project as part of the DOE Innovative Exploration program;
	5)	Negotiating partnership terms for San Emidio Phases I and II and discussing development funding for Phase III;
	6)	Optimizing the operations of the existing San Emidio power plant in Nevada;
	7)	Conducting negotiations for a PPA and with potential equity partners for the El Ciebillo project in Guatemala; and
	8)	The evaluation of potential new geothermal projects acquisitions.

Project Overview

The following is a list of projects that are in operation, under development or under exploration. Projects in operation have producing geothermal power plants. Projects under development have at least a geothermal resource discovery or may have wells in place, but require the drilling of new or additional production and injection wells in order to supply enough geothermal fluid sufficient to operate a commercial power plant. Projects under exploration do not have a geothermal resource discovery occurrence yet, but have significant thermal and other physical evidence that warrants the expenditure of capital in search of the discovery of a geothermal resource. Due to inflation and marketplace increases in the costs of labor and construction materials, previous estimates of property development costs may be low.

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Projects in Operation

Generating

Capacity

Contract

Project

Location

Ownership

(megawatts)(1)

Power Purchaser

Expiration

Raft River (Unit I)

Idaho

JV(2)

13.0

Idaho Power Company

2032

San Emidio (Existing)

Nevada

100%

3.6

Sierra Pacific Power Corp.

2017

(1)	Based on the designed annual average net output. The actual output of the Raft River Unit I plant currently varies between 7.1 and 10.0 megawatts and output of the San Emidio plant is approximately 2.6 megawatts.
(2)	As part of the financing package for Unit I of the Raft River project, we have contributed $16.5 million in cash and approximately $1.5 million in property to Raft River Energy I LLC, the Unit I project joint venture company. Raft River I Holdings, LLC, a subsidiary of The Goldman Sachs Group, contributed $34 million to finance the construction of the project. Additional investment may be required for Unit I to operate at design capacity.
(3)	The repower below includes repairs to operating power plants.

Projects Under Development

Estimated

Target

Projected

Capital

Development

Commercial

Required

Anticipated

Project

Location

Ownership

(Megawatts)

Operation Date

($million)

Power Purchaser

San Emidio Phase I (8.6 MW Repower)

Nevada

100%

5.0

December 2011

$

32

NV Energy

San Emidio Phase II (Expansion)

Nevada

100%

8.6

2nd Quarter 2013

$

50

NV Energy

San Emidio Phase III

Nevada

100%

17.2

4th Quarter 2013

$

100

TBD

Neal Hot Springs I

Oregon

JV(1)

23

3rd Quarter 2012

$

129

Idaho Power

Neal Hot Springs II

Oregon

100%

28

TBD

TBD

TBD

Raft River I (Repower)

Idaho

JV(2)

3

TBD

$

8

Idaho Power

Raft River (Unit II)

Idaho

100%

26

4th Quarter 2013

$

134

Eugene Water and Electric Board

Raft River (Unit III)

Idaho

100%

32

2nd Quarter 2015

$

166

TBD

(1)

In September 2010, the Company’s wholly owned subsidiary (Oregon USG Holdings LLC) entered into agreements that formulated a strategic partnership with Enbridge (U.S.) Inc. (“Enbridge”) may provide up to $23.8 million in funds for the Neal Hot Springs geothermal project. After the planned debt conversion and additional contribution in April of 2011, Enbridge has contributed $18.8 million which they have received a 20% ownership interest in the project.

(2)

As part of the financing package for Unit I of the Raft River project, we have contributed $16.5 million in cash and approximately $1.5 million in property to Raft River Energy I LLC, the Unit I project joint venture company. Raft River I Holdings, LLC, a subsidiary of The Goldman Sachs Group, contributed $34 million to finance the construction of the project. Additional investment may be required for Unit I to operate at design capacity.

Additional Properties
Project		Location			Ownership			Target Development (Megawatts)
Gerlach		Nevada			60%			To be determined
Granite Creek		Nevada			100%			To be determined
El Ceibillo		Guatemala, S.A.			100%			To be determined

Resource Details
											Resource
		Property Size			Temperature						Potential
Property		(square miles)			(°F)						(Megawatts)			Depth (Ft)			Technology
Raft River		10.8 (1)			275-302			(2)			127.0	(1)		4,500-6,000			Binary
San Emidio		35.8			289-305			(2)			64.0	(4)		1,500-2,000			Binary
Neal Hot Springs		9.6			311-347			(3)			50.0	(5)		2,500-3,000			Binary
Gerlach		5.6			338-352			(3)			18.0			TBD			Binary
Granite Creek		8.5			TBD						25.0	(6)		TBD			Binary
El Ciebillo		38.6			410-446			(3)			TBD			TBD			Steam

(1)	A third party’s assessment of 94 megawatts was based on 6.0 square miles. The Company acquired additional acreage. The resource estimate of 127.0 megawatts was provided by Geothermex.

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(2)	Actual production temperatures for existing wells.
(3)	Probable reservoir temperature as measured with a geothermometer.
(4)	A estimate by Black Mountain of 44.0 megawatts.
(5)	A third party resource estimate with respect to 23.0 megawatts, remainder is an internal estimate.
(6)	An estimate provided by Geothermex.

Raft River Update

Raft River Energy Unit I, located in southern Idaho, is a binary cycle geothermal power plant with 13 net megawatts of installed capacity. The power plant achieved commercial operation in January 2008.

Raft River Unit I operated at 94.6% availability and generated an average of 6.8 net megawatts during the first fiscal quarter. For the 2010 calendar year, the plant averaged 8.39 net megawatts of generation with 97.7% availability. The plant is operating at reduced output due to the continued loss of temperature from production well RRG-7 and the shutdown of production well RRG-2.

In early January 2009, production well RRG-7 underwent a temperature decline that has now reduced the inlet fluid temperature to the power plant by approximately 11.8 degrees Fahrenheit. Power generation has been reduced by an estimated 1.5 megawatts due to the lower fluid temperature entering the plant. It was determined that the cement in a lap joint (an overlap of well casing) had failed and washed out, thereby allowing lower temperature fluid to enter the wellbore. Production well RRG-2 was shut down on June 10, 2010 due to a reduction in flow and increased motor load which indicates an impending pump failure.

On May 17, 2011, Raft River I Holdings, LLC consented to a repair plan for both RRG-2 and RRG-7. A Repair Services Agreement was executed between US Geothermal Services and Raft River Energy I LLC, whereby US Geothermal Services will provide up to $1.65 million in funding and manage the well repairs. The cost of the repairs will be repaid from project cash flow, and will be paid preferentially at a rate of 90% of increased cash created by the repairs. A fee of 12.75 % of the actual repair cost incurred will be paid to USG Services. The outstanding balance of the repair cost will also earn USG Services interest income at the rate of 12.0 % per-annum.

Well repairs on RRG-2 and RRG-7 were started in mid-May. At well RRG-7, the pump was pulled, reconditioned and has been reinstalled. A slough of formation material was identified in the open wellbore, and the drill ran a drill bit to the bottom of the well to clean it out and installed a perforated liner to insure that no more material would block the well. The primary focus of the RRG-7 repair was the injection of cement (a “squeeze job”) into a leaking lap joint to stop the inflow of cooler brine and restore the operating temperature of the well. The squeeze job was completed successfully and the well was put back on line July 2nd. The production temperature of the well has recovered to 296.5°F and is slowly increasing toward the former level of 299°F. Repair of well RRG-2 is still in progress.

The $10.2 million DOE cost-shared thermal fracturing program has been delayed while a NEPA evaluation was being done to address any potential seismic issues that may result from the program. The Company’s contributions are made in-kind by the use of the RRG-9 well, well field data, and monitoring support totaling $228,089. Eight solar powered seismic stations were installed in June 2010 to provide a base line of seismic data and will be used to monitor potential impacts from the test. Construction is complete on the injection pipeline that extends from the Unit 1 power plant to well RRG-9. A detailed, 3-D magnetotelluric survey was completed during the 3^rd fiscal quarter of 2010. A delay in starting the injection program was caused by a NEPA issue and it is now expected that a drill rig will be mobilized to set casing down to the geologic formation targeted for the thermal fracture test, and the first phase of cold water injection will commence during the 3rd quarter of 2011.

Raft River Operating Agreement

We hold a 50% interest in Raft River Energy I LLC, which owns Raft River Unit I (“Unit I”). Construction of Unit I required substantial capital, and partnering with a co-venturer tax partner allowed us to share the risks of ownership and monetize valuable tax credits and benefits. The joint venture partner structure allowed the project to monetize production tax credits which would not otherwise have been available to us. When Unit I generates full capacity of 13 megawatts, we estimate we will receive cash payments totaling approximately $1.6 million for each of the first four years of its operations. While Unit I generates at less than full capacity, our annual cash payments from the Raft River I project will be lower. If insufficient cash is generated to satisfy all joint venture obligations, the management fees will be deferred. See Note 5 “Investment in Subsidiaries” in the financial statements for detail of cash payments from RREI.

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The Company’s interests in the RREI as defined in the partnership agreements are summarized as follows:

	(1)	U.S. Geothermal allocates 70% of income and receives 70% of available cash from RECs sold to third- parties. After year 10, REC income is shared with Idaho Power Co. For additional details, see U.S. Geothermal’s Form 10-Q filed on August 10, 2009 (Exhibit 10.36).
	(2)	Flip to next tier occurs after the later of 10 years or Raft River I Holdings’ target IRR is achieved.
	(3)	Flip to next tier occurs after Raft River I Holdings’ target IRR is achieved.

Neal Hot Springs Update

Neal Hot Springs is a commercial geothermal resource located in Eastern Oregon that has a 23 megawatt power plant under construction.

On February 26, 2009 U.S. Geothermal submitted a loan application for the Neal Hot Springs project to the DOE’s Energy Efficiency, Renewable Energy and Advanced Transmission and Distribution Solicitation loan guarantee program under Title XVII of the Energy Policy Act of 2005. The financial closing for the DOE loan guarantee took place on February 23, 2011 which secured a $96.8 million loan guarantee from the Department of Energy and a direct loan from the U.S. Treasury’s Federal Financing Bank. The $96.8 million loan represents 75% of the total project cost which is now estimated to be $129 million for the project. The DOE loan is a combined construction and 22 year term loan. The interest rate on the loan is set at 37.5 basis points over the current average yield on outstanding marketable obligations of the United States of comparable maturity. With the $18.8 million equity investment made by Enbridge Inc., the project is 100 percent financed.

Notice to proceed was issued to both the EPC contractor (Industrial Builders Inc.) and equipment supplier (TAS Energy) on February 24, 2011. Detailed design and construction of the supercritical cycle power plant utilizing significantly improved technology is currently in progress. The new plant, which will consist of three separate power modules, is designed to deliver approximately 23 megawatt of power net to the grid. The first module is scheduled to begin commercial operations during the second calendar quarter of 2012 and the full plant is scheduled to be complete during the 3^rd quarter 2012.

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The EPC contractor has commenced site work and an office and shop complex has been constructed. The power plant area was cleared and grubbed, and excavations for the air cooled condenser foundations are being dug, compacted and formed.

After the long term flow test that was completed in January, a reservoir model was completed on March 24, 2011 by the Company’s consulting reservoir engineer, and after review, the DOE independent reservoir engineer issued a reservoir certificate on March 31, 2011. The final reservoir report and certificate confirmed that the reservoir was able to sustain the production necessary for the planned 23 megawatt project from the existing four production wells. An injection plan was developed as part of the plan, and drilling operations resumed in April 2011 to complete the injection well field for the project. A large diameter injection well, NHS-12 was drilled on the western boundary of the geothermal field to a depth of 6,000 feet. Two additional wells are currently being drilled; NHS-9 and T/G 20, and a third drill rig may be mobilized within the next month.

The Company received the Conditional Use Permit from the Malheur County Planning Commission for construction of its proposed 23 net megawatt power plant at Neal Hot Springs in eastern Oregon. The Conditional Use Permit received unanimous approval at a September 24, 2009 Planning Commission meeting and was issued on October 28, 2009. All of the Federal Energy Regulatory Commission (“FERC”) mandated transmission studies have been completed by Idaho Power Company. An interconnection agreement was signed with the Idaho Power Company in February 2009. Idaho Power Company is responsible for the construction of the transmission line with the cost paid for by the project. A notice to proceed was issued to Idaho Power Company to commence procurement and construction of the transmission line on April 8, 2011. As of the end of the quarter, Idaho Power has constructed access roads and is in the process of setting poles along the transmission line route.

The PPA for the project was signed on December 11, 2009 with the Idaho Power Company. The PPA has a 25 year term with a starting price of $96 per megawatt-hour and escalates at a variable percentage annually. On May 20, 2010, the Idaho Public Utilities Commission approved the PPA with no changes to the terms and conditions.

San Emidio, Nevada

The San Emidio geothermal power plant has been producing power since 1987 and sells electricity to Sierra Pacific Power Corporation under a power purchase agreement that extends through 2017. Deeper wells with higher temperatures were drilled in 1994 to supply the plant after output declined due to cooling of the original, shallow production wells. The current configuration of the plant consists of four 1.2 gross megawatt Ormat Energy Converters (“OEC”), five production wells (two wells in use and three on standby), and four injection wells (three wells in use and one on standby). A cooling tower was added in 1998 to improve summer peak power generation. During the first fiscal quarter ended June 30, 2011, the San Emidio plant operated at 98.1% availability and generated an average of 2.59 net megawatts during the period.

The San Emidio expansion will take place in three phases. Phase I is a repower, and Phases II and III will be the expansion. Phase I will utilize the existing production and injection wells with installation of a new, more efficient 8.6 MW net power plant now under construction and expected to be online in the fourth quarter of 2011. The Phase I repower is anticipated to cost approximately $32 million. The Phase II expansion is anticipated to cost approximately $50 million. For Phases I and II, the Company has made an application for the DOE’s 1705 loan guarantee program anticipating that 75% of the total project capital may be funded by a Department of Energy loan guarantee, with the remainder funded through equity financing. The Company was notified on May 10 that the loan guarantee application had been put on hold by the DOE due to budgetary constraints. A second letter was received on June 13 that confirmed that our application is still on hold, pending clarification of the possible availability of funds under the 2011 Continuing Resolution. We continue to seek clarification and reinstatement into the loan guarantee program. Discussions with several senior lenders for a long term loan to take out the SAIC construction loan are ongoing. Phase III is a further expansion planned a for 17.2 MW net utilizing two additional power modules similar to Phases I and II.

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The Phase I repower began construction in the third calendar quarter of 2010. The Phase II expansion is anticipated to begin construction in the third calendar quarter of 2011 with commercial operations commencing in the second calendar quarter of 2013. The Company expects to utilize Investment Tax Credits in connection with both the repower and the Phase II expansion. Both Phases I and II required an amendment to the Sierra Pacific Power Purchase Agreement, as discussed below. Phase III is expected to follow construction of Phase II and be online by the fourth quarter of 2013. Both Phase II and Phase III are subject to successful development of additional production wells through exploration and drilling activities.

The existing, historic power plant will be placed on operational standby when the Phase I plant comes on line. As shown in the Project Development table above, the Phase I repower is anticipated to cost approximately $32 million, with Phase II at approximately $50 million and Phase III approximately $100 million. We expect 75% of the Phase I and Phase II development may be funded by project loans, with the remainder funded through equity financing.

The Phase I power plant began construction in August of 2010, with final completion scheduled to occur during the 4^th quarter 2011. All major foundations have been placed, main brine line tie to the new plant site completed, transmission line from the new plant site to the existing line installed, the fresh water line for the cooling tower installed, the chemical building completed, underground conduit installed, main transformer delivered and set, and the cooling tower erection is nearly complete. Other ongoing work includes installation of the cooling water circulation lines, and completing the plant site final grading in preparation for delivery of the equipment skids. The bulk of the major components for the power plant are scheduled to start arriving in late July and early August, an approximate 1 month delay to the equipment delivery schedule. The on-site construction work is ahead of schedule.

Phase II began development in the second calendar quarter of 2010 with commercial operations anticipated to commence in the second calendar quarter of 2013. The Company expects that the project will be granted about $28 million in ITC cash grant in lieu of PTC in connection with approximately $82 million Phase I and Phase II megawatt development.

On June 1, 2011, a PPA was signed with Sierra Pacific Power Company d/b/a NV Energy for 19.9 megawatts of electricity. The PPA has a 25 year term with a base price of $89.75 per megawatt-hour, and a 1 percent annual escalation rate. The electrical output from both Phase I and Phase II will be sold under the terms of the PPA. The PPA is subject to approval by the Public Utility Commission of Nevada.

The Company entered into agreements with Science Applications International Corporation (“SAIC”) for a project loan and an engineering procurement and construction contract for the San Emidio Phase I power plant. SAIC’s design-build subsidiary, the Benham Companies LLC, will execute the construction of an 8.6 net megawatt power plant at San Emidio, Nevada. TAS Energy of Houston, Texas will supply a modular power plant to the project. The financing agreement calls for the contractor to provide a non-recourse project loan for the estimated $32 million dollar project. The construction loan is expected to be repaid with a long term project loan.

Two System Feasibility Studies were initiated in July 2008 with Sierra Pacific Power Company to begin the FERC mandated transmission study process for the development of the San Emidio resource. The studies examined two levels of power generation; 15 megawatts and 45 megawatts, several transmission routes and the costs associated with each level of generation. The 15 megawatt study, which is directed toward the Phase I repower and Phase II, has completed the study process and resulted in an increase of available transmission to 16 megawatts. A Small Generator Interconnection Agreement for 16 megawatts of transmission capacity was executed with Sierra Pacific Power Company on December 28, 2010.

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The 45 megawatt study, which is directed toward the full build out of San Emidio with the addition of the 17.2 megawatt Phase III project, completed the second phase System Impact Study in April. A draft Interconnection Facilities Study, the third and final study, was received on November 22, 2010. The remainder of the 45 megawatt study has been put on hold pending further exploration of the project.

On October 30, 2009, the Company was awarded $3.77 million in Recovery Act funding for the exploration and development of its San Emidio geothermal power project using advanced geophysical exploration techniques. This award was categorized under the “Innovative Exploration and Drilling Projects” section of the American Recovery and Reinvestment Act. The project at San Emidio will apply innovative, seismic and satellite imagery techniques along with state-of-the-art structural modeling, to locate large aperture fractures that represent high-productivity geothermal drilling targets.

The results of the innovative portion of the exploration program have been finalized and submitted to the DOE for review. Two zones along the 4.5 mile long San Emidio fault structure were identified as high quality targets for drilling. The program is designed to include drilling up to 10 – 2,000’ deep temperature gradient wells which will be followed by a full diameter production well. The drilling portion of the program under the grant is a 50-50 cost share with the DOE. Drill sites for the temperature gradient wells have been selected, and permitting is underway for a targeted 3^rd Quarter 2011 start on the drilling program.

Guatemala

A geothermal energy rights concession located 14 kilometers southwest of Guatemala City was awarded to U.S. Geothermal Guatemala S.A., a wholly owned subsidiary of the Company in April. The concession contains 24,710 acres (100 square kilometers) in the center of the Aqua and Pacaya twin volcano complex.

The concession contains the El Ceibillo geothermal project which has nine existing geothermal wells that were drilled in the l990s and have depths ranging from 560 to 2,000 feet (170 to 610 meters). Six of the wells have measured reservoir temperatures in the range of 365°F to 400°F and have high conductive gradients that indicate rapidly increasing temperature with depth. Fluid samples and mineralization from the wells indicate the existence of a high permeability reservoir below the existing well field.

An office and staff are located in Guatemala City and planning is underway to advance the project with initial work focused on negotiating necessary surface and access rights, a power sales agreement with the local utility company, strategic investors, and potential project lenders. Follow up work will include a detailed geophysical program, geologic mapping, sampling of hot springs, and to redrill one or two of the existing wells to test for deep, high temperature permeability. Discussions and planning are underway for the development of a power purchase agreement. Also, discussions are taking place with several interested parties for the potential sale of a minority equity interest in the El Ciebillo project to a qualified local partner.

Gerlach Joint Venture

The Gerlach Joint Venture, located adjacent to the town of Gerlach in Washoe County, Nevada is made up of both private and BLM geothermal leases. The Peregrine well, a historic exploration slim hole that encountered a lost circulation zone at a depth of 975 feet, was redrilled and the hole was opened from a 6.5 inch diameter well to a 12.5 inch diameter well. Lost circulation was confirmed with three zones through the 900 to 1,024 foot interval. The well was stopped at 1,070 total depth. Temperature surveys and a short clean out flow test were conducted on the well.

A 2,000 foot deep temperature gradient well is permitted for the BLM lease site and is designed to test the deep temperature potential of the central portion of the interpreted reservoir block. A production target has been identified from previous drilling data at a depth of 2,700 to 3,000 feet.

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Granite Creek

The Granite Creek assets are comprised of three BLM geothermal leases totaling approximately 5,414 acres (8.5 square miles) located about 6 miles north of Gerlach, Nevada along a geologic structure known to host geothermal features including the Great Boiling Spring and the Fly Ranch Geyser. A first stage gravity geophysical program was completed in the third quarter of 2008 and will be used to evaluate the resource potential, and help determine where to drill temperature-gradient exploration wells.

Operating Results

For the three months ended June 30, 2011, the Company reported a net loss of $2.4 million dollars ($0.03 loss per share) which represented a 61.9% increase from the same period in 2010. A notable favorable variance was reported for the San Emidio operations, and notable unfavorable variances were reported in professional and management fees, salaries and related costs, stock based compensation, and subsidiary operations.

San Emidio, Nevada Plant Energy Sales and Plant Operating Expenses

For the three months ended June 30, 2011, the San Emidio plant reported a net loss of $16,818 ($75,065 net loss in 2010), which represented a 78.1% decrease in operating loss from the same period in 2010. Energy sales for the three months ended June 30, 2011, were $623,731, which was a 9.1% increase from the same period in 2010. Energy production for the quarter ended June 30, 2011 was consistent with production levels in the same period in 2010. The average rate received increased 7.1% from the quarter ended June 30, 2010 to the quarter ended June 30, 2011. No energy credit revenues were earned in the quarter ended June 30, 2010 ($38,339 earned in the quarter ended June 30, 2011).

Summarized statements of operations for the San Emidio, Nevada plant are as follows:

	Three Months Ended June 30,
		2011						2010						Variance
		$			%*			$			%*			$			%**
Operating revenues:
Energy sales		623,731			94.2			571,646			100.0			52,085			9.1
Energy credit sales		38,339			5.8			-			-			38,339			-
		662,070			100.0			571,646			100.0			90,424			15.8
Operating expenses:
General and administrative		74,068			11.3			59,786			10.5			(14,282	)		(23.9	)
Salaries and related costs		267,854			40.5			198,761			34.8			(69,093	)		(34.8	)
Operations:
Repairs and maintenance		11,482			1.7			35,892			6.3			24,410			68.0
Other		59,804			9.0			92,690			16.2			32,886			35.5
Rent and lease		6,005			0.9			9,384			1.6			3,379			36.0
Purchased utilities		13,638			2.1			13,671			2.4			33			0.2
Depreciation and amortization		246,038			37.2			238,087			41.6			(7,951	)		(3.3	)
		678,889			102.5			648,271			113.4			(30,617	)		(4.7	)
Net Loss		(16,819	)		(2.5	)		(76,625	)		(13.4	)		59,807			78.1
%* - represents the percentage of total operating revenues.                    %** - represents the percentage of change from 2010 to 2011.

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Key quarterly production data is summarized as follows:

								Ave. Rate						Depreciation
		Kilowatt			Energy			per						&
		Hours x			Sales			Kilowatt-			Net Loss			Amortization
Quarter Ended:		1,000			($)			Hour ($)			($)			($)
June 30, 2009		2,851			243,752			0.0855			(589,082	)		200,972
September 30, 2009		5,224			540,841			0.1035			(46,118	)		207,066
December 31, 2009		4,689			463,286			0.0988			(348,073	)		207,136
March 31, 2010		5,018			496,104			0.0989			(163,597	)		207,191
June 30, 2010		5,449			571,646			0.1049			(76,625	)		238,087
September 30, 2010		5,260			636,992			0.1210			(405	)		298,948
December 31, 2010		5,938			629,867			0.1061			(104,155	)		298,948
March 31, 2011		5,656			600,702			0.1062			(61,083	)		299,010
June 30, 2011		5,556			623,731			0.1123			(16,818	)		246,038

Gain on Investment in Subsidiary (Raft River Energy I, LLC)

The Company uses the hypothetical liquidation at book value method (“HLBV”) for allocating of Raft River Energy I, LLC’s (“RREI”) profits and losses. This method utilizes the specific terms outlined in the RREI’s operating agreement and other authoritative documents. These terms include cash disbursement terms, associated financial instruments, debt arrangements, and rights to specific revenue streams. The primary element of the profit and loss allocation from inception has been the amount of renewable energy credits earned.

The Company’s gain from RREI of $38,677 for the three months ended June 30, 2011, decreased $34,412 (47.1 %) from the same period in 2010. Under the current terms of the operating agreement, the Company receives 70% of energy credit sales generated by RREI. In May 2011, the repairs of wells RRG-2 and RRG-7 began under a repair service agreement between the two partners. The many repair activities along with the already under performing wells resulted in production decreases. Production decreased 19.6% in the quarter ended June 30, 2011, from the same period in 2010. The production decrease directly affected the renewable energy credit revenue which was down $29,548 (25.8%) . During the current quarter, repairs at well RRG-7 included a pump rebuild, sealing of a cold water leak, well clean out, and installation of a perforated liner. The repairs were completed in July 2011, and the well is functioning up to expectations. Well RRG-2 repairs included a pump rebuild, liner replacement and removal of an obstruction. RRG-2 repairs have not been completed. The combined repair costs have exceeded $1.25 million as of June 30, 2011 ($818,149 under the repair service agreement).

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The summarized statements of operations for RREI are as follows:

		Three Months Ended June 30,
		2011						2010						Variance
		$			%*			$			%*			$			%**
Operating revenues:
Energy sales		651,059			88.5			806,439			87.6			(155,380	)		(19.3	)
Energy credit sales		84,846			11.5			114,394			12.4			(29,548	)		(25.8	)
		735,905			100.0			920,833			100.0			(184,928	)		(20.1	)
Operating expenses:
General operations		731,807			99.4			855,969			93.0			1,408,784			14.5
General repairs and maintenance		662,557			90.0			136,907			14.9			(525,650	)		(383.9	)
Repairs under repair service agreement		818,149			111.2			-			0.0			(818,149	)		-
Depreciation and amortization		1,535,487			69.4			512,211			55.6			1,844			0.4
		2,722,880			370.0			1,505,087			163.4			1,217,793			(80.9	)
Operating loss		(1,986,975	)		(270.0	)		(584,254	)		(63.4	)		(1,402,721	)		63.4
Other income		302			0.0			50			0.0			252			504.0
Net loss		(1,986,673	)		(270.0	)		(584,204	)		(63.4	)		(1,402,469	)		(240.1	)
U.S. Geothermal Inc.’s allocation of net loss		38,677						73,089						(34,412	)		(47.1	)

%* - represents the percentage of total operating revenues.
%** - represents the percentage of change from 2010 to 2011.

Key quarterly production data is summarized as follows:

		Kilo-						Renewable			Net Income (Loss)
		watt			Energy			Energy						USG’s
		Hours x			Sales			Credit Sales			Totals			Portion
Quarter Ended:		1,000			($)			($)			($)			($)
June 30, 2009		15,479			848,176			109,873			(1,592,374	)		58,831
September. 30, 2009		17,940			1,253,724			125,788			(450,307	)		82,312
December 31, 2009		19,602			1,352,016			133,644			76,634			92,981
March 31, 2010		20,252			1,158,710			131,621			(102,333	)		89,805
June 30, 2010		17,599			806,439			114,394			(584,204	)		73,089
September 30, 2010		16,116			1,019,499			104,733			(123,032	)		71,035
December 31, 2010		17,878			1,173,232			113,090			(13,931	)		77,893
March 31, 2011		16,898			914,457			101,382			321,507			66,739
June 30, 2011		14,144			689,448			84,846			(1,986,673	)		38,677

Professional and Management Fees

For the three months ended June 30, 2011, the Company incurred professional and management fees of $1,266,767, which was an increase of $711,219 (128.0%) from the same period in 2010. The primary difference related to $1,088,091 in fees paid in the current quarter to a placement agent for obtaining the equity partner in the Neal Hot Springs, Oregon project.

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Salaries and Wages

For the three months ended June 30, 2011, the Company reported $599,036 in salaries and related costs, which was an increase of $128,982 (27.4%) from the same period in 2010. During the current quarter, the Company added an additional management and development employee and paid bonuses which totaled $450,000. A significant port of the overall compensation increases were offset by a higher percentage of salaries and related costs that were allocated to capital projects. Allocations have been made for the Neal Hot Springs project for engineering, design, permitting and project management efforts needed for well drilling and reservoir evaluation. At San Emidio, salary cost allocations have been made for efforts primarily related to the transmission line studies, the new power plant design, and on site construction for Phase I of the project.

Management and development employee salaries and related costs allocated to major U.S. Geothermal projects are summarized as follows:

		For the Three Months Ended June 30,
		2011			2010			Variance
Company/Project		$			$			$			%
USG Nevada LLC, San Emidio Phase I		157,310			28,020			129,290			461.4
USG Oregon LLC, Neal Hot Springs Project		231,527			108,845			122,682			112.7
		388,837			136,865			251,972			184.1

% - represents the percentage of change from 2010 to 2011.

Stock Based Compensation

For the three months ended June 30, 2011, the Company reported $534,898 in stock based compensation, which was an increase of $367,884 (220.3%) from the same period in 2010. The variance was primarily a function of the value assigned to stock option grants. On June 3, 2011, the Board of Directors approved a grant of 2,590,000 stock options to employees. In the prior year, the stock option grant was not approved until September 10, 2010.

Off Balance Sheet Arrangements

As of June 30, 2011, the Company does not have any off balance sheet arrangements.

Liquidity and Capital Resources

We believe our cash and liquid investments at June 30, 2011 are adequate to fund our general operating activities through March 31, 2012 including drilling at Neal Hot Springs, general development support activities at San Emidio and repair activities at Raft River. In addition to government loans and grants discussed below, we anticipate that additional funding may be raised through financial and strategic partnerships, the issuance of equity and/or through the sale of ownership interest in tax credits and benefits.

The current financial credit crisis is not anticipated to impact the ability of our customers, Idaho Power Company and Sierra Pacific Power, to pay for their power. This power is sold under long-term contracts at fixed prices to large utilities. Projections for 2011 indicate that both projects, Raft River and San Emidio, will generate positive cash flows to the Company. However, the current status of the credit and equity markets could delay our project development activities while the Company seeks to obtain economic credit terms or a favorable equity market price to further the drilling and construction activities. The Company continues discussions with potential investors to evaluate alternatives for funding at the corporate and project levels. We are also pursuing additional available DOE loans and guarantees in order to reduce interest costs for any debt instruments the Company may require.

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On March 7, 2011, the Company closed a direct registered placement of 5,000,000 shares of Common Stock at a price of $1.00 per share for gross proceeds of $5 million. Each investor also received a Common Stock Purchase Warrant exercisable for 50% of number of shares of Common Stock purchased. Each Warrant will entitle the holder to purchase one additional share of Common Stock for $1.075 per share. The Warrants expire March 3, 2012. The issue included a placement agent fee of 112,000 Common Shares and 56,000 Warrants plus expenses of approximately $15,000. The securities were offered by the Company pursuant to a registration statement filed with the Securities and Exchange Commission (“SEC”), which became effective on December 31, 2010. A prospectus supplement relating to the offering was filed with the SEC on February 28, 2010. After deducting for fees and expenses, the net proceeds were approximately $4.95 million. The net proceeds of the offering will be used for general working capital, including exploration, development and expansion of its geothermal properties

On February 24, 2011, the Company completed the financial closing with the U.S. Department of Energy (“DOE”) of a $96.8 -million loan guarantee to construct its planned 23-megawatt-net power plant at Neal Hot Springs in Eastern Oregon. Neal Hot Springs is the first geothermal project to complete a loan guarantee under DOE’s Title XVII loan guarantee program, which was created by the Energy Policy Act of 2005 to support the deployment of innovative clean energy technologies. The DOE loan guarantee will guarantee a loan from the U.S. Treasury’s Federal Financing Bank. The $96.8 -million Federal Financing Bank loan represents 75% of total project cost. When combined with the previously announced equity investment by Enbridge Inc., the loan provides 100% of the anticipated capital remaining to fully construct the project.

In September 2010, USG Oregon LLC (a wholly owned subsidiary) entered into agreements with Enbridge (U.S.) Inc. that formed a strategic and financial partnership to finance the Neal Hot Springs project located in eastern Oregon. A component of these agreements included a $5 million convertible promissory note. Upon conversion, the note shall be considered to be an equity contribution to the Company’s subsidiary. The conversion occurs automatically upon the closing of the Department of Energy (“DOE”) guaranteed project loan. The agreements also provide for additional equity contributions of $13.8 million from Enbridge that when combined with the $5 million convertible promissory note, will earn Enbridge a 20% direct ownership in the subsidiary. In the event of cost overruns for the project, and at the election of the Company, an additional payment obligation of up to $5 million would be contributed by Enbridge that would increase their direct ownership by 1.5 percentage points for each $1 million contributed. Added to their base 20% ownership, additional payments could increase Enbridge’s ownership to a maximum of 27.5% .

In August 2010, USG Nevada LLC (a wholly owned subsidiary) entered into agreements with Benham Companies, LLC (subsidiary of Science Applications International Corporation) for a project loan. The project loan is expected to provide substantially all of the funding needed to construct an 8.6 net megawatt power plant for Phase I of the San Emidio project in northwest Nevada. Construction costs are estimated to be approximately $32 million and expected to be completed in October 2011. The construction loan is planned to be repaid with long term financing from available sources such as the Section 1705 loan guarantee program from the U.S. Department of Energy.

On March 16, 2010, the Company closed a private placement of securities issued pursuant to a securities purchase agreement (the "Purchase Agreement") entered into with several institutional investors, pursuant to which the Company issued 8,209,519 shares of common stock at a price of $1.05 per share for gross proceeds of approximately $8.6 million (the "Private Placement"). Pursuant to the terms of the Private Placement, each investor was also issued a common share purchase warrant (a "Warrant") exercisable for 50% of the number of shares of common stock purchased by the investor. The Company paid commissions to agents in connection with the Private Placement in the amount of approximately $516,000 and issued warrants to purchase up to 246,285 shares of common stock. The net proceeds of the offering (approximately $8.0 million) will be used by the Company to further develop its Neal Hot Springs geothermal project and for general working capital purposes.

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On October 30, 2009, the Company was awarded $3.77 million in Recovery Act funding for the exploration and development of its San Emidio geothermal power project using advanced geophysical exploration techniques. This award was categorized under the “Innovative Exploration and Drilling Projects” section of the American Recovery and Reinvestment Act. The project at San Emidio will apply innovative, seismic and satellite imagery techniques along with state-of-the-art structural modeling, to locate large aperture fractures that represent high-productivity geothermal drilling targets.

On August 17, 2009, the Company completed a private placement of 8,100,000 Subscription Receipts (“Receipt”) at $1.35 CDN per Receipt for aggregate gross proceeds of CDN $10,935,000. Each Receipt was exchanged on December 17, 2009 for one share of common stock of the Company and one half of one common stock purchase warrant (a "Warrant"). Each Warrant entitles the holder thereof to acquire one additional share of common stock of the Company for $1.75 for 24 months from closing. The placement agents have been paid an aggregate cash fee of CDN $656,100, representing 6% of the aggregate gross proceeds of the offering, and have been issued compensation options, exercisable for 24 months, entitling the placement agents to purchase up to 243,000 shares of common stock of the Company at $1.22. The proceeds provided funds to drill production size wells at Neal Hot Springs to increase production capacity to 22 MW and allow a 30-day flow test to verify the well reservoir capacity. Completion of drilling is a condition precedent to the funding from the DOE loan program, if our application is approved.

Potential Acquisitions

The Company intends to continue its growth through the acquisition of ownership or leasehold interests in properties and/or property rights that it believes will add to the value of the Company’s geothermal resources, and through possible mergers with or acquisitions of operating power plants and geothermal or other renewable energy properties.

Critical Accounting Policies

The discussion and analysis of our financial condition and results of operations are based upon the consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. The preparation of these financial statements requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been made. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for the financial statements.

See Management’s Discussion and Analysis and the financial statements and related footnotes included in our Annual Report on Form 10-K for the year ended March 31, 2011, for a description of our critical accounting policies.

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Item 3 – Quantitative and Qualitative Disclosures about Market Risk

Interest Risk on Investments

At June 30, 2011, the Company held investments of $5,354,080 in money market accounts. These are highly liquid investments that are subject to risks associated with changes in interest rates. The money market funds are invested in governmental obligations with minimal fluctuations in interest rates and fixed terms.

Foreign Currency Risk

The Company is subject to a limited amount of foreign currency risks associated with cash deposits maintained in Canadian currency. The Company has utilized and it is continuing to utilize the Canadian markets for raising capital. By proper timing of the transactions and then maintenance of adequate operating funds in other financial resources, the Company has been able to mitigate some of the risks surrounding foreign currency exchanges. At quarterly period ended June 30, 2011, the Company held deposits that amounted to less than $10,000 in U.S. dollar equivalents. As a matter of standard operating practice, the Company does not maintain large balances of Canadian currency; and substantially all operating transactions are conducted in U.S. dollars.

Prior to April 1, 2007, the strike price for the Company’s stock option plan had been stated in Canadian dollars as the plan had been administered through our Vancouver office and Pacific Corporate Trust Company. This subjected the Company to foreign currency risk in addition to the normal market risks associated with the stock price fluctuations. A long-term liability has been established to reflect the fair value of the stock options payable. The strike price on subsequent option grants is stated in U.S. dollars.

Commodity Price Risk

The Company is exposed to risks surrounding the volatility of energy prices. These risks are impacted by various circumstances surrounding the energy production from natural gas, nuclear, hydro, solar, coal and oil. The Company has been able to mitigate, to a certain extent, this risk by signing a power purchase contract for a 25 year period for the first power plant scheduled to go into production. This type of arrangement will be the model for power purchase contracts planned for future power plants.

Item 4 - Controls and Procedures

An evaluation was performed under the supervision and with the participation of our management, including the Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) or 15d-15(e) under the Securities Exchange Act of 1934, as amended) as of the end of the period covered by this report. Based on that evaluation, our management, including the CEO and CFO, concluded that our disclosure controls and procedures were effective at the end of this period covered by this report to ensure that information we are required to disclose in the reports that we file or submit under the Securities Exchange Act of 1934, is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms relating to us, including our consolidated subsidiaries, and was accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosure.

There has been no change to our internal control over financial reporting during the quarter ended June 30, 2011 that has materially affected, or is likely to materially affect, our internal control over financial reporting.

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PART II- OTHER INFORMATION

Item 1 - Legal Proceedings

None.

Item 1A - Risk Factors

See “Risk Factors” in our annual report on Form 10-K for the year ended March 31, 2010 and in our quarterly report on Form 10-Q for the quarter ended September 30, 2010. There have been no material changes in the risk factors during the quarter ended June 30, 2011.

Item 2 - Unregistered Sales Of Equity Securities And Use Of Proceeds

None.

Item 3 – Defaults Upon Senior Securities

None.

Item 4 – [Removed and Reserved]

Item 5 - Other Information

None.

Item 6 - Exhibits

See the exhibit index to this quarterly report on Form 10-Q.

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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.

	U.S. GEOTHERMAL INC.
	(Registrant)
Date: August 9, 2011	By: /s/ Daniel J. Kunz
	Daniel J. Kunz
	President, Chief Executive Officer and
	Director
Date: August 9, 2011
	By: /s/ Kerry D. Hawkley
	Kerry D. Hawkley
	Chief Financial Officer and Corporate Secretary

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EXHIBIT LIST

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