Ormat (ORA) 10-Q 4 Aug 16 2016 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 05, 2016
Document Information [Line Items]
Entity Registrant Name	ORMAT TECHNOLOGIES, INC.
Entity Central Index Key	1,296,445
Trading Symbol	ora
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Entity Common Stock, Shares Outstanding (in shares)		49,569,867
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Current Period Unaudited) - USD ($) $ in Thousands	Jun. 30, 2016		Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 192,556		$ 185,919
Restricted cash and cash equivalents (all related to VIEs)	38,005		49,503
Receivables:
Trade	59,042		55,301
Other	14,350		7,885
Inventories	16,690		18,074
Costs and estimated earnings in excess of billings on uncompleted contracts	15,259		25,120
Prepaid expenses and other	44,334		33,334
Total current assets	380,236		375,136
Deposits and other	18,487		17,968
Deferred charges	41,409		42,811
Property, plant and equipment, net	1,562,315		1,559,335
Construction-in-process	241,199		248,835
Deferred financing and lease costs, net	5,131		4,022
Intangible assets, net	24,236		25,875
Total assets	2,273,013	[1]	2,273,982
LIABILITIES AND EQUITY
Accounts payable and accrued expenses	87,511		91,955
Billings in excess of costs and estimated earnings on uncompleted contracts	42,912		33,892
Current portion of long-term debt:
Senior secured notes	29,998		29,930
Other loans	21,495		21,495
Full recourse	11,229		11,229
Total current liabilities	193,145		188,501
Long-term debt, net of current portion:
Senior secured notes (less deferred financing costs of $10,265 and $10,852, respectively)	279,971		294,476
Other loans (less deferred financing costs of $6,937 and $7,492, respectively)	265,696		275,888
Senior unsecured bonds (plus unamortized premium based upon 7% of $359 and $513, respectively and less deferred financing costs of $195 and $283, respectively)	249,632		249,698
Other loans (less deferred financing costs of $348 and $435, respectively)	13,161		18,687
Accumulated losses of unconsolidated company in excess of investment	15,347		8,100
Liability associated with sale of tax benefits	2,064		11,665
Deferred lease income	56,925		58,099
Deferred income taxes	21,907		32,654
Liability for unrecognized tax benefits	9,974		10,385
Liabilities for severance pay	19,026		19,323
Asset retirement obligation	21,677		20,856
Other long-term liabilities	7,053		1,776
Total liabilities	1,155,578		1,190,108
Commitments and contingencies (Note 10)
Equity:
Common stock, par value $0.001 per share; 200,000,000 shares authorized; 49,566,867 and 49,107,901 shares issued and outstanding as of June 30, 2016 and December 31, 2015, respectively	49		49
Additional paid-in capital	856,827		849,223
Retained earnings	183,018		148,396
Accumulated other comprehensive income	(12,838)		(7,667)
	1,027,056		990,001
Noncontrolling interest	90,379		93,873
Total equity	1,117,435		1,083,874
Total liabilities and equity	$ 2,273,013		$ 2,273,982
[1]	Including unconsolidated investments

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Current Period Unaudited) (Parentheticals) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Variable Interest Entity, Primary Beneficiary [Member]
Property, plant and equipment, net	$ 1,506,927	$ 1,481,258
Construction-in-process	68,261	129,165
Senior Secured Notes [Member]
Deferred financing costs	10,265	10,852
Other Loans, Limited and Non-recourse [Member]
Deferred financing costs	6,937	7,492
Senior Unsecured Bonds [Member]
Deferred financing costs	195	283
Other Loans, Full Recourse [Member]
Deferred financing costs	348	435
Property, plant and equipment, net	1,562,315	1,559,335
Construction-in-process	$ 241,199	$ 248,835
Senior unsecured bonds %	7.00%	7.00%
Senior unsecured bonds unamortized premium	$ 359	$ 513
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized (in shares)	200,000,000	200,000,000
Common stock, shares issued (in shares)	49,566,867	49,107,901
Common stock, shares outstanding (in shares)	49,566,867	49,107,901

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations and Comprehensive Income (Unaudited) - USD ($) shares in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues:
Electricity	$ 104,001,000	$ 90,926,000	$ 211,869,000	$ 180,879,000
Product	55,860,000	49,561,000	99,586,000	79,839,000
Total revenues	159,861,000	140,487,000	311,455,000	260,718,000
Cost of revenues:
Electricity	62,243,000	62,522,000	125,929,000	118,103,000
Product	31,822,000	27,182,000	55,857,000	47,807,000
Total cost of revenues	94,065,000	89,704,000	181,786,000	165,910,000
Gross margin	65,796,000	50,783,000	129,669,000	94,808,000
Operating expenses:
Research and development expenses	595,000	414,000	944,000	777,000
Selling and marketing expenses	3,668,000	4,283,000	7,343,000	7,716,000
General and administrative expenses	8,783,000	7,443,000	17,532,000	17,647,000
Write-off of unsuccessful exploration activities	863,000	0	1,420,000	174,000
Operating income	51,887,000	38,643,000	102,430,000	68,494,000
Other income (expense):
Interest income	245,000	44,000	565,000	53,000
Interest expense, net	(18,401,000)	(18,859,000)	(34,424,000)	(36,687,000)
Derivatives and foreign currency transaction gains (losses)	(4,332,000)	(571,000)	(2,370,000)	(1,937,000)
Income attributable to sale of tax benefits	4,519,000	4,731,000	8,917,000	10,283,000
Other non-operating income (expense), net	49,000	(1,675,000)	240,000	(1,392,000)
Income from continuing operations before income taxes and equity in losses of investees	33,967,000	22,313,000	75,358,000	38,814,000
Income tax (provision) benefit	(7,890,000)	(6,056,000)	(17,399,000)	(11,515,000)
Equity in losses of investees, net	(1,144,000)	(984,000)	(2,081,000)	(1,759,000)
Income from continuing operations	24,933,000	15,273,000	55,878,000	25,540,000
Net income attributable to noncontrolling interest	(584,000)	(859,000)	(2,258,000)	(1,094,000)
Net income attributable to the Company's stockholders	24,349,000	14,414,000	53,620,000	24,446,000
Comprehensive income:
Net income	24,933,000	15,273,000	55,878,000	25,540,000
Other comprehensive income (loss), net of related taxes:
Change in unrealized gains or losses in respect of the Company's share in derivatives instruments of unconsolidated investment	(1,987,000)	3,460,000	(5,166,000)	164,000
Loss in respect of derivative instruments designated for cash flow hedge	22,000	23,000	43,000	46,000
Amortization of unrealized gains in respect of derivative instruments designated for cash flow hedge	(24,000)	(31,000)	(48,000)	(61,000)
Comprehensive income	22,944,000	18,725,000	50,707,000	25,689,000
Comprehensive income attributable to noncontrolling interest	(584,000)	(859,000)	(2,258,000)	(1,094,000)
Comprehensive income attributable to the Company's stockholders	$ 22,360,000	$ 17,866,000	$ 48,449,000	$ 24,595,000
Earnings per share attributable to the Company's stockholders:
Net income (in dollars per share)	$ 0.49	$ 0.29	$ 1.09	$ 0.51
Net income (in dollars per share)	$ 0.49	$ 0.28	$ 1.07	$ 0.49
Weighted average number of shares used in computation of earnings per share attributable to the Company's stockholders:
Basic (in shares)	49,456	48,881	49,314	48,063
Diluted (in shares)	50,137	50,600	49,977	49,444
Common Stock, Dividends, Per Share, Declared	$ 0.07	$ 0.06	$ 0.38	$ 0.12

Consolidated Statements of Equi

Consolidated Statements of Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	AOCI Attributable to Parent [Member]	Parent [Member]	Noncontrolling Interest [Member]	Total
Balance (in shares) at Dec. 31, 2014	45,537
Balance at Dec. 31, 2014	$ 46	$ 742,006	$ 41,539	$ (8,668)	$ 774,923	$ 11,823	$ 786,746
Stock-based compensation		2,156			2,156		2,156
Exercise of options by employees and directors (in shares)	469
Exercise of options by employees and directors		3,966			3,966		3,966
Share exchange with Parent (in shares)	2,996
Share exchange with Parent	$ 3	25,754			25,757		25,757
Cash paid to non controlling interest						(432)	(432)
Cash dividend declared			(6,830)		(6,830)		(6,830)
Issuance of shares to noncontrolling interest, net of transaction costs		71,291			71,291	85,470	156,761
Net income			24,446		24,446	1,094	25,540
Loss in respect of derivative instruments designated for cash flow hedge				46	46		46
Change in unrealized gains or losses in respect of the Company's share in derivatives instruments of unconsolidated investment				164	164		164
Amortization of unrealized gains in respect of derivative instruments designated for cash flow hedge				(61)	(61)		(61)
Balance (in shares) at Jun. 30, 2015	49,002
Balance at Jun. 30, 2015	$ 49	845,173	59,155	(8,519)	895,858	97,955	993,813
Balance (in shares) at Dec. 31, 2015	49,107
Balance at Dec. 31, 2015	$ 49	849,223	148,396	(7,667)	990,001	93,873	1,083,874
Stock-based compensation		1,659			1,659		1,659
Exercise of options by employees and directors (in shares)	460
Exercise of options by employees and directors		5,945			5,945		5,945
Cash paid to non controlling interest						(5,752)	(5,752)
Cash dividend declared			(18,998)		(18,998)		(18,998)
Net income			53,620		53,620	2,258	55,878
Loss in respect of derivative instruments designated for cash flow hedge				43	43		43
Change in unrealized gains or losses in respect of the Company's share in derivatives instruments of unconsolidated investment				(5,166)	(5,166)		(5,166)
Amortization of unrealized gains in respect of derivative instruments designated for cash flow hedge				(48)	(48)		(48)
Balance (in shares) at Jun. 30, 2016	49,567
Balance at Jun. 30, 2016	$ 49	$ 856,827	$ 183,018	$ (12,838)	$ 1,027,056	$ 90,379	$ 1,117,435

Consolidated Statements of Equ6

Consolidated Statements of Equity (Unaudited) (Parentheticals) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Retained Earnings [Member]
Cash dividend declared, per share (in dollars per share)	$ 0.38	$ 0.14
Cash flow hedge, tax	$ 25,000	$ 27,000
Change in unrealized gains or losses in respect of the Company's share in derivative instruments of unconsolidated investment, tax	0	0
Amortization of unrealized gains in respect of derivative instruments designated for cash flow hedge, related tax	$ 30,000	$ 38,000
Cash dividend declared, per share (in dollars per share)	$ 0.38	$ 0.12

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities:
Net income	$ 55,878,000	$ 25,540,000
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	51,258,000	52,559,000
Amortization of premium from senior unsecured bonds	(154,000)	(154,000)
Accretion of asset retirement obligation	821,000	752,000
Stock-based compensation	1,659,000	2,156,000
Amortization of deferred lease income	(1,343,000)	(1,342,000)
Income attributable to sale of tax benefits, net of interest expense	(5,076,000)	(6,720,000)
Equity in losses of investees	2,081,000	1,759,000
Mark-to-market of derivative instruments	(162,000)	4,140,000
Loss on disposal of property, plant and equipment		531,000
Write-off of unsuccessful exploration activities	1,420,000	174,000
Gain on severance pay fund asset	(253,000)	(572,000)
Deferred income tax provision	13,254,000	7,024,000
Liability for unrecognized tax benefits	(411,000)	(360,000)
Deferred lease revenues	169,000	(148,000)
Other		484,000
Changes in operating assets and liabilities, net of amounts acquired:
Receivables	(10,206,000)	(12,775,000)
Costs and estimated earnings in excess of billings on uncompleted contracts	9,861,000	20,700,000
Inventories	1,384,000	529,000
Prepaid expenses and other	(11,007,000)	(300,000)
Deposits and other	(153,000)	(362,000)
Accounts payable and accrued expenses	1,808,000	(2,600,000)
Due from/to related entities, net		451,000
Billings in excess of costs and estimated earnings on uncompleted contracts	(9,020,000)	(25,007,000)
Liabilities for severance pay	(297,000)	(975,000)
Other long-term liabilities	22,000	(2,259,000)
Due from/to Parent		(513,000)
Net cash provided by operating activities	119,573,000	112,726,000
Cash flows from investing activities:
Cash acquired in organizational restructuring and share exchange with parent		15,391,000
Net change in restricted cash, cash equivalents and marketable securities	11,498,000	(11,622,000)
Capital expenditures	(67,779,000)	(86,142,000)
Decrease in severance pay fund asset, net of payments made to retired employees	992,000	2,940,000
Net cash used in investing activities	(55,289,000)	(79,433,000)
Cash flows from financing activities:
Proceeds from sale of membership interests to noncontrolling interest, net of transaction costs		156,761,000
Proceeds from exercise of options by employees	5,945,000	3,966,000
Purchase of OFC Senior Secured Notes		(30,638,000)
Proceeds from revolving credit lines with banks	134,500,000	598,800,000
Repayment of revolving credit lines with banks	(134,500,000)	(619,100,000)
Cash received from non-controlling interest	1,972,000	1,654,000
Repayments of long-term debt	(31,386,000)	(29,404,000)
Cash paid to non-controlling interest	(12,249,000)	(7,418,000)
Deferred debt issuance costs	(2,931,000)	(3,649,000)
Cash dividends paid	(18,998,000)	(6,830,000)
Net cash provided by (used in) financing activities	(57,647,000)	64,142,000
Net change in cash and cash equivalents	6,637,000	97,435,000
Cash and cash equivalents at beginning of period	185,919,000	40,230,000
Cash and cash equivalents at end of period	192,556,000	137,665,000
Supplemental non-cash investing and financing activities:
Increase (decrease) in accounts payable related to purchases of property, plant and equipment	(6,956,000)	12,612,000
Accrued liabilities related to financing activities	$ 6,128,000

Note 1 - General and Basis of P

Note 1 - General and Basis of Presentation	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	NOTE 1 — GENERAL AND BASIS OF PRESENTATION These unaudited condensed consolidated interim financial statements of Ormat Technologies, Inc. and its subsidiaries (collectively, the “Company”) have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) for interim financial statements. Accordingly, they do not contain all information and notes required by U.S. GAAP for annual financial statements. In the opinion of management, these unaudited condensed consolidated interim financial statements reflect all adjustments, which include normal recurring adjustments, necessary for a fair statement of the Company’s consolidated financial position as of June 30, 2016, the consolidated results of operations and comprehensive income (loss) for the six-month periods ended June 30, 2016 and 2015 and the consolidated cash flows for the six-month periods ended June 30, 2016 and 2015. The financial data and other information disclosed in the notes to the condensed consolidated financial statements related to these periods are unaudited. The results for the six-month period ended June 30, 2016 are not necessarily indicative of the results to be expected for the year ending December 31, 2016. These condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company’s annual report on Form 10-K for the year ended December 31, 2015. The condensed consolidated balance sheet data as of December 31, 2015 was derived from the Company’s audited consolidated financial statements for the year ended December 31, 2015, but does not include all disclosures required by U.S. GAAP. Dollar amounts, except per share data, in the notes to these financial statements are rounded to the closest $1,000. Alevo transaction On March 30, 2016, the Company signed an agreement with a subsidiary of Alevo Group SA (“Alevo”), a leading provider of energy storage systems, to jointly build, own and operate the Rabbit Hill Energy Storage Project (“Rabbit Hill”) located in Georgetown, Texas. The Company will own and fund the majority of the costs associated with Rabbit Hill and, under the terms of the agreement, will provide engineering and construction services and balance of plant equipment. Alevo will provide its innovative GridBank™ inorganic lithium ion energy storage system in conjunction with the power conversion systems. In addition, Alevo will provide ongoing management and operations and maintenance services for the life of the project. The Company will hold an 85% interest in the Rabbit Hill project entity which will decrease to 50.1% after reaching certain Internal Rate of Return (“IRR”) targets. The Company will consolidate Rabbit Hill as a majority owned indirect subsidiary. Northleaf Transaction On April 30, 2015, Ormat Nevada Inc. (“Ormat Nevada”), a wholly-owned subsidiary of the Company, closed the sale of approximately 36.75% of the aggregate membership interests in ORPD LLC (“ORPD”), a holding company and subsidiary of Ormat Nevada that indirectly owns the Puna geothermal power plant in Hawaii, the Don A. Campbell geothermal power plant in Nevada, and nine power plant units across three recovered energy generation assets known as OREG 1, OREG 2 and OREG 3, to Northleaf Geothermal Holdings, LLC (“Northleaf”). We are currently conducting the required power generation tests to determine the final capacity attributable to the second phase of the Don A. Campbell power plant and upon Ormat Nevada's contribution of the project to ORPD, Northleaf will pay to Ormat Nevada an amount equal to Northleaf's proportionate interest in ORPD multiplied by the value of the project to be contributed. We estimate that Ormat Nevada will receive approximately $43 million cash in connection with the contribution which is expected in the third quarter of 2016. OFC Senior Secured Notes prepayment In June 2015, the Company repurchased $30.6 million aggregate principal amount of its OFC Senior Secured Notes from the OFC noteholders. As a result of the repurchase, the Company recognized a loss of $1.7 million, including amortization of deferred financing costs of $0.5 million, which was included in other non-operating income (expense), net in the consolidated statements of operations and comprehensive income for the three and six months ended June 30, 2015. Other comprehensive income For the six months ended June 30, 2016 and 2015, the Company classified $5,000 and $15,000, respectively, from accumulated other comprehensive income, of which $10,000 and $25,000, respectively, were recorded to reduce interest expense and $5,000 and $10,000, respectively, were recorded against the income tax provision, in the condensed consolidated statements of operations and comprehensive income. For the three months ended June 30, 2016 and 2015, the Company classified $2,000 and $8,000, respectively, related to derivative instruments designated as cash flow hedges, from accumulated other comprehensive income, of which $6,000 and $14,000, respectively, were recorded to reduce interest expense and $4,000 and $5,000, respectively, were recorded against the income tax provision, in the condensed consolidated statements of operations and comprehensive income. The accumulated net loss included in Other comprehensive income as of June 30, 2016, is $582,000 Write-offs of unsuccessful exploration activities Write-offs of unsuccessful exploration activities for the three and six months ended June 30, 2016 were $0.9 million and $1.4 million, respectively, and $0 and $0.2 million for the three and six months ended June 30, 2015, respectively. These write-offs of exploration costs are related to the Company’s exploration activities in Nevada and Chile, which the Company determined would not support commercial operations. Concentration of credit risk Financial instruments that potentially subject the Company to a concentration of credit risk consist principally of temporary cash investments and accounts receivable. The Company places its temporary cash investments with high credit quality financial institutions located in the United States (“U.S.”) and in foreign countries. At June 30, 2016 and December 31, 2015, the Company had deposits totaling $18.6 million and $19.0 million, respectively, in seven U.S. financial institutions that were federally insured up to $250,000 per account. At June 30, 2016 and December 31, 2015, the Company’s deposits in foreign countries amounted to approximately $186.6 million and $181.0 million, respectively. At June 30, 2016 and December 31, 2015, accounts receivable related to operations in foreign countries amounted to approximately $34.7 million and $27.8 million, respectively. At June 30, 2016 and December 31, 2015, accounts receivable from the Company’s primary customers amounted to approximately 59% and 66%, respectively, of the Company’s accounts receivable. Sierra Pacific Power Company and Nevada Power Company (subsidiaries of NV Energy, Inc.) accounted for 19.1% and 20.1% of the Company’s total revenues for the three months ended June 30, 2016 and 2015, respectively, and 21.1% and 21.9% for the six months ended June 30, 2016 and 2015, respectively. Kenya Power and Lighting Co. Ltd. accounted for 17.1% and 15.4% of the Company’s total revenues for the three months ended June 30, 2016 and 2015, respectively, and 17.2% and 16.5% for the six months ended June 30, 2016 and 2015, respectively. Southern California Public Power Authority accounted for 10.4% and 4.1% of the Company’s total revenues for the three months ended June 30, 2016 and 2015, respectively, and 11.2% and 4.9% for the six months ended June 30, 2016 and 2015, respectively. The Company performs ongoing credit evaluations of its customers’ financial condition. The Company has historically been able to collect on all of its receivable balances, and accordingly, no provision for doubtful accounts has been made.

Note 2 - New Accounting Pronoun

Note 2 - New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
New Accounting Pronouncements and Changes in Accounting Principles [Text Block]	NOTE 2 — NEW ACCOUNTING PRONOUNCEMENTS New accounting pronouncements effective in the six-month period ended June 30, 2016 Amendments to Fair Value Measurement In June 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-10, Amendment to Fair Value Measurement, Subtopic 820-10. The amendment provides that the reporting entity shall disclose for each class of assets and liabilities measured at fair value in the statement of financial position the following information: for recurring fair value measurements, the fair value measurement at the end of the reporting period, and for non-recurring fair value measurement, the fair value measurement at the relevant measurement date and the reason for the measurement. The amendments in this update are effective for annual reporting periods beginning after December 15, 2015, including interim periods within those reporting periods. The adoption of this guidance did not have a material impact on the Company’s consolidated financial statements. Amendments to the Consolidation A nalysis In February 2015, the FASB issued ASU 2015-02, Amendments to the Consolidation Analysis, Topic 810. The update provides that all reporting entities that hold a variable interest in other legal entities will need to re-evaluate their consolidation conclusions and potentially revise their disclosures. This amendment affects both variable interest entity (“ VIE” ) and voting interest entity (“ VOE” ) consolidation models. The update does not change the general order in which the consolidation models are applied. A reporting entity that holds an economic interest in, or is otherwise involved with, another legal entity (i.e. has a variable interest) should first determine if the VIE model applies, and if so, whether it holds a controlling financial interest under that model. If the entity being evaluated for consolidation is not a VIE, then the VOE model should be applied to determine whether the entity should be consolidated by the reporting entity. Since consolidation is only assessed for legal entities, the determination of whether there is a legal entity is important. It is often clear when the entity is incorporated, but unincorporated structures can also be legal entities and judgment may be required to make that determination. The update contains a new example that highlights the discretion used to make this legal entity determination. The update is effective for annual reporting periods beginning after December 15, 2015, including interim periods within those reporting periods. The adoption of this guidance did not have a material impact on the Company’s consolidated financial statements. Simplifying the Presentation of Debt Costs In August 2015, the FASB issued ASU 2015-15, Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements, Subtopic 835-30. The update clarifies that given the absence of authoritative guidance within Update 2015-03 for debt issuance costs described below, debt issuance costs related to line-of-credit arrangements can be deferred and presented as assets and subsequently amortized ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings under the line-of-credit arrangement. The amendments in this update are effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. The Company adopted this update in its interim period beginning January 1, 2016 and continues to present debt issuance costs related to such line-of-credit arrangements as assets amortized ratably over the respective term of the line-of credit arrangements. Debt issuance costs related to such line-of-credit arrangements as of June 30, 2016 and December 31, 2015, totaled $2.0 million and $1.0 million, respectively. In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest: Simplifying the Presentation of Debt Costs, Subtopic 835-30. The update provides that debt issuance costs related to a recognized debt liability be presented in the balance sheet as direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The amendments in this update are effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. The Company retrospectively adopted this update in its interim period beginning January 1, 2016. The impact of the adoption resulted in a reclassification of debt issuance costs totaling $17.7 million and $19.1 million as of June 30, 2016 and December 31, 2015, respectively. New accounting pronouncements effective in future periods Improvement to Employee Share-Based Payment Accounting In March 2016, the FASB issued ASU 2016-09, Improvement to Employee Share-Based Payment Accounting, an update to the guidance on stock-based compensation. Under the new guidance, all excess tax benefits and tax deficiencies will be recognized in the income statement as they occur. This will replace the current guidance, which requires tax benefits that exceed compensation cost (windfalls) to be recognized in equity. It will also eliminate the need to maintain a “windfall pool,” and will remove the requirement to delay recognizing a windfall until it reduces current taxes payable. The new guidance will also change the cash flow presentation of excess tax benefits, classifying them as operating inflows, consistent with other cash flows related to income taxes. Today, windfalls are classified as financing activities. Also, this will affect the dilutive effects in earnings per share, as there will no longer be excess tax benefits recognized in additional paid in capital. Today those excess tax benefits are included in assumed proceeds from applying the treasury stock method when computing diluted EPS. Under the amended guidance, companies will be able to make an accounting policy election to either (1) continue to estimate forfeitures or (2) account for forfeitures as they occur. This updated guidance is effective for annual and interim periods beginning after December 15, 2016. Early adoption is permitted. The Company is currently evaluating the potential impact, if any, of the adoption of this update on its consolidated financial statements. Revenues from Contracts with Customers In May 2014, the FASB issued ASU 2014-09, Revenues from Contracts with Customers, Topic 606 (“Topic 606”), which was a joint project of the FASB and the International Accounting Standards Board to clarify the principles for recognizing revenue and to develop a common revenue standard for U.S. GAAP and International Financial Reporting Standards. The update provides that an entity should recognize revenue in connection with the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Specifically, an entity is required to apply each of the following steps: (1) identify the contract(s) with the customer; (2) identify the performance obligations in the contracts; (3) determine the transaction price; (4) allocate the transaction price to the performance obligation in the contract; and (5) recognize revenue when (or as) the entity satisfies a performance obligation. The amendments in this update are effective for annual reporting periods beginning after December 15, 2017, including interim periods within those reporting periods. Early adoption is permitted no earlier than 2017 for calendar fiscal year entities. The Company is currently evaluating the potential impact, if any, of the adoption of these amendments on its consolidated financial statements. In March 2016, the FASB issued ASU 2016-08, Principal versus Agent Considerations. The amendment in this Update do not change the core principal of the guidance and are intended to improve the operability and understandability of the implementation guidance on principal versus agent considerations. When another entity is involved in providing goods or services to a customer, an entity is required to determine if the nature of its promise is to provide the specific good or service itself (that is, the entity is a principal) or to arrange for that good or service to be provided by the other party (that is, the entity is an agent). The guidance includes indicators to assist an entity in determining whether it acts as a principal or agent in a specified transaction. The amendments in this update are effective for annual reporting periods beginning after December 15, 2017, including interim periods within those reporting periods. Early adoption is permitted no earlier than 2017 for calendar fiscal year entities. The Company is currently evaluating the potential impact, if any, of the adoption of these amendments on its consolidated financial statements. Leases In February 2016, the FASB issued ASU 2016-02, Leases, Topic 842. The amendment in this Update introduce a number of changes and simplifications from previous guidance, primarily the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases. The Update retains the distinction between finance leases and operating leases and the classification criteria between the two types remain substantially similar. Also, lessor accounting remains largely unchanged from previous guidance, however, key aspects in the Update were aligned with the revenue recognition guidance in Topic 606. Additionally, the Update defines a lease as a contract, or part of a contract, that conveys the right to control the use of identified asset for a period of time in exchange for considerations. Control over the use of the identified means that the customer has both (a) the right to obtain substantially all of the economic benefits from the use of the asset and (b) the right to direct the use of the asset. The amendments in this update are effective for annual reporting periods beginning after December 15, 2018, including interim periods within those reporting periods. Early adoption is permitted. The Company is currently evaluating the potential impact, if any, of the adoption of these amendments on its consolidated financial statements. Recognition and Measurement of Financial Assets and Financial Liabilities In January 2016, the FASB issued ASU 2016-01, Recognition and Measurement of Financial Assets and Financial Liabilities. The update primarily requires that an entity should present separately, in other comprehensive income, the portion of the total change in the fair value of a liability resulting from a change in the instrument-specific credit risk if the entity has elected to measure the liability at fair value in accordance with the fair value option for financial instruments. The application of this update should be by means of cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The amendments in this update are effective for financial statements issued for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Early adoption is permitted as of the beginning of the fiscal year of adoption. The Company is currently evaluating the potential impact, if any, of the adoption of this update on its consolidated financial statements. Simplifying the Measurement of Inventory In July 2015, the FASB issued ASU 2015-11, Simplifying the Measurement of Inventory, Topic 330. The update contains no amendments to disclosure requirements, but replaces the concept of ‘lower of cost or market’ with that of ‘lower of cost and net realizable value’. The amendments in this update are effective for annual reporting periods beginning after December 15, 2016, including interim periods within those reporting periods. The amendments should be applied prospectively with early adoption permitted. The Company is currently evaluating the potential impact, if any, of the adoption of this update on its consolidated financial statements.

Note 3 - Inventories

Note 3 - Inventories	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Inventory Disclosure [Text Block]	NOTE 3 — INVENTORIES Inventories consist of the following: June 30, December 31, 2016 2015 (Dollars in thousands) Raw materials and purchased parts for assembly $ 6,013 $ 8,819 Self-manufactured assembly parts and finished products 10,677 9,255 Total $ 16,690 $ 18,074

Note 4 - Unconsolidated Investm

Note 4 - Unconsolidated Investments	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Equity Method Investments and Joint Ventures Disclosure [Text Block]	NOTE 4 — UNCONSOLIDATED INVESTMENTS Unconsolidated investments consist of the following: June 30, December 31, 2016 2015 (Dollars in thousands) Sarulla $ (15,347 ) $ (8,100 ) The Sarulla Project The Company holds a 12.75% equity interest in a consortium which is in the process of developing the Sarulla geothermal power project in Indonesia with an expected generating capacity of approximately 330 megawatts (“MW”). The Sarulla project is located in Tapanuli Utara, North Sumatra, Indonesia and will be owned and operated by the consortium members under the framework of a Joint Operating Contract (“JOC”) and Energy Sales Contract (“ESC”) that were signed on April 4, 2013. Under the JOC, PT Pertamina Geothermal Energy (“PGE”), the concession holder for the project, has provided the consortium with the right to use the geothermal field, and under the ESC, PT PLN, the state electric utility, will be the off-taker at Sarulla for a period of 30 years. In addition to its equity holdings in the consortium, the Company designed the Sarulla plant and will supply its Ormat Energy Converters (“OECs”) to the power plant, as further described below. The project will be constructed in three phases of approximately 110 MW each, utilizing both steam and brine extracted from the geothermal field to increase the power plant’s efficiency. The first phase of operations is expected to commence towards the end of 2016 and the remaining two phases of operations are scheduled to commence within 18 months thereafter. For the first phase, engineering and procurement has been substantially completed and construction is in progress with major activities relating to mechanical and electrical equipment installation. Major equipment, including Ormat’s OECs and Toshiba’s steam turbine, has arrived to the site and are currently installed. The drilling of production and injection wells for the first phase is completed. For the second phase, engineering and procurement has been substantially completed, infrastructure work is in progress and most of the equipment to be supplied by Ormat was delivered. For the third phase, engineering and procurement is still in progress, infrastructure work is in progress and manufacturing of equipment to be supplied by Ormat is underway as planned. Currently, for the second and third phases drilling activities is still ongoing and the project achieved to date, based on preliminary estimates, approximately 70% of the required production capacity and approximately 15% of the required injection capacity. The project has missed a few milestones defined under the loan documents, but has received waivers from the lenders. As of June 30, 2016, the project is in compliance with milestones agreed with the lenders. The project is experiencing delays in the field development and certain cost overruns resulting from delays and excess drilling costs. Although estimated cost at completion is still within the approved budget (including contingencies), the lenders have requested that the sponsors commit additional equity. The sponsors have agreed and financing documents were revised to reflect this request. With respect to Ormat’s role as a supplier, all contractual milestones under the supply agreement were achieved. On May 16, 2014, the consortium closed $1.17 billion in financing for the development of the Sarulla project with a consortium of lenders comprised of Japan Bank for International Cooperation (“JBIC”), the Asian Development Bank and six commercial banks and obtained construction and term loans on a limited recourse basis backed by a political risk guarantee from JBIC. Of the $1.17 billion, $0.1 billion (which was drawn down by the Sarulla project company on May 23, 2014) bears a fixed interest rate and $1.07 billion bears interest at a rate linked to LIBOR. The Sarulla consortium entered into interest rate swap agreements with various international banks in order to fix the Libor interest rate on up to $0.96 billion of the $1.07 billion credit facility at a rate of 3.4565%. The interest rate swap became effective as of June 4, 2014 along with the second draw-down by the project company of $50.0 million. The Sarulla project company accounted for the interest rate swap as a cash flow hedge upon which changes in the fair value of the hedging instrument, relative to the effective portion, will be recorded in other comprehensive income (loss). During the three and six months ended June 30, 2016, the project recorded a loss equal to $15.6 million and $40.5 million, respectively, net of deferred tax of $8.0 million and $20.9 million, respectively, of which the Company's share was $2.0 million and $5.2 million, respectively, which were recorded in other comprehensive income (loss). The related accumulated loss recorded by the Company in other comprehensive income (loss) as of June 30, 2016 is $12.3 million. Pursuant to a supply agreement that was signed in October 2013, the Company is supplying its OECs to the power plant and has added the $255.6 million supply contract to its Product Segment backlog. The Company started to recognize revenue from the project during the third quarter of 2014 and will continue to recognize revenue until the end of the first half of 2017. The Company has eliminated the related intercompany profit of $8.4 million against equity in loss of investees. During the six months ended June 30, 2016, the Company did not make any additional equity investments in the Sarulla project.

Note 5 - Fair Value of Financia

Note 5 - Fair Value of Financial Instruments	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Fair Value Disclosures [Text Block]	NOTE 5— FAIR VALUE OF FINANCIAL INSTRUMENTS The fair value measurement guidance clarifies that fair value is an exit price, representing the amount that would be received upon selling an asset or paid upon transferring a liability in an orderly transaction between market participants. As such, fair value is a market-based measurement that should be determined based on assumptions that market participants would use in pricing an asset or liability. The guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques 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 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy under the fair value measurement guidance are described below: Level 1 Level 2 Level 3 The following table sets forth certain fair value information at June 30, 2016 and December 31, 2015 for financial assets and liabilities measured at fair value by level within the fair value hierarchy, as well as cost or amortized cost. As required by the fair value measurement guidance, assets and liabilities are classified in their entirety based on the lowest level of inputs that is significant to the fair value measurement. June 30, 2016 Fair Value Carrying Value at June 30, 2016 Total Level 1 Level 2 Level 3 (Dollars in thousands) Assets: Current assets: Cash equivalents (including restricted cash accounts) $ 23,965 $ 23,965 $ 23,965 $ — $ — Derivatives: Currency forward contracts (2) 38 38 — 38 — Liabilities: Current liabilities: Derivatives: Call and put options on oil price (1) $ (2,349 ) $ (2,349 ) $ — $ (2,349 ) $ — Call option on natural gas price (1) (2,779 ) (2,779 ) — (2,779 ) — Currency forward contracts (2) 190 190 — 190 — $ 19,065 $ 19,065 $ 23,965 $ (4,900 ) $ — December 31, 2015 Fair Value Carrying Value at December 31, 2015 Total Level 1 Level 2 Level 3 (Dollars in thousands) Assets Current assets: Cash equivalents (including restricted cash accounts) $ 31,428 $ 31,428 $ 31,428 $ — $ — Derivatives: Currency forward contracts (2) 7 7 — 7 — Liabilities: Current liabilities: Derivatives: Currency forward contracts (2) (169 ) (169 ) — (169 ) — $ 31,266 $ 31,266 $ 31,428 $ (162 ) $ — (1) These amounts relate to call and put option transactions on oil and natural gas prices, valued primarily based on observable inputs, including spot prices for related commodity indices, and is included within “Accounts payable and accrued expenses” on June 30, 2016 in the consolidated balance sheets with the corresponding gain or loss being recognized within “Derivatives and foreign currency transaction (gains) losses” in the consolidated statement of operations and comprehensive income. (2) These amounts relate to derivatives which represent currency forward contracts valued primarily based on observable inputs, including forward and spot prices for currencies, netted against contracted rates and then multiplied against notional amounts, and are included within “prepaid expenses and other” and “accounts payable and accrued expenses” on June 30, 2016 and December 31, 2015, in the consolidated balance sheet with the corresponding gain or loss being recognized within “Derivatives and foreign currency transaction gains (losses)” in the consolidated statement of operations and comprehensive income. The amounts set forth in the tables above include investments in debt instruments and money market funds (which are included in cash equivalents). Those securities and deposits are classified within Level 1 of the fair value hierarchy because they are valued using quoted market prices in an active market. The following table presents the amounts of gain (loss) recognized in the consolidated statements of operations and comprehensive income on derivative instruments not designated as hedges: Amount of recognized gain (loss) Derivatives not designated as Location of recognized gain Three Months Ended June 30, Six Months Ended June 30, hedging instruments (loss) 2016 2015 2016 2015 Call options on natural gas price (1,664 ) — (1,146 ) — Call and put options on oil price Derivatives and foreign currency transaction gains (losses) (899 ) — (1,542 ) — Swap transactions on natural gas price Electricity revenues — 81 — 398 Currency forward contracts Derivatives and foreign currency transaction gains (losses) (1,349 ) (967 ) 465 (2,218 ) $ (3,912 ) $ (886 ) $ (2,223 ) $ (1,820 ) On March 6, 2014, the Company entered into a Natural Gas Index (“NGI”) swap contract with a bank covering a notional quantity of approximately 2.2 million British Thermal Units (“MMbtu”) for settlement effective January 1, 2015 until March 31, 2015, and covering a notional amount of approximately 2.4 MMbtu for settlement effective June 1, 2015 until December 31, 2015, in order to reduce its exposure to fluctuations in natural gas prices under its power purchase agreements (“PPAs”) with Southern California Edison to below $4.95 per MMbtu and below $3.00 per MMbtu, respectively. The swap contracts did not have any up-front costs. Under the terms of these contracts, the Company made floating rate payments to the bank and received fixed rate payments from the bank on each settlement date. The swap contracts had monthly settlements whereby the difference between the fixed price and the market price on the first commodity business day on which the relevant commodity reference price was published in the relevant calculation period (January 1, 2015 to March 1, 2015 and June 1, 2015 to December 31, 2015) was settled on a cash basis. On February 2, 2016, the Company entered into Henry Hub Natural Gas Future contracts under which it provided a number of call options covering a notional quantity of approximately 4.1 MMbtu with exercise prices of $2 and expiration dates ranging from February 24, 2016 until December 27, 2016 in order to reduce its exposure to fluctuations in natural gas prices under its PPAs with Southern California Edison. The Company received an aggregate premium of approximately $1.9 million from these call options. The call option contracts have monthly expiration dates at which the options can be called and the Company would have to settle its liability on a cash basis. On February 24, 2016, the Company entered into Brent Oil Future contracts under which it has written a number of call options covering a notional quantity of approximately 185,000 barrels (“BBL”) of Brent with exercise prices of $32.80 to $35.50 and expiration dates ranging from March 24, 2016 until December 22, 2016 in order to reduce its exposure to fluctuations in Brent prices under its PPA with HELCO. The Company received an aggregate premium of approximately $1.1 million from these call options. The call option contracts have monthly expiration dates whereby the options can be called and the Company would have to settle its liability on a cash basis. Moreover, during March 2016, the Company rolled 2 existing call options covering a total notional quantity of 31,800 BBL of Brent in order to limit its exposure to $41 to $42.50 instead of $32.80 to $33.50. In addition, the Company entered into Short Risk Reversal transactions (sell call and buy put options) by rolling existing call options covering notional quantities of 16,500 BBL and 17,000 BBL in order to limit its exposure from the outstanding call options originally entered into in February, 2016 to a range of $28.50 to $37.50 and $28 to $38.50, respectively. The foregoing future, forward and swap transactions were not designated as hedge transactions and are marked to market with the corresponding gains or losses recognized within “Derivatives and foreign currency transaction gains (losses)” and “Electricity revenues” in the consolidated statements of operations and comprehensive income, respectively. The Company recognized a net loss from these transactions of $3.9 million and $2.2 million in the three and six months ended June 30, 2016, respectively, compared to a net loss of $1.0 million and $2.2 million in the three and six months ended June 30, 2015, under Derivatives and foreign currency transaction gains (losses), and a net gain of $0.1 million and a $0.4 million, in the three and six months ended June 30, 2015, respectively, under Electricity revenues. There were no transfers of assets or liabilities between Level 1, Level 2 and Level 3 during the six months ended June 30, 2016. The fair value of the Company’s long-term debt approximates its carrying amount, except for the following: Fair Value Carrying Amount June 30, 2016 December 31, 2015 June 30, 2016 December 31, 2015 (Dollars in millions) (Dollars in millions) Olkaria III Loan - DEG $ 20.8 $ 24.2 $ 19.7 $ 23.7 Olkaria III Loan - OPIC 258.3 262.6 255.6 264.6 Amatitlan Loan 39.7 41.7 38.5 40.3 Senior Secured Notes: Ormat Funding Corp. ("OFC") 26.5 30.0 26.5 30.0 OrCal Geothermal Inc. ("OrCal") 41.4 43.8 40.1 43.3 OFC 2 LLC ("OFC 2") 229.0 231.1 253.6 262.0 Senior Unsecured Bonds 259.0 264.5 249.8 250.0 The fair value of OFC Senior Secured Notes is determined using observable market prices as these securities are traded. The fair value of all the other long-term debt is determined by a valuation model, which is based on a conventional discounted cash flow methodology and utilizes assumptions of current borrowing rates. The fair value of revolving lines of credit is determined using a comparison of market-based price sources that are reflective of similar credit ratings to those of the Company. The carrying value of other financial instruments, such as revolving lines of credit, deposits, and other long-term debt approximates fair value. The following table presents the fair value of financial instruments as of June 30, 2016: Level 1 Level 2 Level 3 Total (Dollars in millions) Olkaria III - DEG $ — $ — $ 20.8 $ 20.8 Olkaria III - OPIC — — 258.3 258.3 Amatitlan loan — 39.7 — 39.7 Senior Secured Notes: OFC — 26.5 — 26.5 OrCal — — 41.4 41.4 OFC 2 — — 229.0 229.0 Senior unsecured bonds — — 259.0 259.0 Other long-term debt — 5.0 — 5.0 Deposits 15.2 — — 15.2 The following table presents the fair value of financial instruments as of December 31, 2015: Level 1 Level 2 Level 3 Total (Dollars in millions) Olkaria III Loan - DEG $ — $ — $ 24.2 $ 24.2 Olkaria III Loan - OPIC — — 262.6 262.6 Amatitlan Loan — 41.7 — 41.7 Senior Secured Notes: OFC — 30.0 — 30.0 OrCal — — 43.8 43.8 OFC 2 — — 231.1 231.1 Senior unsecured bonds — — 264.5 264.5 Other long-term debt — 6.7 — 6.7 Deposits 15.9 — — 15.9

Note 6 - Stock-based Compensati

Note 6 - Stock-based Compensation	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	NOTE 6 — STOCK-BASED COMPENSATION The 2004 Incentive Compensation Plan In 2004, the Company’s Board of Directors (the “Board”) adopted the 2004 Incentive Compensation Plan (“2004 Incentive Plan”), which provides for the grant of the following types of awards: incentive stock options, non-qualified stock options, restricted stock, stock appreciation rights (“SARs”), stock units, performance awards, phantom stock, incentive bonuses, and other possible related dividend equivalents to employees of the Company, directors and independent contractors. Under the 2004 Incentive Plan, a total of 3,750,000 shares of the Company’s common stock were reserved for issuance, all of which could be issued as options or as other forms of awards. Options and SARs granted to employees under the 2004 Incentive Plan cliff vest and are exercisable from the grant date as follows: 25% after 24 months, 25% after 36 months, and the remaining 50% after 48 months. Options granted to non-employee directors under the 2004 Incentive Plan cliff vest and are exercisable one year after the grant date. Vested stock-based awards may be exercised for up to ten years from the grant date. The shares of common stock will be issued from the Company’s authorized share capital upon exercise of options or SARs. The 2004 Incentive Plan expired in May 2012 upon adoption of the 2012 Incentive Compensation Plan (“2012 Incentive Plan”), except as to share based awards outstanding under the 2004 Incentive Plan on that date. The 2012 Incentive Compensation Plan In May 2012, the Company’s shareholders adopted the 2012 Incentive Plan, which provides for the grant of the following types of awards: incentive stock options, non-qualified stock options, restricted stock, SARs, stock units, performance awards, phantom stock, incentive bonuses, and other possible related dividend equivalents to employees of the Company, directors and independent contractors. Under the 2012 Incentive Plan, a total of 4,000,000 shares of the Company’s common stock have been reserved for issuance, all of which could be issued as options or as other forms of awards. Options and SARs granted to employees under the 2012 Incentive Plan typically vest and become exercisable as follows: 25% vest 24 months after the grant date, an additional 25% vest 36 months after the grant date, and the remaining 50% vest 48 months after the grant date. Options granted to non-employee directors under the 2012 Incentive Plan will vest and become exercisable one year after the grant date. The term of stock-based awards typically ranges from six to ten years from the grant date. The shares of common stock will be issued from the Company’s authorized share capital upon exercise of options or SARs. The 2012 Incentive Plan empowers the Board, in its discretion, to amend the 2012 Incentive Plan in certain respects. Consistent with this authority, in February 2014 the Board adopted and approved certain amendments to the 2012 Incentive Plan. The key amendments are as follows: ● Increase of per grant limit: Section 15(a) of the 2012 Incentive Plan was amended to allow the grant of up to 400,000 shares of the Company’s common stock with respect to the initial grant of an equity award to newly hired executive officers in any calendar year; and ● Acceleration of vesting: Section 15(l) of the 2012 Incentive Plan was amended to clarify the Company’s ability to provide in the applicable award agreement that part and/or all of the award will be accelerated upon the occurrence of certain predetermined events and/or conditions, such as a "change in control" (as defined in the 2012 Incentive Plan, as amended). On June 13, 2016, the Company granted its employees, in aggregate, 1,080,000 SARs under the Company’s 2012 Incentive Plan. The exercise price of each SAR is $42.87, which represented the fair market value of the Company’s common stock on the grant date. Such SARs will expire six years from the date of the grant and will vest over 4 years as follows: 50% after two years; an additional 25% after three years and the remaining 25% after four years from the grant date. The fair value of each SAR on the grant date was $11.98 for senior management and $11.42 for other employees. The Company calculated the fair value of each SAR on the grant date using the Exercise Multiple-Based Lattice SAR-Pricing model based on the following assumptions: Risk-free interest rate 1.29 % Expected life (in years) 6 Dividend yield 1.14 Expected volatility 30.7 % Forfeiture rate: Senior management 0.0 % Other employees 10.5 % Sub-Optimal Exercise Factor: Senior management 2.5 Other employees 2.0

Note 7 - Interest Expense, Net

Note 7 - Interest Expense, Net	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Interest Expense Disclosure [Text Block]	NOTE 7 — INTEREST EXPENSE, NET The components of interest expense are as follows: Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Interest related to sale of tax benefits $ 2,846 $ 2,807 $ 3,704 $ 4,687 Interest expense 15,863 17,025 31,488 33,920 Less — amount capitalized (308 ) (973 ) (768 ) (1,920 ) $ 18,401 $ 18,859 $ 34,424 $ 36,687

Note 8 - Earnings Per Share

Note 8 - Earnings Per Share	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Earnings Per Share [Text Block]	NOTE 8 — EARNINGS PER SHARE Basic earnings per share attributable to the Company’s stockholders is computed by dividing net income or loss attributable to the Company’s stockholders by the weighted average number of shares of common stock outstanding for the period. The Company does not have any equity instruments that are dilutive, except for employee stock-based awards. The table below shows the reconciliation of the number of shares used in the computation of basic and diluted earnings per share: Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Weighted average number of shares used in computation of basic earnings per share 49,456 48,881 49,314 48,063 Add: Additional shares from the assumed exercise of employee stock options 681 1,719 663 1,381 Weighted average number of shares used in computation of diluted earnings per share 50,137 50,600 49,977 49,444 The number of stock-based awards that could potentially dilute future earnings per share and that were not included in the computation of diluted earnings per share because to do so would have been anti-dilutive was 135,875 and 636,487 for the three months ended June 30, 2016 and 2015, respectively, and 224,116 and 765,424 for the six months ended June 30, 2016 and 2015, respectively.

Note 9 - Business Segments

Note 9 - Business Segments	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Segment Reporting Disclosure [Text Block]	NOTE 9 — BUSINESS SEGMENTS The Company has two reporting segments: the Electricity segment and the Product segment. These segments are managed and reported separately as each offers different products and serves different markets. The Electricity segment is engaged in the sale of electricity from the Company’s power plants pursuant to PPAs. The Product segment is engaged in the manufacture, including design and development, of turbines and power units for the supply of electrical energy and in the associated construction of power plants utilizing the power units manufactured by the Company to supply energy from geothermal fields and other alternative energy sources. Transfer prices between the operating segments are determined based on current market values or cost plus markup of the seller’s business segment. Summarized financial information concerning the Company’s reportable segments is shown in the following tables: Electricity Product Consolidated (Dollars in thousands) Three Months Ended June 30, 2016: Net revenue from external customers $ 104,001 $ 55,860 $ 159,861 Intersegment revenue — 19,266 19,266 Operating income 32,814 19,073 51,887 Segment assets at period end 2,031,650 241,363 2,273,013 Three Months Ended June 30, 2015: Net revenue from external customers $ 90,926 $ 49,561 $ 140,487 Intersegment revenue — 10,900 10,900 Operating income 20,920 17,723 38,643 Segment assets at period end 2,080,209 196,341 2,276,550 Six Months Ended June 30, 2016: Net revenues from external customers $ 211,869 $ 99,586 $ 311,455 Intersegment revenues — 21,206 21,206 Operating income 67,599 34,831 102,430 Segment assets at period end 2,031,650 241,363 2,273,013 Six Months Ended June 30, 2015: Net revenues from external customers $ 180,879 $ 79,839 $ 260,718 Intersegment revenues — 30,657 30,657 Operating income 44,874 23,620 68,494 Segment assets at period end 2,080,209 196,341 2,276,550 Reconciling information between reportable segments and the Company’s consolidated totals is shown in the following table: Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Revenue: Total segment revenue $ 159,861 $ 140,487 $ 311,455 $ 260,718 Intersegment revenue 19,266 10,900 21,206 30,657 Elimination of intersegment revenue (19,266 ) (10,900 ) (21,206 ) (30,657 ) Total consolidated revenue $ 159,861 $ 140,487 $ 311,455 $ 260,718 Operating income: Operating income $ 51,887 $ 38,643 $ 102,430 $ 68,494 Interest income 245 44 565 53 Interest expense, net (18,401 ) (18,859 ) (34,424 ) (36,687 ) Derivatives and foreign currency transaction gains (losses) (4,332 ) (571 ) (2,370 ) (1,937 ) Income attributable to sale of tax benefits 4,519 4,731 8,917 10,283 Other non-operating income (expense), net 49 (1,675 ) 240 (1,392 ) Total consolidated income before income taxes and equity in income of investees $ 33,967 $ 22,313 $ 75,358 $ 38,814

Note 10 - Commitments and Conti

Note 10 - Commitments and Contingencies	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Commitments and Contingencies Disclosure [Text Block]	NOTE 10 — COMMITMENTS AND CONTINGENCIES ● Jon Olson and Hilary Wilt, together with Puna Pono Alliance filed a complaint on February 17, 2015 in the Third Circuit Court for the State of Hawaii, requesting declaratory and injunctive relief requiring that Puna Geothermal Venture (“PGV”) comply with an ordinance that the plaintiffs allege will prohibit PGV from engaging in night drilling operations at its KS-16 well site. On May 17, 2015, the original complaint was amended to add the county of Hawaii and the State of Hawaii Department of Land and Natural Resources as defendants to the case. On or around June 30, 2016, the plaintiffs and each of the defendants filed motions for summary judgement, which are now pending before the court. PGV believes that the allegations of the lawsuit have no merit, and will continue to defend itself vigorously. ● On July 8, 2014, Global Community Monitor, LiUNA, and two residents of Bishop, California filed a complaint in the U.S. District Court for the Eastern District of California, alleging that Mammoth Pacific, L.P., the Company and Ormat Nevada are operating three geothermal generating plants in Mammoth Lakes, California (MP-1, MP-II and PLES-I) in violation of the federal Clean Air Act and Great Basin Unified Air Pollution Control District rules. On June 26, 2015, in response to a motion by the defendants, the court dismissed all but one of the plantiffs’ causes of action. On October 14, 2015, the court denied the defendants’ motion to dismiss the plaintiffs’ sole remaining claim. During the second quarter of 2016, the discovery phase was completed and plaintiff Global Community Monitor was dismissed as a party. The remaining plaintiffs are continuing to pursue the case. The Company believes that the allegations of the lawsuit have no merit, and will continue to defend itself vigorously. ● On April 5, 2012, the International Brotherhood of Electrical Workers Local 1260 (“Union”) filed a petition with the NLRB seeking to organize the operations and maintenance employees at the Puna project. A global settlement was reached in principle in February 2016, which includes a Union disclaimer of interest, the withdrawal of letters from the Union to the NRLB and signed individual settlement agreements, all of which are immaterial. All issues are now settled and closed. ● In January 2014, Ormat learned that two former employees filed a “qui tam” complaint seeking damages, penalties and other relief of approximately $375 million, alleging that the Company and certain of its subsidiaries (collectively, the “Ormat Parties”) submitted fraudulent applications and certifications to obtain grants for the Puna and North Brawley projects. The U.S. Department of Justice declined to intervene. The complaint is pending before the U.S. District Court for the District of Nevada. On July 7, 2015, the Court issued a protective order stipulating limitations against the qui tam relators for the benefit of the Ormat Parties to ensure the protection of confidentiality for sensitive Ormat Parties’ documents. On March 30, 2016, the Court denied the defendants’ motion for summary judgment that was filed on December 15, 2015. On April 1, 2016, the Magistrate rejected the plaintiffs’ allegation that defendants waived the attorney-client privilege for protected documents. The lawsuit is in the discovery and depositions stage, which is presently anticipated to be completed December 31, 2016. V arious filings regarding the discovery process had been filed and ruled upon by the court, and the depositions are continuing. The Ormat Parties believe that they have valid defenses under the law and will continue to defend themselves vigorously. ● O n March 29, 2016, a former local sales representative in Chile, Aquavant, S.A., filed a claim on the basis of unjust enrichment against Ormat’s subsidiaries in the 27th Civil Court of Santiago, Chile. The claim requests that the court order Ormat to pay Aquavant US $4.6 million in connection with its activities in Chile, including the EPC contract for the Cerro Pabellon project and various geothermal concessions, plus 3.75% of Ormat geothermal products sales in Chile over the next 10 years. Ormat filed preliminary defenses on May 30, 2016, and filed a petition for disciplinary measures against the attorneys representing the plaintiff on July 19, 2016. Both filings are pending before the court. The Company believes that it has valid defenses under law, and intends to defend itself vigorously. ● On May 21, 2014, Elko County, Nevada appealed to the Supreme Court of Nevada the Nevada Governor's Office of Energy’s award of an energy tax abatement to ORNI 42 LLC for our Tuscarora power plant. Lander County, Nevada similarly appealed the Office of Energy’s Award of an energy tax abatement to ORNI 39 LLC for our McGinness power plant. Both of the appeals request that the Court overturn the Governor’s decision and deny, retroactively and going forward, the tax abatement benefits for the full 20 year period, valued at approximately $18.6 million for our McGinness power plant and approximately $6.2 million for our Tuscarora power plant, of which only a small portion was utilized as of June 30, 2016. During 2016, Elko and Lander counties each filed opening briefs with the court. The Company believes that it has valid defenses under the law and will continue to defend itself vigorously. ● On June 20, 2016, Nadia Garcia, individually and as successor in interest to Thomas Garcia Valenzuela, and as guardian ad litem to Emerie Garcia, Khamilla Garcia and Reyene Adam, filed a complaint against Ormat Technologies, Ormat Nevada and Ormesa LLC in the Superior Court of Imperial County seeking unspecified monetary damages. The Garcia complaint alleges that the Ormat defendants caused the wrongful death, personal injury and other harm to Thomas Garcia (deceased), when he was employed by Martin Hydroblasting Services, Inc. and suffered injuries leading to his death while performing works at the Ormesa plant site on or around March 31, 2016. Ormat’s insurer has accepted both the costs of defense and the case outcome, and counsel has been appointed to represent Ormat. Additionally, the case has been tendered to the insurer of the employer of the deceased. In addition, from time to time, the Company is named as a party to various other lawsuits, claims and other legal and regulatory proceedings that arise in the ordinary course of our business. These actions typically seek, among other things, compensation for alleged personal injury, breach of contract, property damage, punitive damages, civil penalties or other losses, or injunctive or declaratory relief. With respect to such lawsuits, claims and proceedings, the Company accrues reserves when a loss is probable and the amount of such loss can be reasonably estimated. It is the opinion of the Company’s management that the outcome of these proceedings, individually and collectively, will not be material to the Company’s consolidated financial statements as a whole.

Note 11 - Income Taxes

Note 11 - Income Taxes	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Income Tax Disclosure [Text Block]	NOTE 11 — INCOME TAXES The Company’s effective tax rate for the six months ended June 30, 2016 and 2015 was 23.1% and 29.7%, respectively. The effective tax rate differs from the federal statutory rate of 35% for the six months ended June 30, 2016 due to: (i) a full valuation allowance against the Company’s U.S. deferred tax assets in respect of NOL carryforwards and unutilized tax credits (see below), (ii) lower tax rate in Israel of 16%, partially offset by a tax rate in Kenya of 37.5%; and (iii) a tax credit and tax exemption related to the Company’s subsidiaries in Guatemala. The effect of the tax credit and tax exemption for the three months ended June 30, 2016 and 2015 was $1,130,000 and $880,000, respectively, and for the six months ended June 30, 2016 and 2015 was $2,330,000 and $2,026,000, respectively. The Company is currently in a net deferred tax asset position with a full valuation allowance. As of December 31, 2015, the Company had U.S. federal NOL carryforwards of approximately $261 million and state NOL carryforwards of approximately $191 million, which expire between 2022 and 2034 for federal NOLs and between 2016 and 2034 for state NOLs, and production tax credits (“PTCs”) in the amount of $70.8 million at December 31, 2015 are available for a 20-year period and expire between 2026 and 2036. The Company also has offsetting deferred tax liabilities in the U.S. Realization of the deferred tax assets and tax credits is dependent on generating sufficient taxable income in appropriate jurisdictions prior to expiration of the NOL carryforwards and tax credits. Based upon available evidence of the Company’s ability to generate additional taxable income in the future and historical losses in prior years, a full valuation allowance is recorded against the U.S. deferred tax assets, as it is more likely than not that the deferred tax assets will not be utilized. The total amount of undistributed earnings of foreign subsidiaries for income tax purposes was approximately $233.8 million at December 31, 2015. It is the Company’s intention to reinvest undistributed earnings of its foreign subsidiaries and thereby indefinitely postpone their remittance. Accordingly, no provision has been made for foreign withholding taxes or U.S. income taxes which may become payable if undistributed earnings of foreign subsidiaries were paid as dividends to the Company. The additional taxes on that portion of undistributed earnings which is available for dividends are not practicably determinable. The Company believes that based on its plans to increase operations outside of the U.S., the cash generated from the Company’s operations outside of the U.S. will be reinvested outside of the U.S. and, accordingly, we do not currently plan to repatriate the funds we have designated as being permanently invested outside of the U.S. If we change our plans, we may be required to accrue and pay U.S. taxes to repatriate these funds. The Company is subject to income taxes in the U.S. (federal and state) and numerous foreign jurisdictions. Significant judgment is required in evaluating tax positions and determining the position for income taxes. Reserves are established to tax-related uncertainties based on estimates of whether, and the extent to which additional taxes will be due. As of June 30, 2016, the Company is unaware of any potentially significant uncertain tax positions for which a reserve has not been established. In November 2015, the Kenya Revenue Authority (“KRA”) commenced a tax audit covering all taxes relating to our operations in Kenya. During 2016, the Company submitted all documents requested by the KRA, which is currently processing the provided information. The Company expects to receive KRA’s audit findings once KRA completes its review and audit. A reconciliation of the beginning and ending amounts of unrecognized tax benefits is as follows: Six Months Ended June 30, 2016 2015 (Dollars in thousands) Balance at beginning of year $ 10,385 $ 7,511 Additions based on tax positions taken in prior years 103 58 Additions based on tax positions taken in the current year 528 570 Reduction based on tax positions taken in prior years (1,042 ) (988 ) Balance at end of year $ 9,974 $ 7,151

Note 12 - Subsequent Events

Note 12 - Subsequent Events	6 Months Ended
	Jun. 30, 2016
Notes to Financial Statements
Subsequent Events [Text Block]	NOTE 12 — SUBSEQUENT EVENTS Guadeloupe power plant transaction In July 2016, we announced that we closed the previously announced acquisition of Geothermie Bouillante SA ( “ GB ” ). GB owns and operates the 14.75 MW Bouillante geothermal power plant located in Guadeloupe Island, a French territory in the Caribbean, which currently generates approximately 10 MW. GB also owns two exploration licenses providing an expansion potential of up to 45 MW of capacity. Pursuant to the terms of an Amended and Restated Investment Agreement ( “ Investment Agreement ” ) and Shareholders Agreement with Sageos Holding ( “ Sageos ” ), a wholly owned subsidiary of Bureau de Recherches Géologiques et Minières ( “ BRGM ” ), the Company together with Caisse des Dépôts et Consignations ( “ CDC ” ), a French state-owned financial organization, acquired an approximately 80% interest in GB allocated 75% to the Company and 25% to CDC. The Company and CDC will gradually increase their combined interest in GB to 85% and Sageos will hold the remaining balance. Pursuant to the agreements, the Company paid approximately $18.6 million (approx imately €16.7 million) to Sageos for its approximately 60% interest in GB. In addition, the Company is committed to further invest $8.4 million (approx imately €7.5 million) in the next two years, which will increase the Company’s interest to 63.75%. The cash will be used mainly for the enhancement of the power plant. The Company has planned modifications to the existing equipment as well as to further develop the asset, with a potential of reaching a total of 45 MW in phased development by 2021. Under the Investment Agreement, the Company will pay Sageos an additional amount of up to $13.4 million (approx imately $ €12 million) subject to the achievement of agreed production thresholds and capacity expansion within a defined time period. The Bouillante power plant sells its electricity under a new 15-year PPA that was entered into in February 2016 with Électricité de France S.A. ( “ EDF ” ) , the French electric utility. The Company plan s to optimize the use of the resource at the existing facilities and recover its current production to its design capacity of 14.75 MW by mid-2017. Upon completion of the enhancement, the plant is expected to generate approximately $22.3 million (approx imately €20 million) of annual revenues. Cash dividend On August 2, 2016, the Board declared, approved and authorized payment of a quarterly dividend of $3.5 million ($0.07 per share) to all holders of the Company’s issued and outstanding shares of common stock on August 16, 2016, payable on August 30, 2016.

Significant Accounting Policies

Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	These unaudited condensed consolidated interim financial statements of Ormat Technologies, Inc. and its subsidiaries (collectively, the “Company”) have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) and pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) for interim financial statements. Accordingly, they do not contain all information and notes required by U.S. GAAP for annual financial statements. In the opinion of management, these unaudited condensed consolidated interim financial statements reflect all adjustments, which include normal recurring adjustments, necessary for a fair statement of the Company’s consolidated financial position as of June 30, 2016, the consolidated results of operations and comprehensive income (loss) for the six-month periods ended June 30, 2016 and 2015 and the consolidated cash flows for the six-month periods ended June 30, 2016 and 2015. The financial data and other information disclosed in the notes to the condensed consolidated financial statements related to these periods are unaudited. The results for the six-month period ended June 30, 2016 are not necessarily indicative of the results to be expected for the year ending December 31, 2016. These condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company’s annual report on Form 10-K for the year ended December 31, 2015. The condensed consolidated balance sheet data as of December 31, 2015 was derived from the Company’s audited consolidated financial statements for the year ended December 31, 2015, but does not include all disclosures required by U.S. GAAP.
Rounding [Policy Text Block]	Dollar amounts, except per share data, in the notes to these financial statements are rounded to the closest $1,000.
Consolidation, Subsidiaries or Other Investments, Consolidated Entities, Policy [Policy Text Block]	Alevo transaction On March 30, 2016, the Company signed an agreement with a subsidiary of Alevo Group SA (“Alevo”), a leading provider of energy storage systems, to jointly build, own and operate the Rabbit Hill Energy Storage Project (“Rabbit Hill”) located in Georgetown, Texas. The Company will own and fund the majority of the costs associated with Rabbit Hill and, under the terms of the agreement, will provide engineering and construction services and balance of plant equipment. Alevo will provide its innovative GridBank™ inorganic lithium ion energy storage system in conjunction with the power conversion systems. In addition, Alevo will provide ongoing management and operations and maintenance services for the life of the project. The Company will hold an 85% interest in the Rabbit Hill project entity which will decrease to 50.1% after reaching certain Internal Rate of Return (“IRR”) targets. The Company will consolidate Rabbit Hill as a majority owned indirect subsidiary. Northleaf Transaction On April 30, 2015, Ormat Nevada Inc. (“Ormat Nevada”), a wholly-owned subsidiary of the Company, closed the sale of approximately 36.75% of the aggregate membership interests in ORPD LLC (“ORPD”), a holding company and subsidiary of Ormat Nevada that indirectly owns the Puna geothermal power plant in Hawaii, the Don A. Campbell geothermal power plant in Nevada, and nine power plant units across three recovered energy generation assets known as OREG 1, OREG 2 and OREG 3, to Northleaf Geothermal Holdings, LLC (“Northleaf”). We are currently conducting the required power generation tests to determine the final capacity attributable to the second phase of the Don A. Campbell power plant and upon Ormat Nevada's contribution of the project to ORPD, Northleaf will pay to Ormat Nevada an amount equal to Northleaf's proportionate interest in ORPD multiplied by the value of the project to be contributed. We estimate that Ormat Nevada will receive approximately $43 million cash in connection with the contribution which is expected in the third quarter of 2016.
Receivables and Portions of Securitizations that can be Prepaid at Potential Loss, Policy [Policy Text Block]	OFC Senior Secured Notes prepayment In June 2015, the Company repurchased $30.6 million aggregate principal amount of its OFC Senior Secured Notes from the OFC noteholders. As a result of the repurchase, the Company recognized a loss of $1.7 million, including amortization of deferred financing costs of $0.5 million, which was included in other non-operating income (expense), net in the consolidated statements of operations and comprehensive income for the three and six months ended June 30, 2015.
Comprehensive Income, Policy [Policy Text Block]	Other comprehensive income For the six months ended June 30, 2016 and 2015, the Company classified $5,000 and $15,000, respectively, from accumulated other comprehensive income, of which $10,000 and $25,000, respectively, were recorded to reduce interest expense and $5,000 and $10,000, respectively, were recorded against the income tax provision, in the condensed consolidated statements of operations and comprehensive income. For the three months ended June 30, 2016 and 2015, the Company classified $2,000 and $8,000, respectively, related to derivative instruments designated as cash flow hedges, from accumulated other comprehensive income, of which $6,000 and $14,000, respectively, were recorded to reduce interest expense and $4,000 and $5,000, respectively, were recorded against the income tax provision, in the condensed consolidated statements of operations and comprehensive income. The accumulated net loss included in Other comprehensive income as of June 30, 2016, is $582,000
Exploratory Drilling Costs Capitalization and Impairment, Policy [Policy Text Block]	Write-offs of unsuccessful exploration activities Write-offs of unsuccessful exploration activities for the three and six months ended June 30, 2016 were $0.9 million and $1.4 million, respectively, and $0 and $0.2 million for the three and six months ended June 30, 2015, respectively. These write-offs of exploration costs are related to the Company’s exploration activities in Nevada and Chile, which the Company determined would not support commercial operations.
Concentration Risk, Credit Risk, Policy [Policy Text Block]	Concentration of credit risk Financial instruments that potentially subject the Company to a concentration of credit risk consist principally of temporary cash investments and accounts receivable. The Company places its temporary cash investments with high credit quality financial institutions located in the United States (“U.S.”) and in foreign countries. At June 30, 2016 and December 31, 2015, the Company had deposits totaling $18.6 million and $19.0 million, respectively, in seven U.S. financial institutions that were federally insured up to $250,000 per account. At June 30, 2016 and December 31, 2015, the Company’s deposits in foreign countries amounted to approximately $186.6 million and $181.0 million, respectively. At June 30, 2016 and December 31, 2015, accounts receivable related to operations in foreign countries amounted to approximately $34.7 million and $27.8 million, respectively. At June 30, 2016 and December 31, 2015, accounts receivable from the Company’s primary customers amounted to approximately 59% and 66%, respectively, of the Company’s accounts receivable. Sierra Pacific Power Company and Nevada Power Company (subsidiaries of NV Energy, Inc.) accounted for 19.1% and 20.1% of the Company’s total revenues for the three months ended June 30, 2016 and 2015, respectively, and 21.1% and 21.9% for the six months ended June 30, 2016 and 2015, respectively. Kenya Power and Lighting Co. Ltd. accounted for 17.1% and 15.4% of the Company’s total revenues for the three months ended June 30, 2016 and 2015, respectively, and 17.2% and 16.5% for the six months ended June 30, 2016 and 2015, respectively. Southern California Public Power Authority accounted for 10.4% and 4.1% of the Company’s total revenues for the three months ended June 30, 2016 and 2015, respectively, and 11.2% and 4.9% for the six months ended June 30, 2016 and 2015, respectively. The Company performs ongoing credit evaluations of its customers’ financial condition. The Company has historically been able to collect on all of its receivable balances, and accordingly, no provision for doubtful accounts has been made.

Note 3 - Inventories (Tables)

Note 3 - Inventories (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Schedule of Inventory, Current [Table Text Block]	June 30, December 31, 2016 2015 (Dollars in thousands) Raw materials and purchased parts for assembly $ 6,013 $ 8,819 Self-manufactured assembly parts and finished products 10,677 9,255 Total $ 16,690 $ 18,074

Note 4 - Unconsolidated Inves22

Note 4 - Unconsolidated Investments (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Equity Method Investments [Table Text Block]	June 30, December 31, 2016 2015 (Dollars in thousands) Sarulla $ (15,347 ) $ (8,100 )

Note 5 - Fair Value of Financ23

Note 5 - Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Fair Value, by Balance Sheet Grouping [Table Text Block]	June 30, 2016 Fair Value Carrying Value at June 30, 2016 Total Level 1 Level 2 Level 3 (Dollars in thousands) Assets: Current assets: Cash equivalents (including restricted cash accounts) $ 23,965 $ 23,965 $ 23,965 $ — $ — Derivatives: Currency forward contracts (2) 38 38 — 38 — Liabilities: Current liabilities: Derivatives: Call and put options on oil price (1) $ (2,349 ) $ (2,349 ) $ — $ (2,349 ) $ — Call option on natural gas price (1) (2,779 ) (2,779 ) — (2,779 ) — Currency forward contracts (2) 190 190 — 190 — $ 19,065 $ 19,065 $ 23,965 $ (4,900 ) $ — December 31, 2015 Fair Value Carrying Value at December 31, 2015 Total Level 1 Level 2 Level 3 (Dollars in thousands) Assets Current assets: Cash equivalents (including restricted cash accounts) $ 31,428 $ 31,428 $ 31,428 $ — $ — Derivatives: Currency forward contracts (2) 7 7 — 7 — Liabilities: Current liabilities: Derivatives: Currency forward contracts (2) (169 ) (169 ) — (169 ) — $ 31,266 $ 31,266 $ 31,428 $ (162 ) $ —
Derivative Instruments, Gain (Loss) [Table Text Block]	Amount of recognized gain (loss) Derivatives not designated as Location of recognized gain Three Months Ended June 30, Six Months Ended June 30, hedging instruments (loss) 2016 2015 2016 2015 Call options on natural gas price (1,664 ) — (1,146 ) — Call and put options on oil price Derivatives and foreign currency transaction gains (losses) (899 ) — (1,542 ) — Swap transactions on natural gas price Electricity revenues — 81 — 398 Currency forward contracts Derivatives and foreign currency transaction gains (losses) (1,349 ) (967 ) 465 (2,218 ) $ (3,912 ) $ (886 ) $ (2,223 ) $ (1,820 )
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments [Table Text Block]	Fair Value Carrying Amount June 30, 2016 December 31, 2015 June 30, 2016 December 31, 2015 (Dollars in millions) (Dollars in millions) Olkaria III Loan - DEG $ 20.8 $ 24.2 $ 19.7 $ 23.7 Olkaria III Loan - OPIC 258.3 262.6 255.6 264.6 Amatitlan Loan 39.7 41.7 38.5 40.3 Senior Secured Notes: Ormat Funding Corp. ("OFC") 26.5 30.0 26.5 30.0 OrCal Geothermal Inc. ("OrCal") 41.4 43.8 40.1 43.3 OFC 2 LLC ("OFC 2") 229.0 231.1 253.6 262.0 Senior Unsecured Bonds 259.0 264.5 249.8 250.0
Fair Value, Liabilities Measured on Recurring and Nonrecurring Basis [Table Text Block]	Level 1 Level 2 Level 3 Total (Dollars in millions) Olkaria III - DEG $ — $ — $ 20.8 $ 20.8 Olkaria III - OPIC — — 258.3 258.3 Amatitlan loan — 39.7 — 39.7 Senior Secured Notes: OFC — 26.5 — 26.5 OrCal — — 41.4 41.4 OFC 2 — — 229.0 229.0 Senior unsecured bonds — — 259.0 259.0 Other long-term debt — 5.0 — 5.0 Deposits 15.2 — — 15.2 Level 1 Level 2 Level 3 Total (Dollars in millions) Olkaria III Loan - DEG $ — $ — $ 24.2 $ 24.2 Olkaria III Loan - OPIC — — 262.6 262.6 Amatitlan Loan — 41.7 — 41.7 Senior Secured Notes: OFC — 30.0 — 30.0 OrCal — — 43.8 43.8 OFC 2 — — 231.1 231.1 Senior unsecured bonds — — 264.5 264.5 Other long-term debt — 6.7 — 6.7 Deposits 15.9 — — 15.9

Note 6 - Stock-based Compensa24

Note 6 - Stock-based Compensation (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]	Risk-free interest rate 1.29 % Expected life (in years) 6 Dividend yield 1.14 Expected volatility 30.7 % Forfeiture rate: Senior management 0.0 % Other employees 10.5 % Sub-Optimal Exercise Factor: Senior management 2.5 Other employees 2.0

Note 7 - Interest Expense, Net

Note 7 - Interest Expense, Net (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Schedule of Other Nonoperating Expense, by Component [Table Text Block]	Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Interest related to sale of tax benefits $ 2,846 $ 2,807 $ 3,704 $ 4,687 Interest expense 15,863 17,025 31,488 33,920 Less — amount capitalized (308 ) (973 ) (768 ) (1,920 ) $ 18,401 $ 18,859 $ 34,424 $ 36,687

Note 8 - Earnings Per Share (Ta

Note 8 - Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Schedule of Weighted Average Number of Shares [Table Text Block]	Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Weighted average number of shares used in computation of basic earnings per share 49,456 48,881 49,314 48,063 Add: Additional shares from the assumed exercise of employee stock options 681 1,719 663 1,381 Weighted average number of shares used in computation of diluted earnings per share 50,137 50,600 49,977 49,444

Note 9 - Business Segments (Tab

Note 9 - Business Segments (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Electricity Product Consolidated (Dollars in thousands) Three Months Ended June 30, 2016: Net revenue from external customers $ 104,001 $ 55,860 $ 159,861 Intersegment revenue — 19,266 19,266 Operating income 32,814 19,073 51,887 Segment assets at period end 2,031,650 241,363 2,273,013 Three Months Ended June 30, 2015: Net revenue from external customers $ 90,926 $ 49,561 $ 140,487 Intersegment revenue — 10,900 10,900 Operating income 20,920 17,723 38,643 Segment assets at period end 2,080,209 196,341 2,276,550 Six Months Ended June 30, 2016: Net revenues from external customers $ 211,869 $ 99,586 $ 311,455 Intersegment revenues — 21,206 21,206 Operating income 67,599 34,831 102,430 Segment assets at period end 2,031,650 241,363 2,273,013 Six Months Ended June 30, 2015: Net revenues from external customers $ 180,879 $ 79,839 $ 260,718 Intersegment revenues — 30,657 30,657 Operating income 44,874 23,620 68,494 Segment assets at period end 2,080,209 196,341 2,276,550
Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block]	Three Months Ended June 30, Six Months Ended June 30, 2016 2015 2016 2015 Revenue: Total segment revenue $ 159,861 $ 140,487 $ 311,455 $ 260,718 Intersegment revenue 19,266 10,900 21,206 30,657 Elimination of intersegment revenue (19,266 ) (10,900 ) (21,206 ) (30,657 ) Total consolidated revenue $ 159,861 $ 140,487 $ 311,455 $ 260,718 Operating income: Operating income $ 51,887 $ 38,643 $ 102,430 $ 68,494 Interest income 245 44 565 53 Interest expense, net (18,401 ) (18,859 ) (34,424 ) (36,687 ) Derivatives and foreign currency transaction gains (losses) (4,332 ) (571 ) (2,370 ) (1,937 ) Income attributable to sale of tax benefits 4,519 4,731 8,917 10,283 Other non-operating income (expense), net 49 (1,675 ) 240 (1,392 ) Total consolidated income before income taxes and equity in income of investees $ 33,967 $ 22,313 $ 75,358 $ 38,814

Note 11 - Income Taxes (Tables)

Note 11 - Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2016
Notes Tables
Summary of Income Tax Contingencies [Table Text Block]	Six Months Ended June 30, 2016 2015 (Dollars in thousands) Balance at beginning of year $ 10,385 $ 7,511 Additions based on tax positions taken in prior years 103 58 Additions based on tax positions taken in the current year 528 570 Reduction based on tax positions taken in prior years (1,042 ) (988 ) Balance at end of year $ 9,974 $ 7,151

Note 1 - General and Basis of29

Note 1 - General and Basis of Presentation (Details Textual)	Mar. 30, 2016	Jun. 30, 2015USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)	Apr. 29, 2015	Dec. 31, 2014USD ($)
Rabbit Hill Project Entity [Member]
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions	85.00%
Subsidiary or Equity Method Investee, Cumulative Percentage Ownership after All Transactions, Subsequent to Reaching Certain IRR Achievements	50.10%
Northleaf Geothermal Holdings, Northleaf [Member]
Equity Method Investment, Ownership Percentage									36.75%
Number of Power Plants Acquired									9
Recovered Energy Generation Assets									3
Scenario, Forecast [Member] | Second Phase of Don Campbell [Member]
Proceeds from Divestiture of Businesses			$ 43,000,000
Ormat Funding Corp [Member] | Other Nonoperating Income (Expense) [Member]
Amortization of Debt Issuance Costs		$ 500,000
Ormat Funding Corp [Member]
Repayments of Secured Debt		30,600,000
Gain (Loss) on Extinguishment of Debt		1,700,000
Reclassification out of Accumulated Other Comprehensive Income [Member]
Net Income (Loss) Attributable to Parent				$ 2,000	$ 8,000	$ 5,000	$ 15,000
Interest Expense				6,000	14,000	10,000	25,000
Income Tax Expense (Benefit)				4,000	$ 5,000	5,000	$ 10,000
Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax				582,000		582,000
UNITED STATES
Cash, Cash Equivalents, and Short-term Investments				18.60		18.60		$ 19
Foreign Countries [Member]
Cash, Cash Equivalents, and Short-term Investments				186.60		186.60		181
Accounts Receivable, Net, Current				34.70		34.70		27.80
Maximum [Member]
Cash, FDIC Insured Amount				$ 250,000		$ 250,000		$ 250,000
Accounts Receivable [Member] | Customer Concentration Risk [Member] | Primary Customers [Member]
Concentration Risk, Percentage						59.00%		66.00%
Sales Revenue, Net [Member] | Customer Concentration Risk [Member] | Sierra Pacific Power Company And Nevada Power Company [Member]
Concentration Risk, Percentage				19.10%	20.10%	21.10%	21.90%
Sales Revenue, Net [Member] | Customer Concentration Risk [Member] | Kenya Power And Lighting Co LTD [Member]
Concentration Risk, Percentage				17.10%	15.40%	17.20%	16.50%
Sales Revenue, Net [Member] | Customer Concentration Risk [Member] | Southern California Edison Company [Member]
Concentration Risk, Percentage				10.40%	4.10%	11.20%	4.90%
Repayments of Secured Debt							$ 30,638,000
Net Income (Loss) Attributable to Parent				$ 24,349,000	$ 14,414,000	53,620,000	24,446,000
Interest Expense				18,401,000	18,859,000	34,424,000	36,687,000
Income Tax Expense (Benefit)				7,890,000	6,056,000	17,399,000	11,515,000
Accumulated Other Comprehensive Income (Loss), Net of Tax				(12,838,000)		(12,838,000)		$ (7,667,000)
Exploration Abandonment and Impairment Expense				863,000	0	1,420,000	174,000
Cash, Cash Equivalents, and Short-term Investments		$ 137,665,000		192,556,000	$ 137,665,000	192,556,000	$ 137,665,000	185,919,000		$ 40,230,000
Accounts Receivable, Net, Current				$ 59,042,000		59,042,000		$ 55,301,000
Provision for Doubtful Accounts						$ 0

Note 2 - New Accounting Prono30

Note 2 - New Accounting Pronouncements (Details Textual) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Reclassification of Debt Issuance Costs [Member] | December 2015 [Member]
Prior Period Reclassification Adjustment	$ 19.1
Reclassification of Debt Issuance Costs [Member]
Current Period Reclassification Adjustment	17.7
Debt Issuance Costs, Line of Credit Arrangements, Net	$ 2	$ 1

Note 3 - Inventories - Inventor

Note 3 - Inventories - Inventories, Current (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Raw materials and purchased parts for assembly	$ 6,013	$ 8,819
Self-manufactured assembly parts and finished products	10,677	9,255
Total	$ 16,690	$ 18,074

Note 4 - Unconsolidated Inves32

Note 4 - Unconsolidated Investments (Details Textual)	Jun. 04, 2014USD ($)	May 23, 2014USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)MWh	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	May 16, 2014USD ($)
Sarulla [Member] | Lenders Consortium [Member] | Subject to Fixed Interest Rate [Member]
Proceeds from Issuance of Senior Long-term Debt		$ 100,000,000
Sarulla [Member] | Lenders Consortium [Member] | Subject to LIBOR based Interest Rate [Member]
Senior Notes								$ 1,070,000,000
Sarulla [Member] | Lenders Consortium [Member] | Subject to Fixed LIBOR Interest Rate [Member] | Interest Rate Swap [Member]
Senior Notes							$ 960,000,000
Sarulla [Member] | Lenders Consortium [Member] | Interest Rate Swap [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument, Basis Spread on Variable Rate	3.4565%
Sarulla [Member] | Lenders Consortium [Member] | Interest Rate Swap [Member]
Proceeds from Issuance of Senior Long-term Debt	$ 50,000,000
Sarulla [Member] | Lenders Consortium [Member]
Senior Notes								$ 1,170,000,000
Sarulla [Member] | Interest Rate Swap [Member] | Sarulla Project Company [Member]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax			$ (15,600,000)		$ (40,500,000)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax			(8,000,000)		(20,900,000)
Sarulla [Member] | Interest Rate Swap [Member]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax			(2,000,000)		(5,200,000)
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax			$ 12,300,000		$ 12,300,000
Sarulla [Member]
Jointly Owned Utility Plant, Proportionate Ownership Share			12.75%		12.75%
Expected Power Generating Capacity | MWh					330
Power Plant Usage Agreement Term					30 years
Payments to Acquire Projects					$ 0
Number Of Phases Of Construction					3
Power Utilization | MWh					110
Percentage of Required Production Capacity			70.00%		70.00%
Percentage of Required Injection Capacity			15.00%		15.00%
Number of Commercial Lenders in Funding Consortium								6
Supply Commitment, Remaining Minimum Amount Committed			$ 255,600,000		$ 255,600,000
Intersegment Eliminations [Member]
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest					8,400,000
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax			(1,987,000)	$ 3,460,000	(5,166,000)	$ 164,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest			$ 24,933,000	$ 15,273,000	$ 55,878,000	$ 25,540,000

Note 4 - Unconsolidated Inves33

Note 4 - Unconsolidated Investments - Unconsolidated Investments Mainly in Power Plants (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Sarulla [Member]
Sarulla	$ (15,347)	$ (8,100)

Note 5 - Fair Value of Financ34

Note 5 - Fair Value of Financial Instruments (Details Textual) $ in Millions

Mar. 24, 2016Boe$ / item

Feb. 24, 2016BTU$ / item

Mar. 14, 2015BTU$ / BTU

Mar. 06, 2014BTU$ / BTU

Mar. 31, 2016Boe$ / item

Jun. 30, 2016USD ($)

Jun. 30, 2015USD ($)

Jun. 30, 2016USD ($)

Jun. 30, 2016USD ($)

Jun. 30, 2016USD ($)

Jun. 30, 2015USD ($)

Feb. 28, 2016$ / item

NGI Swap Contract [Member]

Derivative, Nonmonetary Notional Amount, Energy Measure | BTU

2.4

2,200,000

Underlying, Derivative Energy Measure | $ / BTU

3

4.95

Henry Hub Natural Gas Future ("NG") Contracts [Member] | Call Option [Member]

Proceeds from Derivative Instrument, Investing Activities | $

$ 1.9

Henry Hub Natural Gas Future ("NG") Contracts [Member]

Derivative, Nonmonetary Notional Amount, Energy Measure | BTU

4,100,000

Derivative, Price Risk Option Strike Price

2

Brent Oil Future Contracts [Member] | Call Option [Member]

Proceeds from Derivative Instrument, Investing Activities | $

$ 1.1

Brent Oil Future Contracts [Member] | Minimum [Member]

Derivative, Price Risk Option Strike Price

32.8

Brent Oil Future Contracts [Member] | Maximum [Member]

Derivative, Price Risk Option Strike Price

35.5

Brent Oil Future Contracts [Member]

Derivative, Nonmonetary Notional Amount, Energy Measure | Boe

185,000

Rolled Two Existing Options [Member] | Minimum [Member]

Derivative, Price Risk Option Strike Price

41

Rolled Two Existing Options [Member] | Maximum [Member]

Derivative, Price Risk Option Strike Price

42.5

Rolled Two Existing Options [Member]

Derivative, Nonmonetary Notional Amount, Energy Measure | Boe

31,800

Before Rolling Two Existing Options [Member] | Minimum [Member]

Derivative, Price Risk Option Strike Price

32.8

Before Rolling Two Existing Options [Member] | Maximum [Member]

Derivative, Price Risk Option Strike Price

33.5

Short Risk Reversal Transactions, Rolling Existing Call Option 1 [Member] | Minimum [Member]

Derivative, Price Risk Option Strike Price

28.5

Short Risk Reversal Transactions, Rolling Existing Call Option 1 [Member] | Maximum [Member]

Derivative, Price Risk Option Strike Price

37.5

Short Risk Reversal Transactions, Rolling Existing Call Option 1 [Member]

Derivative, Nonmonetary Notional Amount, Energy Measure | Boe

16,500

Short Risk Reversal Transactions, Rolling Existing Call Option 2 [Member] | Minimum [Member]

Derivative, Price Risk Option Strike Price

28

Short Risk Reversal Transactions, Rolling Existing Call Option 2 [Member] | Maximum [Member]

Derivative, Price Risk Option Strike Price

38.5

Short Risk Reversal Transactions, Rolling Existing Call Option 2 [Member]

Derivative, Nonmonetary Notional Amount, Energy Measure | Boe

17,000

Foreign Currency Gain (Loss) [Member]

Gain (Loss) on Price Risk Derivative Instruments Not Designated as Hedging Instruments | $

$ (1)

$ (2.2)

Electricity Revenues [Member]

Gain (Loss) on Price Risk Derivative Instruments Not Designated as Hedging Instruments | $

$ 0.1

$ 0.4

Derivative, Number of Options Rolled

2

Gain (Loss) on Price Risk Derivative Instruments Not Designated as Hedging Instruments | $

$ (3.9)

$ (2.2)

Note 5 - Fair Value of Financ35

Note 5 - Fair Value of Financial Instruments - Financial Assets and Liabilities at Fair Value (Details) - USD ($) $ in Thousands		Jun. 30, 2016	Dec. 31, 2015
Reported Value Measurement [Member] | Forward Contracts [Member]
Assets:
Derivative assets	[1]	$ 38	$ 7
Liabilities:
Derivative liabilities	[1]	(190)	(169)
Derivative liabilities	[1]	190	169
Reported Value Measurement [Member] | Call and Put Options on Oil Price [Member]
Liabilities:
Derivative liabilities	[2]	(2,349)
Derivative liabilities	[2]	2,349
Reported Value Measurement [Member] | Call Option on Natural Gas Price [Member]
Liabilities:
Derivative liabilities		(2,779)
Derivative liabilities		2,779
Reported Value Measurement [Member]
Assets:
Cash equivalents (including restricted cash accounts)		23,965	31,428
Liabilities:
		19,065	31,266
Fair Value, Inputs, Level 1 [Member] | Forward Contracts [Member]
Assets:
Derivative assets	[1]
Liabilities:
Derivative liabilities	[1]
Derivative liabilities	[1]
Fair Value, Inputs, Level 1 [Member] | Call and Put Options on Oil Price [Member]
Liabilities:
Derivative liabilities	[2]
Derivative liabilities	[2]
Fair Value, Inputs, Level 1 [Member] | Call Option on Natural Gas Price [Member]
Liabilities:
Derivative liabilities	[2]
Derivative liabilities	[2]
Fair Value, Inputs, Level 1 [Member]
Assets:
Cash equivalents (including restricted cash accounts)		23,965	31,428
Liabilities:
		23,965	31,428
		(23,965)	(31,428)
Fair Value, Inputs, Level 2 [Member] | Forward Contracts [Member]
Assets:
Derivative assets	[1]	38	7
Liabilities:
Derivative liabilities	[1]	(190)	(169)
Derivative liabilities	[1]	190	169
Fair Value, Inputs, Level 2 [Member] | Call and Put Options on Oil Price [Member]
Liabilities:
Derivative liabilities	[2]	(2,349)
Derivative liabilities	[2]	2,349
Fair Value, Inputs, Level 2 [Member] | Call Option on Natural Gas Price [Member]
Liabilities:
Derivative liabilities	[2]	(2,779)
Derivative liabilities	[2]	2,779
Fair Value, Inputs, Level 2 [Member]
Assets:
Cash equivalents (including restricted cash accounts)
Liabilities:
		4,900	162
		(4,900)	(162)
Fair Value, Inputs, Level 3 [Member] | Forward Contracts [Member]
Assets:
Derivative assets	[1]
Liabilities:
Derivative liabilities	[1]
Derivative liabilities	[1]
Fair Value, Inputs, Level 3 [Member] | Call and Put Options on Oil Price [Member]
Liabilities:
Derivative liabilities	[2]
Derivative liabilities	[2]
Fair Value, Inputs, Level 3 [Member] | Call Option on Natural Gas Price [Member]
Liabilities:
Derivative liabilities	[2]
Derivative liabilities	[2]
Fair Value, Inputs, Level 3 [Member]
Assets:
Cash equivalents (including restricted cash accounts)
Liabilities:
Forward Contracts [Member]
Assets:
Derivative assets	[1]	38	7
Liabilities:
Derivative liabilities	[1]	(190)	169
Derivative liabilities	[1]	190	(169)
Call and Put Options on Oil Price [Member]
Liabilities:
Derivative liabilities	[2]	(2,349)
Derivative liabilities	[2]	2,349
Call Option on Natural Gas Price [Member]
Liabilities:
Derivative liabilities	[2]	(2,779)
Derivative liabilities	[2]	2,779
Cash equivalents (including restricted cash accounts)		192,556	185,919
Cash equivalents (including restricted cash accounts)		23,965	31,428
		19,065	31,266
		$ (19,065)	$ (31,266)
[1]	These amounts relate to derivatives which represent currency forward contracts valued primarily based on observable inputs, including forward and spot prices for currencies, netted against contracted rates and then multiplied against notional amounts, and are included within “prepaid expenses and other” and “accounts payable and accrued expenses” on June 30, 2016 and December 31, 2015, in the consolidated balance sheet with the corresponding gain or loss being recognized within “Foreign currency translation and transaction gains (losses)” in the consolidated statement of operations and comprehensive income.
[2]	These amounts relate to call and put option transactions on oil and natural gas prices, valued primarily based on observable inputs, including spot prices for related commodity indices, and is included within “Accounts payable and accrued expenses” on June 30, 2016 in the consolidated balance sheets with the corresponding gain or loss being recognized within “Foreign currency translation and transaction losses” in the consolidated statement of operations and comprehensive income.

Note 5 - Fair Value of Financ36

Note 5 - Fair Value of Financial Instruments - Amounts of Gain (Loss) Recognized in Condensed Consolidated Statements on Derivative Instruments not Designated as Hedges (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Electricity Revenues [Member] | Call Option on Natural Gas Price [Member]
Amount of gain (loss) recognized	$ (1,664)		$ (1,146)
Electricity Revenues [Member] | Currency Forward Contracts [Member]
Amount of gain (loss) recognized	(1,349)	(967)	465	(2,218)
Foreign Currency Gain (Loss) [Member] | Call and Put Options on Oil Price [Member]
Amount of gain (loss) recognized	(899)		(1,542)
Foreign Currency Gain (Loss) [Member] | Natural Gas Price Swap [Member]
Amount of gain (loss) recognized		81		398
Amount of gain (loss) recognized	$ (3,912)	$ (886)	$ (2,223)	$ (1,820)

Note 5 - Fair Value of Financ37

Note 5 - Fair Value of Financial Instruments - Fair Value of Long-term Debt Approximates its Carrying Amount, Exceptions (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Olkaria III DEG [Member] | Estimate of Fair Value Measurement [Member]
Loans	$ 20.8	$ 24.2
Olkaria III DEG [Member] | Reported Value Measurement [Member]
Loans	19.7	23.7
Olkaria III OPIC [Member] | Estimate of Fair Value Measurement [Member]
Loans	258.3	262.6
Olkaria III OPIC [Member] | Reported Value Measurement [Member]
Loans	255.6	264.6
Amatitlan Loan [Member] | Estimate of Fair Value Measurement [Member]
Loans	39.7	41.7
Amatitlan Loan [Member] | Reported Value Measurement [Member]
Loans	38.5	40.3
Ormat Funding Corp [Member] | Estimate of Fair Value Measurement [Member]
Notes	26.5	30
Ormat Funding Corp [Member] | Reported Value Measurement [Member]
Notes	26.5	30
Orcal Geothermal Inc [Member] | Estimate of Fair Value Measurement [Member]
Notes	41.4	43.8
Orcal Geothermal Inc [Member] | Reported Value Measurement [Member]
Notes	40.1	43.3
Ofc Two Senior Secured Notes [Member] | Estimate of Fair Value Measurement [Member]
Notes	229	231.1
Ofc Two Senior Secured Notes [Member] | Reported Value Measurement [Member]
Notes	253.6	262
Senior Unsecured Bonds [Member] | Estimate of Fair Value Measurement [Member]
Senior Unsecured Bonds	259	264.5
Senior Unsecured Bonds [Member] | Reported Value Measurement [Member]
Senior Unsecured Bonds	$ 249.8	$ 250

Note 5 - Fair Value of Financ38

Note 5 - Fair Value of Financial Instruments - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Olkaria III DEG [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Olkaria III DEG [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt
Olkaria III DEG [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt	20.8	24.2
Olkaria III DEG [Member]
Fair value levels-secured, unsecured and long term debt	20.8	24.2
Olkaria III OPIC [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Olkaria III OPIC [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt
Olkaria III OPIC [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt	258.3	262.6
Olkaria III OPIC [Member]
Fair value levels-secured, unsecured and long term debt	258.3	262.6
Amatitlan Loan [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Amatitlan Loan [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt	39.7
Amatitlan Loan [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt
Amatitlan Loan [Member]
Fair value levels-secured, unsecured and long term debt	39.7
Amatitlan [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Amatitlan [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt		41.7
Amatitlan [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt
Amatitlan [Member]
Fair value levels-secured, unsecured and long term debt		41.7
Ormat Funding Corp [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Ormat Funding Corp [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt	26.5	30
Ormat Funding Corp [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt
Ormat Funding Corp [Member]
Fair value levels-secured, unsecured and long term debt	26.5	30
Orcal Geothermal Inc [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Orcal Geothermal Inc [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt
Orcal Geothermal Inc [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt	41.4	43.8
Orcal Geothermal Inc [Member]
Fair value levels-secured, unsecured and long term debt	41.4	43.8
Ofc Two Senior Secured Notes [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Ofc Two Senior Secured Notes [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt
Ofc Two Senior Secured Notes [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt	229	231.1
Ofc Two Senior Secured Notes [Member]
Fair value levels-secured, unsecured and long term debt	229	231.1
Senior Unsecured Bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Senior Unsecured Bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt
Senior Unsecured Bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt	259	264.5
Senior Unsecured Bonds [Member]
Fair value levels-secured, unsecured and long term debt	259	264.5
Other Long-term Debt [Member] | Fair Value, Inputs, Level 1 [Member]
Fair value levels-secured, unsecured and long term debt
Other Long-term Debt [Member] | Fair Value, Inputs, Level 2 [Member]
Fair value levels-secured, unsecured and long term debt	5	6.7
Other Long-term Debt [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt
Other Long-term Debt [Member]
Fair value levels-secured, unsecured and long term debt	5	6.7
Fair Value, Inputs, Level 1 [Member]
Deposits	15.2	15.9
Fair Value, Inputs, Level 2 [Member]
Deposits
Fair Value, Inputs, Level 3 [Member]
Deposits
Deposits	$ 15.2	$ 15.9

Note 6 - Stock-based Compensa39

Note 6 - Stock-based Compensation (Details Textual) - $ / shares	Jun. 13, 2016	May 31, 2012	Dec. 31, 2004	Jun. 30, 2016
2004 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member] | Share-based Compensation Award, Tranche One [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage			25.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			2 years
2004 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member] | Share-based Compensation Award, Tranche Two [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage			25.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
2004 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member] | Share-based Compensation Award, Tranche Three [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage			50.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			4 years
2004 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized			3,750,000
2004 Stock Incentive Plan [Member] | Employee Stock Option [Member] | Non Employee Director [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			1 year
2004 Stock Incentive Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award Awards Exercise Period			10 years
2012 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member] | Share-based Compensation Award, Tranche One [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage		25.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		2 years
2012 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member] | Share-based Compensation Award, Tranche Two [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage		25.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		3 years
2012 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member] | Share-based Compensation Award, Tranche Three [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage		50.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		4 years
2012 Stock Incentive Plan [Member] | Stock Options And Stock Appreciation Rights [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized		4,000,000
2012 Stock Incentive Plan [Member] | Stock Appreciation Rights (SARs) [Member] | Share-based Compensation Award, Tranche One [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	50.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	2 years
2012 Stock Incentive Plan [Member] | Stock Appreciation Rights (SARs) [Member] | Share-based Compensation Award, Tranche Two [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	25.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
2012 Stock Incentive Plan [Member] | Stock Appreciation Rights (SARs) [Member] | Share-based Compensation Award, Tranche Three [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	25.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	4 years
2012 Stock Incentive Plan [Member] | Stock Appreciation Rights (SARs) [Member] | Senior Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 11.98
2012 Stock Incentive Plan [Member] | Stock Appreciation Rights (SARs) [Member] | Other Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$ 11.42
2012 Stock Incentive Plan [Member] | Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	4 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	1,080,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Exercise Price	$ 42.87
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	6 years
2012 Stock Incentive Plan [Member] | Non Employee Director [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period		1 year
2012 Stock Incentive Plan [Member] | Officer [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized				400,000
2012 Stock Incentive Plan [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award Awards Exercise Period		6 years
2012 Stock Incentive Plan [Member] | Maximum [Member]
Share Based Compensation Arrangement By Share Based Payment Award Awards Exercise Period		10 years

Note 6 - Stock-based Compensa40

Note 6 - Stock-based Compensation - Fair Value of Stock-based Award on the Date of Grant (Details) - Stock Appreciation Rights (SARs) [Member]	6 Months Ended
	Jun. 30, 2016
Senior Management [Member]
Forfeiture rate	0.00%
Sub-Optimal Exercise Factor	2.5
Other Employees [Member]
Forfeiture rate	10.50%
Sub-Optimal Exercise Factor	2
Risk-free interest rate	1.29%
Expected life (in years)	6 years
Dividend yield	1.14%
Expected volatility	30.70%

Note 7 - Interest Expense, Ne41

Note 7 - Interest Expense, Net - Components of Interest Expense (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Interest related to sale of tax benefits	$ 2,846	$ 2,807	$ 3,704	$ 4,687
Interest expense	15,863	17,025	31,488	33,920
Less — amount capitalized	(308)	(973)	(768)	(1,920)
Interest Expense	$ 18,401	$ 18,859	$ 34,424	$ 36,687

Note 8 - Earnings Per Share (De

Note 8 - Earnings Per Share (Details Textual) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	135,875	636,487	224,116	765,424

Note 8 - Earnings Per Share - R

Note 8 - Earnings Per Share - Reconciliation of Number of Shares Used in Computation of Basic and Diluted Earnings (Loss) Per Share (Details) - shares shares in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Basic (in shares)	49,456	48,881	49,314	48,063
Add:
Additional shares from the assumed exercise of employee stock options (in shares)	681	1,719	663	1,381
Weighted average number of shares used in computation of diluted earnings per share (in shares)	50,137	50,600	49,977	49,444

Note 9 - Business Segments (Det

Note 9 - Business Segments (Details Textual)	6 Months Ended
	Jun. 30, 2016
Number of Reportable Segments	2

Note 9 - Business Segments - Su

Note 9 - Business Segments - Summarized Financial Information Concerning Reportable Segments (Details) - USD ($) $ in Thousands		3 Months Ended				6 Months Ended
		Jun. 30, 2016		Jun. 30, 2015		Jun. 30, 2016		Jun. 30, 2015		Dec. 31, 2015
Electricity [Member] | Intersegment Eliminations [Member]
Revenue
Electricity [Member]
Net revenue from external customers		104,001		90,926		211,869		180,879
Operating income		32,814		20,920		67,599		44,874
Segment assets at period end	[1]	2,031,650		2,080,209		2,031,650		2,080,209
Product Segment [Member] | Intersegment Eliminations [Member]
Revenue		19,266		10,900		21,206		30,657
Product Segment [Member]
Net revenue from external customers		55,860		49,561		99,586		79,839
Operating income		19,073		17,723		34,831		23,620
Segment assets at period end	[1]	241,363		196,341		241,363		196,341
Intersegment Eliminations [Member]
Revenue		19,266		10,900		21,206		30,657
Net revenue from external customers		159,861		140,487		311,455		260,718
Revenue		159,861		140,487		311,455		260,718
Operating income		51,887		38,643		102,430		68,494
Segment assets at period end		$ 2,273,013	[1]	$ 2,276,550	[1]	$ 2,273,013	[1]	$ 2,276,550	[1]	$ 2,273,982
[1]	Including unconsolidated investments

Note 9 - Business Segments - Re

Note 9 - Business Segments - Reconciling Information Between Reportable Segments and Consolidated Totals (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Total Segment Revenues [Member]
Revenues:
Revenue	$ 159,861	$ 140,487	$ 311,455	$ 260,718
Intersegment Eliminations [Member]
Revenues:
Revenue	19,266	10,900	21,206	30,657
Consolidation, Eliminations [Member]
Revenues:
Revenue	(19,266)	(10,900)	(21,206)	(30,657)
Revenue	159,861	140,487	311,455	260,718
Operating income:
Operating income	51,887	38,643	102,430	68,494
Interest income	245	44	565	53
Interest expense, net	(18,401)	(18,859)	(34,424)	(36,687)
Derivatives and foreign currency transaction gains (losses)	(4,332)	(571)	(2,370)	(1,937)
Income attributable to sale of tax benefits	4,519	4,731	8,917	10,283
Other non-operating income (expense), net	49	(1,675)	240	(1,392)
Total consolidated income before income taxes and equity in income of investees	$ 33,967	$ 22,313	$ 75,358	$ 38,814

Note 10 - Commitments and Con47

Note 10 - Commitments and Contingencies (Details Textual) - USD ($) $ in Millions	Mar. 29, 2016	May 21, 2014	Jan. 31, 2014
Two Former Employees Vs. Ormat [Member] | Pending Litigation [Member]
Loss Contingency, Damages Sought, Value			$ 375
Former Local Sales Representative vs. Ormat [Member] | Pending Litigation [Member]
Loss Contingency, Damages Sought, Value	$ 4.6
Loss Contingency, Additional Damages Sought for Ormat Geothermal Products Sales in Chile, Percent	3.75%
Loss Contingency, Damages Sought, Ormat Geothermal Products Sales in Chile, Period	10 years
McGinness Plant[Member]
Tax Abatement Benefit, Value		$ 18.6
Tuscorura Plant [Member]
Tax Abatement Benefit, Value		$ 6.2
Tax Abatement, Period		20 years

Note 11 - Income Taxes (Details

Note 11 - Income Taxes (Details Textual) - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
ISRAEL
National Corporate Tax Rate			16.00%
KENYA
National Corporate Tax Rate			37.50%
Domestic Tax Authority [Member]
Operating Loss Carryforwards					$ 261,000,000
State and Local Jurisdiction [Member]
Operating Loss Carryforwards					$ 191,000,000
General Business Tax Credit Carryforward [Member] | Minimum [Member]
Tax Credit Carryforward Expiration Year					2,026
General Business Tax Credit Carryforward [Member] | Maximum [Member]
Tax Credit Carryforward Expiration Year					2,036
General Business Tax Credit Carryforward [Member]
Tax Credit Carryforward Expiration Period					20 years
Effective Income Tax Rate Reconciliation, Percent			23.10%	29.70%
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent			35.00%
Effective Income Tax Rate Reconciliation, Tax Exempt Income, Amount	$ 1,130,000	$ 880,000	$ 2,330,000	$ 2,026,000
Deferred Tax Assets, Tax Credit Carryforwards, General Business					$ 70,800,000
Undistributed Earnings of Foreign Subsidiaries					$ 233,800,000

Note 11 - Income Taxes - Reconc

Note 11 - Income Taxes - Reconciliation of Beginning and Ending Amounts of Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Balance at beginning of year	$ 10,385	$ 7,511
Additions based on tax positions taken in prior years	103	58
Additions based on tax positions taken in the current year	528	570
Reduction based on tax positions taken in prior years	(1,042)	(988)
Balance at end of year	$ 9,974	$ 7,151

Note 12 - Subsequent Events (De

Note 12 - Subsequent Events (Details Textual) $ / shares in Units, $ in Thousands, € in Millions	Aug. 02, 2016USD ($)$ / shares	Jul. 31, 2016EUR (€)MWh	Jul. 31, 2016USD ($)	Jun. 30, 2016$ / shares	Jun. 30, 2015$ / shares	Jun. 30, 2016USD ($)$ / shares	Jun. 30, 2015USD ($)$ / shares	Jul. 31, 2016USD ($)MWh
Subsequent Event [Member] | Geothermie Bouillante SA (“GB”) [Member] | Ormat Systems LTD and Caisse des Depots et Consignations (CDC) [Member]
Business Acquisition, Percentage of Voting Interests Acquired		80.00%						80.00%
Business Combination, Expected Ownership Interest		85.00%						85.00%
Subsequent Event [Member] | Geothermie Bouillante SA (“GB”) [Member]
Business Acquisition, Maximum Capacity		14.75						14.75
Business Acquisition, Current Capacity		10						10
Number of Exploration Licenses Owned		2						2
Business Acquisition, Expansion Capacity		45						45
Business Acquisition, Percentage of Voting Interests Acquired		60.00%						60.00%
Business Combination, Expected Ownership Interest		63.75%						63.75%
Payments to Acquire Businesses, Gross		€ 16.7	$ 18,600
Business Combination, Future Investment Committed		7.5						$ 8,400
Business Combination, Additional Capacity Expansion Investment, Maximum		€ 12	$ 13,400
Business Combination, Future Investment Committed, Period		2 years	2 years
Purchase Agreement Period		15 years	15 years
Expected Revenues Upon Completion of the Enhancement		€ 20	$ 22,300
Subsequent Event [Member] | Ormat Systems Ltd [Member]
Business Combination, Co-acquisition, Percentage of Ownership Interest Allocated		75.00%						75.00%
Subsequent Event [Member] | Caisse des Depots et Consignations (CDC) [Member]
Business Combination, Co-acquisition, Percentage of Ownership Interest Allocated		25.00%						25.00%
Subsequent Event [Member]
Dividends, Common Stock | $	$ 3,500
Common Stock, Dividends, Per Share, Declared | $ / shares	$ 0.07
Dividends, Common Stock | $						$ 18,998	$ 6,830
Common Stock, Dividends, Per Share, Declared | $ / shares				$ 0.07	$ 0.06	$ 0.38	$ 0.12