Ormat (ORA) 10-Q 8 Nov 16 2016 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Nov. 09, 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)		49,634,659
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Amendment Flag	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 90,066	$ 185,919
Restricted cash and cash equivalents (all related to VIEs)	50,525	49,503
Receivables:
Trade	65,198	55,301
Other	13,645	7,885
Inventories	12,973	18,074
Costs and estimated earnings in excess of billings on uncompleted contracts	38,025	25,120
Prepaid expenses and other	38,940	33,334
Total current assets	309,372	375,136
Deposits and other	18,738	17,968
Deferred charges	40,690	42,811
Property, plant and equipment, net	1,570,307	1,559,335
Construction-in-process	271,853	248,835
Deferred financing and lease costs, net	5,188	4,022
Intangible assets, net	56,052	25,875
Goodwill	7,071
Total assets	2,279,271	2,273,982
LIABILITIES AND EQUITY
Accounts payable and accrued expenses	102,854	91,955
Billings in excess of costs and estimated earnings on uncompleted contracts	37,134	33,892
Current portion of long-term debt:
Senior secured notes	28,121	29,930
Other loans	21,494	21,495
Full recourse	12,302	11,229
Total current liabilities	201,905	188,501
Long-term debt, net of current portion:
Senior secured notes (less deferred financing costs of $9,957 and $10,852, respectively)	273,017	294,476
Other loans (less deferred financing costs of $6,821 and $7,492, respectively)	267,210	275,888
Senior unsecured bonds (plus unamortized premium based upon 7% of $0 and $513, respectively and less deferred financing costs of $849 and $283, respectively)	203,483	249,698
Other loans (less deferred financing costs of $290 and $435, respectively)	12,373	18,687
Accumulated losses of unconsolidated company in excess of investment	16,664	8,100
Liability associated with sale of tax benefits	1,043	11,665
Deferred lease income	55,460	58,099
Deferred income taxes	34,961	32,654
Liability for unrecognized tax benefits	10,260	10,385
Liabilities for severance pay	19,020	19,323
Asset retirement obligation	22,099	20,856
Other long-term liabilities	20,862	1,776
Total liabilities	1,138,357	1,190,108
Commitments and contingencies (Note 10)
Reedemable noncontrolling interest	4,972
Equity:
Common stock, par value $0.001 per share; 200,000,000 shares authorized; 49,634,659 and 49,107,901 shares issued and outstanding as of September 30, 2016 and December 31, 2015, respectively	50	49
Additional paid-in capital	859,855	849,223
Retained earnings	191,627	148,396
Accumulated other comprehensive income	(11,503)	(7,667)
	1,040,029	990,001
Noncontrolling interest	95,913	93,873
Total equity	1,135,942	1,083,874
Total liabilities and equity	$ 2,279,271	$ 2,273,982

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Unaudited) (Parentheticals) - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Variable Interest Entity, Primary Beneficiary [Member]
Property, plant and equipment, net	$ 1,499,112,000	$ 1,481,258,000
Construction-in-process	82,476,000	129,165,000
Senior Secured Notes [Member]
Deferred financing costs	9,957,000	10,852,000
Other Loans, Limited and Non-recourse [Member]
Deferred financing costs	6,821,000	7,492,000
Senior Unsecured Bonds [Member]
Deferred financing costs	849,000	283,000
Other Loans, Full Recourse [Member]
Deferred financing costs	290,000	435,000
Property, plant and equipment, net	1,570,307,000	1,559,335,000
Construction-in-process	$ 271,853,000	$ 248,835,000
Senior unsecured bonds %	7.00%	7.00%
Senior unsecured bonds unamortized premium	$ 0	$ 513,000
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)	49,634,659	49,107,901
Common stock, shares outstanding (in shares)	49,634,659	49,107,901

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations and Comprehensive Income (Unaudited) - USD ($) shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Revenues:
Electricity	$ 109,795,000	$ 97,245,000	$ 321,664,000	$ 278,124,000
Product	74,822,000	65,607,000	174,408,000	145,446,000
Total revenues	184,617,000	162,852,000	496,072,000	423,570,000
Cost of revenues:
Electricity	66,481,000	61,501,000	192,410,000	179,604,000
Product	43,647,000	42,019,000	99,504,000	89,826,000
Total cost of revenues	110,128,000	103,520,000	291,914,000	269,430,000
Gross margin	74,489,000	59,332,000	204,158,000	154,140,000
Operating expenses:
Research and development expenses	1,086,000	335,000	2,030,000	1,112,000
Selling and marketing expenses	4,793,000	4,383,000	12,136,000	12,099,000
General and administrative expenses	19,093,000	7,950,000	36,625,000	25,597,000
Write-off of unsuccessful exploration activities	1,294,000	185,000	2,714,000	359,000
Operating income	48,223,000	46,479,000	150,653,000	114,973,000
Other income (expense):
Interest income	266,000	53,000	831,000	106,000
Interest expense, net	(17,137,000)	(17,748,000)	(51,561,000)	(54,435,000)
Derivatives and foreign currency transaction gains (losses)	(222,000)	1,296,000	(2,592,000)	(641,000)
Income attributable to sale of tax benefits	3,463,000	8,634,000	12,380,000	18,917,000
Other non-operating income (expense), net	(5,546,000)	(131,000)	(5,306,000)	(1,523,000)
Income from continuing operations before income taxes and equity in losses of investees	29,047,000	38,583,000	104,405,000	77,397,000
Income tax (provision) benefit	(11,988,000)	38,211,000	(29,387,000)	26,696,000
Equity in losses of investees, net	(2,653,000)	(3,133,000)	(4,734,000)	(4,892,000)
Income from continuing operations	14,406,000	73,661,000	70,284,000	99,201,000
Net income attributable to noncontrolling interest	(2,326,000)	(1,522,000)	(4,584,000)	(2,616,000)
Net income attributable to the Company's stockholders	12,080,000	72,139,000	65,700,000	96,585,000
Comprehensive income:
Net income	14,406,000	73,661,000	70,284,000	99,201,000
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	1,337,000	(4,318,000)	(3,829,000)	(4,154,000)
Loss in respect of derivative instruments designated for cash flow hedge	22,000	22,000	65,000	68,000
Amortization of unrealized gains in respect of derivative instruments designated for cash flow hedge	(24,000)	(29,000)	(72,000)	(90,000)
Comprehensive income	15,741,000	69,336,000	66,448,000	95,025,000
Comprehensive income attributable to noncontrolling interest	(2,326,000)	(1,522,000)	(4,584,000)	(2,616,000)
Comprehensive income attributable to the Company's stockholders	$ 13,415,000	$ 67,814,000	$ 61,864,000	$ 92,409,000
Earnings per share attributable to the Company's stockholders:
Net income (in dollars per share)	$ 0.24	$ 1.47	$ 1.33	$ 2
Net income (in dollars per share)	$ 0.24	$ 1.41	$ 1.31	$ 1.93
Weighted average number of shares used in computation of earnings per share attributable to the Company's stockholders:
Basic (in shares)	49,599	49,023	49,410	48,388
Diluted (in shares)	50,289	51,113	50,097	50,011
Common Stock, Dividends, Per Share, Declared	$ 0.07	$ 0.06	$ 0.45	$ 0.20

Consolidated Statements of Equi

Consolidated Statements of Equity (Unaudited) - USD ($) $ 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		3,077			3,077		3,077
Exercise of options by employees and directors (in shares)	502
Exercise of options by employees and directors		4,612			4,612		4,612
Share exchange with Parent (in shares)	2,996
Share exchange with Parent	$ 3	26,012			26,015		26,015
Cash paid to non controlling interest						(4,507)	(4,507)
Cash dividend declared			(9,772)		(9,772)		(9,772)
Issuance of shares to noncontrolling interest, net of transaction costs		71,291			71,291	85,470	156,761
Net income			96,585		96,585	2,616	99,201
Loss in respect of derivative instruments designated for cash flow hedge				68	68		68
Change in unrealized gains or losses in respect of the Company's share in derivatives instruments of unconsolidated investment				(4,154)	(4,154)		(4,154)
Amortization of unrealized gains in respect of derivative instruments designated for cash flow hedge				(90)	(90)		(90)
Balance (in shares) at Sep. 30, 2015	49,035
Balance at Sep. 30, 2015	$ 49	846,998	128,352	(12,844)	962,555	95,402	1,057,957
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		3,383			3,383		3,383
Exercise of options by employees and directors (in shares)	528
Exercise of options by employees and directors	$ 1	7,249			7,250		7,250
Cash paid to non controlling interest						(10,622)	(10,622)
Cash dividend declared			(22,469)		(22,469)		(22,469)
Issuance of shares to noncontrolling interest, net of transaction costs						8,272	8,272
Net income			65,700		65,700	4,390	70,284
Loss in respect of derivative instruments designated for cash flow hedge				65	65		65
Change in unrealized gains or losses in respect of the Company's share in derivatives instruments of unconsolidated investment				(3,829)	(3,829)		(3,829)
Amortization of unrealized gains in respect of derivative instruments designated for cash flow hedge				(72)	(72)		(72)
Balance (in shares) at Sep. 30, 2016	49,635
Balance at Sep. 30, 2016	$ 50	$ 859,855	$ 191,627	$ (11,503)	$ 1,040,029	$ 95,913	$ 1,135,942

Consolidated Statements of Equ6

Consolidated Statements of Equity (Unaudited) (Parentheticals) - USD ($)	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Retained Earnings [Member]
Cash dividend declared, per share (in dollars per share)	$ 0.45	$ 0.02
Cash flow hedge, tax	$ 40,000	$ 42,000
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	$ 44,000	$ 56,000
Cash dividend declared, per share (in dollars per share)	$ 0.45	$ 0.20

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($)	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash flows from operating activities:
Net income	$ 70,284,000	$ 99,201,000
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	77,565,000	80,463,000
Amortization of premium from senior unsecured bonds	(513,000)	(230,000)
Accretion of asset retirement obligation	1,243,000	1,140,000
Stock-based compensation	3,383,000	3,077,000
Amortization of deferred lease income	(2,014,000)	(2,014,000)
Income attributable to sale of tax benefits, net of interest expense	(5,920,000)	(13,068,000)
Equity in losses of investees	4,735,000	4,893,000
Mark-to-market of derivative instruments	(381,000)	3,906,000
Loss on disposal of property, plant and equipment		531,000
Write-off of unsuccessful exploration activities	2,714,000	359,000
Gain on severance pay fund asset	(690,000)	(102,000)
Deferred income tax provision	20,742,000	(34,613,000)
Liability for unrecognized tax benefits	(125,000)	(399,000)
Deferred lease revenues	(625,000)	(221,000)
Other		484,000
Changes in operating assets and liabilities, net of amounts acquired:
Receivables	(13,711,000)	(2,879,000)
Costs and estimated earnings in excess of billings on uncompleted contracts	(12,905,000)	13,334,000
Inventories	5,339,000	335,000
Prepaid expenses and other	(5,364,000)	(3,033,000)
Deposits and other	(867,000)	(294,000)
Accounts payable and accrued expenses	10,463,000	(21,904,000)
Due from/to related entities, net		451,000
Billings in excess of costs and estimated earnings on uncompleted contracts	(3,242,000)	2,108,000
Liabilities for severance pay	(369,000)	(1,573,000)
Other long-term liabilities	1,801,000	(2,259,000)
Due from/to Parent		(513,000)
Net cash provided by operating activities	158,027,000	122,965,000
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	(1,022,000)	22,725,000
Capital expenditures	(107,951,000)	(117,588,000)
Cash paid for acquisition of controlling interest in a subsidiary, net of cash acquired	(18,135,000)
Decrease in severance pay fund asset, net of payments made to retired employees	1,919,000	2,934,000
Net cash used in investing activities	(125,189,000)	(76,538,000)
Cash flows from financing activities:
Proceeds from exercise of options by employees	7,250,000	4,612,000
Proceeds from issuance of senior unsecured notes, net of transaction costs	203,483,000
Purchase of Senior unsecured notes	(249,468,000)
Purchase of OFC Senior Secured Notes	(6,815,000)	(30,638,000)
Proceeds from sale of membership interests to uncontrolling interest, net of transaction costs		156,761,000
Proceeds from long-term loans, net at transaction costs		42,000,000
Proceeds from revolving credit lines with banks	259,900,000	598,800,000
Repayment of revolving credit lines with banks	(259,900,000)	(619,100,000)
Cash received from non-controlling interest	1,972,000	1,654,000
Repayments of long-term debt	(40,997,000)	(40,532,000)
Cash paid to noncontrolling interest	(17,296,000)	(13,863,000)
Payments of capital leases	(845,000)
Deferred debt issuance costs	(3,506,000)	(5,038,000)
Cash dividends paid	(22,469,000)	(9,772,000)
Net cash provided by (used in) financing activities	(128,691,000)	84,884,000
Net change in cash and cash equivalents	(95,853,000)	131,311,000
Cash and cash equivalents at beginning of period	185,919,000	40,230,000
Cash and cash equivalents at end of period	90,066,000	171,541,000
Supplemental non-cash investing and financing activities:
Increase (decrease) in accounts payable related to purchases of property, plant and equipment	(4,517,000)	18,930,000
Accrued liabilities related to financing activities	$ 6,291,000

Note 1 - General and Basis of P

Note 1 - General and Basis of Presentation	9 Months Ended
	Sep. 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 September 30, 2016, the consolidated results of operations and comprehensive income (loss) for the nine-month periods ended September 30, 2016 and 2015 and the consolidated cash flows for the nine-month periods ended September 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 nine-month period ended September 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. Issuance of Senior Unsecured Bonds On September 11, 2016, the Company concluded an auction tender and accepted subscriptions for $204 million aggregate principal amount of two tranches (approximately $67 million principal amount of Series 2 and approximately $137 million principal amount of Series 3) of senior unsecured bonds (Series 2 Bonds, Series 3 Bonds and, collectively, "Bonds"). The Bonds were issued in an unregistered offering outside the United States to investors who are not "U.S. persons",as such term is defined in Regulation S under the Securities Act of 1933, as amended (the "Securities Act"), and otherwise subject to the requirements of Regulation S. The "Series 2 Bonds" will mature in September 2020 and bear interest at a fixed rate of 3.7% per annum, payable semi-annually. The "Series 3 Bonds" will mature in September 2022 and bear interest at a fixed rate of 4.45% per annum, payable semi-annually. The Bonds will be repaid at maturity in a single bullet payment, unless earlier prepaid by Ormat pursuant to the terms and conditions of the trust instrument that governs the Bonds. Both tranches received a rating of ilA+ from Maloot S&P in Israel with a stable outlook. The Company used the proceeds from the offering and sale of the Bonds to fully prepay its existing senior unsecured bonds in the amount of $250 million. As a result of the prepayment, the Company recognized a loss in the amount of $5 million, including prepayment fees of approximately $5 million and amortization of premium of $0.3 million, which was included in other non-operating income (expense), net in the consolidated statements of operations and comprehensive income for the three and nine months ended September 30, 2016. 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 13 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. As part of the agreement, CDC will pay the Company a premium. Pursuant to the agreements, the Company paid approximately $20.6 million (of which approximately $2.0 million was paid in October 2016 as a subsequent adjustment to the purchase price) to Sageos for its approximately 60% interest in GB. In addition, the Company is committed to further invest $8.4 million (approximately €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 (approximately €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 15-year PPA that was entered into in February 2016 with Électricité de France S.A. (“EDF”), the French electric utility. The Company plans 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. The Company accounted for the transaction based on the provision of Accounting Standard Codification 805, Business Combinations, and consequently recorded intangible asset of $33.0 million pertaining to the 15-year PPA with EDF and $7.1 million of goodwill. Additionally, following the transaction, the Company gained control over GB effective July 5, 2016 and consolidated the entity with redeemable noncontrolling interest of $5.0 million and noncontrolling interest of $8.3 million being recorded. The redeemable noncontrolling interest pertains to Sageos right to sell its equity interest in GB to the Company for cash considerations. The noncontrolling interest pertains to CDC and was included under noncontrolling interest in the consolidated statements of equity. The revenues of GB of approximately $4.1 million were included in the Company’s consolidated statements of operations and comprehensive income for the three and nine months ended September 2016. 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 finalizing the documentation related to the sale of a minority interest in the second phase of the Don A. Campbell power plant. Upon Ormat Nevada's contribution of the project to ORPD, Northleaf will pay to Ormat Nevada an amount equal to Northleaf 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 fourth quarter of 2016. Deferred tax asset in Kenya On September 11, 2015, Kenya's Income Tax Act was amended pursuant to certain provisions of the recently adopted Finance Act, 2015. Among other matters, these amendments retain the enhanced investment deduction of 150% under Section 17B of the Income Tax Act, extend the period for deduction of tax losses from 5 years to 10 years under Sections 15(4) and 15(5) of the Income Tax Act, and amend the effective date from January 1, 2016 to January 1, 2015 under Sections 15(4) and 15(5) of the Income Tax Act. Previously, the Company had a valuation allowance for the additional 50% investment deduction reducing its deferred tax asset in Kenya as the utilization of the related tax losses was not probable within the original five year carryforward period. As a result of the change in legislation and the expected continued profitability during the extended carryforward period, the Company expects that it will be able to fully utilize the carryforward tax losses within the ten year period and as such released the valuation allowance in Kenya, resulting in $49.4 million of tax benefits in the three month period ended September 30, 2015. OFC Senior Secured Notes prepayment In September 2016, the Company repurchased $6.8 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 $0.6 million, including amortization of deferred financing costs, which was included in other non-operating income (expense), net in the consolidated statements of operations and comprehensive income for the three and nine months ended September 30, 2016. 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 nine months ended September 30, 2015. Other comprehensive income For the nine months ended September 30, 2016 and 2015, the Company classified $7,000 and $22,000, respectively, from accumulated other comprehensive income, of which $11,000 and $35,000, respectively, were recorded to reduce interest expense and $4,000 and $13,000, respectively, were recorded against the income tax provision, in the condensed consolidated statements of operations and comprehensive income. For the three months ended September 30, 2016 and 2015, the Company classified $2,000 and $7,000, respectively, related to derivative instruments designated as cash flow hedges, from accumulated other comprehensive income, of which $3,000 and $10,000, respectively, were recorded to reduce interest expense and $1,000 and $3,000, 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 September 30, 2016, is $582,000 Write-offs of unsuccessful exploration activities Write-offs of unsuccessful exploration activities for the nine and three months ended September 30, 2016, were $2.7 million and $1.3 million, respectively, and $0 million for the nine and three months ended September 30, 2015. These write-offs of exploration costs are related to the Company’s exploration activities in The United States 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 September 30, 2016 and December 31, 2015, the Company had deposits totaling $35.2 million and $19 million, respectively, in seven U.S. financial institutions that were federally insured up to $250,000 per account. At September 30, 2016 and December 31, 2015, the Company’s deposits in foreign countries amounted to approximately $72.4 million and $181.0 million, respectively. At September 30, 2016 and December 31, 2015, accounts receivable related to operations in foreign countries amounted to approximately $36.3 million and $27.8 million, respectively. At September 30, 2016 and December 31, 2015, accounts receivable from the Company’s primary customers amounted to approximately 60% and 66%, respectively, of the Company’s accounts receivable. Sierra Pacific Power Company and Nevada Power Company (subsidiaries of NV Energy, Inc.) accounted for 14.4% and 15.3% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 18.6% and 19.3% for the nine months ended September 30, 2016 and 2015, respectively. Kenya Power and Lighting Co. Ltd. accounted for 15.1% and 13.5% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 16.4% and 15.4% for the nine months ended September 30, 2016 and 2015, respectively. Southern California Public Power Authority accounted for 7.7% and 3.3% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 9.9% and 4.3% for the nine months ended September 30, 2016 and 2015, respectively. Hyundai (Sarulla geothermal power project) accounted for 24% and 22% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 14% and 16% for the nine months ended September 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	9 Months Ended
	Sep. 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 nine-month period ended September 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 82 0-10. 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 September 30, 2016 and December 31, 2015, totaled $2 .6 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 .9 million and $19.1 million as of September 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, 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	9 Months Ended
	Sep. 30, 2016
Notes to Financial Statements
Inventory Disclosure [Text Block]	NOTE 3 — INVENTORIES Inventories consist of the following: September 30, December 31, 2016 2015 (Dollars in thousands) Raw materials and purchased parts for assembly $ 2,915 $ 8,819 Self-manufactured assembly parts and finished products 10,058 9,255 Total $ 12,973 $ 18,074

Note 4 - Unconsolidated Investm

Note 4 - Unconsolidated Investments	9 Months Ended
	Sep. 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: September 30, December 31, 2016 2015 (Dollars in thousands) Sarulla $ (16,664 ) $ (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 is being 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 is currently in the commissioning and fine tuning stage but commercial operation date is expected to be delayed by few weeks. The delay is a result of local riots protesting the EPC contractor that caused a work stoppage. Work has resumed and we currently expect commercial operation of the first phase to begin in January 2017. For the second phase, engineering and procurement has been substantially completed, site construction is in progress and all of the equipment to be supplied by Ormat was delivered. For the third phase, engineering and procurement is still in progress, Construction work at the site is in progress and manufacturing of equipment to be supplied by Ormat is underway as planned. Drilling activities for the second and third phases are still ongoing and the project has achieved to date, based on preliminary estimates, approximately 80% of the required production capacity and approximately 80% of the required injection capacity. The project has missed a few milestones defined under the loan documents, but has received waivers from the lenders and commercial operation of the second and third phases is still expected to commence within 18 months after commercial operation of the first phase. As of September 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 nine months ended September 30, 2016, the project recorded a gain equal to $10.5 million and a loss of $30 million, respectively, net of deferred tax of $5.4 million and $15.4 million, respectively, of which the Company's share was $1.3 million and $3.8 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 September 30, 2016 is $10.9 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 over the course of the next two years. The Company has eliminated the related intercompany profit of $10.8 million against equity in loss of investees. During the nine months ended September 30, 2016, the Company did not make any additional cash equity investments in the Sarulla project.

Note 5 - Fair Value of Financia

Note 5 - Fair Value of Financial Instruments	9 Months Ended
	Sep. 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 September 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. September 30, 2016 Fair Value Carrying Value at September 30, 2016 Total Level 1 Level 2 Level 3 (Dollars in thousands) Assets: Current assets: Cash equivalents (including restricted cash accounts) $ 12,635 $ 12,635 $ 12,635 $ — $ — Derivatives: Currency forward contracts (2) 249 249 — 249 — Liabilities: Current liabilities: Derivatives: Call and put options on oil price (1) $ (1,776 ) $ (1,776 ) $ — $ (1,776 ) $ — Call option on natural gas price (1) (1,534 ) (1,534 ) — (1,534 ) — Currency forward contracts (2) (30 ) (30 ) — (30 ) — $ 9,544 $ 9,544 $ 12,635 $ (3,091 ) $ — 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 September 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 September 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) Three Months Ended September 30, Nine Months Ended September 30, Derivatives not designated as hedging instruments Location of recognized gain (loss) 2016 2015 2016 2015 Call options on natural gas price Derivatives and foreign currency transaction gains (losses) 32 — (1,114 ) — Call and put options on oil price Derivatives and foreign currency transaction gains (losses) 230 — (1,312 ) — Swap transactions on natural gas price Electricity revenue — 369 — 767 Currency forward contracts Derivatives and foreign currency and transaction gains (losses) 689 869 1,154 (1,349 ) $ 951 $ 1,238 $ (1,272 ) $ (582 ) 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 has written 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 gain from these transactions of $1.0 million and a net loss of $1.3 million in the three and nine months ended September 30, 2016, respectively, compared to a net gain of $0.9 million and a net loss of $1.3 million in the three and nine months ended September 30, 2015, under Derivatives and foreign currency transaction gains (losses), and a net gain of $0.4 million and a $0.8 million, in the three and nine months ended September 30, 2015, respectively, under Electricity revenues. There were no transfers of assets or liabilities between Level 1, Level 2 and Level 3 during the nine months ended September 30, 2016. The fair value of the Company’s long-term debt approximates its carrying amount, except for the following: Fair Value Carrying Amount September 30, 2016 December 31, 2015 September 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 257.3 262.6 251.1 264.6 Amatitlan Loan 38.5 41.7 37.6 40.3 Senior Secured Notes: Ormat Funding Corp. ("OFC") 19.6 30.0 19.7 30.0 OrCal Geothermal Inc. ("OrCal") 41.6 43.8 40.1 43.3 OFC 2 LLC ("OFC 2") 231.0 231.1 251.3 262.0 Senior Unsecured Bonds 201.0 264.5 204.3 250.0 Other long-term debt 7.2 — 8.7 — 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 September 30, 2016: Level 1 Level 2 Level 3 Total (Dollars in millions) Olkaria III - DEG $ — $ — $ 20.8 $ 20.8 Olkaria III - OPIC — — 257.3 257.3 Amatitlan loan — 38.5 — 38.5 Senior Secured Notes: OFC — 19.6 — 19.6 OrCal — — 41.6 41.6 OFC 2 — — 231.0 231.0 Senior unsecured bonds — — 201.0 201.0 Other long-term debt — — 7.2 7.2 Deposits 14.5 — — 14.5 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	9 Months Ended
	Sep. 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 aggregated 1,080,000 SAR 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	9 Months Ended
	Sep. 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Interest related to sale of tax benefits $ 2,565 $ 2,375 $ 6,269 $ 7,062 Interest expense 15,726 16,510 47,214 50,430 Less — amount capitalized (1,154 ) (1,137 ) (1,922 ) (3,057 ) $ 17,137 $ 17,748 $ 51,561 $ 54,435

Note 8 - Earnings Per Share

Note 8 - Earnings Per Share	9 Months Ended
	Sep. 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 September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Weighted average number of shares used in computation of basic earnings per share 49,599 49,023 49,410 48,388 Add: Additional shares from the assumed exercise of employee stock options 690 2,090 687 1,626 Weighted average number of shares used in computation of diluted earnings per share 50,289 51,113 50,097 50,014 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 225,191 and 341,946 for the three months ended September 30, 2016 and 2015, respectively, and 116,641 and 600,169 for the nine months ended September 30, 2016 and 2015, respectively.

Note 9 - Business Segments

Note 9 - Business Segments	9 Months Ended
	Sep. 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 September 30, 2016: Net revenue from external customers $ 109,795 $ 74,822 $ 184,617 Intersegment revenue — 14,835 14,835 Operating income 23,903 24,320 48,223 Segment assets at period end 2,137,845 141,426 2,279,271 Three Months Ended September 30, 2015: Net revenue from external customers $ 97,245 $ 65,607 $ 162,852 Intersegment revenue — 10,658 10,658 Operating income 28,346 18,133 46,479 Segment assets at period end 2,103,754 182,579 2,286,333 Nine Months Ended September 30, 2016: Net revenues from external customers $ 321,664 $ 174,408 $ 496,072 Intersegment revenues — 36,042 36,042 Operating income 91,502 59,151 150,653 Segment assets at period end 2,137,845 141,426 2,279,271 Nine Months Ended September 30, 2015: Net revenues from external customers $ 278,124 $ 145,446 $ 423,570 Intersegment revenues — 41,314 41,314 Operating income 73,220 41,753 114,973 Segment assets at period end 2,103,754 182,579 2,286,333 Reconciling information between reportable segments and the Company’s consolidated totals is shown in the following table: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Revenue: Total segment revenue $ 184,617 $ 162,852 $ 496,072 $ 423,570 Intersegment revenue 14,835 10,658 36,042 41,314 Elimination of intersegment revenue (14,835 ) (10,658 ) (36,042 ) (41,314 ) Total consolidated revenue $ 184,617 $ 162,852 $ 496,072 $ 423,570 Operating income: Operating income $ 48,223 $ 46,479 $ 150,653 $ 114,973 Interest income 266 53 831 106 Interest expense, net (17,137 ) (17,748 ) (51,561 ) (54,435 ) Derivatives and foreign currency transaction gains (losses) (222 ) 1,296 (2,592 ) (641 ) Income attributable to sale of tax benefits 3,463 8,634 12,380 18,917 Other non-operating income (expense), net (5,546 ) (131 ) (5,306 ) (1,523 ) Total consolidated income before income taxes and equity in income of investees $ 29,047 $ 38,583 $ 104,405 $ 77,397

Note 10 - Commitments and Conti

Note 10 - Commitments and Contingencies	9 Months Ended
	Sep. 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 October 10, 2016, the court issued its decision in response to each of the plaintiffs’ and defendants’ motions for summary judgment, denying plaintiffs’ motion and granting defendant PGV's and the County of Hawaii’s cross motions for summary judgment, effectively rendering the plaintiffs’ action moot. ● 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 plaintiffs’ 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. Both the remaining plaintiffs and the defendants have submitted cross motions for summary judgment. The motions have been briefed and are pending before the court. 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. On October 25, 2016, the parties entered into a final settlement agreement providing for the dismissal of the claim without any admission of wrongdoing by the Ormat Parties and payment of $11 million (inclusive of fees and costs). The settlement amount of $11 million was included in general and administrative expenses in the consolidated statements of operations and comprehensive income for the three and nine months ended September 30, 2016. ● On 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 $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. Pursuant to various petitions submitted by defendants, including a motion describing preliminary, procedural defenses, on August 18, 2016, and then on October 10, 2016, the 27th Civil Court issued a number of decisions, which include removal of the file to the 11th Civil Court of Santiago, thereby delaying a determination on the larger issues of jurisdiction and competency of the Chilean courts as a substantive (and not procedural) defense. The Company believes that it has valid defenses under law, and intends to defend itself vigorously. ● On August 5, 2016 George Douvris, Stephanie Douvris, Michael Hale, Cheryl Cacocci, Hillary E. Wilt and Christina Bryan, acting for themselves and on behalf of all other similarly situated residents of the lower Puna District, filed a complaint in the Third Circuit Court of the State of Hawaii’ seeking certification of a class action for preliminary and permanent injunctive relief, consequential and punitive damages, attorney’s fees and statutory interest against PGV and other presently unknown defendants, The complaint purports that injury and other damages in an undisclosed amount were caused to the plaintiffs as a result of an alleged toxic release by PGV in the wake of Hurricane Iselle in August 2014. On August 25, 2016, the Company filed to remove the case to the United States District Court for the District of Hawaii. On September 23, 2016, plaintiffs filed a motion for joinder of HELCO as an additional defendant, to amend the complaint, and to remand the case back to the Third Circuit Court. The plaintiffs’ motion will be heard before the federal court in mid-November, 2016. 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 Office of Energy’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 September 30, 2016. Following full briefing on both plaintiffs’ and defendants’ motions for summary judgment, on September 7, 2016, a hearing was held before 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 when he was employed by Martin Hydroblasting Services, Inc. and suffered injuries leading to his death while performing work at the Ormesa plant site on or around March 31, 2016. Subject to reservations, the insurer of the deceased’s employer has accepted the tender for both the costs of defense and the case outcome, and counsel has been appointed to represent Ormat. 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	9 Months Ended
	Sep. 30, 2016
Notes to Financial Statements
Income Tax Disclosure [Text Block]	NOTE 11 — INCOME TAXES The Company’s effective tax rate for the nine months ended September 30, 2016 and 2015 was 28.1% and 29.3%, respectively. The effective rate for the nine months ended September 30, 2015 excludes the income tax benefit of $49.4 million due to the release of the valuation allowance in Kenya. The effective tax rate differs from the federal statutory rate of 35% for the nine months ended September 30, 2016 due to: (i) a full valuation allowance against the Company’s U.S. deferred tax assets in respect of net operating loss ("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 September 30, 2016 and 2015 was $600,000 and $602,000, respectively, and for the nine months ended September 30, 2016 and 2015 was $2,398,000 and $2,628,000, 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 $281 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 $71.4 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 September 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.

Note 12 - Subsequent Events

Note 12 - Subsequent Events	9 Months Ended
	Sep. 30, 2016
Notes to Financial Statements
Subsequent Events [Text Block]	NOTE 12 — SUBSEQUENT EVENTS Cash dividend On November 7, 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 November 21, 2016, payable on December 6, 2016.

Significant Accounting Policies

Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 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 September 30, 2016, the consolidated results of operations and comprehensive income (loss) for the nine-month periods ended September 30, 2016 and 2015 and the consolidated cash flows for the nine-month periods ended September 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 nine-month period ended September 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.
Consolidation, Subsidiaries or Other Investments, Consolidated Entities, Policy [Policy Text Block]	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 $20.6 million (of which approximately $2.0 million were paid in October 2016 as a subsequent adjustment to the purchase price) to Sageos for its approximately 60% interest in GB. In addition, the Company is committed to further invest $8.4 million (approximately €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 (approximately $€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 plans 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. 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 finalizing the documentations related to the sale of minority interest in the second phase of the Don A. Campbell power plant. Upon Ormat Nevada's contribution of the project to ORPD, Northleaf’s will pay to Ormat Nevada an amount equal to Northleaf 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 fourth quarter of 2016.
Deferred Tax Asset [Policy Text Block]	Deferred tax asset in Kenya On September 11, 2015, Kenya's Income Tax Act was amended pursuant to certain provisions of the recently adopted Finance Act, 2015. Among other matters, these amendments retain the enhanced investment deduction of 150% under Section 17B of the Income Tax Act, extend the period for deduction of tax losses from 5 years to 10 years under Sections 15(4) and 15(5) of the Income Tax Act, and amend the effective date from January 1, 2016 to January 1, 2015 under Sections 15(4) and 15(5) of the Income Tax Act. Previously, the Company had a valuation allowance for the additional 50% investment deduction reducing its deferred tax asset in Kenya as the utilization of the related tax losses was not probable within the original five year carryforward period. As a result of the change in legislation and the expected continued profitability during the extended carryforward period, the Company expects that it will be able to fully utilize the carryforward tax losses within the ten year period and as such released the valuation allowance in Kenya resulting in a $49.4 million of tax benefits in the three month period ended September 30, 2015.
Receivables and Portions of Securitizations that can be Prepaid at Potential Loss, Policy [Policy Text Block]	OFC Senior Secured Notes prepayment In September 2016, the Company repurchased $6.8 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 $0.6 million, including amortization of deferred financing costs, which was included in other non-operating income (expense), net in the consolidated statements of operations and comprehensive income for the three and nine months ended September 30, 2016. 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 nine months ended September 30, 2015.
Comprehensive Income, Policy [Policy Text Block]	Other comprehensive income For the nine months ended September 30, 2016 and 2015, the Company classified $7,000 and $22,000, respectively, from accumulated other comprehensive income, of which $11,000 and $35,000, respectively, were recorded to reduce interest expense and $4,000 and $13,000, respectively, were recorded against the income tax provision, in the condensed consolidated statements of operations and comprehensive income. For the three months ended September 30, 2016 and 2015, the Company classified $2,000 and $7,000, respectively, related to derivative instruments designated as cash flow hedges, from accumulated other comprehensive income, of which $3,000 and $10,000, respectively, were recorded to reduce interest expense and $1,000 and $3,000, 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 September 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 nine and three months ended September 30, 2016, were $1.3 million and $2.7 million, respectively, and $0 million for the nine and three months ended September 30, 2015. These write-offs of exploration costs are related to the Company’s exploration activities in The United States 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 September 30, 2016 and December 31, 2015, the Company had deposits totaling $35.2 million and $19 million, respectively, in seven U.S. financial institutions that were federally insured up to $250,000 per account. At September 30, 2016 and December 31, 2015, the Company’s deposits in foreign countries amounted to approximately $72.4 million and $181.0 million, respectively. At September 30, 2016 and December 31, 2015, accounts receivable related to operations in foreign countries amounted to approximately $36.3 million and $27.8 million, respectively. At September 30, 2016 and December 31, 2015, accounts receivable from the Company’s primary customers amounted to approximately 60% and 66%, respectively, of the Company’s accounts receivable. Sierra Pacific Power Company and Nevada Power Company (subsidiaries of NV Energy, Inc.) accounted for 14.4% and 15.3% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 18.6% and 19.3% for the nine months ended September 30, 2016 and 2015, respectively. Kenya Power and Lighting Co. Ltd. accounted for 15.1% and 13.5% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 16.4% and 15.4% for the nine months ended September 30, 2016 and 2015, respectively. Southern California Public Power Authority accounted for 7.7% and 3.3% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 9.9% and 4.3% for the nine months ended September 30, 2016 and 2015, respectively. Hyundai (Sarulla geothermal power project) accounted for 24% and 22% of the Company’s total revenues for the three months ended September 30, 2016 and 2015, respectively, and 14% and 16% for the nine months ended September 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)	9 Months Ended
	Sep. 30, 2016
Notes Tables
Schedule of Inventory, Current [Table Text Block]	September 30, December 31, 2016 2015 (Dollars in thousands) Raw materials and purchased parts for assembly $ 2,915 $ 8,819 Self-manufactured assembly parts and finished products 10,058 9,255 Total $ 12,973 $ 18,074

Note 4 - Unconsolidated Inves22

Note 4 - Unconsolidated Investments (Tables)	9 Months Ended
	Sep. 30, 2016
Notes Tables
Equity Method Investments [Table Text Block]	September 30, December 31, 2016 2015 (Dollars in thousands) Sarulla $ (16,664 ) $ (8,100 )

Note 5 - Fair Value of Financ23

Note 5 - Fair Value of Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
Notes Tables
Fair Value, by Balance Sheet Grouping [Table Text Block]	September 30, 2016 Fair Value Carrying Value at September 30, 2016 Total Level 1 Level 2 Level 3 (Dollars in thousands) Assets: Current assets: Cash equivalents (including restricted cash accounts) $ 12,635 $ 12,635 $ 12,635 $ — $ — Derivatives: Currency forward contracts (2) 249 249 — 249 — Liabilities: Current liabilities: Derivatives: Call and put options on oil price (1) $ (1,776 ) $ (1,776 ) $ — $ (1,776 ) $ — Call option on natural gas price (1) (1,534 ) (1,534 ) — (1,534 ) — Currency forward contracts (2) (30 ) (30 ) — (30 ) — $ 9,544 $ 9,544 $ 12,635 $ (3,091 ) $ — 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) Three Months Ended September 30, Nine Months Ended September 30, Derivatives not designated as hedging instruments Location of recognized gain (loss) 2016 2015 2016 2015 Call options on natural gas price Derivatives and foreign currency transaction gains (losses) 32 — (1,114 ) — Call and put options on oil price Derivatives and foreign currency transaction gains (losses) 230 — (1,312 ) — Swap transactions on natural gas price Electricity revenue — 369 — 767 Currency forward contracts Derivatives and foreign currency and transaction gains (losses) 689 869 1,154 (1,349 ) $ 951 $ 1,238 $ (1,272 ) $ (582 )
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments [Table Text Block]	Fair Value Carrying Amount September 30, 2016 December 31, 2015 September 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 257.3 262.6 251.1 264.6 Amatitlan Loan 38.5 41.7 37.6 40.3 Senior Secured Notes: Ormat Funding Corp. ("OFC") 19.6 30.0 19.7 30.0 OrCal Geothermal Inc. ("OrCal") 41.6 43.8 40.1 43.3 OFC 2 LLC ("OFC 2") 231.0 231.1 251.3 262.0 Senior Unsecured Bonds 201.0 264.5 204.3 250.0 Other long-term debt 7.2 — 8.7 —
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 — — 257.3 257.3 Amatitlan loan — 38.5 — 38.5 Senior Secured Notes: OFC — 19.6 — 19.6 OrCal — — 41.6 41.6 OFC 2 — — 231.0 231.0 Senior unsecured bonds — — 201.0 201.0 Other long-term debt — — 7.2 7.2 Deposits 14.5 — — 14.5 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)	9 Months Ended
	Sep. 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)	9 Months Ended
	Sep. 30, 2016
Notes Tables
Schedule of Other Nonoperating Expense, by Component [Table Text Block]	Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Interest related to sale of tax benefits $ 2,565 $ 2,375 $ 6,269 $ 7,062 Interest expense 15,726 16,510 47,214 50,430 Less — amount capitalized (1,154 ) (1,137 ) (1,922 ) (3,057 ) $ 17,137 $ 17,748 $ 51,561 $ 54,435

Note 8 - Earnings Per Share (Ta

Note 8 - Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2016
Notes Tables
Schedule of Weighted Average Number of Shares [Table Text Block]	Three Months Ended September 30, Nine Months Ended September 30, 2016 2015 2016 2015 Weighted average number of shares used in computation of basic earnings per share 49,599 49,023 49,410 48,388 Add: Additional shares from the assumed exercise of employee stock options 690 2,090 687 1,626 Weighted average number of shares used in computation of diluted earnings per share 50,289 51,113 50,097 50,014

Note 9 - Business Segments (Tab

Note 9 - Business Segments (Tables)	9 Months Ended
	Sep. 30, 2016
Notes Tables
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Electricity Product Consolidated (Dollars in thousands) Three Months Ended September 30, 2016: Net revenue from external customers $ 109,795 $ 74,822 $ 184,617 Intersegment revenue — 14,835 14,835 Operating income 23,903 24,320 48,223 Segment assets at period end 2,137,845 141,426 2,279,271 Three Months Ended September 30, 2015: Net revenue from external customers $ 97,245 $ 65,607 $ 162,852 Intersegment revenue — 10,658 10,658 Operating income 28,346 18,133 46,479 Segment assets at period end 2,103,754 182,579 2,286,333 Nine Months Ended September 30, 2016: Net revenues from external customers $ 321,664 $ 174,408 $ 496,072 Intersegment revenues — 36,042 36,042 Operating income 91,502 59,151 150,653 Segment assets at period end 2,137,845 141,426 2,279,271 Nine Months Ended September 30, 2015: Net revenues from external customers $ 278,124 $ 145,446 $ 423,570 Intersegment revenues — 41,314 41,314 Operating income 73,220 41,753 114,973 Segment assets at period end 2,103,754 182,579 2,286,333
Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block]	Three Months Ended Nine Months Ended 2016 2015 2016 2015 Revenue: Total segment revenue $ 184,617 $ 162,852 $ 496,072 $ 423,570 Intersegment revenue 14,835 10,658 36,042 41,314 Elimination of intersegment revenue (14,835 ) (10,658 ) (36,042 ) (41,314 ) Total consolidated revenue $ 184,617 $ 162,852 $ 496,072 $ 423,570 Operating income: Operating income $ 48,223 $ 46,479 $ 150,653 $ 114,973 Interest income 266 53 831 106 Interest expense, net (17,137 ) (17,748 ) (51,561 ) (54,435 ) Derivatives and foreign currency transaction gains (losses) (222 ) 1,296 (2,592 ) (641 ) Income attributable to sale of tax benefits 3,463 8,634 12,380 18,917 Other non-operating income (expense), net (5,546 ) (131 ) (5,306 ) (1,523 ) Total consolidated income before income taxes and equity in income of investees $ 29,047 $ 38,583 $ 104,405 $ 77,397

Note 1 - General and Basis of28

Note 1 - General and Basis of Presentation (Details Textual) € in Millions	Sep. 11, 2016USD ($)	Mar. 30, 2016	Oct. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jul. 31, 2016USD ($)MWh	Jul. 31, 2016EUR (€)MWh	Jun. 30, 2015USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)	Apr. 30, 2015	Dec. 31, 2014USD ($)
Senior Unsecured Bonds [Member] | Series 2 Bonds [Member]
Proceeds from Issuance of Unsecured Debt	$ 67,000,000
Debt Instrument, Interest Rate, Stated Percentage	3.70%
Senior Unsecured Bonds [Member] | Series 3 Bonds [Member]
Proceeds from Issuance of Unsecured Debt	$ 137,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.45%
Senior Unsecured Bonds [Member] | Nonoperating Income (Expense) [Member]
Amortization of Debt Discount (Premium)									$ 300,000		$ 300,000
Senior Unsecured Bonds [Member]
Proceeds from Issuance of Unsecured Debt	$ 204,000,000								250,000,000
Loss on Debt Prepayment									5,000,000
Prepayment Penalty Charges									5,000,000
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
Nonoperating Income (Expense) [Member]
Gain (Loss) on Repurchase of Debt Instrument				$ 600,000
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%
Geothermie Bouillante SA (“GB”) [Member] | Ormat Systems Ltd [Member]
Business Combination, Co-acquisition, Percentage of Ownership Interest Allocated					75.00%
Geothermie Bouillante SA (“GB”) [Member] | Caisse des Depots et Consignations (CDC) [Member]
Business Combination, Co-acquisition, Percentage of Ownership Interest Allocated					25.00%
Geothermie Bouillante SA (“GB”) [Member] | Subsequent Event [Member]
Payments to Acquire Businesses, Net of Cash Acquired			$ 2,000,000
Geothermie Bouillante SA (“GB”) [Member] | After Further Invest in Two Years [Member]
Business Combination, Expected Ownership Interest					63.75%
Payments to Acquire Additional Interest in Subsidiaries					$ 8,400,000	€ 7.5
Geothermie Bouillante SA (“GB”) [Member] | Service Agreements [Member]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles					$ 33,000,000
Geothermie Bouillante SA (“GB”) [Member]
Expected Power Generating Capacity | MWh					14.75	14.75
Power Utilization | MWh					13	13
Number of Exploration Licenses Owned					2
Business Acquisition, Expansion Capacity | MWh					45
Business Acquisition, Percentage of Voting Interests Acquired					60.00%
Business Combination, Expected Ownership Interest					85.00%
Payments to Acquire Businesses, Net of Cash Acquired									20,600,000
Payments to Acquire Businesses, Additional Amount Subject to Achievement of Agreed upon Production Thresholds					$ 13,400,000	€ 12
Power Purchase Agreements Term					15 years	15 years
Goodwill					$ 7,100,000
Redeemable Noncontrolling Interest, Equity, Carrying Amount				5,000,000					5,000,000		5,000,000
Stockholders' Equity Attributable to Noncontrolling Interest				8,300,000					8,300,000		8,300,000
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual									4,100,000		4.10
Scenario, Forecast [Member] | Second Phase of Don Campbell [Member]
Proceeds from Divestiture of Businesses								$ 43,000,000
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
Foreign Tax Authority [Member] | KENYA | Minimum [Member]
Extended Period for Deduction of Tax Losses, Term										5 years
Foreign Tax Authority [Member] | KENYA | Maximum [Member]
Extended Period for Deduction of Tax Losses, Term										10 years
Foreign Tax Authority [Member] | KENYA
Investment Deduction Percentage										150.00%
KENYA
Investment Deduction Percentage										50.00%
Deferred Foreign Income Tax Expense (Benefit)										$ 49,400,000
UNITED STATES
Cash, Cash Equivalents, and Short-term Investments				35,200,000					35,200,000		35,200,000		$ 19,000,000
Foreign Countries [Member]
Cash, Cash Equivalents, and Short-term Investments				72,400,000					72,400,000		72,400,000		181,000,000
Accounts Receivable, Net, Current				36,300,000					36,300,000		36,300,000		27,800,000
Maximum [Member]
Cash, FDIC Insured Amount				250,000,000					250,000,000		250,000,000		$ 250,000
Reclassification out of Accumulated Other Comprehensive Income [Member]
Net Income (Loss) Attributable to Parent									2,000	7,000	7,000	$ 22,000
Interest Expense									3,000	10,000	11,000	35,000
Income Tax Expense (Benefit)									1,000	$ 3,000	4,000	$ 13,000
Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax				$ 582,000					$ 582,000		$ 582,000
Accounts Receivable [Member] | Customer Concentration Risk [Member] | Primary Customers [Member]
Concentration Risk, Percentage											60.00%		66.00%
Sales Revenue, Net [Member] | Customer Concentration Risk [Member] | Sierra Pacific Power Company And Nevada Power Company [Member]
Concentration Risk, Percentage									14.40%	15.30%	18.60%	19.30%
Sales Revenue, Net [Member] | Customer Concentration Risk [Member] | Kenya Power And Lighting Co LTD [Member]
Concentration Risk, Percentage									15.10%	13.50%	16.40%	15.40%
Sales Revenue, Net [Member] | Customer Concentration Risk [Member] | Southern California Public Power Authority [Member]
Concentration Risk, Percentage									7.70%	3.30%	9.90%	4.30%
Sales Revenue, Net [Member] | Customer Concentration Risk [Member] | Hyundai (Sarulla Goethermal Power Project) [Member]
Concentration Risk, Percentage									24.00%	22.00%	14.00%	16.00%
Proceeds from Issuance of Unsecured Debt											$ 203,483,000
Debt Instrument, Interest Rate, Stated Percentage				7.00%					7.00%		7.00%		7.00%
Amortization of Debt Discount (Premium)											$ (513,000)	(230,000)
Payments to Acquire Businesses, Net of Cash Acquired											18,135,000
Goodwill				$ 7,071,000					$ 7,071,000		7,071,000
Redeemable Noncontrolling Interest, Equity, Carrying Amount				4,972,000					4,972,000		4,972,000
Stockholders' Equity Attributable to Noncontrolling Interest				95,913,000					95,913,000		95,913,000		93,873,000
Debt Instrument, Repurchased Face Amount				6,800,000					6,800,000		6,800,000
Repayments of Secured Debt											6,815,000	30,638,000
Net Income (Loss) Attributable to Parent									12,080,000	$ 72,139,000	65,700,000	96,585,000
Interest Expense									17,137,000	17,748,000	51,561,000	54,435,000
Income Tax Expense (Benefit)									11,988,000	(38,211,000)	29,387,000	(26,696,000)
Accumulated Other Comprehensive Income (Loss), Net of Tax				(11,503,000)					(11,503,000)		(11,503,000)		(7,667,000)
Exploration Abandonment and Impairment Expense									1,294,000	185,000	2,714,000	359,000
Cash, Cash Equivalents, and Short-term Investments				90,066,000					90,066,000	$ 171,541,000	90,066,000	$ 171,541,000	185,919,000		$ 40,230,000
Accounts Receivable, Net, Current				$ 65,198,000					$ 65,198,000		65,198,000		$ 55,301,000
Provision for Doubtful Accounts											$ 0

Note 2 - New Accounting Prono29

Note 2 - New Accounting Pronouncements (Details Textual) - USD ($) $ in Millions	9 Months Ended
	Sep. 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	17.9
Debt Issuance Costs, Line of Credit Arrangements, Net	$ 2.6	$ 1

Note 3 - Inventories - Inventor

Note 3 - Inventories - Inventories, Current (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Raw materials and purchased parts for assembly	$ 2,915	$ 8,819
Self-manufactured assembly parts and finished products	10,058	9,255
Total	$ 12,973	$ 18,074

Note 4 - Unconsolidated Inves31

Note 4 - Unconsolidated Investments (Details Textual)	Jun. 04, 2014USD ($)	May 23, 2014USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)MWh	Sep. 30, 2015USD ($)	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			$ 10,500,000		$ (30,000,000)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax			5,400,000		15,400,000
Sarulla [Member] | Interest Rate Swap [Member]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax			1,300,000		3,800,000
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax			$ 10,900,000		10,900,000
Sarulla [Member]
Payments to Acquire Projects					$ 0
Jointly Owned Utility Plant, Proportionate Ownership Share			12.75%		12.75%
Expected Power Generating Capacity | MWh					330
Power Plant Usage Agreement Term					30 years
Number Of Phases Of Construction					3
Power Utilization | MWh					110
Percentage of Required Production Capacity			80.00%		80.00%
Percentage of Required Injection Capacity			80.00%		80.00%
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					10,800,000
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax			1,337,000	$ (4,318,000)	(3,829,000)	$ (4,154,000)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest			$ 14,406,000	$ 73,661,000	$ 70,284,000	$ 99,201,000

Note 4 - Unconsolidated Inves32

Note 4 - Unconsolidated Investments - Unconsolidated Investments Mainly in Power Plants (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Sarulla [Member]
Sarulla	$ (16,664)	$ (8,100)

Note 5 - Fair Value of Financ33

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

Feb. 24, 2016BoeBTU$ / item

Mar. 14, 2015$ / BTU

Mar. 06, 2014BTU$ / BTU

Mar. 31, 2016Boe$ / item

Sep. 30, 2016USD ($)

Sep. 30, 2015USD ($)

Mar. 31, 2015BTU

Sep. 30, 2016USD ($)

Sep. 30, 2016USD ($)

Sep. 30, 2016USD ($)

Sep. 30, 2015USD ($)

Feb. 28, 2016$ / item

NGI Swap Contract [Member]

Derivative, Nonmonetary Notional Amount, Energy Measure | BTU

2.2

2.4

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

4.1

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 | $

$ (0.9)

$ (1.3)

Electricity Revenues [Member]

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

$ 0.4

$ 0.8

Derivative, Number of Options Rolled

2

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

$ (1)

$ (1.3)

Note 5 - Fair Value of Financ34

Note 5 - Fair Value of Financial Instruments - Financial Assets and Liabilities at Fair Value (Details) - USD ($) $ in Thousands		Sep. 30, 2016		Dec. 31, 2015
Reported Value Measurement [Member] | Forward Contracts [Member]
Assets:
Derivative assets		$ 249	[1]	$ 7
Derivative liabilities		(30)		(169)
Liabilities:
Derivative liabilities		30		169
Derivative liabilities		(30)		(169)
Reported Value Measurement [Member] | Call and Put Options on Oil Price [Member]
Assets:
Derivative liabilities	[1]	1,776
Liabilities:
Derivative liabilities	[1]	(1,776)
Derivative liabilities	[1]	1,776
Reported Value Measurement [Member] | Call Option on Natural Gas Price [Member]
Assets:
Derivative liabilities		1,534
Liabilities:
Derivative liabilities		(1,534)
Derivative liabilities		1,534
Reported Value Measurement [Member]
Assets:
Cash equivalents (including restricted cash accounts)		12,635		31,428
		9,544		31,266
Liabilities:
		9,544		31,266
Fair Value, Inputs, Level 1 [Member] | Forward Contracts [Member]
Assets:
Derivative assets			[1]
Derivative liabilities			[1]
Liabilities:
Derivative liabilities			[1]
Derivative liabilities			[1]
Fair Value, Inputs, Level 1 [Member] | Call and Put Options on Oil Price [Member]
Assets:
Derivative liabilities	[2]
Liabilities:
Derivative liabilities	[2]
Derivative liabilities	[2]
Fair Value, Inputs, Level 1 [Member] | Call Option on Natural Gas Price [Member]
Assets:
Derivative liabilities	[2]
Liabilities:
Derivative liabilities	[2]
Derivative liabilities	[2]
Fair Value, Inputs, Level 1 [Member]
Assets:
Cash equivalents (including restricted cash accounts)		12,635		31,428
		12,635		31,428
Liabilities:
		12,635		31,428
Fair Value, Inputs, Level 2 [Member] | Forward Contracts [Member]
Assets:
Derivative assets		249	[1]	7
Derivative liabilities		(30)	[1]	(169)
Liabilities:
Derivative liabilities		30	[1]	169
Derivative liabilities		(30)	[1]	(169)
Fair Value, Inputs, Level 2 [Member] | Call and Put Options on Oil Price [Member]
Assets:
Derivative liabilities	[2]	1,776
Liabilities:
Derivative liabilities	[2]	(1,776)
Derivative liabilities	[2]	1,776
Fair Value, Inputs, Level 2 [Member] | Call Option on Natural Gas Price [Member]
Assets:
Derivative liabilities	[2]	1,534
Liabilities:
Derivative liabilities	[2]	(1,534)
Derivative liabilities	[2]	1,534
Fair Value, Inputs, Level 2 [Member]
Assets:
Cash equivalents (including restricted cash accounts)
		(3,091)		(162)
Liabilities:
		(3,091)		(162)
Fair Value, Inputs, Level 3 [Member] | Forward Contracts [Member]
Assets:
Derivative assets			[1]
Derivative liabilities			[1]
Liabilities:
Derivative liabilities			[1]
Derivative liabilities			[1]
Fair Value, Inputs, Level 3 [Member] | Call and Put Options on Oil Price [Member]
Assets:
Derivative liabilities	[2]
Liabilities:
Derivative liabilities	[2]
Derivative liabilities	[2]
Fair Value, Inputs, Level 3 [Member] | Call Option on Natural Gas Price [Member]
Assets:
Derivative liabilities	[2]
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		249	[1]	7
Derivative liabilities		(30)	[1]	(169)
Liabilities:
Derivative liabilities		30	[1]	169
Derivative liabilities		(30)	[1]	(169)
Call and Put Options on Oil Price [Member]
Assets:
Derivative liabilities	[2]	1,776
Liabilities:
Derivative liabilities	[2]	(1,776)
Derivative liabilities	[2]	1,776
Call Option on Natural Gas Price [Member]
Assets:
Derivative liabilities	[2]	1,534
Liabilities:
Derivative liabilities	[2]	(1,534)
Derivative liabilities	[2]	1,534
Cash equivalents (including restricted cash accounts)		90,066		185,919
Cash equivalents (including restricted cash accounts)		12,635		31,428
		9,544		31,266
		$ 9,544		$ 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 September 30, 2016 and December 31, 2015, in the consolidated balance sheet with the corresponding gain or loss being recognized within "Derivatives and foreign 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 September 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.

Note 5 - Fair Value of Financ35

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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Foreign Currency Gain (Loss) [Member] | Call Option on Natural Gas Price [Member]
Amount of gain (loss) recognized	$ 32		$ (1,114)
Foreign Currency Gain (Loss) [Member] | Call and Put Options on Oil Price [Member]
Amount of gain (loss) recognized	230		(1,312)
Foreign Currency Gain (Loss) [Member] | Natural Gas Price Swap [Member]
Amount of gain (loss) recognized		369		767
Electricity Revenues [Member] | Currency Forward Contracts [Member]
Amount of gain (loss) recognized	689	869	1,154	(1,349)
Amount of gain (loss) recognized	$ 951	$ 1,238	$ (1,272)	$ (582)

Note 5 - Fair Value of Financ36

Note 5 - Fair Value of Financial Instruments - Fair Value of Long-term Debt Approximates its Carrying Amount, Exceptions (Details) - USD ($) $ in Millions	Sep. 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 DEG [Member]
Other long-term debt	20.8	24.2
Olkaria III OPIC [Member] | Estimate of Fair Value Measurement [Member]
Loans	257.3	262.6
Olkaria III OPIC [Member] | Reported Value Measurement [Member]
Loans	251.1	264.6
Olkaria III OPIC [Member]
Other long-term debt	257.3	262.6
Amatitlan Loan [Member] | Estimate of Fair Value Measurement [Member]
Loans	38.5	41.7
Amatitlan Loan [Member] | Reported Value Measurement [Member]
Loans	37.6	40.3
Amatitlan Loan [Member]
Other long-term debt	38.5
Ormat Funding Corp [Member] | Estimate of Fair Value Measurement [Member]
Notes	19.6	30
Ormat Funding Corp [Member] | Reported Value Measurement [Member]
Notes	19.7	30
Ormat Funding Corp [Member]
Other long-term debt	19.6	30
Orcal Geothermal Inc [Member] | Estimate of Fair Value Measurement [Member]
Notes	41.6	43.8
Orcal Geothermal Inc [Member] | Reported Value Measurement [Member]
Notes	40.1	43.3
Orcal Geothermal Inc [Member]
Other long-term debt	41.6	43.8
Ofc Two Senior Secured Notes [Member] | Estimate of Fair Value Measurement [Member]
Notes	231	231.1
Ofc Two Senior Secured Notes [Member] | Reported Value Measurement [Member]
Notes	251.3	262
Ofc Two Senior Secured Notes [Member]
Other long-term debt	231	231.1
Senior Unsecured Bonds [Member] | Estimate of Fair Value Measurement [Member]
Senior Unsecured Bonds	201	264.5
Senior Unsecured Bonds [Member] | Reported Value Measurement [Member]
Senior Unsecured Bonds	204.3	250
Senior Unsecured Bonds [Member]
Other long-term debt	201	264.5
Other Long-term Debt [Member] | Estimate of Fair Value Measurement [Member]
Other long-term debt	7.2
Other Long-term Debt [Member] | Reported Value Measurement [Member]
Other long-term debt	8.7
Other Long-term Debt [Member]
Other long-term debt	$ 7.2	$ 6.7

Note 5 - Fair Value of Financ37

Note 5 - Fair Value of Financial Instruments - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Sep. 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	257.3	262.6
Olkaria III OPIC [Member]
Fair value levels-secured, unsecured and long term debt	257.3	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	38.5
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	38.5
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	19.6	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	19.6	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	41.6	43.8
Orcal Geothermal Inc [Member]
Fair value levels-secured, unsecured and long term debt	41.6	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	231	231.1
Ofc Two Senior Secured Notes [Member]
Fair value levels-secured, unsecured and long term debt	231	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	201	264.5
Senior Unsecured Bonds [Member]
Fair value levels-secured, unsecured and long term debt	201	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		6.7
Other Long-term Debt [Member] | Fair Value, Inputs, Level 3 [Member]
Fair value levels-secured, unsecured and long term debt	7.2
Other Long-term Debt [Member]
Fair value levels-secured, unsecured and long term debt	7.2	6.7
Fair Value, Inputs, Level 1 [Member]
Deposits	14.5	15.9
Fair Value, Inputs, Level 2 [Member]
Deposits
Fair Value, Inputs, Level 3 [Member]
Deposits
Deposits	$ 14.5	$ 15.9

Note 6 - Stock-based Compensa38

Note 6 - Stock-based Compensation (Details Textual) - $ / shares	Jun. 13, 2016	May 31, 2012	Dec. 31, 2004	Sep. 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 Compensa39

Note 6 - Stock-based Compensation - Fair Value of Stock-based Award on the Date of Grant (Details) - Stock Appreciation Rights (SARs) [Member]	9 Months Ended
	Sep. 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, Ne40

Note 7 - Interest Expense, Net - Components of Interest Expense (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Interest related to sale of tax benefits	$ 2,565	$ 2,375	$ 6,269	$ 7,062
Interest expense	15,726	16,510	47,214	50,430
Less — amount capitalized	(1,154)	(1,137)	(1,922)	(3,057)
Interest Expense	$ 17,137	$ 17,748	$ 51,561	$ 54,435

Note 8 - Earnings Per Share (De

Note 8 - Earnings Per Share (Details Textual) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	225,191	341,946	116,641	600,169

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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Basic (in shares)	49,599	49,023	49,410	48,388
Add:
Additional shares from the assumed exercise of employee stock options (in shares)	690	2,090	687	1,626
Weighted average number of shares used in computation of diluted earnings per share (in shares)	50,289	51,113	50,097	50,011

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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Electricity [Member]
Net revenue from external customers	$ 109,795	$ 97,245	$ 321,664	$ 278,124
Intersegment revenue
Operating income	23,903	28,346	91,502	73,220
Segment assets at period end	2,137,845	2,103,754	2,137,845	2,103,754
Product Segment [Member]
Net revenue from external customers	74,822	65,607	174,408	145,446
Intersegment revenue	14,835	10,658	36,042	41,314
Operating income	24,320	18,133	59,151	41,753
Segment assets at period end	141,426	182,579	141,426	182,579
Net revenue from external customers	184,617	162,852	496,072	423,570
Intersegment revenue	14,835	10,658	36,042	41,314
Operating income	48,223	46,479	150,653	114,973
Segment assets at period end	$ 2,279,271	$ 2,286,333	$ 2,279,271	$ 2,286,333	$ 2,273,982

Note 9 - Business Segments - Re

Note 9 - Business Segments - Reconciling Information Between Reportable Segments and Consolidated Totals (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Operating Segments [Member]
Revenues:
Net revenue from external customers	$ 184,617	$ 162,852	$ 496,072	$ 423,570
Intersegment Eliminations [Member]
Revenues:
Net revenue from external customers	14,835	10,658	36,042	41,314
Consolidation, Eliminations [Member]
Revenues:
Net revenue from external customers	(14,835)	(10,658)	(36,042)	(41,314)
Net revenue from external customers	184,617	162,852	496,072	423,570
Operating income:
Operating income	48,223	46,479	150,653	114,973
Interest income	266	53	831	106
Interest expense, net	(17,137)	(17,748)	(51,561)	(54,435)
Derivatives and foreign currency transaction gains (losses)	(222)	1,296	(2,592)	(641)
Income attributable to sale of tax benefits	3,463	8,634	12,380	18,917
Other non-operating income (expense), net	(5,546)	(131)	(5,306)	(1,523)
Total consolidated income before income taxes and equity in income of investees	$ 29,047	$ 38,583	$ 104,405	$ 77,397

Note 10 - Commitments and Con46

Note 10 - Commitments and Contingencies (Details Textual) - USD ($) $ in Millions	Oct. 26, 2016	Mar. 29, 2016	May 21, 2014	Jan. 31, 2014	Sep. 30, 2016	Sep. 30, 2016
Two Former Employees Vs. Ormat [Member] | Settled Litigation [Member] | General and Administrative Expense [Member]
Litigation Settlement, Amount					$ (11)	$ (11)
Two Former Employees Vs. Ormat [Member] | Settled Litigation [Member]
Payments for Legal Settlements	$ 11
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		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
General Business Tax Credit Carryforward [Member] | Maximum [Member]
Tax Credit Carryforward Expiration Year					2,036
General Business Tax Credit Carryforward [Member] | Minimum [Member]
Tax Credit Carryforward Expiration Year					2,026
General Business Tax Credit Carryforward [Member]
Tax Credit Carryforward Expiration Period					20 years
ISRAEL
National Corporate Tax Rate			16.00%
KENYA
National Corporate Tax Rate			37.50%
Domestic Tax Authority [Member]
Operating Loss Carryforwards					$ 281,000,000
State and Local Jurisdiction [Member]
Operating Loss Carryforwards					191,000,000
Effective Income Tax Rate Reconciliation, Percent			28.10%	29.30%
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount				$ (49,400,000)
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent			35.00%
Effective Income Tax Rate Reconciliation, Tax Exempt Income, Amount	$ 600,000	$ 602,000	$ 2,398,000	$ 2,628,000
Deferred Tax Assets, Tax Credit Carryforwards, General Business					71,400,000
Undistributed Earnings of Foreign Subsidiaries					$ 233,800,000

Note 12 - Subsequent Events (De

Note 12 - Subsequent Events (Details Textual) - USD ($) $ / shares in Units, $ in Thousands	Nov. 07, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Subsequent Event [Member]
Dividends, Common Stock	$ 3,500
Common Stock, Dividends, Per Share, Declared	$ 0.07
Dividends, Common Stock				$ 22,469	$ 9,772
Common Stock, Dividends, Per Share, Declared		$ 0.07	$ 0.06	$ 0.45	$ 0.20