8point3 Energy Partners (CAFD) 10-Q 6 Apr 17 2017 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Feb. 28, 2017	Apr. 03, 2017
Document And Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Feb. 28, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q1
Trading Symbol	CAFD
Entity Registrant Name	8POINT3 ENERGY PARTNERS LP
Entity Central Index Key	1,635,581
Current Fiscal Year End Date	--11-30
Entity Filer Category	Accelerated Filer
Class A shares
Document And Entity Information [Line Items]
Entity Common Stock Shares Outstanding		28,076,907
Class B shares
Document And Entity Information [Line Items]
Entity Common Stock Shares Outstanding		51,000,000

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands		Feb. 28, 2017	Nov. 30, 2016
Current assets:
Cash and cash equivalents		$ 7,010	$ 14,261
Accounts receivable and short-term financing receivables, net		5,665	5,401
Prepaid and other current assets	[1]	9,369	15,745
Total current assets		22,044	35,407
Property and equipment, net		726,189	720,132
Long-term financing receivables, net		79,232	80,014
Investments in unconsolidated affiliates		788,000	475,078
Other long-term assets		25,515	24,432
Total assets		1,640,980	1,335,063
Current liabilities:
Accounts payable and other current liabilities	[1]	11,144	23,771
Short-term debt and financing obligations	[1]	2,200	1,964
Deferred revenue, current portion		612	870
Total current liabilities		13,956	26,605
Long-term debt and financing obligations	[1]	708,473	384,436
Deferred revenue, net of current portion		243	308
Deferred tax liabilities		31,264	30,733
Asset retirement obligations		14,129	13,448
Total liabilities		768,065	455,530
Redeemable noncontrolling interests		17,346	17,624
Commitments and contingencies (Note 5)
Equity:
Accumulated earnings		16,311	22,440
Total shareholders' equity attributable to 8point3 Energy Partners LP		265,505	271,578
Noncontrolling interests		590,064	590,331
Total equity		855,569	861,909
Total liabilities and equity		1,640,980	1,335,063
Class A shares
Equity:
Capital units, value		249,194	249,138
Class B shares
Equity:
Capital units, value		$ 0	$ 0
[1]	The Partnership has related-party balances for transactions made with the Sponsors and tax equity investors. Related-party balances recorded within “Prepaid and other current assets” in the unaudited condensed consolidated balance sheets were $0.8 million and $0.9 million as of February 28, 2017 and November 30, 2016, respectively. Related-party balances recorded within “Accounts payable and other current liabilities” in the unaudited condensed consolidated balance sheets were $6.4 million and $19.7 million due to Sponsors as of February 28, 2017 and November 30, 2016, respectively, and $1.0 million due to tax equity investors as of both February 28, 2017 and November 30, 2016. Related-party balances recorded within “Short-term debt and financing obligations” and “Long-term debt and financing obligations” in the unaudited condensed consolidated balance sheets were $2.2 million and $47.8 million, respectively, as of February 28, 2017, and $2.0 million and zero, respectively, as of November 30, 2016.

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($)		Feb. 28, 2017	Nov. 30, 2016
Partnership shares, outstanding		79,076,907	79,072,680
Accounts payable and other current liabilities related parties		$ 7,006,000	$ 20,653,000
Short-term debt and financing obligations	[1]	2,200,000	1,964,000
Long-term debt and financing obligations	[1]	708,473,000	384,436,000
Sponsors
Prepaid and other current assets related parties		800,000	900,000
Accounts payable and other current liabilities related parties		6,400,000	19,700,000
Short-term debt and financing obligations		2,200,000	2,000,000
Long-term debt and financing obligations		47,800,000	0
Tax Equity Investors
Accounts payable and other current liabilities related parties		$ 1,000,000	$ 1,000,000
Class A shares
Partnership shares, Issued		28,076,907	28,072,680
Partnership shares, outstanding		28,076,907	28,072,680
Class B shares
Partnership shares, Issued		51,000,000	51,000,000
Partnership shares, outstanding		51,000,000	51,000,000
[1]	The Partnership has related-party balances for transactions made with the Sponsors and tax equity investors. Related-party balances recorded within “Prepaid and other current assets” in the unaudited condensed consolidated balance sheets were $0.8 million and $0.9 million as of February 28, 2017 and November 30, 2016, respectively. Related-party balances recorded within “Accounts payable and other current liabilities” in the unaudited condensed consolidated balance sheets were $6.4 million and $19.7 million due to Sponsors as of February 28, 2017 and November 30, 2016, respectively, and $1.0 million due to tax equity investors as of both February 28, 2017 and November 30, 2016. Related-party balances recorded within “Short-term debt and financing obligations” and “Long-term debt and financing obligations” in the unaudited condensed consolidated balance sheets were $2.2 million and $47.8 million, respectively, as of February 28, 2017, and $2.0 million and zero, respectively, as of November 30, 2016.

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended
		Feb. 28, 2017	Feb. 29, 2016
Revenues:
Operating revenues	[1]	$ 9,897	$ 7,102
Total revenues		9,897	7,102
Operating costs and expenses:
Cost of operations	[1]	2,222	1,266
Selling, general and administrative	[1]	1,902	1,636
Depreciation and accretion	[1]	6,763	4,626
Acquisition-related transaction costs	[1]	13	833
Total operating costs and expenses	[1]	10,900	8,361
Operating loss		(1,003)	(1,259)
Other expense (income):
Interest expense		5,495	2,873
Interest income		(271)	(285)
Other expense (income):		(834)	74
Total other expense, net		4,390	2,662
Loss before income taxes		(5,393)	(3,921)
Income tax provision		(533)	(3,537)
Equity in earnings of unconsolidated investees		606	405
Net loss		(5,320)	(7,053)
Less: Net loss attributable to noncontrolling interests and redeemable noncontrolling interests		(6,181)	(12,361)
Net income attributable to 8point3 Energy Partners LP Class A shares		$ 861	$ 5,308
Net income per Class A share:
Basic		$ 0.03	$ 0.27
Diluted		0.03	0.27
Distributions per Class A share:		$ 0.25	$ 0.22
Weighted average number of Class A shares:
Basic		28,073	20,007
Diluted		43,573	35,507
[1]	The Partnership has related-party activities for transactions made with the Sponsors. Related party transactions recorded within “Operating revenues” in the unaudited condensed consolidated statement of operations were $1.3 million for each of the three months ended February 28, 2017 and February 29, 2016. Related party transactions recorded within “Operating costs and expenses” in the unaudited condensed consolidated statement of operations were $2.0 million and $1.4 million for the three months ended February 28, 2017 and February 29, 2016, respectively.

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Operations (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Income Statement [Abstract]
Revenue from sponsors	$ 1.3	$ 1.3
Costs and expenses related to sponsors	$ 2	$ 1.4

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Redeemable Noncontrolling Interests and Equity (Unaudited) - USD ($) $ in Thousands	Total	Redeemable Noncontrolling Interest	Accumulated Earnings	Total Shareholders Equity	Noncontrolling Interest	Class A shares	Class B shares
Beginning Balance at Nov. 30, 2015	$ 602,386		$ 15,580	$ 408,328	$ 194,058	$ 392,748
Beginning Balance at Nov. 30, 2015		$ 89,747
Beginning Balance, shares at Nov. 30, 2015						20,007,281	51,000,000
Noncontrolling interests obtained through acquisition	40,128				40,128
Cash and accrued distributions to noncontrolling interests - tax equity investors	(3,574)	(3,580)			(3,574)
Issuance of Class shares, value	113,325			113,325		$ 113,325
Issuance of Class shares, shares						8,050,000
Reclassification of noncontrolling interests due to issuance of Class A shares				(257,159)	257,159	$ (257,159)
Share-based compensation, Value	224			224		$ 224
Share-based compensation, Shares						15,399
Contributions from SunPower	9,973				9,973
Contributions from tax equity investors	50,507				50,507
Cash distributions to Class A shareholders	(20,241)		(20,241)	(20,241)
Cash distributions to Sponsors as OpCo unitholders	(12,271)				(12,271)
Net income (loss)	(68,543)
Net income (loss)	81,452		27,101	27,101	54,351
Ending Balance at Nov. 30, 2016	861,909		22,440	271,578	590,331	$ 249,138
Ending Balance at Nov. 30, 2016	17,624	17,624
Ending Balance, shares at Nov. 30, 2016						28,072,680	51,000,000
Noncontrolling interests obtained through acquisition	1,078				1,078
Cash and accrued distributions to noncontrolling interests - tax equity investors	(880)	(613)			(880)
Share-based compensation, Value	56			56		$ 56
Share-based compensation, Shares						4,227
Contributions from tax equity investors	18,750				18,750
Cash distributions to Class A shareholders	(6,990)		(6,990)	(6,990)
Cash distributions to Sponsors as OpCo unitholders	(12,699)				(12,699)
Net income (loss)	335
Net income (loss)	(5,655)		861	861	(6,516)
Ending Balance at Feb. 28, 2017	855,569		$ 16,311	$ 265,505	$ 590,064	$ 249,194
Ending Balance at Feb. 28, 2017	$ 17,346	$ 17,346
Ending Balance, shares at Feb. 28, 2017	0					28,076,907	51,000,000

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Cash flows from operating activities:
Net loss	$ (5,320)	$ (7,053)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, amortization and accretion	6,871	4,626
Distributions from unconsolidated investees	1,107	2,694
Equity in earnings of unconsolidated investees	(606)	(405)
Deferred income taxes	531	3,537
Share-based compensation	56	56
Amortization of debt issuance costs	237	153
Other, net	(8)	95
Changes in operating assets and liabilities:
Accounts receivable and financing receivable, net	501	(546)
Prepaid and other current assets	5,627	(550)
Deferred revenue	(319)	(336)
Accounts payable and other current liabilities	1,457	553
Net cash provided by operating activities	9,464	2,898
Cash flows from investing activities:
Cash provided by (used in) purchases of property and equipment	(86)	1,341
Cash paid for acquisitions	(304,432)	(4,887)
Distributions from unconsolidated investees	16,604	3,584
Net cash provided by (used in) investing activities	(287,914)	38
Cash flows from financing activities:
Proceeds from issuance of bank loans, net of issuance costs	275,987	0
Cash contributions from noncontrolling interests and redeemable noncontrolling interests - tax equity investors	18,750	0
Cash distributions to noncontrolling interests and redeemable noncontrolling interests - tax equity investors	(1,885)	(484)
Net cash provided by financing activities	271,199	5,148
Net increase (decrease) in cash and cash equivalents	(7,251)	8,084
Cash and cash equivalents, beginning of period	14,261	56,781
Cash and cash equivalents, end of period	7,010	64,865
Non-cash transactions:
Property and equipment acquisitions funded by liabilities	4,287	3,435
Noncontrolling interests obtained through acquisition	1,078	864
Accrued distributions to noncontrolling interests and redeemable noncontrolling interests - tax equity investors	581	630
Interest Rate Swap
Adjustments to reconcile net loss to net cash provided by operating activities:
Unrealized loss (gain) on interest rate swap	(670)	74
OpCo Unitholders
Cash flows from financing activities:
Cash distribution	(12,699)	0
First Solar
Cash flows from financing activities:
Repayment of promissory note to First Solar	(1,964)	0
Non-cash transactions:
Issuance by OpCo of promissory note to First Solar in connection with the Stateline Acquisition	50,000	0
SunPower
Cash flows from financing activities:
Capital contributions from SunPower	0	9,973
Class A
Cash flows from financing activities:
Cash distribution	$ (6,990)	$ (4,341)

Description of Business

Description of Business	3 Months Ended
	Feb. 28, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Description of Business	Note 1. Description of Business The Partnership 8point3 Energy Partners LP (together with its subsidiaries, the “Partnership”) is a limited partnership formed on March 3, 2015 under a master formation agreement by SunPower Corporation (“SunPower”) and First Solar, Inc. (“First Solar” and, together with SunPower, the “Sponsors”) to own, operate and acquire solar energy generation systems. As of February 28, 2017, 8point3 Energy Partners LP owned a controlling non-economic managing member interest in 8point3 Operating Company, LLC (“OpCo”) and a 35.5% limited liability company interest in OpCo, and the Sponsors collectively owned a noncontrolling 64.5% limited liability company interest in OpCo. The following table provides an overview of the assets that comprise the Portfolio as of February 28, 2017: Project Location Commercial Operation Date(1) MW(ac) (2) Counterparty Remaining Term of Offtake Agreement (in years)(3) Utility Maryland Solar Maryland February 2014 20 FirstEnergy Solutions 16.1 Solar Gen 2 California November 2014 150 San Diego Gas & Electric 22.7 Lost Hills Blackwell California April 2015 32 City of Roseville/Pacific Gas and Electric 26.8(4) North Star California June 2015 60 Pacific Gas and Electric 18.3 RPU California September 2015 7 City of Riverside 23.6 Quinto California November 2015 108 Southern California Edison 18.8 Hooper Colorado December 2015 50 Public Service Company of Colorado 18.8 Kingbird California April 2016 40 Southern California Public Power Authority(5) 19.2 Henrietta California October 2016 102 Pacific Gas and Electric 19.6 Stateline California August 2016 300 Southern California Edison 19.5 Commercial & Industrial UC Davis California September 2015 13 University of California 18.5 Macy's California California October 2015 3 Macy's Corporate Services 18.7 Macy’s Maryland Maryland December 2016 5 Macy's Corporate Services 19.8 Kern(6) California June 2017 16 Kern High School District 19.8(7) Residential Portfolio U.S. – Various June 2014 39 Approx. 5,900 homeowners(8) 15.5(9) Total 945 (1) For the Macy’s California Project, the Macy’s Maryland Project, and the Kern Project, COD represents the first date on which all of the solar generation systems within each of the Macy’s California Project, the Macy’s Maryland Project and the Kern Project, respectively, have achieved or are expected to achieve COD. For the Residential Portfolio, COD represents the first date on which all of the residential systems within the Residential Portfolio have achieved COD. (2) The MW for the projects in which the Partnership owns less than a 100% interest or in which the Partnership is the lessor under any sale-leaseback financing are shown on a gross basis. Please read Part I, Item 1. “Business—Tax Equity Financing” of our 2016 10-K for a description of our tax equity structures, which such description reflects the Partnership’s ownership on a net basis. (3) Remaining term of offtake agreement is measured from the later of February 28, 2017 or the expected COD of the applicable project. (4) Remaining term comprised of 1.8 years on a PPA with the City of Roseville, California, followed by a 25-year PPA with PG&E starting in 2019. (5) The Kingbird Project is subject to two separate PPAs with member cities of the Southern California Public Power Authority. (6) OpCo’s acquisition of the Kern Project is being effectuated in five phases, with the closing of the first phase, reflecting a nameplate capacity of approximately 3 MW, having occurred on January 26, 2016, the closing of the second phase, reflecting a nameplate capacity of approximately 5 MW, having occurred on September 9, 2016, the closing of the third phase, reflecting a nameplate capacity of approximately 5 MW, having occurred on November 30, 2016, the closing of the fourth phase, reflecting a nameplate capacity of approximately 3 MW, having closed on February 24, 2017, and the closing of the Kern Phase 2(c) Assets to occur in the future. (7) Remaining term is the weighted average duration of the first four phases of the Kern Project. (8) Comprised of the approximately 5,900 solar installations located at homes in Arizona, California, Colorado, Hawaii, Massachusetts, New Jersey, New York, Pennsylvania and Vermont, that are held by the Residential Portfolio Project Entity and have an aggregate nameplate capacity of 39 MW. (9) Remaining term is the weighted average duration of all of the residential leases, in each case measured from February 28, 2017. Basis of Presentation and Preparation The direct and indirect contributions of the IPO Project Entities by the Sponsors to OpCo in connection with the IPO resulted in a business combination for accounting purposes with the IPO SunPower Project Entities being considered the acquirer of the interests contributed by First Solar in the IPO First Solar Project Entities. Therefore, the IPO SunPower Project Entities constitute the “Predecessor.” As used herein, the term “IPO Project Entities” refers to: • the IPO SunPower Project Entities, including: • the Macy’s California Project Entities, which hold the Macy’s California Project; • the Quinto Project Entity, which holds the Quinto Project; • the RPU Project Entity, which holds the RPU Project; • the UC Davis Project Entity, which holds the UC Davis Project; and • the Residential Portfolio Project Entity, which holds the Residential Portfolio Project; and • the IPO First Solar Project Entities, including: • the Lost Hills Blackwell Project, which holds the Lost Hills Project and the Blackwell Project; • the Maryland Solar Project Entity, which holds the Maryland Solar Project; • the North Star Project Entity, which holds the North Star Project; and • the Solar Gen 2 Project Entity, which holds the Solar Gen 2 Project. In connection with the IPO, SunPower contributed a nearly 100% interest in each of the IPO SunPower Project Entities to OpCo, subject, in the case of the Quinto Project, the RPU Project, the UC Davis Project and the Macy’s California Project, to the tax equity investor’s right to a varying portion of the cash flows from the projects. In connection with the IPO, First Solar directly contributed to OpCo a 100% interest in the Maryland Solar Project Entity and indirectly contributed to OpCo a 49% economic interest in each of the Lost Hills Blackwell Project, the North Star Project and the Solar Gen 2 Project. Since November 30, 2015, the partnership completed six acquisitions from our Sponsors, four from SunPower and two from First Solar. Four of the acquisitions are treated as business combinations: • the Kern Project Entity, which holds the Kern Project; • the Kingbird Project Entities, which holds the Kingbird Project; • the Hooper Project Entity, which holds the Hooper Project; and • the Macy’s Maryland Project Entity, which holds the Macy’s Maryland Project. Two of the acquisitions are accounted for as equity method investments: • the Henrietta Project Entity, which holds the Henrietta Project. OpCo owns a 49% economic interest in the Henrietta Project Entity; and • the Stateline Project Entity, which holds the Stateline Project. OpCo owns a 34% economic interest in the Stateline Project Entity. Principles of Consolidation The unaudited condensed consolidated financial statements are prepared in accordance with U.S. GAAP, and include the accounts of the Partnership, and all of its subsidiaries, as appropriate under consolidation accounting guidelines. The year-end condensed consolidated balance sheet data was derived from the audited financial statements, but does not include all disclosures required by U.S. GAAP. Investments in unconsolidated affiliates in which the Partnership has less than a controlling interest are accounted for using the equity method of accounting. All significant inter-entity accounts and transactions have been eliminated in consolidation. In the opinion of management, the accompanying unaudited condensed consolidated financial statements include all adjustments (consisting of normal, recurring items) necessary to state fairly its financial position, results of operations and cash flows for the periods presented. The unaudited condensed consolidated financial statements should be read in conjunction with the accounting policies previously disclosed in Part II, Item 8. “Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note 1—Description of Business” and “—Note 2—Summary of Significant Accounting Policies” of the 2016 10-K. Interim results are not necessarily indicative of results for a full year. Management Estimates The preparation of the unaudited condensed consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the unaudited condensed consolidated financial statements and accompanying notes. Significant estimates in these unaudited condensed consolidated financial statements include the assumptions and methodology underlying allowances for doubtful accounts related to accounts receivable and financing receivables; estimates of future cash flows and economic useful lives of property and equipment; the fair value and residual value of leased solar power systems; fair value of financial instruments; fair value of acquired assets and liabilities; valuation of certain accrued liabilities such as accrued system output performance warranty and AROs; and income taxes including the related valuation allowance. Actual results could materially differ from those estimates. Recent Accounting Pronouncements In January 2017, the FASB issued an update to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions of assets or businesses. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2019 and is applied prospectively. The Partnership is evaluating the impact of this standard on its and disclosures. In October 2016, the FASB issued an update which amends the guidance on related parties that are under common control. Specifically, this update requires that a single decision maker consider indirect interests held by related parties under common control on a proportionate basis in a manner consistent with its evaluation of indirect interests held through other related parties. That is, the single decision maker does not consider indirect interests held through related parties as equivalent to direct interests in determining whether it meets the economics criterion to be a primary beneficiary. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2018. Early adoption is permitted, including adoption in an interim period. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In October 2016, the FASB issued an update which eliminates a prior exception and now requires an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory, such as property and equipment, when such transfer occurs. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2020 and shall be applied on a modified retrospective basis through a cumulative–effect adjustment directly to retained earnings as of the beginning of the period of adoption. Early adoption is permitted. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In August 2016, the FASB issued an update to the statement of cash flows guidance, which addresses eight specific cash flow issues with the objective of reducing the existing diversity in practice. One identified cash flow issue relates to distributions received from equity method investees whereby the reporting entity should make an accounting policy election to classify distributions received from equity method investees using either the cumulative earnings approach or the nature of the distribution approach. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2018 and is applied retrospectively. Early adoption is permitted, including adoption in an interim period. The Partnership is evaluating the change in accounting policy from the cumulative earnings approach to the nature of the distribution approach and the impact on its unaudited condensed consolidated statements of cash flows and disclosures. In March 2016, the FASB issued an update to the equity method investments guidance, which eliminates the requirement that an entity retroactively adopt the equity method of accounting if an investment qualifies for use of the equity method as a result of an increase in the level of ownership or degree of influence. The update requires that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. This new guidance will be effective for the Partnership beginning on December 1, 2017 using a modified retrospective approach. The modified retrospective approach includes a number of optional practical expedients that entities may elect to apply. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In February 2016, the FASB issued an update to the lease accounting guidance, which requires entities to begin recording assets and liabilities arising from substantially all leases on the balance sheet. The new guidance will also require significant additional disclosures about the amount, timing and uncertainty of cash flows from leases. This new guidance will be effective for the Partnership beginning on December 1, 2019 using a modified retrospective approach. The modified retrospective approach includes a number of optional practical expedients that entities may elect to apply. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In August 2014, the FASB issued an update to the standards to require management to evaluate whether there are conditions and events that raise substantial doubt about the Partnership’s ability to continue as a going concern within one year after the date the financial statements are issued, and to provide related disclosures. The Partnership adopted the new guidance beginning on December 1, 2016 and the impact of this standard on its unaudited condensed consolidated financial statements and disclosures is not material. In May 2014, the FASB issued a new revenue recognition standard based on the principle that revenue is recognized to depict 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 and services. The FASB has issued several updates to the standard which (i) clarify the application of the principal versus agent guidance; (ii) clarify the guidance relating to performance obligations and licensing; and (iii) clarify assessment of the collectability criterion, presentation of sales taxes, measurement date for non-cash consideration and completed contracts at transaction. The new revenue recognition standard, amended by the updates, becomes effective for the Partnership in the first quarter of fiscal 2019 and is to be applied retrospectively using one of two prescribed methods. Early adoption is permitted. The Partnership is currently evaluating and considering the possibility of early adoption of the new standard effective December 1, 2017. The Partnership’s ability to early adopt, potentially using the modified retrospective method, is dependent on process, internal control and system readiness and a complete evaluation of all the disclosures required under the new standard. While the Partnership is continuing to assess all potential impacts of the standard, it currently believes the impact on its unaudited condensed consolidated financial statements is not material because over 90% of the Partnership’s total revenue for all periods is comprised of lease revenue, which is substantially unchanged under the new standard. Other than as described above, there has been no issued accounting guidance not yet adopted by the Partnership that it believes is material or potentially material to its unaudited condensed consolidated financial statements

Business Combinations

Business Combinations	3 Months Ended
	Feb. 28, 2017
Business Combinations [Abstract]
Business Combinations	Note 2. Business Combinations Acquisition accounting is dependent upon certain valuations and other studies that must be completed as of the acquisition date. The judgments made in the context of the purchase price allocation can materially impact the Partnership’s future results of operations. The Partnership’s purchase price allocations for acquisitions completed through November 30, 2016 are final and not subject to revision. For the acquisition completed during the three months ended February 28, 2017, the valuation is based on the preliminary assessment of the fair values of the assets acquired, liabilities assumed and noncontrolling interests as of the acquisition date, and is subject to change as the Partnership obtains additional information for its estimates during the respective measurement period. Kern Acquisition: On January 26, 2016, OpCo and SunPower entered into the Kern Purchase Agreement, which was amended on September 28, 2016, November 30, 2016 and February 24, 2017, pursuant to which OpCo agreed to purchase an interest in the Kern Project. OpCo’s acquisition of the Kern Project is being effectuated in five phases summarized below: (i) Phase 1(a): On January 26, 2016, 8point3 OpCo Holdings, LLC, a wholly owned subsidiary of OpCo, acquired from SunPower all of the class B limited liability company interests of the Kern Class B Partnership. Prior to the date of the execution of the Kern Purchase Agreement and in connection with the closing of the tax equity financing for the Kern Project, described below, the Kern Project Entity, an indirect subsidiary of the Kern Class B Partnership, acquired the Kern Phase 1(a) Assets. The initial phase of the acquisition of the Kern Project is referred to herein as the “Kern Phase 1(a) Acquisition.” (ii) Phase 1(b) : On September 9, 2016, the Kern Project Entity acquired the assets included in the Kern Phase 1(b) Assets from SunPower. The second phase of the acquisition of the Kern Project is referred to herein as the “Kern Phase 1(b) Acquisition.” (iii) Phase 2(a): On November 30, 2016, the Kern Project Entity acquired the Kern Phase 2(a) Assets from SunPower. The third phase of the acquisition of the Kern Project is referred to herein as the “Kern Phase 2(a) Acquisition.” (iv) Phase 2(b): On February 24, 2017 , the Kern Project Entity acquired the Kern Phase 2(b) Assets from SunPower. The fourth phase of the acquisition of the Kern Project is referred to herein as the “Kern Phase 2(b) Acquisition.” (v) Phase 2(c): At a future closing date, the Kern Project Entity will acquire the Kern Phase 2(c) Assets from SunPower. The aggregate purchase price for the acquisition is up to $36.6 million in cash, of which OpCo paid approximately $4.9 million on January 27, 2016 in connection with the closing of the first phase on January 26, 2016, approximately $9.2 million on September 9, 2016 in connection with the closing of the second phase on September 9, 2016, approximately $8.4 million on November 30, 2016 in connection with the closing of the third phase on November 30, 2016 and approximately $6.0 million on February 24, 2017 in connection with the closing of the fourth phase on February 24, 2017. OpCo will pay the remaining balance of up to $8.1 million purchase price at the closing of the fifth phase. In addition, on January 22, 2016, a subsidiary of the Kern Class B Partnership entered into a tax equity financing facility with a third-party investor, which allocates to OpCo a certain share of cash flows from the Kern Project pursuant to a distribution waterfall. Pursuant to this distribution waterfall, the tax equity investor is entitled to a monthly amount of project cash flow until a specified “flip” point is achieved. After the “flip” point, the cash allocations to OpCo increase. In addition, upon reaching the flip point, OpCo has a right to purchase the tax equity investor’s interests in the project for an amount that is not less than its fair market value. The tax equity investor will make capital contributions to fund purchase price payments up to approximately $30.0 million, of which $0.9 million, $1.8 million, $1.3 million, $6.7 million and $8.2 million was paid on January 22, 2016, September 9, 2016, November 30, 2016, December 14, 2016 and February 24, 2017, respectively. The remaining capital contribution balance of up to $11.1 million will be made when the Kern Project’s phases meet certain construction milestones and will be transferred to affiliates of SunPower for the remaining purchase price payments. For more information about our tax equity structures in general, please read Part I, Item 1. “Business—Tax Equity Financing” of our 2016 10-K. The Kern Phase 1(a) Acquisition, the Kern Phase 1(b) Acquisition, the Kern Phase 2(a) Acquisition and the Kern Phase 2(b) Acquisition qualify as business combinations and the Partnership accounts for the transactions under the acquisition method. The purchase allocation of the identifiable assets acquired, liabilities assumed and noncontrolling interests of the Kern Phase 1(a) Assets, the Kern Phase 1(b) Assets, the Kern Phase 2(a) Assets and the Kern Phase 2(b) Assets are disclosed in the following table. Fair Value Kern Phase 1(a) Kern Phase 1(b) Kern Phase 2(a) Kern Phase 2(b) (in thousands) Assets Assets Assets Assets Property and equipment $ 9,510 $ 18,856 $ 14,873 $ 11,872 Related party payable (3,435 ) (7,123 ) (4,504 ) (4,287 ) Asset retirement obligation (322 ) (785 ) (623 ) (493 ) Noncontrolling interest (866 ) (1,794 ) (1,332 ) (1,078 ) Net assets acquired $ 4,887 $ 9,154 $ 8,414 $ 6,014 Valuation methodology: The Partnership utilized the discounted cash flow method under the income approach to value property and equipment for the Kern Phase 1(a) Assets, the Kern Phase 1(b) Assets, the Kern Phase 2(a) Assets and the Kern Phase 2(b) Assets. Key assumptions used in the discounted cash flow method included forecasted pre-tax cash flows, forecasted taxable income and discount rates. All estimates, key assumptions and forecasts were reviewed by the Partnership and the fair value analyses and related valuations represent the conclusions of management. Supplementary Data: The results of operations for the Kern Phase 1(a) Assets, the Kern Phase 1(b) Assets, the Kern Phase 2(a) Assets and the Kern Phase 2(b) Assets have been included in the Partnership’s consolidated statements of operations since their respective dates of acquisition. No revenue was generated from the Kern Phase 2(b) Assets in the quarter ended February 28, 2017. Pro forma results of operations have not been presented as the impact of the acquisition on February 24, 2017 is not material to the Partnership’s results of operations for the current or prior periods. Additionally, the Kern Phase 2(b) Assets became operational after the acquisition date; therefore, would not have had any pro forma results in the prior period.

Investment in Unconsolidated Af

Investment in Unconsolidated Affiliates	3 Months Ended
	Feb. 28, 2017
Equity Method Investments And Cost Method Investments [Abstract]
Investment in Unconsolidated Affiliates	Note 3. Investment in Unconsolidated Affiliates On November 11, 2016, OpCo entered into the Stateline Purchase Agreement with First Solar to acquire a 34% interest in the Stateline Project for $329.5 million (the “Stateline Acquisition”). The Stateline Acquisition closed on December 1, 2016 and the Partnership recorded an investment of $329.9 million after consideration of acquisition-related costs. As of February 28, 2017, the Partnership owns a 49% ownership interest in each of SG2 Holdings, North Star Holdings, Lost Hills Blackwell Holdings and Henrietta Holdings, and a 34% ownership interest in Stateline Holdings. The minority membership interests are accounted for as equity method investments, as the Partnership is able to exercise significant influence through its governing board, while the non-affiliated majority owner otherwise controls. The following table summarizes the activity of the Partnership’s investments in its unconsolidated affiliates during the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Balance at the beginning of the period $ 475,078 $ 352,070 Investments in its unconsolidated affiliates during the period 330,027 — Equity in earnings in unconsolidated affiliates (1) 606 405 Distributions from unconsolidated affiliates (17,711 ) (6,278 ) Balance at the end of the period $ 788,000 $ 346,197 (1) The net income (loss) used to determine the Partnership’s equity in earnings of unconsolidated affiliates reflects adjustments pursuant to the equity method of accounting, including the amortization of basis differences resulting from the Partnership’s proportionate share of certain equity method investees’ net assets exceeding their carrying values. The difference between the amounts at which the Partnership’s investments in unconsolidated affiliates are carried and the Partnership’s proportionate share of the equity method investee’s net assets for equity method investments was $139.4 million and $83.2 million as of February 28, 2017 and November 30, 2016, respectively. The Partnership accretes the basis difference over the life of the underlying assets and the accretion expense was $1.0 million and $0.4 million for the three months ended February 28, 2017 and February 29, 2016, respectively The following table presents summarized financial information of SG2 Holdings, North Star Holdings, Lost Hills Blackwell Holdings, Henrietta Holdings and Stateline Holdings as derived from the unaudited condensed consolidated financial statements of such entities for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Summary statements of operations information: Revenue $ 19,616 $ 8,650 Operating expenses 26,393 10,924 Net loss (7,759 ) (2,170 )

Balance Sheet Components

Balance Sheet Components	3 Months Ended
	Feb. 28, 2017
Balance Sheet Related Disclosures [Abstract]
Balance Sheet Components	Note 4. Balance Sheet Components Financing Receivables The Partnership’s net investment in sales-type leases presented in “Accounts receivable and short-term financing receivables, net” and “Long-term financing receivables, net” on the unaudited condensed consolidated balance sheets is as follows: As of February 28, November 30, (in thousands) 2017 2016 Minimum lease payment receivable, net (1) $ 98,684 $ 100,161 Unguaranteed residual value 12,908 12,926 Less: unearned income (29,801 ) (30,557 ) Net financing receivables $ 81,791 $ 82,530 Short-term financing receivables, net (2) $ 2,559 $ 2,516 Long-term financing receivables, net $ 79,232 $ 80,014 (1) Allowance for losses on financing receivables was $0.6 million and $0.7 million as of February 28, 2017 and November 30, 2016, respectively. (2) Accounts receivable and short-term financing receivables, net on the unaudited condensed consolidated balance sheets includes other trade accounts receivable of $3.1 million and $2.9 million, as of February 28, 2017 and November 30, 2016, respectively. Current and Non-current Assets As of February 28, November 30, (in thousands) 2017 2016 Prepaid expense and other current assets Reimbursable network upgrade costs (1) $ 7,496 $ 13,870 Other current assets (2) 1,873 1,875 Total $ 9,369 $ 15,745 Property and equipment, net Utility solar power systems 613,293 578,817 Leased solar power systems 137,410 137,475 Land 1,020 1,020 Construction-in-progress (3) 15,210 36,981 $ 766,933 $ 754,293 Less: accumulated depreciation (40,744 ) (34,161 ) Total $ 726,189 $ 720,132 Other long-term assets Reimbursable network upgrade costs (1) $ 22,301 $ 21,781 Intangible assets (4) 1,647 1,754 Derivative financial instruments 1,567 897 Total $ 25,515 $ 24,432 (1) For the Kingbird Project and the Quinto Project, the construction costs related to the network upgrade of a transmission grid belonging to a utility company are reimbursable by that utility company over five years from the date the project reached commercial operation. (2) Other current assets included $0.4 million due from SunPower related to system output performance warranties and system repairs in connection with $0.1 million of system output performance warranty accrual and $0.3 million of system repairs accrual recorded in the “Accounts payable and other current liabilities” line item on the unaudited condensed consolidated balance sheets as of February 28, 2017. Similarly, other current assets included $0.5 million due from SunPower related to system output performance warranties and system repairs in connection with $0.2 million of system output performance warranty accrual and $0.3 million of system repairs accrual recorded in the “Accounts payable and other current liabilities” line item on the consolidated balance sheet as of November 30, 2016. (3) Construction-in-progress is the project assets related to the Kern Phase 1(a) Assets and Kern Phase 2(b) Assets. (4) Intangible assets represents a customer contract intangible that is amortized on a straight-line basis beginning on COD through the contract term end date of December 31, 2020, of which $0.1 million and zero reduced operating revenues in the three months ended February 28, 2017 and February 29, 2016, respectively. Current Liabilities As of February 28, November 30, (in thousands) 2017 2016 Accounts payable and other current liabilities Trade and accrued accounts payable $ 1,313 $ 1,089 Related party payable (1) 7,006 20,653 System output performance warranty 138 196 Residential lease system repairs accrual 269 331 Other short-term liabilities 2,418 1,502 Total $ 11,144 $ 23,771 (1) Related party payable on the unaudited condensed consolidated balance sheets as of February 28, 2017 consists of (i) $5.8 million related to the purchase price payable to SunPower, which will be funded by tax equity investors for the Kern Phase 1(a) Acquisition and the Kern Phase 2(b) Acquisition; (ii) $0.6 million related to accrued distribution to tax equity investors; and (iii) $0.6 million for accounts payable to related parties associated with O&M, AMA and MSA fees owed to the Sponsors. Related party payable on the consolidated balance sheets as of November 30, 2016 consists of (i) $19.5 million related to the purchase price payable to SunPower for the Kern Phase 1(a) Acquisition, the Kern Phase 1(b) Acquisition, the Kern Phase 2(a) Acquisition and the Macy’s Maryland Acquisition; (ii) $1.0 million related to accrued distribution to tax equity investors; and (iii) $0.1 million for accounts payable to related parties associated with O&M, AMA and MSA fees owed to the Sponsors.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Feb. 28, 2017
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 5. Commitments and Contingencies Land Use Commitments The Partnership is a party to various agreements that provide for payments to landowners for the right to use the land upon which projects under PPAs are located. The total minimum lease and easement commitments at February 28, 2017 under these land use agreements are as follows: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total Land use payments $ 871 $ 1,329 $ 1,686 $ 1,742 $ 1,782 $ 56,249 $ 63,659 Solar Power System Performance Warranty Lease agreements require the Partnership to undertake a system output performance warranty. The Partnership has recorded in “Accounts payable and other current liabilities” amounts related to these system output performance warranties totaling $0.1 million and $0.2 million as of February 28, 2017 and November 30, 2016, respectively. The Partnership has also recorded in “Other current assets” amounts of $0.1 million and $0.2 million as of February 28, 2017 and November 30, 2016, relating to anticipated performance warranty reimbursements from the O&M provider. The following table summarizes accrued system output performance warranty activity for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Balance at the beginning of the period $ 196 $ 237 Settlements during the period (29 ) (76 ) Adjustments during the period (29 ) 65 Balance at the end of the period $ 138 $ 226 Asset Retirement Obligations The Partnership’s AROs are based on estimated third-party costs associated with the decommissioning of the applicable project assets. Revisions to these costs may increase or decrease in the future as a result of changes in regulations, engineering designs and technology, permit modifications, inflation or other factors. Decommissioning activities generally occur over a period of time commencing at the end of the system’s life. The following table summarizes ARO activity for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Balance at the beginning of the period $ 13,448 $ 9,992 ARO assumed in acquisition 493 547 Accretion expense 171 119 Revisions to ARO during the period 17 — Balance at the end of the period $ 14,129 $ 10,658 Legal Proceedings In the normal course of business, the Partnership may be notified of possible claims or assessments. The Partnership will record a provision for these claims when it is both probable that a liability has been incurred and the amount of the loss, or a range of the potential loss, can be reasonably estimated. These provisions are reviewed regularly and adjusted to reflect the impacts of negotiations, settlements, rulings, advice of legal counsel, and other information or events pertaining to a particular case. Although the Partnership may, from time to time, be involved in litigation and claims arising out of its operations in the ordinary course of business, the Partnership is not a party to any litigation or governmental or other proceeding that the Partnership believes will have a material adverse impact on its financial position, results of operations, or liquidity. Environmental Contingencies The Partnership reviews its obligations as they relate to compliance with environmental laws, including site restoration and remediation. During the three months ended February 28, 2017 and February 29, 2016, there were no known environmental contingencies that required the Partnership to recognize a liability.

Lease Agreements and Power Purc

Lease Agreements and Power Purchase Agreements	3 Months Ended
	Feb. 28, 2017
Leases [Abstract]
Lease Agreements and Power Purchase Agreements	Note 6. Lease Agreements and Power Purchase Agreements Lease Agreements As of February 28, 2017, the Partnership’s unaudited The following table presents the Partnership’s minimum future rental receipts on operating leases (including the lease agreement for the Maryland Solar Project and the residential lease portfolio) placed in service as of February 28, 2017: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total Minimum future rentals on residential operating leases placed in service (1) $ 2,779 $ 3,723 $ 3,743 $ 3,765 $ 3,787 $ 42,563 $ 60,360 Maryland Solar lease 4,249 5,173 4,912 — — — 14,334 Total operating leases $ 7,028 $ 8,896 $ 8,655 $ 3,765 $ 3,787 $ 42,563 $ 74,694 (1) Minimum future rentals on operating leases placed in service do not include contingent rentals that may be received from customers under agreements that include performance-based incentives and executory costs. As of February 28, 2017, future maturities of net financing receivables for sales-type leases are as follows: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total Scheduled maturities of minimum lease payments receivable (1) $ 4,196 $ 5,681 $ 5,768 $ 5,860 $ 5,955 $ 71,224 $ 98,684 (1) Minimum future rentals on sales-type leases placed in service do not include contingent rentals that may be received from customers under agreements that include performance-based incentives and executory costs. Power Purchase Agreements Under the terms of various PPAs, the Partnership’s contracted counterparties may be obligated to take all or part of the output from the system at stipulated prices over defined periods. All PPAs associated with solar generation systems operating as of February 28, 2017 have no minimum lease payments and all of the rental income under these leases is recorded as revenue when the electricity is delivered. SREC Sales Agreement The Partnership applies for and receives SRECs for power generated by certain of our solar power systems. The Partnership has entered into an SREC Sales Agreement with a non-affiliated party to assist it in meeting its own emissions reduction or conservation requirements. Under the terms of the SREC Sales Agreement, the contracted counterparty is obligated to purchase an annual number of SRECs from the Partnership at stipulated prices over a defined period of time. The Partnership recognizes revenue and associated costs upon delivery of the SRECs to the counterparty. As of February 28, 2017, firm sales under the SREC Sales Agreement are as follows: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total SREC sales $ 586 $ 781 $ 781 $ 781 $ 195 $ — $ 3,124

Debt and Financing Obligations

Debt and Financing Obligations	3 Months Ended
	Feb. 28, 2017
Debt Disclosure [Abstract]
Debt and Financing Obligations	Note 7. Debt and Financing Obligations Credit Facility and Stateline Promissory Note On June 5, 2015, OpCo entered into a $525.0 million credit facility, consisting of a $300.0 million term loan facility, a $25.0 million delayed draw term loan facility and a $200.0 million revolving credit facility. OpCo borrowed $300.0 million under the term loan facility on June 5, 2015, which indebtedness will mature on the fifth anniversary of its issuance, at which point all amounts outstanding under the $525.0 million credit facility will become due and payable. There will be no principal amortization over the term of the credit facility. The discount and incremental debt issuance costs associated with these borrowings were $3.1 million and were reported as a direct deduction from the face amount of the note. The Partnership used the net proceeds of the term loan facility to pay distributions of $129.4 million and $168.9 million to First Solar and SunPower, respectively. On March 30, 2016, OpCo drew down $40.0 million from its revolving credit facility and $25.0 million from its delayed draw term loan facility. On September 29, 2016, OpCo drew down $23.0 million from its revolving credit facility. On September 30, 2016, OpCo entered into the Joinder Agreement under its existing senior secured credit facility, pursuant to which OpCo obtained a new $250.0 million incremental term loan facility, increasing the maximum borrowing capacity under the credit facility to $775.0 million. On December 1, 2016, in connection with the Stateline Acquisition, OpCo drew down $250.0 million under the incremental term loan facility and $20.0 million under the revolving credit facility. On February 24, 2017 in connection with the Kern Phase 2(b) Acquisition, OpCo drew down $6.0 million under the revolving credit facility. As of February 28, 2017, OpCo had outstanding borrowings of $300.0 million under the term loan facility, $250.0 million under the incremental term loan facility, $25.0 million under the delayed draw term loan facility and $89.0 million under the revolving credit facility, as well as approximately $54.9 million of letters of credit outstanding under the revolving credit facility. The remaining portion of the revolving credit facility is undrawn as of February 28, 2017. As of November 30, 2016, OpCo had outstanding borrowings of $300.0 million under the term loan facility, $25.0 million under the delayed draw term loan facility and $63.0 million under the revolving credit facility, as well as approximately $54.9 million of letters of credit outstanding under the revolving credit facility. OpCo’s credit facility is collateralized by a pledge of the equity of OpCo and certain of its subsidiaries. The Partnership and each of OpCo’s subsidiaries, other than certain non-guarantor subsidiaries, have guaranteed the obligations of OpCo under the credit facility. Loans outstanding under the credit facility bear interest at either (i) a base rate, which is the highest of (x) the federal funds rate plus 0.50%, (y) the administrative agent’s prime rate and (z) one-month LIBOR, in each case, plus an applicable margin; or (ii) one-, two-, three- or six-month LIBOR plus an applicable margin. The unused portion of the revolving credit facility and delayed draw term loan facility is subject to a commitment fee of 0.30% per annum. OpCo may prepay the borrowings under the term loan facility and the delayed draw term loan facility at any time. The term loan bears an interest rate of approximately 2.78% and 2.61% per annum as of February 28, 2017 and November 30, 2016, respectively. OpCo has entered into interest rate swap agreements to hedge the interest rate on a portion of the borrowings under the term loan facility. For more details, please read “—Note 8. Fair Value.” OpCo’s credit facility contains covenants including, among others, requiring the Partnership to maintain the following financial ratios: (i) a debt to cash flow ratio of not more than (a) 6.00 to 1.00 for the fiscal quarters ending November 30, 2016 through November 30, 2017; and (b) 5.00 to 1.00 for each fiscal quarter ending thereafter; and (ii) a debt service coverage ratio of not less than 1.75 to 1.00. In addition, an event of default occurs under the credit facility upon a change of control. The credit facility defines a change of control as occurring when, among other things, (i) the Sponsors (or either of them) cease to direct the management, directly or indirectly, of the Partnership or OpCo, or (ii) the Sponsors collectively cease to own 35% of the economic interest in OpCo. In addition, the credit facility contains customary non-financial covenants and certain restrictions that will limit the Partnership’s, OpCo’s and certain of the Partnership’s and its domestic subsidiaries’ ability to, among other things, incur or guarantee additional debt and to make distributions on or redeem or repurchase OpCo common units. The Joinder Agreement amended OpCo’s credit facility to permit OpCo to incur up to $50.0 million in subordinated indebtedness from First Solar or its affiliate to pay a portion of the purchase price for the Stateline Project. As of February 28, 2017, the Partnership was in compliance with its debt covenants. On April 6, 2016, the parties thereto amended OpCo’s credit facility (i) to provide for the lenders’ consent to the Omnibus Agreement, (ii) to expand OpCo’s ability to further amend the Omnibus Agreement without lender consent in the future, subject to certain conditions, (iii) to permit certain customary restrictions on transfers of the equity interests of certain Project Entities, which are jointly owned, indirectly, by OpCo and SunPower, (iv) to supplement the Pledge and Security Agreement between the parties in light of the foregoing amendment, and (v) to make certain clarifying modifications to definitions and cross references. On December 1, 2016, in connection with the Stateline Acquisition, OpCo issued a promissory note to First Solar in the principal amount of $50.0 million. The Stateline Promissory Note is unsecured and matures on the date that is six months after the maturity date under OpCo’s credit facility. Interest will accrue at a rate of 4% per annum, except it will accrue at a rate of 6% per annum (i) upon the occurrence and during the continuation of a specified event of default and (ii) in respect of amounts accrued as payments-in-kind pursuant to the terms of the note. OpCo is not permitted to prepay the $50.0 million promissory note without the consent of certain lenders under its existing credit agreement (except for certain mandatory prepayments). Until OpCo has paid in full the principal and interest on promissory note, OpCo is restricted in its ability to: (i) acquire interests in additional projects (other than the acquisition of the Kern Phase 2 Assets); (ii) use the net proceeds of equity issuances except as prescribed in the promissory note; (iii) incur additional indebtedness to which the promissory note would be subordinate; and (iv) extend the maturity date under OpCo’s existing credit facility. As of February 28, 2017, OpCo had outstanding borrowings of $50.0 million under the Stateline Promissory Note. The following table summarizes the Partnership’s debt obligations: February 28, 2017 November 30, 2016 (in thousands) Amount Interest Rate Amount Interest Rate Term loan due June 2020 $ 300,000 2.78 % $ 300,000 2.61 % Incremental term loan due June 2020 250,000 2.78 % — N/A Delayed draw term loan facility due June 2020 25,000 2.78 % 25,000 2.61 % Revolving credit facility due June 2020 89,000 2.78 % 63,000 2.61 % Stateline Promissory Note due December 2020 50,000 4.00 % — N/A Less: debt issuance costs (3,327 ) N/A (3,564 ) N/A Total $ 710,673 $ 384,436 August 2011 Letter of Credit Facility with Deutsche Bank In August 2011, the Predecessor’s parent, SunPower, entered into a letter of credit facility agreement with Deutsche Bank, as administrative agent, and certain financial institutions. Payment of obligations under the letter of credit facility is guaranteed by the majority shareholder of SunPower, Total S.A. As of February 28, 2017, and November 30, 2016, letters of credit issued and outstanding under the August 2011 letter of credit facility with Deutsche Bank which is available to SunPower for the Quinto Project and the RPU Project totaled $11.5 million and $30.7 million, respectively. The associated fees incurred for the letters of credit to Deutsche Bank were $0.1 million for both the three months ended February 28, 2017 and February 29, 2016, and were recognized as interest expense in the unaudited condensed consolidated statements

Fair Value

Fair Value	3 Months Ended
	Feb. 28, 2017
Fair Value Disclosures [Abstract]
Fair Value	Note 8. Fair Value Fair value is estimated by applying the following hierarchy, which prioritizes the inputs used to measure fair value into three levels and bases the categorization within the hierarchy upon the lowest level of input that is available and significant to the fair value measurement (observable inputs are the preferred basis of valuation): • Level 1—Quoted prices in active markets for identical assets or liabilities. • Level 2—Measurements are inputs that are observable for assets or liabilities, either directly or indirectly, other than quoted prices included within Level 1. • Level 3—Prices or valuations that require management inputs that are both significant to the fair value measurement and unobservable. The first two levels in the hierarchy are considered observable inputs and the last is considered unobservable. Assets and Liabilities Measured at Fair Value on a Recurring Basis The following table presents the Partnership’s assets and liabilities measured at estimated fair value on a recurring basis, categorized in accordance with the fair value hierarchy: February 28, 2017 November 30, 2016 (in thousands) Level 2 Total Level 2 Total Assets Derivative financial instruments $ 1,567 $ 1,567 $ 897 $ 897 Total assets $ 1,567 $ 1,567 $ 897 $ 897 Derivative financial instruments: On July 17, 2015, OpCo entered into interest rate swap agreements intended to hedge the interest rate risk on the outstanding borrowings under the term loan with an aggregate notional value of $240.0 million. Under the interest rate swap agreements, OpCo paid a fixed swap rate of interest of 1.55% and the counterparties to the agreements paid a floating interest rate based on three-month LIBOR at quarterly intervals through the maturity date of August 31, 2018. OpCo had the right to cancel the interest rate swap agreements on August 31, 2016 and any quarterly fixed payment date thereafter with a minimum of five business days’ notification. OpCo exercised its right to cancel the interest rate swap agreements on August 31, 2016 and entered into new interest rate swap agreements intended to hedge the interest rate risk on the outstanding borrowings under the term loan with an aggregate notional value of $250.0 million. Under the new interest rate swap agreements, OpCo will pay a fixed swap rate of interest of approximately 0.85% and the counterparties to the agreements will pay a floating interest rate based on one-month LIBOR at monthly intervals through the maturity date of August 31, 2018. On January 5, 2017, OpCo entered into another interest rate swap agreement intended to hedge the interest rate risk on the outstanding borrowings under the term loan with an aggregate notional value of $40.0 million. Under this interest rate swap agreement, OpCo will pay a fixed swap rate of interest of approximately 1.16% and the counterparty to the agreement will pay a floating interest rate based on one-month LIBOR at monthly intervals through the maturity date of August 31, 2018. As of both February 28, 2017 and November 30, 2016, these interest rate swap agreements had not been designated as cash flow hedges and are reflected at fair value on the unaudited condensed consolidated balance sheets. As of both February 28, 2017, and November 30, 2016, these interest rate swap agreements have been presented in other long-term assets on the unaudited condensed consolidated balance sheet since the maturity date is over one year after the balance sheet date. During the three months ended February 28, 2017 and February 29, 2016, the Partnership recorded a change in fair value of $0.7 million and $0.1 million, respectively, within other income and other expense, respectively, in the unaudited condensed consolidated statement of operations. The primary inputs into the valuation of interest rate swaps are interest yield curves, interest rate volatility, and credit spreads. The Partnership's interest rate swaps are classified within Level 2 of the fair value hierarchy, since all significant inputs are corroborated by market observable data. There were no transfers in or out of Level 1, Level 2 and Level 3 during the period. Liabilities Measured at Fair Value on a Nonrecurring Basis Long-term debt and financing obligations: The estimated fair value of the Partnership’s long-term debt was classified within Level 2 of the fair value hierarchy as of February 29, 2017 and November 30, 2016, and approximated its carrying value of $708.5 million and $384.4 million, respectively, as the term loan facility is a variable rate debt with the interest rate indexed to the market and reset on a frequent and short-term basis .

Noncontrolling Interests

Noncontrolling Interests	3 Months Ended
	Feb. 28, 2017
Noncontrolling Interest [Abstract]
Noncontrolling Interests	Note 9. Noncontrolling Interests Noncontrolling interests represent the portion of net assets in consolidated subsidiaries that are not attributable, directly or indirectly, to the Partnership. For accounting purposes, the holders of noncontrolling interests of the Partnership include the Sponsors, which are SunPower and First Solar, as described in “—Note 1—Description of Business,” and third-party investors under the tax equity financing facilities. As of February 28, 2017 and November 30, 2016, First Solar and SunPower had noncontrolling interests of 28.0% and 36.5%, respectively, in OpCo . In addition, certain subsidiaries of OpCo have entered into tax equity financing facilities with third-party investors under which the parties invest in entities that hold the solar power systems. The Partnership, through OpCo, holds controlling interests in these less-than-wholly-owned entities and has therefore fully consolidated these entities. The Partnership accounts for the portion of net assets using the HLBV Method in the consolidated entities attributable to the investors as “Redeemable noncontrolling interests” and “Noncontrolling interests” in its unaudited condensed consolidated financial statements. Noncontrolling interests in subsidiaries that are redeemable at the option of the noncontrolling interest holder are classified as “Redeemable noncontrolling interests in subsidiaries” between liabilities and equity on the unaudited condensed consolidated balance sheets and the balance is the greater of the carrying value calculated under the HLBV Method or the redemption value. In connection with the Kern Phase 2(b) Acquisition on February 24, 2017, OpCo acquired the noncontrolling interest balance totaling $1.1 million. Please read “ — As of February 28, 2017 and November 30, 2016, redeemable noncontrolling interests attributable to tax equity investors after adjusting the carrying amount to the redemption value was $17.3 million and $17.6 million $40.8 million During the three months ended February 28, 2017 and February 29, 2016 such indirect subsidiaries of OpCo received $18.8 million and zero, respectively, contributions from third-party investors under the related facilities and attributed $8.8 million and $34.9 million, respectively, in losses to the third-party investors primarily as a result of allocating certain assets, including tax credits, if any, to the investors. During the three months ended February 28, 2017 and February 29, 2016 such indirect subsidiaries of OpCo made $1.5 million and $0.9 million, respectively, in distributions to third-party investors under the related facilities. The following table presents the noncontrolling interest balances by entity, reported in shareholders’ equity in the unaudited condensed consolidated balance sheets as of February 28, 2017 and November 30, 2016: As of February 28, November 30, (in thousands) 2017 2016 First Solar $ 233,847 $ 238,210 SunPower 305,644 311,327 Tax equity investors 50,573 40,794 Total $ 590,064 $ 590,331

Shareholders_ Equity

Shareholders’ Equity	3 Months Ended
	Feb. 28, 2017
Stockholders Equity Note [Abstract]
Shareholders’ Equity	Note 10. Shareholders’ Equity On June 24, 2015, the Partnership completed its IPO by issuing 20,000,000 of its Class A shares representing limited partner interests in the Partnership to the public. On September 28, 2016 the Partnership sold in an underwritten registered public offering 8,050,000 Class A shares representing limited partner interests in the Partnership. ATM Program On January 30, 2017, the Partnership established the ATM Program under which the Partnership may sell Class A shares from time to time through the ATM Agents up to an aggregate sales price of $125.0 million. The Partnership may also sell Class A shares to any ATM Agent, as principal for its own account, at a price agreed upon at the time of the sale. The Partnership will use the net proceeds from sales under the ATM Program to purchase a number of common units in OpCo equal to the number of Class A shares issued under the ATM Program. OpCo may use the proceeds for general corporate purposes, which may include, among other things, repaying borrowings under the Stateline Promissory Note and OpCo’s credit facilities, and funding working capital or acquisitions. As of both February 28, 2017 and November 30, 2016 The following shares of the Partnership were outstanding as of November 30, 2016, respectively: As of Shares February 28, 2017 November 30, 2016 Shareholder Class A shares 28,076,907 28,072,680 Public Class B shares 22,116,925 22,116,925 First Solar Class B shares 28,883,075 28,883,075 SunPower Total shares outstanding 79,076,907 79,072,680 Cash Distribution On January 13, 2017, the Partnership distributed $7.0 million on its Class A shares and OpCo distributed $12.7 million on its common and subordinated units, or in each case $0.2490 per share or unit, for the period from September 1, 2016 to November 30, 2016.

Net Income Per Share

Net Income Per Share	3 Months Ended
	Feb. 28, 2017
Earnings Per Share [Abstract]
Net Income Per Share	Note 11. Net Income Per Share Basic net income per share is computed by dividing net income for the three months ended February 28, 2017 and February 29, 2016, respectively, attributable to Class A shareholders by the weighted average number of Class A shares outstanding for the applicable period. Diluted net income per share is computed using basic weighted average Class A shares outstanding plus, if dilutive, any potentially dilutive securities outstanding during the period using the treasury-stock-type method. Pursuant to the Exchange Agreement entered into among the Partnership, the General Partner, OpCo, a wholly owned subsidiary of SunPower and a wholly owned subsidiary of First Solar, the Sponsors can tender OpCo common units and an equal number of such Sponsor’s Class B shares for redemption, and the Partnership has the right to directly purchase the tendered OpCo common units and Class B shares for, subject to the approval of its conflicts committee, cash or the issuance of Class A shares of the Partnership. If the Partnership elects to issue Class A shares, it would cancel the tendered Class B shares and hold the OpCo common units with the other OpCo common units it previously held, since the number of Class A shares issued must at all time equal the number of OpCo common units held by the Partnership. Since the Partnership would be holding additional OpCo common units, the net income attributable to Class A shares would proportionately increase, resulting in no change to net income per share for the three months ended February 28, 2017 and February 29, 2016, respectively. In addition, there were no potentially dilutive securities (including any stock options, restricted stock and restricted stock units) for the three months ended February 28, 2017 and February 29, 2016, respectively. Accordingly, basic and diluted net income per share for the three months ended February 28, 2017 and February 29, 2016, respectively was as follows: Three Months Ended February 28, February 29, (in thousands, except per share amounts) 2017 2016 Basic net income per share: Numerator: Net income attributable to Class A shareholders $ 861 $ 5,308 Denominator: Basic weighted-average shares 28,073 20,007 Basic net income per share $ 0.03 $ 0.27 Diluted net income per share: Numerator: Net income attributable to Class A shareholders $ 861 $ 5,308 Add: Additional net income attributable to Class A shares due to increased percentage ownership in OpCo, net of tax, from the conversion of Class B shares 514 4,112 $ 1,375 $ 9,420 Denominator: Basic weighted-average shares 28,073 20,007 Effect of dilutive securities: Class B shares (1) 15,500 15,500 Diluted weighted-average shares 43,573 35,507 Diluted net income per share $ 0.03 $ 0.27 (1) Up to the amount of OpCo common units held by Sponsors

Related Parties

Related Parties	3 Months Ended
	Feb. 28, 2017
Related Party Transactions [Abstract]
Related Parties	Note 12. Related Parties Management Services Agreements Immediately prior to the completion of the IPO on June 24, 2015, the Partnership, together with the General Partner, OpCo and Holdings, entered into similar but separate MSAs with affiliates of each of the Sponsors (each, a “Service Provider”). Under the MSAs, the Service Providers provide or arrange for the provision of certain administrative and management services for the Partnership and certain of its subsidiaries, including managing the Partnership’s day-to-day affairs, in addition to those services that are provided under existing O&M agreements and AMAs between affiliates of the Sponsors and certain of the subsidiaries of the Partnership. In August 2015, the First Solar MSA and the SunPower MSA were amended to adjust the annual management fee payable to each respective Service Provider. Under the First Solar MSA, OpCo pays an annual management fee of $0.6 million to the First Solar Service Provider. Under the SunPower MSA, OpCo pays an annual management fee of $1.1 million to the SunPower Service Provider. These payments are subject to annual adjustments for inflation. On January 20, 2017, the parties thereto amended the SunPower MSA to include Kingbird Solar, LLC and the Kingbird Project Entities under certain aspects of SunPower’s scope of managerial services effective April 30, 2016 in return for the associated AMA fee payable by First Solar Asset Management, LLC. Costs incurred for these services were $0.4 million for both the three months ended February 28, 2017 and February 29, 2016. EPC Agreements Various projects are designed, engineered, constructed and commissioned pursuant to EPC agreements with affiliates of the Sponsors, which may include a 2- to 10-year system warranty against defects in materials, construction, fabrication and workmanship, and in some cases, may include a 25-year power and product warranty on certain modules. As of February 28, 2017, all of the projects contributed by the Sponsors on the date of the IPO, along with the Henrietta Project, the Hooper Project, the Kern Phase 1(b) Assets, Kern Phase 2(a) Assets, the Kingbird Project, the Macy’s Maryland Project and the Stateline Project have achieved COD. The Kern Phase 1(a) Assets and Kern Phase 2(b) Assets are construction-in-progress as of February 28, 2017 and expected to achieve COD in June 2017. SunPower as the EPC provider is required to complete the Kern Phase 1(a) Assets and the Kern Phase 2(b) Assets and pursuant to the Omnibus Agreement, all the associated costs to complete the Kern Phase 1(a) Assets and the Kern Phase 2(b) Assets are obligations of SunPower. O&M Agreements and Asset Management Agreements The Project Entities and certain other subsidiaries have entered into O&M agreements and AMAs with affiliates of the Sponsors, as applicable (except where such persons are otherwise subject to O&M agreements or AMAs with unaffiliated third parties). Under the terms of the O&M agreements and the AMAs, such affiliates have agreed to provide a variety of operation, maintenance and asset management services, and certain performance warranties or availability guarantees, to the subsidiaries of the Partnership in exchange for annual fees, which are subject to certain adjustments. Costs incurred for O&M and AMA services were $1.5 million and $1.0 million for the three months ended February 28, 2017 and February 29, 2016, respectively. Omnibus Agreement The Partnership has entered into the Omnibus Agreement with its Sponsors, the General Partner, OpCo and Holdings. The material provisions of the Omnibus Agreement are as follows: (a) each Sponsor was granted an exclusive right to perform certain services not otherwise covered by an O&M agreement or an AMA on behalf of the Project Entities contributed by such Sponsor; (b) with respect to any project in the Portfolio that had not achieved commercial operation as of the date contributed to the Partnership, the Sponsor who contributed such project agreed to pay to OpCo all costs required to complete such project, as well as certain liquidated damages in the event such project fails to achieve operability pursuant to an agreed schedule (subject to certain adjustments); (c) with respect to the Quinto Project and the North Star Project, the Sponsor who contributed such project agreed to pay to OpCo the difference, if any, between the amount of network upgrade refunds projected to be received in respect of such Sponsor’s contributed project at the time of the IPO and the amount of network upgrade refunds projected to be received given the actual amount of upgrade costs incurred in respect of such project; (d) each Sponsor agreed to certain undertakings on the part of its affiliates who are members of the Project Entities or who provide asset management, construction, operating and maintenance and other services to the Project Entities contributed by such Sponsor; (e) to the extent a Sponsor continues to post credit support on behalf of a Project Entity after it has been contributed to OpCo, OpCo agreed to reimburse such Sponsor upon any demand or draw under such credit support, and the Sponsor agreed to maintain such support pursuant to the applicable underlying contractual or regulatory requirements; (f) each Sponsor agreed to indemnify OpCo for any costs it incurs with respect to certain tax-related events and events in connection with tax equity financing arrangements; and (g) the parties agreed to a mutual undertaking regarding confidentiality and use of names, trademarks, trade names and other insignias. The schedules of the Omnibus Agreement are amended in connection with each project acquisition to include the solar power systems acquired effective the closing date of such acquisition. During the three months ended February 28, 2017, the Partnership received $0.1 million in indemnity payments from the Sponsors for the delay in commercial operations of the Kern Phase 1(a) Assets. During the three months ended February 29, 2016, the Partnership received $13.9 million related to the shortfall associated with the network upgrade refunds and test energy projected to be received. Promissory Notes On November 25, 2015, OpCo issued a short-term promissory note to First Solar in the principal amount of $2.0 million (the “Short-term Note”), in exchange for First Solar’s loan of such amount to OpCo. Upon the receipt of certain payments by the Solar Gen 2 Project Entity from SDG&E under the power purchase agreement between the Solar Gen 2 Project Entity and SDG&E, which had been previously withheld pending completion of an administrative requirement (each, a “Specified Payment”), OpCo was obligated to repay a portion of the principal amount of the Short-term Note equal to such Specified Payment and the unpaid balance of all interest accrued under the Short-term Note to and including the date of such repayment. Interest under the Short-term Note accrued at a rate of 1% on the portion of the principal of the Short-term Note equal to the amount of each Specified Payment from the date SDG&E remitted such payment to the Solar Gen 2 Project Entity through the date that OpCo repaid such amount to First Solar as described above. OpCo is permitted to prepay the Short-term Note at any time without penalty or premium. On December 30, 2016, OpCo repaid the Short-term Note to First Solar. In connection with the closing of the Stateline Acquisition on December 1, 2016, OpCo issued the Stateline Promissory Note to First Solar in the principal amount of $50.0 million. Please read “—Note 7— Debt and Financing Obligations” for further details. Purchase and Sale Agreements On November 11, 2016, OpCo entered into the Stateline Purchase Agreement with First Solar and First Solar Asset Management, LLC pursuant to which OpCo agreed to purchase an interest in the Stateline Project, as further described above in “—Note 3—Investment in Unconsolidated Affiliates.” Effective December 1, 2016, OpCo acquired Stateline Holdings from First Solar for a total purchase price of $329.5 million (before consideration of acquisition-related costs). On January 26, 2016, OpCo entered into the Kern Purchase Agreement with SunPower pursuant to which OpCo agreed to purchase an interest in the Kern Project, as further described above in “—Note 2—Business Combinations.” Effective January 26, 2016, a subsidiary of OpCo acquired from SunPower all of the class B limited liability company interests of the Kern Class B Partnership. Pursuant to the Kern Purchase Agreement, the purchase price for the Kern Project will be paid by OpCo when each phase of the project reaches “mechanical completion.” In addition, on January 22, 2016, a subsidiary of the Kern Class B Partnership entered into a tax equity financing facility with a third-party investor, which allocates to OpCo a certain share of cash flows from the Kern Project pursuant to a specified distribution waterfall. Purchase price payments of up to approximately $30.0 million will be funded by the tax equity investor’s capital contributions, of which $0.9 million, $1.8 million, $1.3 million, $6.7 million and $8.2 million was paid on January 22, 2016, September 9, 2016, November 30, 2016, December 14, 2016 and February 24, 2017, respectively, and the remaining capital contribution balance of up to $11.1 million will be made when the Kern Project’s phases meet certain construction milestones and will be transferred to affiliates of SunPower for the remaining purchase price payments. First Solar ROFO Agreement Pursuant to the First Solar ROFO Agreement, First Solar previously granted to OpCo a right of first offer to purchase certain solar energy generating facilities for a period of five years. Such solar projects included the 179 MW Switch Station solar generation project in Nevada (“Switch Station”). On February 13, 2017, OpCo waived the 45-day negotiation period under the First Solar ROFO Agreement with respect to Switch Station; following such waiver, First Solar has the right to offer and sell Switch Station to a third party, in accordance with the terms of the First Solar ROFO Agreement. SunPower ROFO Agreement On February 13, 2017, OpCo entered into the Second Amendment and Waiver to Right of First Offer Agreement (the “Waiver”) with SunPower. Pursuant to SunPower ROFO Agreement, SunPower previously granted to OpCo a right of first offer to purchase certain solar energy generating facilities for a period of five years. Such solar projects included the 100 MW El Pelicano solar generation project in Chile (“El Pelicano”). Pursuant to the Waiver, OpCo waived its rights under the ROFO Agreement with respect to El Pelicano. The Waiver also contains customary representations, warranties and agreements of OpCo and SunPower. Maryland Solar Lease Arrangement The Maryland Solar Project Entity has leased the Maryland Solar Project to an affiliate of First Solar. Under the arrangement, First Solar’s affiliate is obligated to pay a fixed amount of rent that is set based on the expected operations of the plant. The lease agreement will expire on December 31, 2019 (unless terminated earlier pursuant to its terms). FirstEnergy Solutions Corp. (“FirstEnergy”), the Partnership’s offtake counterparty with respect to the Maryland Solar Project, had its credit rating downgraded multiple times in 2016. As of January 23, 2017, the credit rating of FirstEnergy was Caa1 and CCC+ by Moody’s Investors Service and Standard & Poor’s Ratings Services, respectively, both of which are significantly below investment grade. In addition, Standard & Poor’s Ratings Services placed FirstEnergy on CreditWatch with negative implications, based on a $1.51 billion pretax impairment charge that the company’s competitive business will incur from the deactivation of several coal units. In November 2016, FirstEnergy Corp., the parent of FirstEnergy, announced a strategic review of its competitive business, pursuant to which the company would seek to move away from competitive markets. FirstEnergy’s annual report on Form 10-K for the year ended December 31, 2016 reported a substantial uncertainty as to their ability to continue as a going concern. While their credit rating has not subsequently been downgraded they remain on Standard & Poor’s Ratings Services under CreditWatch. As of February 28, 2017, FirstEnergy is current with respect to the payments due under the PPA for the Maryland Solar Project. As further described Part III, Item 13. “Certain Relationships and Related Transactions, and Director Independence—Agreements with our Sponsors—Maryland Solar Lease Arrangement” in the 2016 10-K, First Solar’s affiliate is obligated under the Maryland Solar lease arrangement to pay a fixed amount of rent that is set based on the expected operations of the plant. Such lease agreement will terminate upon any termination of the PPA for the Maryland Solar Project or the site ground lease. Pursuant to the PPA for the Maryland Solar Project, a FirstEnergy bankruptcy would be an event of default under the PPA, permitting (subject to applicable law) the termination of the PPA. Upon any such early termination of the lease agreement, First Solar’s affiliate is obligated to return the facility in its then-current condition and location to the Partnership, without any warranties, and no rent shall thereafter be payable by such First Solar affiliate. In the event that the PPA was terminated and First Solar were to subsequently terminate the Maryland Solar Lease Agreement, the Maryland Solar Project would have no agreement through which to sell the energy that it produces, which equates to approximately $8.0 million in annual revenue.

Income Taxes

Income Taxes	3 Months Ended
	Feb. 28, 2017
Income Tax Disclosure [Abstract]
Income Taxes	Note 13. Income Taxes The provision for income taxes differed from the amount computed by applying the statutory U.S. federal rate of 35% primarily due to the tax impact of equity in earnings, the tax impact of noncontrolling interest, and state tax rates (net of federal benefit) in various jurisdictions, most significantly California. The Partnership’s financial reporting year-end is November 30 while its tax year-end is December 31. The Partnership has elected to base the tax provision on the financial reporting year; therefore, since the 2017 financial reporting year is December 1, 2016 through November 30, 2017, the taxable income (loss) included in the 2017 tax provision is for the tax year ended December 31, 2016. The provision accrued at the financial reporting year-end will be a discrete period computation, and the tax credits and permanent differences recognized in that accrual will be those generated between the tax year-end date and the financial reporting year-end date. With the exception of minimum state income and franchise tax payments, any amounts recorded for income tax provision (benefit) represent deferred income taxes being provided on the net income before taxes of OpCo, a non-taxable partnership, which is allocated to the Partnership. Although organized as a limited partnership under state law, the Partnership elected to be treated as a corporation for U.S. federal income tax purposes. Accordingly, the Partnership is subject to U.S. federal income taxes at regular corporate rates on its net taxable income, and distributions it makes to holders of its Class A shares will be taxable as ordinary dividend income to the extent of its current and accumulated earnings and profits as computed for U.S. federal income tax purposes. The Partnership accounts for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the unaudited condensed consolidated financial statements. Under this method, deferred tax assets and liabilities are determined on the basis of the differences between the financial statement and tax bases of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. Valuation allowances are provided against deferred tax assets when management cannot conclude that it is more likely than not that some portion or all deferred tax assets will be realized. The Partnership recognizes deferred tax assets to the extent that it believes these assets are more likely than not to be realized. In making such a determination, the Partnership considers all available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax-planning strategies, and results of recent operations. If the Partnership determines that it would be able to realize its deferred tax assets in the future in excess of their net recorded amount, it would make an adjustment to the deferred tax asset valuation allowance, which would reduce the provision for income taxes. The Partnership records uncertain tax positions on the basis of a two-step process whereby (1) it determines whether it is more likely than not that the tax positions will be sustained on the basis of the technical merits of the position and (2) for those tax positions that meet the more-likely-than-not recognition threshold, the Partnership recognizes the largest amount of tax benefit that is more than 50 percent likely to be realized upon ultimate settlement with the related tax authority.

Segment Information

Segment Information	3 Months Ended
	Feb. 28, 2017
Segment Reporting [Abstract]
Segment Information	Note 14. Segment Information The Partnership manages its Portfolio as one segment that operates a portfolio of solar energy generation systems. It operates as a single reportable segment based on the “management” approach. Long-lived assets consisting of property and equipment, net, were located in the United States. All operating revenues for the three months ended February 28, 2017 and February 29, 2016 were from customers located in the United States. The following customers each comprised 10% or more of our total revenue for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, Customers 2017 2016 Southern California Edison 29.5 % 44.2 % First Solar 12.8 % 18.1 % Southern California Public Power Authority 10.7 % * *Total revenue to these customers were less than 10% of our total revenue for the period.

Subsequent Events

Subsequent Events	3 Months Ended
	Feb. 28, 2017
Subsequent Events [Abstract]
Subsequent Events	Note 15. Subsequent Events On March 23, 2017, our general partner’s board of directors declared a cash distribution for our Class A shares of $0.2565 per share for the first quarter of 2017. Our general partner’s board of directors declared a corresponding cash distribution for OpCo’s common and subordinated units, which includes all common and subordinated units held by First Solar and SunPower. The first quarter distribution will be paid on April 14, 2017 to shareholders and unitholders of record as of April 4, 2017. Pursuant to the First Solar ROFO Agreement, First Solar previously granted to OpCo a right of first offer to purchase certain solar energy generating facilities for a period of five years. Such solar projects included the 40 MW Cuyama solar generation project in California (“Cuyama”) and the 280 MW California Flats solar generation project in California (“California Flats”). On April 3, 2017, First Solar offered the Cuyama and California Flats projects to OpCo in accordance with the terms of the First Solar ROFO Agreement. On April 5, 2017, First Solar notified our general partner’s board of directors of its intention to explore alternatives related to its interests in the Partnership. Following such announcement, SunPower also notified our general partner’s board of directors that it is exploring alternatives related to its interests in the Partnership, including but not limited to seeking a potential new partner in the Partnership.

Description of Business (Polici

Description of Business (Policies)	3 Months Ended
	Feb. 28, 2017
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The unaudited condensed consolidated financial statements are prepared in accordance with U.S. GAAP, and include the accounts of the Partnership, and all of its subsidiaries, as appropriate under consolidation accounting guidelines. The year-end condensed consolidated balance sheet data was derived from the audited financial statements, but does not include all disclosures required by U.S. GAAP. Investments in unconsolidated affiliates in which the Partnership has less than a controlling interest are accounted for using the equity method of accounting. All significant inter-entity accounts and transactions have been eliminated in consolidation. In the opinion of management, the accompanying unaudited condensed consolidated financial statements include all adjustments (consisting of normal, recurring items) necessary to state fairly its financial position, results of operations and cash flows for the periods presented. The unaudited condensed consolidated financial statements should be read in conjunction with the accounting policies previously disclosed in Part II, Item 8. “Financial Statements and Supplementary Data—Notes to Consolidated Financial Statements—Note 1—Description of Business” and “—Note 2—Summary of Significant Accounting Policies” of the 2016 10-K. Interim results are not necessarily indicative of results for a full year.
Management Estimates	Management Estimates The preparation of the unaudited condensed consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the unaudited condensed consolidated financial statements and accompanying notes. Significant estimates in these unaudited condensed consolidated financial statements include the assumptions and methodology underlying allowances for doubtful accounts related to accounts receivable and financing receivables; estimates of future cash flows and economic useful lives of property and equipment; the fair value and residual value of leased solar power systems; fair value of financial instruments; fair value of acquired assets and liabilities; valuation of certain accrued liabilities such as accrued system output performance warranty and AROs; and income taxes including the related valuation allowance. Actual results could materially differ from those estimates.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In January 2017, the FASB issued an update to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions of assets or businesses. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2019 and is applied prospectively. The Partnership is evaluating the impact of this standard on its and disclosures. In October 2016, the FASB issued an update which amends the guidance on related parties that are under common control. Specifically, this update requires that a single decision maker consider indirect interests held by related parties under common control on a proportionate basis in a manner consistent with its evaluation of indirect interests held through other related parties. That is, the single decision maker does not consider indirect interests held through related parties as equivalent to direct interests in determining whether it meets the economics criterion to be a primary beneficiary. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2018. Early adoption is permitted, including adoption in an interim period. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In October 2016, the FASB issued an update which eliminates a prior exception and now requires an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory, such as property and equipment, when such transfer occurs. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2020 and shall be applied on a modified retrospective basis through a cumulative–effect adjustment directly to retained earnings as of the beginning of the period of adoption. Early adoption is permitted. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In August 2016, the FASB issued an update to the statement of cash flows guidance, which addresses eight specific cash flow issues with the objective of reducing the existing diversity in practice. One identified cash flow issue relates to distributions received from equity method investees whereby the reporting entity should make an accounting policy election to classify distributions received from equity method investees using either the cumulative earnings approach or the nature of the distribution approach. This new guidance becomes effective for the Partnership in the first quarter of fiscal 2018 and is applied retrospectively. Early adoption is permitted, including adoption in an interim period. The Partnership is evaluating the change in accounting policy from the cumulative earnings approach to the nature of the distribution approach and the impact on its unaudited condensed consolidated statements of cash flows and disclosures. In March 2016, the FASB issued an update to the equity method investments guidance, which eliminates the requirement that an entity retroactively adopt the equity method of accounting if an investment qualifies for use of the equity method as a result of an increase in the level of ownership or degree of influence. The update requires that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. This new guidance will be effective for the Partnership beginning on December 1, 2017 using a modified retrospective approach. The modified retrospective approach includes a number of optional practical expedients that entities may elect to apply. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In February 2016, the FASB issued an update to the lease accounting guidance, which requires entities to begin recording assets and liabilities arising from substantially all leases on the balance sheet. The new guidance will also require significant additional disclosures about the amount, timing and uncertainty of cash flows from leases. This new guidance will be effective for the Partnership beginning on December 1, 2019 using a modified retrospective approach. The modified retrospective approach includes a number of optional practical expedients that entities may elect to apply. The Partnership is evaluating the impact of this standard on its unaudited condensed consolidated financial statements In August 2014, the FASB issued an update to the standards to require management to evaluate whether there are conditions and events that raise substantial doubt about the Partnership’s ability to continue as a going concern within one year after the date the financial statements are issued, and to provide related disclosures. The Partnership adopted the new guidance beginning on December 1, 2016 and the impact of this standard on its unaudited condensed consolidated financial statements and disclosures is not material. In May 2014, the FASB issued a new revenue recognition standard based on the principle that revenue is recognized to depict 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 and services. The FASB has issued several updates to the standard which (i) clarify the application of the principal versus agent guidance; (ii) clarify the guidance relating to performance obligations and licensing; and (iii) clarify assessment of the collectability criterion, presentation of sales taxes, measurement date for non-cash consideration and completed contracts at transaction. The new revenue recognition standard, amended by the updates, becomes effective for the Partnership in the first quarter of fiscal 2019 and is to be applied retrospectively using one of two prescribed methods. Early adoption is permitted. The Partnership is currently evaluating and considering the possibility of early adoption of the new standard effective December 1, 2017. The Partnership’s ability to early adopt, potentially using the modified retrospective method, is dependent on process, internal control and system readiness and a complete evaluation of all the disclosures required under the new standard. While the Partnership is continuing to assess all potential impacts of the standard, it currently believes the impact on its unaudited condensed consolidated financial statements is not material because over 90% of the Partnership’s total revenue for all periods is comprised of lease revenue, which is substantially unchanged under the new standard. Other than as described above, there has been no issued accounting guidance not yet adopted by the Partnership that it believes is material or potentially material to its unaudited condensed consolidated financial statements

Description of Business (Tables

Description of Business (Tables)	3 Months Ended
	Feb. 28, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Summary of Assets Comprise the Portfolio	The following table provides an overview of the assets that comprise the Portfolio as of February 28, 2017: Project Location Commercial Operation Date(1) MW(ac) (2) Counterparty Remaining Term of Offtake Agreement (in years)(3) Utility Maryland Solar Maryland February 2014 20 FirstEnergy Solutions 16.1 Solar Gen 2 California November 2014 150 San Diego Gas & Electric 22.7 Lost Hills Blackwell California April 2015 32 City of Roseville/Pacific Gas and Electric 26.8(4) North Star California June 2015 60 Pacific Gas and Electric 18.3 RPU California September 2015 7 City of Riverside 23.6 Quinto California November 2015 108 Southern California Edison 18.8 Hooper Colorado December 2015 50 Public Service Company of Colorado 18.8 Kingbird California April 2016 40 Southern California Public Power Authority(5) 19.2 Henrietta California October 2016 102 Pacific Gas and Electric 19.6 Stateline California August 2016 300 Southern California Edison 19.5 Commercial & Industrial UC Davis California September 2015 13 University of California 18.5 Macy's California California October 2015 3 Macy's Corporate Services 18.7 Macy’s Maryland Maryland December 2016 5 Macy's Corporate Services 19.8 Kern(6) California June 2017 16 Kern High School District 19.8(7) Residential Portfolio U.S. – Various June 2014 39 Approx. 5,900 homeowners(8) 15.5(9) Total 945 (1) For the Macy’s California Project, the Macy’s Maryland Project, and the Kern Project, COD represents the first date on which all of the solar generation systems within each of the Macy’s California Project, the Macy’s Maryland Project and the Kern Project, respectively, have achieved or are expected to achieve COD. For the Residential Portfolio, COD represents the first date on which all of the residential systems within the Residential Portfolio have achieved COD. (2) The MW for the projects in which the Partnership owns less than a 100% interest or in which the Partnership is the lessor under any sale-leaseback financing are shown on a gross basis. Please read Part I, Item 1. “Business—Tax Equity Financing” of our 2016 10-K for a description of our tax equity structures, which such description reflects the Partnership’s ownership on a net basis. (3) Remaining term of offtake agreement is measured from the later of February 28, 2017 or the expected COD of the applicable project. (4) Remaining term comprised of 1.8 years on a PPA with the City of Roseville, California, followed by a 25-year PPA with PG&E starting in 2019. (5) The Kingbird Project is subject to two separate PPAs with member cities of the Southern California Public Power Authority. (6) OpCo’s acquisition of the Kern Project is being effectuated in five phases, with the closing of the first phase, reflecting a nameplate capacity of approximately 3 MW, having occurred on January 26, 2016, the closing of the second phase, reflecting a nameplate capacity of approximately 5 MW, having occurred on September 9, 2016, the closing of the third phase, reflecting a nameplate capacity of approximately 5 MW, having occurred on November 30, 2016, the closing of the fourth phase, reflecting a nameplate capacity of approximately 3 MW, having closed on February 24, 2017, and the closing of the Kern Phase 2(c) Assets to occur in the future. (7) Remaining term is the weighted average duration of the first four phases of the Kern Project. (8) Comprised of the approximately 5,900 solar installations located at homes in Arizona, California, Colorado, Hawaii, Massachusetts, New Jersey, New York, Pennsylvania and Vermont, that are held by the Residential Portfolio Project Entity and have an aggregate nameplate capacity of 39 MW. (9) Remaining term is the weighted average duration of all of the residential leases, in each case measured from February 28, 2017.

Business Combinations (Tables)

Business Combinations (Tables)	3 Months Ended
	Feb. 28, 2017
Kern Acquisition
Purchase Allocation for Acquired Assets and Liabilities	The Kern Phase 1(a) Acquisition, the Kern Phase 1(b) Acquisition, the Kern Phase 2(a) Acquisition and the Kern Phase 2(b) Acquisition qualify as business combinations and the Partnership accounts for the transactions under the acquisition method. The purchase allocation of the identifiable assets acquired, liabilities assumed and noncontrolling interests of the Kern Phase 1(a) Assets, the Kern Phase 1(b) Assets, the Kern Phase 2(a) Assets and the Kern Phase 2(b) Assets are disclosed in the following table. Fair Value Kern Phase 1(a) Kern Phase 1(b) Kern Phase 2(a) Kern Phase 2(b) (in thousands) Assets Assets Assets Assets Property and equipment $ 9,510 $ 18,856 $ 14,873 $ 11,872 Related party payable (3,435 ) (7,123 ) (4,504 ) (4,287 ) Asset retirement obligation (322 ) (785 ) (623 ) (493 ) Noncontrolling interest (866 ) (1,794 ) (1,332 ) (1,078 ) Net assets acquired $ 4,887 $ 9,154 $ 8,414 $ 6,014

Investment in Unconsolidated 26

Investment in Unconsolidated Affiliates (Tables)	3 Months Ended
	Feb. 28, 2017
Equity Method Investments And Cost Method Investments [Abstract]
Partnerships Investments Unconsolidated Affiliates	The following table summarizes the activity of the Partnership’s investments in its unconsolidated affiliates during the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Balance at the beginning of the period $ 475,078 $ 352,070 Investments in its unconsolidated affiliates during the period 330,027 — Equity in earnings in unconsolidated affiliates (1) 606 405 Distributions from unconsolidated affiliates (17,711 ) (6,278 ) Balance at the end of the period $ 788,000 $ 346,197 (1) The net income (loss) used to determine the Partnership’s equity in earnings of unconsolidated affiliates reflects adjustments pursuant to the equity method of accounting, including the amortization of basis differences resulting from the Partnership’s proportionate share of certain equity method investees’ net assets exceeding their carrying values.
Summary of Financial Information	The following table presents summarized financial information of SG2 Holdings, North Star Holdings, Lost Hills Blackwell Holdings, Henrietta Holdings and Stateline Holdings as derived from the unaudited condensed consolidated financial statements of such entities for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Summary statements of operations information: Revenue $ 19,616 $ 8,650 Operating expenses 26,393 10,924 Net loss (7,759 ) (2,170 )

Balance Sheet Components (Table

Balance Sheet Components (Tables)	3 Months Ended
	Feb. 28, 2017
Balance Sheet Related Disclosures [Abstract]
Schedule of Financing Receivables	The Partnership’s net investment in sales-type leases presented in “Accounts receivable and short-term financing receivables, net” and “Long-term financing receivables, net” on the unaudited condensed consolidated balance sheets is as follows: As of February 28, November 30, (in thousands) 2017 2016 Minimum lease payment receivable, net (1) $ 98,684 $ 100,161 Unguaranteed residual value 12,908 12,926 Less: unearned income (29,801 ) (30,557 ) Net financing receivables $ 81,791 $ 82,530 Short-term financing receivables, net (2) $ 2,559 $ 2,516 Long-term financing receivables, net $ 79,232 $ 80,014 (1) Allowance for losses on financing receivables was $0.6 million and $0.7 million as of February 28, 2017 and November 30, 2016, respectively. (2) Accounts receivable and short-term financing receivables, net on the unaudited condensed consolidated balance sheets includes other trade accounts receivable of $3.1 million and $2.9 million, as of February 28, 2017 and November 30, 2016, respectively.
Schedule of Current and Non-Current Assets	Current and Non-current Assets As of February 28, November 30, (in thousands) 2017 2016 Prepaid expense and other current assets Reimbursable network upgrade costs (1) $ 7,496 $ 13,870 Other current assets (2) 1,873 1,875 Total $ 9,369 $ 15,745 Property and equipment, net Utility solar power systems 613,293 578,817 Leased solar power systems 137,410 137,475 Land 1,020 1,020 Construction-in-progress (3) 15,210 36,981 $ 766,933 $ 754,293 Less: accumulated depreciation (40,744 ) (34,161 ) Total $ 726,189 $ 720,132 Other long-term assets Reimbursable network upgrade costs (1) $ 22,301 $ 21,781 Intangible assets (4) 1,647 1,754 Derivative financial instruments 1,567 897 Total $ 25,515 $ 24,432 (1) For the Kingbird Project and the Quinto Project, the construction costs related to the network upgrade of a transmission grid belonging to a utility company are reimbursable by that utility company over five years from the date the project reached commercial operation. (2) Other current assets included $0.4 million due from SunPower related to system output performance warranties and system repairs in connection with $0.1 million of system output performance warranty accrual and $0.3 million of system repairs accrual recorded in the “Accounts payable and other current liabilities” line item on the unaudited condensed consolidated balance sheets as of February 28, 2017. Similarly, other current assets included $0.5 million due from SunPower related to system output performance warranties and system repairs in connection with $0.2 million of system output performance warranty accrual and $0.3 million of system repairs accrual recorded in the “Accounts payable and other current liabilities” line item on the consolidated balance sheet as of November 30, 2016. (3) Construction-in-progress is the project assets related to the Kern Phase 1(a) Assets and Kern Phase 2(b) Assets. (4) Intangible assets represents a customer contract intangible that is amortized on a straight-line basis beginning on COD through the contract term end date of December 31, 2020, of which $0.1 million and zero reduced operating revenues in the three months ended February 28, 2017 and February 29, 2016, respectively.
Schedule of Current Liabilities	Current Liabilities As of February 28, November 30, (in thousands) 2017 2016 Accounts payable and other current liabilities Trade and accrued accounts payable $ 1,313 $ 1,089 Related party payable (1) 7,006 20,653 System output performance warranty 138 196 Residential lease system repairs accrual 269 331 Other short-term liabilities 2,418 1,502 Total $ 11,144 $ 23,771 (1) Related party payable on the unaudited condensed consolidated balance sheets as of February 28, 2017 consists of (i) $5.8 million related to the purchase price payable to SunPower, which will be funded by tax equity investors for the Kern Phase 1(a) Acquisition and the Kern Phase 2(b) Acquisition; (ii) $0.6 million related to accrued distribution to tax equity investors; and (iii) $0.6 million for accounts payable to related parties associated with O&M, AMA and MSA fees owed to the Sponsors. Related party payable on the consolidated balance sheets as of November 30, 2016 consists of (i) $19.5 million related to the purchase price payable to SunPower for the Kern Phase 1(a) Acquisition, the Kern Phase 1(b) Acquisition, the Kern Phase 2(a) Acquisition and the Macy’s Maryland Acquisition; (ii) $1.0 million related to accrued distribution to tax equity investors; and (iii) $0.1 million for accounts payable to related parties associated with O&M, AMA and MSA fees owed to the Sponsors.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	3 Months Ended
	Feb. 28, 2017
Total Minimum Lease and Easement Commitments under Land use Agreements	The total minimum lease and easement commitments at February 28, 2017 under these land use agreements are as follows: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total Land use payments $ 871 $ 1,329 $ 1,686 $ 1,742 $ 1,782 $ 56,249 $ 63,659
Summary of Asset Retirement Obligations	The following table summarizes ARO activity for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Balance at the beginning of the period $ 13,448 $ 9,992 ARO assumed in acquisition 493 547 Accretion expense 171 119 Revisions to ARO during the period 17 — Balance at the end of the period $ 14,129 $ 10,658
Solar Power System Performance Warranty
Summary of Accrued Warranty Activity	The following table summarizes accrued system output performance warranty activity for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, (in thousands) 2017 2016 Balance at the beginning of the period $ 196 $ 237 Settlements during the period (29 ) (76 ) Adjustments during the period (29 ) 65 Balance at the end of the period $ 138 $ 226

Lease Agreements and Power Pu29

Lease Agreements and Power Purchase Agreements (Tables)	3 Months Ended
	Feb. 28, 2017
Leases [Abstract]
Minimum Future Rental Receipts on Operating Leases	The following table presents the Partnership’s minimum future rental receipts on operating leases (including the lease agreement for the Maryland Solar Project and the residential lease portfolio) placed in service as of February 28, 2017: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total Minimum future rentals on residential operating leases placed in service (1) $ 2,779 $ 3,723 $ 3,743 $ 3,765 $ 3,787 $ 42,563 $ 60,360 Maryland Solar lease 4,249 5,173 4,912 — — — 14,334 Total operating leases $ 7,028 $ 8,896 $ 8,655 $ 3,765 $ 3,787 $ 42,563 $ 74,694 (1) Minimum future rentals on operating leases placed in service do not include contingent rentals that may be received from customers under agreements that include performance-based incentives and executory costs.
Future Maturities of Net Financing Receivables for Sales-type Leases	As of February 28, 2017, future maturities of net financing receivables for sales-type leases are as follows: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total Scheduled maturities of minimum lease payments receivable (1) $ 4,196 $ 5,681 $ 5,768 $ 5,860 $ 5,955 $ 71,224 $ 98,684 (1) Minimum future rentals on sales-type leases placed in service do not include contingent rentals that may be received from customers under agreements that include performance-based incentives and executory costs.
Schedule of Firm Sales under SREC Sales Agreement	As of February 28, 2017, firm sales under the SREC Sales Agreement are as follows: (in thousands) 2017 (remaining nine months) 2018 2019 2020 2021 Thereafter Total SREC sales $ 586 $ 781 $ 781 $ 781 $ 195 $ — $ 3,124

Debt and Financing Obligations

Debt and Financing Obligations (Tables)	3 Months Ended
	Feb. 28, 2017
Debt Disclosure [Abstract]
Summary of the Partnership’s Debt Obligations	The following table summarizes the Partnership’s debt obligations: February 28, 2017 November 30, 2016 (in thousands) Amount Interest Rate Amount Interest Rate Term loan due June 2020 $ 300,000 2.78 % $ 300,000 2.61 % Incremental term loan due June 2020 250,000 2.78 % — N/A Delayed draw term loan facility due June 2020 25,000 2.78 % 25,000 2.61 % Revolving credit facility due June 2020 89,000 2.78 % 63,000 2.61 % Stateline Promissory Note due December 2020 50,000 4.00 % — N/A Less: debt issuance costs (3,327 ) N/A (3,564 ) N/A Total $ 710,673 $ 384,436

Fair Value (Tables)

Fair Value (Tables)	3 Months Ended
	Feb. 28, 2017
Fair Value Disclosures [Abstract]
Summary of Assets and Liabilities Measured at Estimated Fair Value on Recurring basis	The following table presents the Partnership’s assets and liabilities measured at estimated fair value on a recurring basis, categorized in accordance with the fair value hierarchy: February 28, 2017 November 30, 2016 (in thousands) Level 2 Total Level 2 Total Assets Derivative financial instruments $ 1,567 $ 1,567 $ 897 $ 897 Total assets $ 1,567 $ 1,567 $ 897 $ 897

Noncontrolling Interests (Table

Noncontrolling Interests (Tables)	3 Months Ended
	Feb. 28, 2017
Noncontrolling Interest [Abstract]
Schedule Of Non Controlling Interest Balance by Entity	The following table presents the noncontrolling interest balances by entity, reported in shareholders’ equity in the unaudited condensed consolidated balance sheets as of February 28, 2017 and November 30, 2016: As of February 28, November 30, (in thousands) 2017 2016 First Solar $ 233,847 $ 238,210 SunPower 305,644 311,327 Tax equity investors 50,573 40,794 Total $ 590,064 $ 590,331

Shareholders_ Equity (Tables)

Shareholders’ Equity (Tables)	3 Months Ended
	Feb. 28, 2017
Stockholders Equity Note [Abstract]
Summary of Partnership Shares Outstanding	The following shares of the Partnership were outstanding as of November 30, 2016, respectively: As of Shares February 28, 2017 November 30, 2016 Shareholder Class A shares 28,076,907 28,072,680 Public Class B shares 22,116,925 22,116,925 First Solar Class B shares 28,883,075 28,883,075 SunPower Total shares outstanding 79,076,907 79,072,680

Net Income Per Share (Tables)

Net Income Per Share (Tables)	3 Months Ended
	Feb. 28, 2017
Earnings Per Share [Abstract]
Summary of Net Income Per Share	Accordingly, basic and diluted net income per share for the three months ended February 28, 2017 and February 29, 2016, respectively was as follows: Three Months Ended February 28, February 29, (in thousands, except per share amounts) 2017 2016 Basic net income per share: Numerator: Net income attributable to Class A shareholders $ 861 $ 5,308 Denominator: Basic weighted-average shares 28,073 20,007 Basic net income per share $ 0.03 $ 0.27 Diluted net income per share: Numerator: Net income attributable to Class A shareholders $ 861 $ 5,308 Add: Additional net income attributable to Class A shares due to increased percentage ownership in OpCo, net of tax, from the conversion of Class B shares 514 4,112 $ 1,375 $ 9,420 Denominator: Basic weighted-average shares 28,073 20,007 Effect of dilutive securities: Class B shares (1) 15,500 15,500 Diluted weighted-average shares 43,573 35,507 Diluted net income per share $ 0.03 $ 0.27 (1) Up to the amount of OpCo common units held by Sponsors

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Feb. 28, 2017
Segment Reporting [Abstract]
Summary of Customers Comprising 10% or More of Total Revenue	The following customers each comprised 10% or more of our total revenue for the three months ended February 28, 2017 and February 29, 2016, respectively: Three Months Ended February 28, February 29, Customers 2017 2016 Southern California Edison 29.5 % 44.2 % First Solar 12.8 % 18.1 % Southern California Public Power Authority 10.7 % * *Total revenue to these customers were less than 10% of our total revenue for the period.

Description of Business - Addit

Description of Business - Additional Information (Details)	3 Months Ended	12 Months Ended
	Feb. 28, 2017	Nov. 30, 2016
Description Of Business And Basis Of Presentation [Line Items]
Noncontrolling interest, ownership percentage by parent	35.50%	35.50%
Minimum
Description Of Business And Basis Of Presentation [Line Items]
Portion of lease revenue	90.00%
OpCo | Henrietta Project
Description Of Business And Basis Of Presentation [Line Items]
Economic interest in entities	49.00%
OpCo | Stateline Project
Description Of Business And Basis Of Presentation [Line Items]
Economic interest in entities	34.00%
OpCo | SunPower
Description Of Business And Basis Of Presentation [Line Items]
Contribution of Interest in entities	100.00%
OpCo | Maryland Solar
Description Of Business And Basis Of Presentation [Line Items]
Contribution of Interest in entities	100.00%
OpCo | Lost Hills Blackwell Project Entity
Description Of Business And Basis Of Presentation [Line Items]
Economic interest in entities	49.00%
OpCo | North Star Project Entity
Description Of Business And Basis Of Presentation [Line Items]
Economic interest in entities	49.00%
OpCo | Solar Gen Two Project Entity
Description Of Business And Basis Of Presentation [Line Items]
Economic interest in entities	49.00%
Noncontrolling Interest | OpCo
Description Of Business And Basis Of Presentation [Line Items]
Noncontrolling interest, ownership percentage by parent	35.50%
Noncontrolling Interest | Sponsors
Description Of Business And Basis Of Presentation [Line Items]
Noncontrolling interest, ownership percentage by parent	64.50%	64.50%

Description of Business - Summa

Description of Business - Summary of Assets Comprise the Portfolio (Details)	3 Months Ended
	Feb. 28, 2017MW
Description Of Business And Basis Of Presentation [Line Items]
MW(ac)	945
California | Macy's Corporate Services
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2015-08
MW(ac)	3
Remaining Term of Offtake Agreement (in years)	18 years 8 months 12 days
Maryland Solar | Maryland | First Energy Solutions
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2014-02
MW(ac)	20
Remaining Term of Offtake Agreement (in years)	16 years 1 month 6 days
Solar Gen Two Project Entity | California | San Diego Gas & Electric
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2014-11
MW(ac)	150
Remaining Term of Offtake Agreement (in years)	22 years 8 months 12 days
Lost Hills Blackwell Project Entity | California | City of Roseville/Pacific Gas and Electric
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2015-04
MW(ac)	32
Remaining Term of Offtake Agreement (in years)	26 years 9 months 18 days
North Star Project Entity | California | Pacific Gas and Electric
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2015-06
MW(ac)	60
Remaining Term of Offtake Agreement (in years)	18 years 3 months 18 days
Hooper | Colorado | Publix Service Company of Colorado
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2015-12
MW(ac)	50
Remaining Term of Offtake Agreement (in years)	18 years 9 months 18 days
RPU | California | City of Riverside
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2015-09
MW(ac)	7
Remaining Term of Offtake Agreement (in years)	23 years 7 months 6 days
Kingbird | California | Southern California Public Power Authority
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2016-04
MW(ac)	40
Remaining Term of Offtake Agreement (in years)	19 years 2 months 12 days
Quinto | California | Southern California Edison
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2015-11
MW(ac)	108
Remaining Term of Offtake Agreement (in years)	18 years 9 months 18 days
Henrietta | California | Pacific Gas and Electric
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2016-10
MW(ac)	102
Remaining Term of Offtake Agreement (in years)	19 years 7 months 6 days
Stateline Project | California | Southern California Edison
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2016-08
MW(ac)	300
Remaining Term of Offtake Agreement (in years)	19 years 6 months
UC Davis | California | University of California
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2015-09
MW(ac)	13
Remaining Term of Offtake Agreement (in years)	18 years 6 months
Macy's Maryland | Maryland | Macy's Corporate Services
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2016-12
MW(ac)	5
Remaining Term of Offtake Agreement (in years)	19 years 9 months 18 days
Residential Portfolio | U.S. – Various | Approximately 5,900 homeowners
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2014-06
MW(ac)	39
Remaining Term of Offtake Agreement (in years)	15 years 6 months
Kern | California | Kern High School District
Description Of Business And Basis Of Presentation [Line Items]
Commercial Operation Date	2017-01
MW(ac)	16
Remaining Term of Offtake Agreement (in years)	19 years 9 months 18 days

Description of Business - Sum38

Description of Business - Summary of Assets Comprise the Portfolio (Parenthetical) (Details)	3 Months Ended
	Feb. 28, 2017LeaseMW	Feb. 24, 2017MW	Nov. 30, 2016MW	Sep. 09, 2016MW	Jan. 26, 2016MW
Description Of Business And Basis Of Presentation [Line Items]
Aggregate solar nameplate megawatts	945
Lost Hills Blackwell Project Entity | California | City of Roseville
Description Of Business And Basis Of Presentation [Line Items]
Remaining Term of Offtake Agreement (in years)	1 year 9 months 18 days
Kern | California | OpCo
Description Of Business And Basis Of Presentation [Line Items]
Aggregate solar nameplate megawatts		3	5	5	3
Residential Portfolio
Description Of Business And Basis Of Presentation [Line Items]
Number of solar residential installations | Lease	5,900
Residential Portfolio | U.S. – Various
Description Of Business And Basis Of Presentation [Line Items]
Number of solar residential installations | Lease	5,900
Residential Portfolio | U.S. – Various | Approximately 5,900 homeowners
Description Of Business And Basis Of Presentation [Line Items]
Remaining Term of Offtake Agreement (in years)	15 years 6 months
Aggregate solar nameplate megawatts	39

Business Combinations - Additio

Business Combinations - Additional Information (Details) - USD ($)		Feb. 24, 2017	Dec. 14, 2016	Nov. 30, 2016	Sep. 09, 2016	Jan. 26, 2016	Jan. 22, 2016	Feb. 28, 2017	Feb. 29, 2016
Business Acquisition [Line Items]
Operating revenues	[1]							$ 9,897,000	$ 7,102,000
Kern Acquisition
Business Acquisition [Line Items]
Agreement date								Jan. 26, 2016
Net assets acquired		$ 6,000,000		$ 8,400,000	$ 9,200,000	$ 4,900,000
Business combination capital contribution received from tax equity investor		$ 8,200,000	$ 6,700,000	1,300,000	$ 1,800,000		$ 900,000
Operating revenues								$ 0
Kern Acquisition | Maximum
Business Acquisition [Line Items]
Aggregate purchase price						$ 36,600,000
Purchase price to be paid on the closing of phases				$ 8,100,000
Future capital contribution from tax equity investor							$ 30,000,000
Related party transaction, payable in acquiring business on certain construction milestones								$ 11,100,000
[1]	The Partnership has related-party activities for transactions made with the Sponsors. Related party transactions recorded within “Operating revenues” in the unaudited condensed consolidated statement of operations were $1.3 million for each of the three months ended February 28, 2017 and February 29, 2016. Related party transactions recorded within “Operating costs and expenses” in the unaudited condensed consolidated statement of operations were $2.0 million and $1.4 million for the three months ended February 28, 2017 and February 29, 2016, respectively.

Business Combinations - Purchas

Business Combinations - Purchase Allocation for Acquired Assets and Liabilities and Non Controlling Interests (Details) - USD ($) $ in Thousands	Feb. 24, 2017	Jan. 26, 2016
Kern Phase 1(a) Assets
Business Acquisition [Line Items]
Property and equipment		$ 9,510
Related party payable		(3,435)
Asset retirement obligation		(322)
Noncontrolling interest		(866)
Net assets acquired		4,887
Kern Phase 1(b) Assets
Business Acquisition [Line Items]
Property and equipment		18,856
Related party payable		(7,123)
Asset retirement obligation		(785)
Noncontrolling interest		(1,794)
Net assets acquired		9,154
Kern Phase 2(a) Assets
Business Acquisition [Line Items]
Property and equipment		14,873
Related party payable		(4,504)
Asset retirement obligation		(623)
Noncontrolling interest		(1,332)
Net assets acquired		8,414
Kern Phase 2(b) Assets
Business Acquisition [Line Items]
Property and equipment		11,872
Related party payable		(4,287)
Asset retirement obligation		(493)
Noncontrolling interest	$ (1,100)	(1,078)
Net assets acquired		$ 6,014

Investment in Unconsolidated 41

Investment in Unconsolidated Affiliates - Additional Information (Details) - USD ($) $ in Millions	Dec. 02, 2016	Nov. 11, 2016	Feb. 28, 2017	Feb. 29, 2016	Nov. 30, 2016
Schedule Of Equity Method Investments [Line Items]
Difference between partnership's investment unconsolidated affiliates and partnership's proportionate share of the equity method of investee's net assets			$ 139.4		$ 83.2
Difference over the life of the assets and accretion expense			$ 1	$ 0.4
OpCo | SG2 Holdings
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest			49.00%
OpCo | North Star Holdings
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest			49.00%
OpCo | Lost Hills Blackwell Holdings
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest			49.00%
OpCo | Henrietta Holdings
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest			49.00%
OpCo | Stateline Holdings
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest			34.00%
OpCo | Stateline Project
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest			34.00%
OpCo | First Solar | Stateline Project
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest		34.00%
Payment to acquire equity method investment		$ 329.5
Acquisition-related costs	$ 329.9

Investment in Unconsolidated 42

Investment in Unconsolidated Affiliates - Partnerships Investments Unconsolidated Affiliates (Details) - USD ($) $ in Thousands	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Equity Method Investments And Joint Ventures [Abstract]
Balance at the beginning of the period	$ 475,078	$ 352,070
Investments in its unconsolidated affiliates during the period	330,027
Equity in earnings in unconsolidated affiliates	606	405
Distributions from unconsolidated affiliates	(17,711)	(6,278)
Balance at the end of the period	$ 788,000	$ 346,197

Investment in Unconsolidated 43

Investment in Unconsolidated Affiliates - Summary of Financial Information (Details) - SG2 Holdings, North Star Holdings, Lost Hills Blackwell Holdings, Henrietta Holdings and Stateline Holdings - USD ($) $ in Thousands	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Summary statements of operations information:
Revenue	$ 19,616	$ 8,650
Operating expenses	26,393	10,924
Net loss	$ (7,759)	$ (2,170)

Balance Sheet Components - Sche

Balance Sheet Components - Schedule of Financing Receivables (Details) - USD ($) $ in Thousands	Feb. 28, 2017	Nov. 30, 2016
Accounts Notes And Loans Receivable [Line Items]
Minimum lease payment receivable, net	$ 98,684	$ 100,161
Unguaranteed residual value	12,908	12,926
Less: unearned income	(29,801)	(30,557)
Net financing receivables	81,791	82,530
Long-term financing receivables, net	79,232	80,014
Short-Term Financing Receivables
Accounts Notes And Loans Receivable [Line Items]
Net financing receivables	$ 2,559	$ 2,516

Balance Sheet Components - Sc45

Balance Sheet Components - Schedule of Financing Receivables (Parenthetical) (Details) - USD ($) $ in Millions	Feb. 28, 2017	Nov. 30, 2016
Balance Sheet Related Disclosures [Abstract]
Allowance for losses on financing receivables	$ 0.6	$ 0.7
Other trade accounts receivable	$ 3.1	$ 2.9

Balance Sheet Components - Summ

Balance Sheet Components - Summary of Balance Sheet Components (Details) - USD ($) $ in Thousands		Feb. 28, 2017	Nov. 30, 2016
Prepaid expense and other current assets
Prepaid and other current assets	[1]	$ 9,369	$ 15,745
Other current assets		1,873	1,875
Property and equipment, net
Property and equipment, gross		766,933	754,293
Less: accumulated depreciation		(40,744)	(34,161)
Total		726,189	720,132
Other long-term assets
Other long-term assets		25,515	24,432
Utility Solar Power Systems
Property and equipment, net
Property and equipment, gross		613,293	578,817
Leased Solar Power Systems
Property and equipment, net
Property and equipment, gross		137,410	137,475
Land
Property and equipment, net
Property and equipment, gross		1,020	1,020
Construction in Progress
Property and equipment, net
Property and equipment, gross		15,210	36,981
Reimbursable Network Upgrade Costs
Prepaid expense and other current assets
Prepaid and other current assets		7,496	13,870
Other long-term assets
Other long-term assets		22,301	21,781
Intangible Assets
Other long-term assets
Other long-term assets		1,647	1,754
Derivative Financial Instruments
Other long-term assets
Other long-term assets		$ 1,567	$ 897
[1]	The Partnership has related-party balances for transactions made with the Sponsors and tax equity investors. Related-party balances recorded within “Prepaid and other current assets” in the unaudited condensed consolidated balance sheets were $0.8 million and $0.9 million as of February 28, 2017 and November 30, 2016, respectively. Related-party balances recorded within “Accounts payable and other current liabilities” in the unaudited condensed consolidated balance sheets were $6.4 million and $19.7 million due to Sponsors as of February 28, 2017 and November 30, 2016, respectively, and $1.0 million due to tax equity investors as of both February 28, 2017 and November 30, 2016. Related-party balances recorded within “Short-term debt and financing obligations” and “Long-term debt and financing obligations” in the unaudited condensed consolidated balance sheets were $2.2 million and $47.8 million, respectively, as of February 28, 2017, and $2.0 million and zero, respectively, as of November 30, 2016.

Balance Sheet Components - Su47

Balance Sheet Components - Summary of Balance Sheet Components (Parenthetical) (Details) - USD ($) $ in Thousands		3 Months Ended
		Feb. 28, 2017	Feb. 29, 2016	Nov. 30, 2016
Condensed Balance Sheet Statements Captions [Line Items]
Reimbursement period of construction cost		5 years
Accounts payable and other current liabilities	[1]	$ 11,144		$ 23,771
Reduced operating revenues		100	$ 0
SunPower | Solar Energy System Performance Warranty
Condensed Balance Sheet Statements Captions [Line Items]
Due from related parties related to system output performance warranties		400		500
System output performance warranty		100		200
Accounts payable and other current liabilities		$ 300		$ 300
[1]	The Partnership has related-party balances for transactions made with the Sponsors and tax equity investors. Related-party balances recorded within “Prepaid and other current assets” in the unaudited condensed consolidated balance sheets were $0.8 million and $0.9 million as of February 28, 2017 and November 30, 2016, respectively. Related-party balances recorded within “Accounts payable and other current liabilities” in the unaudited condensed consolidated balance sheets were $6.4 million and $19.7 million due to Sponsors as of February 28, 2017 and November 30, 2016, respectively, and $1.0 million due to tax equity investors as of both February 28, 2017 and November 30, 2016. Related-party balances recorded within “Short-term debt and financing obligations” and “Long-term debt and financing obligations” in the unaudited condensed consolidated balance sheets were $2.2 million and $47.8 million, respectively, as of February 28, 2017, and $2.0 million and zero, respectively, as of November 30, 2016.

Balance Sheet Components - Sc48

Balance Sheet Components - Schedule of Account Payables and Other Current Liabilities (Details) - USD ($) $ in Thousands		Feb. 28, 2017	Nov. 30, 2016
Accounts payable and other current liabilities
Trade and accrued accounts payable		$ 1,313	$ 1,089
Related party payable		7,006	20,653
Residential lease system repairs accrual		269	331
Other short-term liabilities		2,418	1,502
Accounts payable and other current liabilities, Total	[1]	11,144	23,771
Solar Energy System Performance Warranty
Accounts payable and other current liabilities
System output performance warranty		$ 138	$ 196
[1]	The Partnership has related-party balances for transactions made with the Sponsors and tax equity investors. Related-party balances recorded within “Prepaid and other current assets” in the unaudited condensed consolidated balance sheets were $0.8 million and $0.9 million as of February 28, 2017 and November 30, 2016, respectively. Related-party balances recorded within “Accounts payable and other current liabilities” in the unaudited condensed consolidated balance sheets were $6.4 million and $19.7 million due to Sponsors as of February 28, 2017 and November 30, 2016, respectively, and $1.0 million due to tax equity investors as of both February 28, 2017 and November 30, 2016. Related-party balances recorded within “Short-term debt and financing obligations” and “Long-term debt and financing obligations” in the unaudited condensed consolidated balance sheets were $2.2 million and $47.8 million, respectively, as of February 28, 2017, and $2.0 million and zero, respectively, as of November 30, 2016.

Balance Sheet Components - Sc49

Balance Sheet Components - Schedule of Account Payables and Other Current Liabilities (Parenthetical) (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Feb. 28, 2017	Feb. 29, 2016	Nov. 30, 2016
Schedule Of Account Payables And Other Liabilities [Line Items]
Accrued distributions to tax equity investors	$ 581	$ 630	$ 1,000
Accounts payable to related parties	600		100
SunPower | Macy's Maryland Acquisition
Schedule Of Account Payables And Other Liabilities [Line Items]
Purchase price paid by tax equity investors			19,500
SunPower | Kern Phase 1(a) Assets
Schedule Of Account Payables And Other Liabilities [Line Items]
Purchase price paid by tax equity investors	5,800		19,500
SunPower | Kern Phase 2(b) Assets
Schedule Of Account Payables And Other Liabilities [Line Items]
Purchase price paid by tax equity investors	$ 5,800
SunPower | Kern Phase 1(b) Assets
Schedule Of Account Payables And Other Liabilities [Line Items]
Purchase price paid by tax equity investors			19,500
SunPower | Kern Phase 2(a)
Schedule Of Account Payables And Other Liabilities [Line Items]
Purchase price paid by tax equity investors			$ 19,500

Commitments and Contingencies -

Commitments and Contingencies - Total Minimum Lease and Easement Commitments (Details) $ in Thousands	Feb. 28, 2017USD ($)
Commitments And Contingencies Disclosure [Abstract]
Land use payments, 2017 (remaining nine months)	$ 871
Land use payments, 2018	1,329
Land use payments, 2019	1,686
Land use payments, 2020	1,742
Land use payments, 2021	1,782
Land use payments, Thereafter	56,249
Land use payments, Total	$ 63,659

Commitments and Contingencies51

Commitments and Contingencies - Additional Information (Details) - USD ($)		3 Months Ended
		Feb. 28, 2017	Feb. 29, 2016	Nov. 30, 2016
Commitments And Contingencies Disclosure [Line Items]
Accounts payable and other current liabilities	[1]	$ 11,144,000		$ 23,771,000
Other current assets		1,873,000		1,875,000
Environmental contingencies		0	$ 0
Solar Power System Performance Warranty
Commitments And Contingencies Disclosure [Line Items]
Accounts payable and other current liabilities		100,000		200,000
Other current assets		$ 100,000		$ 200,000
[1]	The Partnership has related-party balances for transactions made with the Sponsors and tax equity investors. Related-party balances recorded within “Prepaid and other current assets” in the unaudited condensed consolidated balance sheets were $0.8 million and $0.9 million as of February 28, 2017 and November 30, 2016, respectively. Related-party balances recorded within “Accounts payable and other current liabilities” in the unaudited condensed consolidated balance sheets were $6.4 million and $19.7 million due to Sponsors as of February 28, 2017 and November 30, 2016, respectively, and $1.0 million due to tax equity investors as of both February 28, 2017 and November 30, 2016. Related-party balances recorded within “Short-term debt and financing obligations” and “Long-term debt and financing obligations” in the unaudited condensed consolidated balance sheets were $2.2 million and $47.8 million, respectively, as of February 28, 2017, and $2.0 million and zero, respectively, as of November 30, 2016.

Commitments and Contingencies52

Commitments and Contingencies - Summary of Accrued Warranty Activity (Details) - Solar Power System Performance Warranty - USD ($) $ in Thousands	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Product Warranty Liability [Line Items]
Balance at the beginning of the period	$ 196	$ 237
Settlements during the period	(29)	(76)
Adjustments during the period	(29)	65
Balance at the end of the period	$ 138	$ 226

Commitments and Contingencies53

Commitments and Contingencies - Summary of Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Commitments And Contingencies Disclosure [Abstract]
Balance at the beginning of the period	$ 13,448	$ 9,992
ARO assumed in acquisition	493	547
Accretion expense	171	119
Revisions to ARO during the period	17	0
Balance at the end of the period	$ 14,129	$ 10,658

Lease Agreements and Power Pu54

Lease Agreements and Power Purchase Agreements - Additional Information (Details)	3 Months Ended
	Feb. 28, 2017Lease
Operating Leased Assets [Line Items]
Estimated residual value over the lease term	20 years
Lease term expiration date	Dec. 31, 2019
Residential Portfolio
Operating Leased Assets [Line Items]
Number of operating lease agreements	5,900

Lease Agreements and Power Pu55

Lease Agreements and Power Purchase Agreements - Minimum Future Rental Receipts on Operating Leases (Details) $ in Thousands	Feb. 28, 2017USD ($)
Operating Leased Assets [Line Items]
Minimum future rental receipts on operating leases, 2017 (remaining nine months)	$ 7,028
Minimum future rental receipts on operating leases, 2018	8,896
Minimum future rental receipts on operating leases, 2019	8,655
Minimum future rental receipts on operating leases, 2020	3,765
Minimum future rental receipts on operating leases, 2021	3,787
Minimum future rental receipts on operating leases, Thereafter	42,563
Minimum future rental receipts on operating leases, Total	74,694
Minimum future rentals on residential operating leases placed in service
Operating Leased Assets [Line Items]
Minimum future rental receipts on operating leases, 2017 (remaining nine months)	2,779
Minimum future rental receipts on operating leases, 2018	3,723
Minimum future rental receipts on operating leases, 2019	3,743
Minimum future rental receipts on operating leases, 2020	3,765
Minimum future rental receipts on operating leases, 2021	3,787
Minimum future rental receipts on operating leases, Thereafter	42,563
Minimum future rental receipts on operating leases, Total	60,360
Maryland Solar Lease
Operating Leased Assets [Line Items]
Minimum future rental receipts on operating leases, 2017 (remaining nine months)	4,249
Minimum future rental receipts on operating leases, 2018	5,173
Minimum future rental receipts on operating leases, 2019	4,912
Minimum future rental receipts on operating leases, 2020	0
Minimum future rental receipts on operating leases, 2021	0
Minimum future rental receipts on operating leases, Thereafter	0
Minimum future rental receipts on operating leases, Total	$ 14,334

Lease Agreements and Power Pu56

Lease Agreements and Power Purchase Agreements - Future Maturities of Net Financing Receivables for Sales-Type Leases (Details) - USD ($) $ in Thousands	Feb. 28, 2017	Nov. 30, 2016
Leases [Abstract]
Scheduled maturities of minimum lease payments receivable, 2017 (remaining nine months)	$ 4,196
Scheduled maturities of minimum lease payments receivable, 2018	5,681
Scheduled maturities of minimum lease payments receivable, 2019	5,768
Scheduled maturities of minimum lease payments receivable, 2020	5,860
Scheduled maturities of minimum lease payments receivable, 2021	5,955
Scheduled maturities of minimum lease payments receivable, Thereafter	71,224
Scheduled maturities of minimum lease payments receivable, Total	$ 98,684	$ 100,161

Lease Agreements and Power Pu57

Lease Agreements and Power Purchase Agreements - Schedule of Firm Sales under SREC Sales Agreement (Details) - USD ($) $ in Thousands		3 Months Ended
		Feb. 28, 2017	Feb. 29, 2016
Sale Agreement [Line Items]
SREC Sales, Total	[1]	$ 9,897	$ 7,102
SREC Sales Agreement
Sale Agreement [Line Items]
SREC Sales, 2017 (remaining nine months)		586
SREC Sales, 2018		781
SREC Sales, 2019		781
SREC Sales, 2020		781
SREC Sales, 2021		195
SREC Sales, Total		$ 3,124
[1]	The Partnership has related-party activities for transactions made with the Sponsors. Related party transactions recorded within “Operating revenues” in the unaudited condensed consolidated statement of operations were $1.3 million for each of the three months ended February 28, 2017 and February 29, 2016. Related party transactions recorded within “Operating costs and expenses” in the unaudited condensed consolidated statement of operations were $2.0 million and $1.4 million for the three months ended February 28, 2017 and February 29, 2016, respectively.

Debt and Financing Obligation58

Debt and Financing Obligations - Additional Information (Details) - USD ($)	Feb. 24, 2017	Dec. 02, 2016	Sep. 29, 2016	Mar. 30, 2016	Feb. 28, 2017	Feb. 29, 2016	Nov. 30, 2016	Sep. 30, 2016	Jun. 05, 2015
Debt Instrument [Line Items]
Distributions to sponsors					$ 880,000		$ 3,574,000
OpCo | Maximum
Debt Instrument [Line Items]
Subordinated indebtedness					$ 50,000,000
First Solar | OpCo | Stateline Project
Debt Instrument [Line Items]
Maturity description of promissory note					The principal amount of $50.0 million. The Stateline Promissory Note is unsecured and matures on the date that is six months after the maturity date under OpCo’s credit facility.
Promissory Note issued		$ 50,000,000
Interest rate of Promissory Note		4.00%
Interest rate of promissory note contingent upon certain conditions		6.00%
Term Loan Facility
Debt Instrument [Line Items]
Debt, carrying amount					$ 300,000,000		300,000,000
Line of credit facility interest rate description					Loans outstanding under the credit facility bear interest at either (i) a base rate, which is the highest of (x) the federal funds rate plus 0.50%, (y) the administrative agent’s prime rate and (z) one-month LIBOR, in each case, plus an applicable margin; or (ii) one-, two-, three- or six-month LIBOR plus an applicable margin.
Delayed Draw Term Loan Facility
Debt Instrument [Line Items]
Debt, carrying amount					$ 25,000,000		25,000,000
Revolving Credit Facility
Debt Instrument [Line Items]
Debt, carrying amount					89,000,000		63,000,000
Incremental Term Loan Facility
Debt Instrument [Line Items]
Debt, carrying amount					250,000,000
Stateline Promissory Note
Debt Instrument [Line Items]
Debt, carrying amount					50,000,000
Senior Secured Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing amount									$ 525,000,000
Line Of Credit Facility Amortization Of Principal					0
Discount and incremental debt issuance costs					$ 3,100,000
Line of credit facility unused capacity, commitment fee percentage					0.30%
Debt service coverage ratio					1.75%
Senior Secured Credit Facility | Maximum
Debt Instrument [Line Items]
Debt to cash flow ratio					600.00%
Debt to cash flow ratio					500.00%
Senior Secured Credit Facility | Base Rate
Debt Instrument [Line Items]
Line of credit facility interest rate					0.50%
Senior Secured Credit Facility | OpCo
Debt Instrument [Line Items]
Economic interest in entities					35.00%
Senior Secured Credit Facility | First Solar
Debt Instrument [Line Items]
Distributions to sponsors					$ 129,400,000
Senior Secured Credit Facility | SunPower
Debt Instrument [Line Items]
Distributions to sponsors					168,900,000
Senior Secured Credit Facility | Term Loan Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing amount									300,000,000
Line of credit facility, amount outstanding					$ 300,000,000		$ 300,000,000		300,000,000
Line of credit facility, interest rate at period end					2.78%		2.61%
Senior Secured Credit Facility | Delayed Draw Term Loan Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing amount									25,000,000
Debt, carrying amount					$ 25,000,000		$ 25,000,000
Senior Secured Credit Facility | Delayed Draw Term Loan Facility | OpCo
Debt Instrument [Line Items]
Term loan facility drawn amount				$ 25,000,000
Senior Secured Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing amount									$ 200,000,000
Line of credit drawn amount					89,000,000		63,000,000
Letters of credit outstanding amount					54,900,000		54,900,000
Senior Secured Credit Facility | Revolving Credit Facility | OpCo
Debt Instrument [Line Items]
Line of credit drawn amount				$ 40,000,000
Senior Secured Credit Facility | Revolving Credit Facility | Kern Phase 2(b) Acquisition | OpCo
Debt Instrument [Line Items]
Line of credit drawn amount	$ 6,000,000
Senior Secured Credit Facility | Revolving Credit Facility | Henrietta Acquisition | OpCo
Debt Instrument [Line Items]
Line of credit drawn amount			$ 23,000,000
Senior Secured Credit Facility | Revolving Credit Facility | Stateline Acquisition | OpCo
Debt Instrument [Line Items]
Line of credit drawn amount		$ 20,000,000
Senior Secured Credit Facility | Incremental Term Loan Facility
Debt Instrument [Line Items]
Line of credit facility, amount outstanding					250,000,000
Senior Secured Credit Facility | Incremental Term Loan Facility | OpCo
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing amount								$ 775,000,000
Line of credit facility, increase in borrowing capacity								$ 250,000,000
Senior Secured Credit Facility | Incremental Term Loan Facility | Stateline Acquisition | OpCo
Debt Instrument [Line Items]
Term loan facility drawn amount		$ 250,000,000
August Two Thousand Eleven Letter Of Credit Facility With Deutsche Bank | Predecessor
Debt Instrument [Line Items]
Letters of credit outstanding amount					11,500,000		$ 30,700,000
Line of credit facility, commitment fee amount					$ 100,000	$ 100,000

Debt and Financing Obligation59

Debt and Financing Obligations - Summary of the Partnership's Debt Obligations (Details) - USD ($) $ in Thousands	Feb. 28, 2017	Nov. 30, 2016
Term Loan Facility
Debt Instrument [Line Items]
Debt, carrying amount	$ 300,000	$ 300,000
Less: debt issuance costs	(3,327)	(3,564)
Total	$ 710,673	$ 384,436
Debt, Effective Interest Rate	2.78%	2.61%
Incremental Term Loan Facility
Debt Instrument [Line Items]
Debt, carrying amount	$ 250,000
Debt, Effective Interest Rate	2.78%
Delayed Draw Term Loan Facility
Debt Instrument [Line Items]
Debt, carrying amount	$ 25,000	$ 25,000
Debt, Effective Interest Rate	2.78%	2.61%
Revolving Credit Facility
Debt Instrument [Line Items]
Debt, carrying amount	$ 89,000	$ 63,000
Debt, Effective Interest Rate	2.78%	2.61%
Stateline Promissory Note
Debt Instrument [Line Items]
Debt, carrying amount	$ 50,000
Debt, Effective Interest Rate	4.00%

Debt and Financing Obligation60

Debt and Financing Obligations - Summary of the Partnership's Debt Obligations (Parenthetical) (Details)	3 Months Ended
	Feb. 28, 2017
Term Loan Facility
Debt Instrument [Line Items]
Debt maturity period	2,020
Incremental Term Loan Facility
Debt Instrument [Line Items]
Debt maturity period	2,020
Delayed Draw Term Loan Facility
Debt Instrument [Line Items]
Debt maturity period	2,020
Revolving Credit Facility
Debt Instrument [Line Items]
Debt maturity period	2,020
Stateline Promissory Note
Debt Instrument [Line Items]
Debt maturity period	2,020

Fair Value - Summary of Assets

Fair Value - Summary of Assets and Liabilities Measured at Estimated Fair Value on Recurring basis (Details) - Recurring Basis - USD ($) $ in Thousands	Feb. 28, 2017	Nov. 30, 2016
Assets
Derivative financial instruments	$ 1,567	$ 897
Total assets	1,567	897
Level 2
Assets
Derivative financial instruments	1,567	897
Total assets	$ 1,567	$ 897

Fair Value - Additional Informa

Fair Value - Additional Information (Details) - Interest Rate Swap - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Feb. 28, 2017	Feb. 29, 2016	Nov. 30, 2016	Jan. 05, 2017	Jul. 17, 2015
Derivatives Fair Value [Line Items]
Derivative liability, notional amount	$ 250			$ 40	$ 240
Fixed swap interest rate	0.85%			1.16%	1.55%
Derivative maturity date	Aug. 31, 2018
Interest rate swap agreements termination minimum notification days	5 days
Interest rate fair value ineffective portion recognized in earnings	$ 0.7	$ 0.1
Interest Rate Swap Agreements Termination Period	1 year		1 year
Level 2
Derivatives Fair Value [Line Items]
Partnership long term debt carrying value of term loan facility under variable rate of debt	$ 708.5		$ 384.4

Noncontrolling Interests - Addi

Noncontrolling Interests - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016	Feb. 24, 2017	Nov. 30, 2016	Jan. 26, 2016
Minority Interest [Line Items]
Redeemable noncontrolling interests attributable to tax equity investors	$ 17,346			$ 17,624
Noncontrolling interests attributable to tax equity investors	590,064			$ 590,331
Losses attributed to the investors	$ (6,181)	$ (12,361)
Kern Phase 2(b) Assets
Minority Interest [Line Items]
Noncontrolling interests			$ 1,100		$ 1,078
First Solar
Minority Interest [Line Items]
Non-controlling interest, ownership percentage	28.00%			36.50%
Noncontrolling interests attributable to tax equity investors	$ 233,847			$ 238,210
SunPower
Minority Interest [Line Items]
Non-controlling interest, ownership percentage	28.00%			36.50%
Noncontrolling interests attributable to tax equity investors	$ 305,644			$ 311,327
Tax Equity Investors
Minority Interest [Line Items]
Redeemable noncontrolling interests attributable to tax equity investors	17,300			17,600
Noncontrolling interests attributable to tax equity investors	50,600			$ 40,800
Subsidiaries
Minority Interest [Line Items]
Amount received from investors under the related facilities	18,800	0
Losses attributed to the investors	8,800	34,900
Amount distributions to investors under the related facilities	$ 1,500	$ 900

Noncontrolling Interests - Sche

Noncontrolling Interests - Schedule of Non-Controlling Interest Balances by Entity (Details) - USD ($) $ in Thousands	Feb. 28, 2017	Nov. 30, 2016
Minority Interest [Line Items]
Noncontrolling interests	$ 590,064	$ 590,331
Tax Equity Investors
Minority Interest [Line Items]
Noncontrolling interests	50,573	40,794
First Solar
Minority Interest [Line Items]
Noncontrolling interests	233,847	238,210
SunPower
Minority Interest [Line Items]
Noncontrolling interests	$ 305,644	$ 311,327

Shareholders' Equity - Addition

Shareholders' Equity - Additional Information (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 30, 2017	Jan. 13, 2017	Sep. 28, 2016	Jun. 24, 2015	Feb. 28, 2017	Nov. 30, 2016	Nov. 30, 2015
Class Of Stock [Line Items]
Partnership interest					35.50%	35.50%
Partnership shares, Issued					0
Sponsors | Noncontrolling Interest
Class Of Stock [Line Items]
Partnership interest					64.50%	64.50%
OpCo | Noncontrolling Interest
Class Of Stock [Line Items]
Partnership interest					35.50%
Class A shares
Class Of Stock [Line Items]
New issuance of shares			8,050,000
Partnership shares, Issued					28,076,907	28,072,680	20,007,281
Class A shares | OpCo
Class Of Stock [Line Items]
Cash distribution payment to Partnership		$ 7
Cash distribution payment to partnership, Per unit		$ 0.2490
Class A shares | ATM Program
Class Of Stock [Line Items]
Aggregate sale price of common limited partners units	$ 125
Class A shares | I P O
Class Of Stock [Line Items]
New issuance of shares				20,000,000
Class B shares
Class Of Stock [Line Items]
Partnership shares, outstanding					51,000,000	51,000,000
Partnership shares, Issued					51,000,000	51,000,000	51,000,000
Class B shares | SunPower
Class Of Stock [Line Items]
Partnership shares, outstanding					28,883,075	28,883,075
Class B shares | First Solar
Class Of Stock [Line Items]
Partnership shares, outstanding					22,116,925	22,116,925
Common and Subordinated Units | OpCo
Class Of Stock [Line Items]
Cash distribution payment to Partnership		$ 12.7
Cash distribution payment to partnership, Per unit		$ 0.2490

Shareholders' Equity - Summary

Shareholders' Equity - Summary of Partnership Shares Outstanding (Details) - shares	Feb. 28, 2017	Nov. 30, 2016
Class Of Stock [Line Items]
Partnership shares, outstanding	79,076,907	79,072,680
Class A shares
Class Of Stock [Line Items]
Partnership shares, outstanding	28,076,907	28,072,680
Class B shares
Class Of Stock [Line Items]
Partnership shares, outstanding	51,000,000	51,000,000
Class B shares | First Solar
Class Of Stock [Line Items]
Partnership shares, outstanding	22,116,925	22,116,925
Class B shares | SunPower
Class Of Stock [Line Items]
Partnership shares, outstanding	28,883,075	28,883,075

Net Income Per Share - Addition

Net Income Per Share - Additional Information (Details) - shares	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Earnings Per Share [Abstract]
Potentially dilutive securities include in the computation of diluted shares	0	0

Net Income Per Share - Summary

Net Income Per Share - Summary of Net Income Per Share (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Basic net income per share:
Net income attributable to Class A shareholders	$ 861	$ 5,308
Basic weighted-average shares	28,073,000	20,007,000
Basic net income per share	$ 0.03	$ 0.27
Diluted net income per share:
Net income attributable to Class A shareholders	$ 861	$ 5,308
Basic weighted-average shares	28,073,000	20,007,000
Effect of dilutive securities:
Potentially dilutive securities include in the computation of diluted shares	0	0
Diluted weighted-average shares	43,573,000	35,507,000
Diluted net income per share	$ 0.03	$ 0.27
Class A shares
Basic net income per share:
Net income attributable to Class A shareholders	$ 861	$ 5,308
Diluted net income per share:
Net income attributable to Class A shareholders	861	5,308
Add: Additional net income attributable to Class A shares due to increased percentage ownership in OpCo, net of tax, from the conversion of Class B shares	514	4,112
Total	$ 1,375	$ 9,420
Class B shares
Effect of dilutive securities:
Potentially dilutive securities include in the computation of diluted shares	15,500,000	15,500,000

Related Parties - Additional In

Related Parties - Additional Information (Details) $ in Thousands

Feb. 24, 2017USD ($)

Feb. 13, 2017MW

Dec. 14, 2016USD ($)

Dec. 02, 2016USD ($)

Nov. 30, 2016USD ($)

Sep. 09, 2016USD ($)

Jan. 22, 2016USD ($)

Aug. 31, 2015USD ($)

Feb. 28, 2017USD ($)MW

Feb. 29, 2016USD ($)

Jan. 23, 2017USD ($)

Nov. 25, 2015USD ($)

Related Party Transaction [Line Items]

MW(ac) | MW

945

Lease term expiration date

Dec. 31, 2019

Annual revenue

$ 9,897

$ 7,102

Kern Acquisition

Related Party Transaction [Line Items]

Agreement date

Jan. 26, 2016

Business combination capital contribution received from tax equity investor

$ 8,200

$ 6,700

$ 1,300

$ 1,800

$ 900

El Pelicano Solar Generation Project | SunPower ROFO Waiver

Related Party Transaction [Line Items]

MW(ac) | MW

100

Maximum | Kern Acquisition

Related Party Transaction [Line Items]

Future capital contribution from tax equity investor

$ 30,000

Related party transaction, payable in acquiring business on certain construction milestones

$ 11,100

First Solar MSA

Related Party Transaction [Line Items]

Annual management fee

$ 600

SunPower MSA

Related Party Transaction [Line Items]

Annual management fee

$ 1,100

Service Provider

Related Party Transaction [Line Items]

Management fee expense

$ 400

400

Affiliated Entity

Related Party Transaction [Line Items]

Period of warranty for power and product

25 years

Affiliated Entity | Minimum

Related Party Transaction [Line Items]

Period of warranty for materials, construction, fabrication and workmanship

2 years

Affiliated Entity | Maximum

Related Party Transaction [Line Items]

Period of warranty for materials, construction, fabrication and workmanship

10 years

Leased Solar Energy Systems | Predecessor

Related Party Transaction [Line Items]

Cost of operations-SunPower, prior to IPO

$ 1,500

1,000

OpCo

Related Party Transaction [Line Items]

Cash received as indemnity

$ 100

$ 13,900

Promissory Note issued

$ 2,000

Interest rate of Promissory Note

1.00%

Number of year, power purchase agreement serving

5 years

OpCo | First Solar ROFO Agreement

Related Party Transaction [Line Items]

Negotiation period

45 days

OpCo | SunPower ROFO Waiver

Related Party Transaction [Line Items]

Number of year, power purchase agreement serving

5 years

OpCo | Stateline Project | First Solar And First Solar Asset Management

Related Party Transaction [Line Items]

Agreement date

Nov. 11, 2016

Payment to acquire business

$ 329,500

OpCo | Switch Station Solar Generation Project

Related Party Transaction [Line Items]

MW(ac) | MW

179

OpCo | First Solar | Stateline Project

Related Party Transaction [Line Items]

Promissory Note issued

$ 50,000

Maryland Solar

Related Party Transaction [Line Items]

Lease term expiration date

Dec. 31, 2019

Pretax impairment charge

$ 1,510,000

Annual revenue

$ 8,000

Income Taxes - Additional Infor

Income Taxes - Additional Information (Details)	3 Months Ended
	Feb. 28, 2017
Income Tax Disclosure [Abstract]
Federal statutory tax rate	35.00%

Segment Information - Additiona

Segment Information - Additional Information (Details)	3 Months Ended
	Feb. 28, 2017Segment
Segment Reporting [Abstract]
Number of reportable segments	1

Segment Information - Summary o

Segment Information - Summary of Customers Comprising 10% or More of Total Revenue (Details) - Customer Concentration Risk - Operating Revenues - United States	3 Months Ended
	Feb. 28, 2017	Feb. 29, 2016
Southern California Edison
Segment Reporting Information [Line Items]
Total operating revenues percentage	29.50%	44.20%
Southern California Public Power Authority
Segment Reporting Information [Line Items]
Total operating revenues percentage	10.70%
First Solar
Segment Reporting Information [Line Items]
Total operating revenues percentage	12.80%	18.10%

Subsequent Events - Additional

Subsequent Events - Additional Information (Details)	Mar. 23, 2017$ / sharesMW	Feb. 28, 2017MW
Subsequent Event [Line Items]
MW(ac)		945
OpCo
Subsequent Event [Line Items]
Number of year, power purchase agreement serving		5 years
Subsequent Event | OpCo
Subsequent Event [Line Items]
Number of year, power purchase agreement serving	5 years
Subsequent Event | OpCo | Cuyama Solar Generation Project
Subsequent Event [Line Items]
MW(ac)	40
Subsequent Event | OpCo | California Flats Solar Generation Project
Subsequent Event [Line Items]
MW(ac)	280
Class A shares | Subsequent Event
Subsequent Event [Line Items]
Distribution made to limited partner, Distributions declared | $ / shares	$ 0.2565
Cash distribution payment date	Apr. 14, 2017
Cash distribution date of record	Apr. 4, 2017