10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2016

Commission File Number	Exact name of registrant as specified in its charter, address of principal executive office and registrant's telephone number	IRS Employer Identification Number
001-36518	NEXTERA ENERGY PARTNERS, LP	30-0818558
	700 Universe Boulevard Juno Beach, Florida 33408 (561) 694-4000

State or other jurisdiction of incorporation or organization:  Delaware

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months.   Yes þ    No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Securities Exchange Act of 1934.

Large Accelerated Filer þ Accelerated Filer ¨ Non-Accelerated Filer ¨ Smaller Reporting Company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Securities Exchange Act of 1934).   Yes ¨   No þ

Number of NextEra Energy Partners, LP common units outstanding as of September 30, 2016:  54,236,995

DEFINITIONS

Acronyms and defined terms used in the text include the following:

Term	Meaning
2015 Form 10-K	NEP's Annual Report on Form 10-K for the year ended December 31, 2015
ASA	administrative services agreement(s)
BLM	U.S. Bureau of Land Management
CITC	Convertible Investment Tax Credit
COD	commercial operation date
CSCS agreement	cash sweep and credit support agreement
FIT	Feed-in-Tariff
GWh	gigawatt-hour(s)
IDR fee	certain payments from NEP OpCo to NEE Management as a component of the MSA which are based on the achievement by NEP OpCo of certain target quarterly distribution levels to its unitholders
IPP	independent power producer
management sub-contract	management services sub-contract between NEE Management and NEER
Management's Discussion	Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
MSA	Management Services Agreement among NEP, NEE Management, NEP OpCo and NEP GP
MW	megawatt(s)
NEE	NextEra Energy, Inc.
NEECH	NextEra Energy Capital Holdings, Inc.
NEE Equity	NextEra Energy Equity Partners, LP
NEE Management	NextEra Energy Management Partners, LP
NEE Operating GP	NextEra Energy Operating Partners GP, LLC
NEER	NextEra Energy Resources, LLC
NEP	NextEra Energy Partners, LP
NEP GP	NextEra Energy Partners GP, Inc.
NEP OpCo	NextEra Energy Operating Partners, LP
NOLs	net operating losses
Note __	Note __ to condensed consolidated financial statements
O&M	operations and maintenance
Pemex	Petróleos Mexicanos
PPA	power purchase agreement, which could include contracts under a FIT or RESOP
PTC	production tax credit
RESOP	Renewable Energy Standard Offer Program
SEC	U.S. Securities and Exchange Commission
Texas pipelines	natural gas pipeline assets located in Texas
Texas pipelines acquisition	Acquisition of NET Holdings Management, LLC (the Texas pipeline business)
Texas pipeline entities	the subsidiaries of NEP that directly own the Texas pipelines
U.S.	United States of America
U.S. Project Entities	project entities located within the U.S.

Each of NEP and NEP OpCo has subsidiaries and affiliates with names that may include NextEra Energy, NextEra Energy Partners and similar references. For convenience and simplicity, in this report, the terms NEP and NEP OpCo are sometimes used as abbreviated references to specific subsidiaries, affiliates or groups of subsidiaries or affiliates. The precise meaning depends on the context. Discussions of NEP's ownership of subsidiaries and projects refers to its controlling interest in the general partner of NEP OpCo and NEP's indirect interest in and control over the subsidiaries of NEP OpCo. See Note 5 for a description of the noncontrolling interest in NEP OpCo.

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TABLE OF CONTENTS

		Page No.
Definitions		2
Forward-Looking Statements		4
	PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements	8
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	23
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	31
Item 4.	Controls and Procedures	31
	PART II - OTHER INFORMATION
Item 1A.	Risk Factors	32
Item 6.	Exhibits	32
Signatures		33

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FORWARD-LOOKING STATEMENTS

This report includes forward-looking statements within the meaning of the federal securities laws. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, strategies, future events or performance (often, but not always, through the use of words or phrases such as result, are expected to, will continue, is anticipated, aim, believe, will, could, should, would, estimated, may, plan, potential, future, projection, goals, target, outlook, predict and intend or words of similar meaning) are not statements of historical facts and may be forward looking. Forward-looking statements involve estimates, assumptions and uncertainties. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, the following important factors (in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements) that could have a significant impact on NEP's operations and financial results, and could cause NEP's actual results to differ materially from those contained or implied in forward-looking statements made by or on behalf of NEP in this Form 10-Q, in presentations, on its website, in response to questions or otherwise.

Operational Risks

• NEP has a limited operating history and its projects include renewable energy projects with a limited operating history. Such projects may not perform as expected.

• NEP's ability to make cash distributions to its unitholders is affected by wind and solar conditions at its renewable energy projects.

• NEP's business, financial condition, results of operations and prospects can be materially adversely affected by weather conditions, including, without limitation, the impact of severe weather.

• As a result of the Texas pipelines acquisition, NEP's operations and business have substantially changed. NEP's expansion into the natural gas pipeline industry may not be successful.

• NEP may fail to realize expected profitability or growth, and may incur unanticipated liabilities, as a result of the Texas pipelines acquisition.

• NEP is pursuing the expansion of natural gas pipelines in its portfolio that will require up-front capital expenditures and expose NEP to project development risks.

• NEP's ability to maximize the productivity of the Texas pipeline business and to complete potential pipeline expansion projects is dependent on the continued availability of natural gas production in the Texas pipelines’ areas of operation.

• Operation and maintenance of renewable energy projects involve significant risks that could result in unplanned power outages, reduced output, personal injury or loss of life.

• The wind turbines at some of NEP's projects and some of NEER's right of first offer projects are not generating the amount of energy estimated by their manufacturers' original power curves, and the manufacturers may not be able to restore energy capacity at the affected turbines.

• NEP depends on the Texas pipelines and certain of the renewable energy projects in its portfolio for a substantial portion of its anticipated cash flows.

• Terrorist or similar attacks could impact NEP's projects or surrounding areas and adversely affect its business.

• NEP's energy production and pipeline transportation capability may be substantially below its expectations if severe weather or a natural disaster or meteorological conditions damage its turbines, solar panels, pipelines or other equipment or facilities.

• The ability of NEP to obtain insurance and the terms of any available insurance coverage could be materially adversely affected by international, national, state or local events and company-specific events, as well as the financial condition of insurers. NEP's insurance coverage does not insure against all potential risks and it may become subject to higher insurance premiums.

• Warranties provided by the suppliers of equipment for NEP's projects may be limited by the ability of a supplier to satisfy its warranty obligations, or by the terms of the warranty, so the warranties may be insufficient to compensate NEP for its losses.

• Supplier concentration at certain of NEP's projects may expose it to significant credit or performance risks.

• NEP relies on interconnection and transmission facilities of third parties to deliver energy from its renewable energy projects and, if these facilities become unavailable, NEP's wind and solar projects may not be able to operate or deliver energy.

• NEP's business is subject to liabilities and operating restrictions arising from environmental, health and safety laws and regulations.

• NEP's renewable energy projects may be adversely affected by legislative changes or a failure to comply with applicable energy regulations.

• A change in the jurisdictional characterization of some of the Texas pipeline entities' assets, or a change in law or regulatory policy, could result in increased regulation of these assets, which could have material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.

• NEP may incur significant costs and liabilities as a result of pipeline integrity management program testing and any necessary pipeline repair or preventative or remedial measures.

• The Texas pipelines’ operations could incur significant costs if the Pipeline and Hazardous Materials Safety Administration or the Railroad Commission of Texas adopts more stringent regulations.

• Pemex may claim certain immunities under the Foreign Sovereign Immunities Act and Mexican law, and the Texas pipeline entities' ability to sue or recover from Pemex for breach of contract may be limited.

• Portions of NEP’s pipeline systems have been in service for several decades. There could be unknown events or conditions or increased maintenance or repair expenses and downtime associated with NEP's pipelines that could have a material adverse effect on NEP's business, financial condition, results of operations, liquidity and ability to make distributions.

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• Natural gas operations are subject to numerous environmental laws and regulations, compliance with which may require significant capital expenditures, increase NEP's cost of operations and affect or limit its business plans, or expose NEP to liabilities.

• Natural gas gathering and transmission activities involve numerous risks that may result in accidents or otherwise affect the Texas pipelines’ operations.

• NEP's partnership agreement restricts the voting rights of unitholders owning 20% or more of its common units, and under certain circumstances this could be reduced to 10%.

• NEP does not own all of the land on which the projects in its portfolio are located and its use and enjoyment of the property may be adversely affected to the extent that there are any lienholders or leaseholders that have rights that are superior to NEP's rights or the BLM suspends its federal rights-of-way grants.

• NEP is subject to risks associated with litigation or administrative proceedings that could materially impact its operations, including, without limitation, proceedings related to projects it acquires in the future.

• NEP's wind projects located in Canada are subject to Canadian domestic content requirements under their FIT contracts.

• NEP's cross-border operations require NEP to comply with anti-corruption laws and regulations of the U.S. government and non-U.S. jurisdictions.

• NEP is subject to risks associated with its ownership or acquisition of projects that remain under construction, which could result in its inability to complete construction projects on time or at all, and make projects too expensive to complete or cause the return on an investment to be less than expected.

Contract Risks

• NEP relies on a limited number of customers and NEP is exposed to the risk that they are unwilling or unable to fulfill their contractual obligations to NEP or that they otherwise terminate their agreements with NEP.

• NEP may not be able to extend, renew or replace expiring or terminated PPAs at favorable rates or on a long-term basis.

• NEP may be unable to secure renewals of long-term natural gas transportation agreements, which could expose its revenues to increased volatility.

• If the energy production by or availability of NEP's U.S. renewable energy projects is less than expected, they may not be able to satisfy minimum production or availability obligations under NEP's U.S. Project Entities’ PPAs.

• If third-party pipelines and other facilities interconnected to the Texas pipelines become partially or fully unavailable to transport natural gas, NEP's revenues and cash available for distribution to unitholders could be adversely affected.

Risks Related to NEP's Acquisition Strategy and Future Growth

• NEP's growth strategy depends on locating and acquiring interests in additional projects consistent with its business strategy at favorable prices.

• NEP OpCo's partnership agreement requires that it distribute its available cash, which could limit its ability to grow and make acquisitions.

• NEP's ability to consummate future acquisitions will depend on NEP's ability to finance those acquisitions.

• Lower prices for other fuel sources may reduce the demand for wind and solar energy.

• Reductions in demand for natural gas in the United States or Mexico and low market prices of natural gas could materially adversely affect the Texas pipelines’ operations and cash flows.

• Government regulations providing incentives and subsidies for clean energy could change at any time and such changes may negatively impact NEP's growth strategy.

• NEP's growth strategy depends on the acquisition of projects developed by NEE and third parties, which face risks related to project siting, financing, construction, permitting, the environment, governmental approvals and the negotiation of project development agreements.

• Acquisitions of existing clean energy projects involve numerous risks.

• Renewable energy procurement is subject to U.S. state and Canadian provincial regulations, with relatively irregular, infrequent and often competitive procurement windows.

• NEP may continue to acquire other sources of clean energy, including, without limitation, natural gas and nuclear projects, and may expand to include other types of assets including, without limitation, transmission projects, and any further acquisition of non-renewable energy projects, including, without limitation, transmission projects, may present unforeseen challenges and result in a competitive disadvantage relative to NEP's more-established competitors. A failure to successfully integrate such acquisitions with NEP's then-existing projects as a result of unforeseen operational difficulties or otherwise, could have a material adverse effect on NEP's business, financial condition, results of operations and ability to grow its business and make cash distributions to its unitholders.

• NEP faces substantial competition primarily from regulated utilities, developers, IPPs, pension funds and private equity funds for opportunities in North America.

• The natural gas pipeline industry is highly competitive, and increased competitive pressure could adversely affect NEP's business.

Risks Related to NEP's Financial Activities

• NEP may not be able to access sources of capital on commercially reasonable terms, which would have a material adverse effect on its ability to consummate future acquisitions.

• Restrictions in NEP OpCo's subsidiaries' revolving credit facility and term loan agreements could adversely affect NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.

5

• NEP's cash distributions to its unitholders may be reduced as a result of restrictions on NEP's subsidiaries’ cash distributions to NEP under the terms of their indebtedness.

• NEP's subsidiaries’ substantial amount of indebtedness may adversely affect NEP's ability to operate its business and its failure to comply with the terms of its subsidiaries' indebtedness could have a material adverse effect on NEP's financial condition.

• Currency exchange rate fluctuations may affect NEP's operations.

• NEP is exposed to risks inherent in its use of interest rate swaps.

Risks Related to NEP's Relationship with NEE

• NEE exercises substantial influence over NEP and NEP is highly dependent on NEE and its affiliates.

• NEER may lose key employees assigned to manage the Texas pipelines.

• NEP is highly dependent on credit support from NEE and its affiliates. NEP's subsidiaries may default under contracts or become subject to cash sweeps if credit support is terminated, if NEE or its affiliates fail to honor their obligations under credit support arrangements, or if NEE or another credit support provider ceases to satisfy creditworthiness requirements, and NEP will be required in certain circumstances to reimburse NEE for draws that are made on credit support.

• NEER or one of its affiliates is permitted to borrow funds received by NEP's subsidiaries, including, without limitation, NEP OpCo, as partial consideration for its obligation to provide credit support to NEP, and NEER will use these funds for its own account without paying additional consideration to NEP and is obligated to return these funds only as needed to cover project costs and distributions or as demanded by NEP OpCo.

• NEP's financial condition and ability to make distributions to its unitholders, as well as its ability to grow distributions in the future, is highly dependent on NEER’s performance of its obligations to return all or a portion of these funds.

• NEP may not be able to consummate future acquisitions from NEER or from third parties.

• NEP GP and its affiliates, including, without limitation, NEE, have conflicts of interest with NEP and limited duties to NEP and its unitholders and they may favor their own interests to the detriment of NEP and holders of NEP common units.

• Common units are subject to NEP GP's limited call right.

• NEE and other affiliates of NEP GP are not restricted in their ability to compete with NEP.

• NEP may be unable to terminate the MSA.

• If NEE Management terminates the MSA, NEER terminates the management sub-contract or either of them defaults in the performance of its obligations thereunder, NEP may be unable to contract with a substitute service provider on similar terms, or at all.

• NEP's arrangements with NEE limit NEE's liability, and NEP has agreed to indemnify NEE against claims that it may face in connection with such arrangements, which may lead NEE to assume greater risks when making decisions relating to NEP than it otherwise would if acting solely for its own account.

• The credit and business risk profiles of NEP GP and its owner, NEE, could adversely affect any NEP credit ratings and risk profile, which could increase NEP's borrowing costs or hinder NEP's ability to raise capital.

Risks Related to Ownership of NEP's Common Units

• NEP's ability to make distributions to its unitholders depends on the ability of NEP OpCo to make cash distributions to its limited partners.

• If NEP incurs material tax liabilities, NEP's distributions to its unitholders may be reduced, without any corresponding reduction in the amount of the IDR fee.

• Holders of NEP's common units have limited voting rights and are not entitled to elect NEP's general partner or NEP GP's directors.

• NEP's partnership agreement restricts the remedies available to holders of NEP's common units for actions taken by NEP GP that might otherwise constitute breaches of fiduciary duties.

• NEP's partnership agreement replaces NEP GP's fiduciary duties to holders of its common units with contractual standards governing its duties.

• Even if holders of NEP's common units are dissatisfied, they cannot initially remove NEP GP without NEE's consent.

• NEE's interest in NEP GP and the control of NEP GP may be transferred to a third party without unitholder consent.

• The IDR fee may be transferred to a third party without unitholder consent.

• NEP may issue additional units without unitholder approval, which would dilute unitholder interests.

• Reimbursements and fees owed to NEP GP and its affiliates for services provided to NEP or on NEP's behalf will reduce cash distributions to or from NEP OpCo and from NEP to NEP's unitholders, and the amount and timing of such reimbursements and fees will be determined by NEP GP and there are no limits on the amount that NEP OpCo may be required to pay.

• Discretion in establishing cash reserves by NEE Operating GP may reduce the amount of cash distributions to unitholders.

• While NEP's partnership agreement requires NEP to distribute its available cash, NEP's partnership agreement, including, without limitation, provisions requiring NEP to make cash distributions, may be amended.

• NEP OpCo can borrow money to pay distributions, which would reduce the amount of credit available to operate NEP's business.

• Increases in interest rates could adversely impact the price of NEP's common units, NEP's ability to issue equity or incur debt for acquisitions or other purposes and NEP's ability to make cash distributions to its unitholders.

• The price of NEP's common units may fluctuate significantly and unitholders could lose all or part of their investment and a market that will provide unitholders with adequate liquidity may not develop.

6

• The liability of holders of NEP's common units, which represent limited partnership interests in NEP, may not be limited if a court finds that unitholder action constitutes control of NEP's business.

• Unitholders may have liability to repay distributions that were wrongfully distributed to them.

• Except in limited circumstances, NEP GP has the power and authority to conduct NEP's business without unitholder approval.

• Contracts between NEP, on the one hand, and NEP GP and its affiliates, on the other hand, will not be the result of arm's-length negotiations.

• Unitholders have no right to enforce the obligations of NEP GP and its affiliates under agreements with NEP.

• NEP GP decides whether to retain separate counsel, accountants or others to perform services for NEP.

• The New York Stock Exchange does not require a publicly traded limited partnership like NEP to comply with certain of its corporate governance requirements.

Taxation Risks

• NEP's future tax liability may be greater than expected if NEP does not generate NOLs sufficient to offset taxable income or if tax authorities challenge certain of NEP's tax positions.

• NEP's ability to use NOLs to offset future income may be limited.

• NEP will not have complete control over NEP's tax decisions.

• A valuation allowance may be required for NEP's deferred tax assets.

• Distributions to unitholders may be taxable as dividends.

• Unitholders who are not resident in Canada may be subject to Canadian tax on gains from the sale of common units if NEP’s common units derive more than 50% of their value from Canadian real property at any time.

These factors should be read together with the risk factors included in Part I, Item 1A. Risk Factors in the 2015 Form 10-K and investors should refer to that section of the 2015 Form 10-K. Any forward-looking statement speaks only as of the date on which such statement is made, and NEP undertakes no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law. New factors emerge from time to time and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.

Website Access to U.S. Securities and Exchange Commission (SEC) Filings. NEP makes its SEC filings, including the annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports, available free of charge on NEP's internet website, www.nexteraenergypartners.com, as soon as reasonably practicable after those documents are electronically filed with or furnished to the SEC. The information and materials available on NEP's website are not incorporated by reference into this Form 10-Q. The SEC maintains an internet website that contains reports and other information regarding registrants that file electronically with the SEC at www.sec.gov.

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PART I - FINANCIAL INFORMATION

Item 1.  Financial Statements

NEXTERA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(millions, except per unit amounts)

(unaudited)

	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2016			2015(a)			2016			2015(a)
OPERATING REVENUES	$	186		$	115		$	539		$	348
OPERATING EXPENSES
Operations and maintenance	34			22			101			62
Operations and maintenance - related party	17			4			41			13
Depreciation and amortization	51			38			151			111
Taxes other than income taxes and other	5			3			14			10
Total operating expenses	107			67			307			196
OPERATING INCOME	79			48			232			152
OTHER INCOME (DEDUCTIONS)
Interest expense	(41		)	(31		)	(203		)	(85		)
Benefits associated with differential membership interests - net	13			5			41			17
Equity in losses of equity method investees	—			—			(20		)	(1		)
Revaluation of contingent consideration	101			—			118			—
Other - net	—			(4		)	(4		)	(4		)
Total other income (deductions) - net	73			(30		)	(68		)	(73		)
INCOME BEFORE INCOME TAXES	152			18			164			79
INCOME TAXES	25			5			15			12
NET INCOME	127			13			149			67
Less net income attributable to noncontrolling interest(b)	100			12			109			61
NET INCOME ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP	$	27		$	1		$	40		$	6
Weighted average number of common units outstanding - basic and assuming dilution	44.3			22.6			40.3			20.5
Earnings per common unit attributable to NextEra Energy Partners, LP - basic and assuming dilution	$	0.62		$	0.05		$	0.99		$	0.28
Distributions per common unit	$	0.3300		$	0.2350		$	0.9563		$	0.6350

____________________

(a) Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

(b) The calculation of net income attributable to noncontrolling interest includes the pre-acquisition net income of the common control acquisitions. See Note 1.

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2015 Form 10-K.

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NEXTERA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(millions)

(unaudited)

	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2016			2015(a)			2016		2015(a)
NET INCOME	$	127		$	13		$	149	$	67
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized losses (net of $3 and $4 tax benefit, respectively)	—			(16		)	—		(16		)
Reclassification from accumulated other comprehensive loss to net income (net of less than $1 tax benefit, less than $1, $1 and $1 tax expense, respectively)	2			1			5		4
Net unrealized gains (losses) on foreign currency translation (net of less than $1 and $1 tax benefit, $1 tax expense and $2 tax benefit, respectively)	(1		)	(11		)	6		(37		)
Total other comprehensive income (loss), net of tax	1			(26		)	11		(49		)
COMPREHENSIVE INCOME (LOSS)	128			(13		)	160		18
Less comprehensive income (loss) attributable to noncontrolling interest(b)	100			(10		)	118		16
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP	$	28		$	(3	)	$	42	$	2

____________________

(a) Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

(b) The calculation of comprehensive income (loss) attributable to noncontrolling interest includes the pre-acquisition comprehensive income (loss) of the common control acquisitions. See Note 1.

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2015 Form 10-K.

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NEXTERA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(millions)

(unaudited)

	September 30, 2016			December 31, 2015(a)
ASSETS
Current assets:
Cash and cash equivalents	$	133		$	164
Accounts receivable	91			80
Due from related parties	349			70
Restricted cash	33			16
Other current assets	22			24
Total current assets	628			354
Non-current assets:
Property, plant and equipment - net	5,098			5,122
Deferred income taxes	261			176
Intangible assets - customer relationships	683			696
Goodwill	628			622
Investments in equity method investees	10			22
Other non-current assets	61			61
Total non-current assets	6,741			6,699
TOTAL ASSETS	$	7,369		$	7,053
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable and accrued expenses	$	15		$	303
Short-term debt	—			12
Due to related parties	29			17
Current maturities of long-term debt	78			101
Acquisition holdbacks	267			—
Accrued interest	20			28
Derivatives	21			22
Other current liabilities	29			29
Total current liabilities	459			512
Non-current liabilities:
Long-term debt	3,586			3,334
Deferral related to differential membership interests	897			929
Acquisition holdbacks	—			375
Deferred income taxes	37			43
Asset retirement obligation	49			41
Non-current due to related party	21			19
Other non-current liabilities	151			82
Total non-current liabilities	4,741			4,823
TOTAL LIABILITIES	5,200			5,335
COMMITMENTS AND CONTINGENCIES
EQUITY
Limited partners (common units issued and outstanding 54.2 and 30.6, respectively)	1,706			935
Accumulated other comprehensive loss	(4		)	(6		)
Noncontrolling interest	467			789
TOTAL EQUITY	2,169			1,718
TOTAL LIABILITIES AND EQUITY	$	7,369		$	7,053

____________________

(a) Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2015 Form 10-K.

10

NEXTERA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(millions)

(unaudited)

	Nine Months Ended September 30,
	2016			2015(a)
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	149		$	67
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	151			111
Amortization of deferred financing costs	6			4
Accretion of acquisition holdbacks	10			—
Change in value of derivative contracts	75			—
Deferred income taxes	15			7
Benefits associated with differential membership interests - net	(41		)	(17		)
Equity in losses of equity method investees	20			—
Change in fair value of contingent consideration for pipeline acquisition	(118		)	—
Other - net	—			2
Changes in operating assets and liabilities:
Accounts receivable	(10		)	—
Other current assets	1			16
Other non-current assets	(1		)	(6		)
Accounts payable and accrued expenses	—			4
Due to related parties	(5		)	(1		)
Other current liabilities	(8		)	(3		)
Other non-current liabilities	3			(3		)
Net cash provided by operating activities	247			181
CASH FLOWS FROM INVESTING ACTIVITIES
Acquisition of membership interests in subsidiaries	(641		)	(716		)
Capital expenditures	(276		)	(149		)
Changes in restricted cash	(23		)	66
Payments (to) from related parties under CSCS agreement - net	(280		)	179
Net cash used in investing activities	(1,220		)	(620		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common units - net	645			319
Issuances of long-term debt	671			558
Retirements of long-term debt	(477		)	(190		)
Deferred financing costs	(10		)	(10		)
Partners/Members' contributions	251			136
Partners/Members' distributions	(154		)	(460		)
Proceeds from differential membership investors	18			5
Payments to differential membership investors	(9		)	(4		)
Proceeds from short-term debt	—			325
Repayments of short-term debt	(12		)	(313		)
Change in amounts due to related parties	17			(20		)
Proceeds from issuance of NEP OpCo common units to noncontrolling interest	—			702
Net cash provided by financing activities	940			1,048
Effect of exchange rate changes on cash	2			(3		)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(31		)	606
CASH AND CASH EQUIVALENTS - BEGINNING OF PERIOD	164			111
CASH AND CASH EQUIVALENTS - END OF PERIOD	$	133		$	717
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Partners/Members' noncash distributions	$	31		$	21
Members’ noncash contributions for construction costs and other	$	90		$	285
Change in accounts receivable for CITCs	$	2		$	13
Change in investments in equity method investees - net	$	7		$	1
Asset retirement obligation additions	$	7		$	—
Change in accrued but not paid for capital expenditures	$	3		$	265
Noncash member distribution upon transition from predecessor method	$	3		$	3
Change in goodwill related to change in purchase accounting valuation	$	6		$	—

_________________________

(a) Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2015 Form 10-K.

11

NEXTERA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(millions)

(unaudited)

	Units	Limited Partners				Accumulated Other Comprehensive Loss(a)			Noncontrolling Interest(a)				Total Equity(a)
Balances, December 31, 2015	30.6	$	935			$	(6	)	$	789			$	1,718
Acquisition of membership interests in subsidiaries	—	—				—			(641		)		(641		)
Limited partners/related party contribution and transition	—	123			(b)	—			(3		)	(c)	120
Issuance of common units	23.6	645				—			—				645
Related party note receivable	—	—				—			(24		)		(24		)
Net income(d)	—	40				—			109				149
Other comprehensive income	—	—				2			9				11
Related party contributions	—	—				—			350				350
Related party distributions	—	—				—			(122		)		(122		)
Distributions to unitholders	—	(37		)		—			—				(37		)
Balances, September 30, 2016	54.2	$	1,706			$	(4	)	$	467			$	2,169

	Units	Limited Partners				Accumulated Other Comprehensive Loss(a)			Noncontrolling Interest(a)				Total Equity(a)
Balances, December 31, 2014	18.7	$	551			$	(3	)	$	1,240			$	1,788
Acquisition of membership interests in subsidiaries	—	—				—			(716		)		(716		)
Limited partners/related party contribution and transition	—	34			(b)	—			3			(c)	37
Issuance of common units	11.0	319				—			—				319
Net income(d)	—	6				—			61				67
Other comprehensive loss	—	—				(4		)	(45		)		(49		)
Proceeds from issuance of NEP OpCo common units to noncontrolling interest	—	—				—			702				702
Related party contributions	—	—				—			422				422
Related party distributions	—	—				—			(470		)		(470		)
Distributions to unitholders	—	(13		)		—			—				(13		)
Balances, September 30, 2015	29.7	$	897			$	(7	)	$	1,197			$	2,087

____________________

(a) Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

(b) Deferred tax asset recognized by NEP related to NEP equity issuances and acquisition of subsidiary membership interests.

(c) Related party noncash contribution (distribution), net, upon transition from predecessor accounting method.

(d) Net income attributable to noncontrolling interest includes the pre-acquisition net income of the common control acquisitions. See Note 1.

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2015 Form 10-K.

12

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

The accompanying condensed consolidated financial statements should be read in conjunction with the 2015 Form 10-K. In the opinion of NEP management, all adjustments (consisting of normal recurring accruals) considered necessary for fair financial statement presentation have been made. Certain amounts included in the prior year's condensed consolidated financial statements have been reclassified to conform to the current year's presentation. The results of operations for an interim period generally will not give a true indication of results for the year.

1. ACQUISITIONS

On March 1, 2016, a subsidiary of NEP completed the acquisition from NEER of Seiling Wind Investments, LLC, which indirectly owns two wind generation facilities, Seiling I and Seiling II, with a combined generating capacity of approximately 299 MW, located in Dewey and Woodward counties, Oklahoma, for approximately $323 million, plus working capital of $3 million and the assumption of $257 million in existing liabilities related to differential membership interests. As part of this acquisition and included in the cash consideration, a subsidiary of NEP acquired an approximately $25 million receivable from a subsidiary of NEER (related party note receivable) relating to operational performance issues at this facility. The related party note receivable is intended to compensate NEP for the operational performance issues and is supported in full by corrective actions or compensation expected from an equipment vendor under an undertaking the vendor has with NEER. The related party note receivable can be settled, in part or in whole, to the extent the operational performance issues are improved or resolved by the vendor by the end of 2016. This receivable bears interest at 7.1% per annum, is payable by NEER in equal semi-annual installments and matures in December 2035. The related party note receivable, interest and related payments are reflected in noncontrolling interest on the condensed consolidated financial statements.

On July 5, 2016, a subsidiary of NEP completed the acquisition from NEER of Bayhawk Wind Holdings, LLC for approximately $312 million, plus working capital of $6 million and the assumption of $253 million in existing liabilities related to differential membership interests. Bayhawk Wind Holdings, LLC indirectly owns two wind generation facilities that commenced commercial operations in December 2015, Cedar Bluff Wind and Golden Hills Wind, with a combined generating capacity of approximately 285 MW, located in Ellis, Ness, Rush and Trego counties, Kansas, and Alameda county, California, respectively.

The 2016 acquisitions discussed above and the acquisitions from NEER completed in 2015 (collectively, the common control acquisitions), were transfers of assets between entities under common control, which required them to be accounted for as if the transfers occurred since the inception of common control, with prior periods retrospectively adjusted to furnish comparative information. Accordingly, the accompanying condensed consolidated financial statements have been retrospectively adjusted to include the historical results and financial position of the common control acquisitions prior to their respective acquisition dates.

On October 28, 2016, a subsidiary of NEP completed the acquisition from NEER of an indirect 24% interest in Desert Sunlight Investment Holdings, LLC (Desert Sunlight) for $218 million, plus an adjustment of approximately $9 million related to working capital (subject to post-closing adjustments). Desert Sunlight owns two project entities, which together make up the Desert Sunlight Solar Energy Center, a 550 MW solar generation plant located in Riverside County, California. NEER retained an interest in Desert Sunlight and will remain the managing member.

On October 1, 2015, NEP acquired 100% of the membership interests in the Texas pipeline business, a developer, owner and operator of a portfolio of seven long-term contracted natural gas pipeline assets located in Texas. Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on the acquisition date based on their estimated fair value. During the nine months ended September 30, 2016, NEP recorded adjustments to the purchase price allocation which increased goodwill by approximately $6 million, decreased property, plant and equipment - net by $4 million and increased noncontrolling interest by $2 million.

Supplemental Pro forma Results of Operations

NEP’s pro forma results of operations had the acquisition of the Texas pipeline business been completed on January 1, 2014 are as follows:

	Three Months Ended   September 30, 2015			Nine Months Ended   September 30, 2015
	(millions)
Pro forma results of operations:
Pro forma revenues	$	140		$	425
Pro forma operating income	$	62		$	188
Pro forma net income	$	1		$	57
Pro forma net income (loss) attributable to NEP	$	(1	)	$	4

13

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

The pro forma consolidated results of operations include adjustments to:

• reflect the historical results of the Texas pipeline business beginning on January 1, 2014, excluding certain operations which were not acquired by NEP;

• reflect the estimated depreciation and amortization expense based on the estimated fair value of property, plant and equipment - net and the intangible assets - customer relationships;

• reflect additional interest expense related to financing transactions to fund the acquisition; and

• reflect related income tax effects.

The pro forma information is not necessarily indicative of the results of operations that would have occurred had the transaction been completed on January 1, 2014 or the future results of the consolidated operations.

2. INCOME TAXES

For periods prior to the date a project is acquired by NEP (NEP acquisition date), income taxes are calculated on the predecessor method using the separate return method for each of the projects acquired from NEER which are structured as limited liability companies or corporations. Income taxes are not included for entities that are structured as flow through entities (partnerships) electing to be taxed as partnerships.

For periods after the NEP acquisition date, income taxes are calculated on the successor method where taxes are calculated for NEP as a single taxpaying entity for U.S. federal and state income tax purposes. Because NEP OpCo is a limited partnership electing to be taxed as a partnership for U.S. federal and state income tax purposes, NEP only recognizes in income its applicable ownership share of U.S. income taxes related to both U.S. and Canadian projects, allocated to NEP OpCo. The Canadian subsidiaries are all Canadian taxpayers subject to Canadian income tax and, therefore, NEP recognizes in income all of the Canadian taxes.

Consequently for periods after the NEP acquisition date, income taxes include NEP's applicable ownership share of U.S. taxes and 100% of Canadian taxes. Net income or loss attributable to noncontrolling interest includes no U.S. taxes and NEER's applicable ownership share of Canadian taxes. Net income attributable to NEP includes NEP's applicable ownership share of U.S. and Canadian taxes.

The effective tax rates for the three months ended September 30, 2016 and 2015 were approximately 16% and 28%, respectively, and for the nine months ended September 30, 2016 and 2015 were approximately 9% and 15%, respectively. The effective tax rate is affected by recurring items, such as the relative amount of income earned in jurisdictions (earnings mix), valuation allowances on deferred tax assets, taxes attributable to the noncontrolling interest and the taxation of Canadian income in both Canada and the U.S.

Additionally, the effective tax rate for the nine months ended September 30, 2016 was affected by an April 2016 court decision approving a reorganization of certain of NEP's Canadian assets that provided for tax bases in certain of these assets. NEP recorded approximately $12 million of the associated income tax benefits during the nine months ended September 30, 2016.

3. FAIR VALUE MEASUREMENTS

The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEP uses several different valuation techniques to measure the fair value of assets and liabilities relying primarily on the market approach of using prices and other market information for identical or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. Certain financial instruments may be valued using multiple inputs including discount rates, counterparty credit ratings and credit enhancements. NEP’s assessment of the significance of any particular input to the fair value measurement requires judgment and may affect the fair value measurement of its assets and liabilities and the placement of those assets and liabilities within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value. All transfers between fair value hierarchy levels occur at the beginning of the period in which the transfer occurred.

Cash Equivalents and Restricted Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less, and are included in cash and cash equivalents, restricted cash and other non-current assets on the condensed consolidated balance sheets. NEP primarily holds these investments in money market funds and estimates the fair value of these funds using a market approach based on current observable market prices.

Interest Rate and Foreign Currency Contracts - NEP estimates the fair value of its derivatives using an income approach, or a discounted cash flows valuation technique, based on the net amount of estimated future cash inflows and outflows related to the

14

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

agreements. The primary inputs used in the fair value measurements include the contractual terms of the derivative agreements, current interest rates, foreign currency exchange rates and credit spreads. The significant inputs for the resulting fair value measurement are market-observable inputs and the measurements are reported as Level 2 in the fair value hierarchy.

NEP’s financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	September 30, 2016						December 31, 2015
	Level 1		Level 2		Total		Level 1		Level 2		Total
	(millions)
Assets:
Cash equivalents	$	52	$	—	$	52	$	63	$	—	$	63
Restricted cash equivalents	29		—		29		5		—		5
Interest rate contracts	—		—		—		—		2		2
Foreign currency contracts	—		—		—		—		2		2
Total assets	$	81	$	—	$	81	$	68	$	4	$	72
Liabilities:
Interest rate contracts	$	—	$	133	$	133	$	—	$	68	$	68
Total liabilities	$	—	$	133	$	133	$	—	$	68	$	68

Financial Instruments Recorded at Other than Fair Value - The carrying amounts of accounts receivable, accounts payable, certain accrued expenses and short-term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments, excluding those recorded at fair value and disclosed above, are as follows:

	September 30, 2016				December 31, 2015
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(millions)
Long-term debt, including current maturities(a)	$	3,664	$	3,876	$	3,435	$	3,532

____________________

(a) Fair value is estimated based on the borrowing rates as of each date for similar issues of debt with similar remaining maturities (Level 2).

Contingent Consideration - NEP recorded a liability related to a contingent holdback as part of the Texas pipelines acquisition. See Note 10 - Acquisition Holdbacks. The contingent holdback will be payable if the Texas pipelines enter into one or more written contracts by December 31, 2016 related to certain financial performance and capital expenditure thresholds. Contingent consideration is required to be reported at fair value at each reporting date. NEP determined this fair value measurement based on management's probability assessment. The significant inputs and assumptions used in the fair value measurement included the estimated probability of executing contracts related to financial performance and capital expenditure thresholds as well as the appropriate discount rate. At September 30, 2016 and December 31, 2015, the estimated fair value of the contingent holdback was approximately $70 million and $186 million, respectively, and is recorded as acquisition holdbacks on the condensed consolidated balance sheets. During the three and nine months ended September 30, 2016, NEP recorded approximately $101 million and $118 million, respectively, of fair value adjustments to decrease the contingent holdback based on updated estimates associated with management's probability assessment. The fair value adjustments are included in NEP's condensed consolidated statements of income.

4. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITY

NEP recognizes all derivative instruments, when required to be marked to market, on the balance sheet as either assets or liabilities and measures them at fair value each reporting period. In connection with certain of its debt financings, NEP entered into interest rate contracts to manage interest rate cash flow risk. These agreements allow NEP to offset the variability of its floating-rate loan interest cash flows with the variable interest cash flows received from the interest rate contracts. In January 2016, NEP discontinued hedge accounting for its cash flow hedges related to interest rate swaps and, therefore, essentially all changes in the fair value of the interest rate swaps are recognized in interest expense in NEP's condensed consolidated statements of income. The commencement and termination dates of the interest rate swap agreements and the related hedging relationship coincide with the corresponding dates of the underlying variable-rate debt instruments, with maturity dates through 2033. As of September 30, 2016 and December 31, 2015, the combined notional amounts of the interest rate contracts were approximately $1,435 million and $1,277 million, respectively.

At September 30, 2016, NEP's accumulated other comprehensive loss (AOCI) included amounts related to discontinued cash flow hedges which have expiration dates through 2033. Approximately $8 million of net losses included in AOCI at September 30, 2016,

15

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

is expected to be reclassified into interest expense within the next 12 months as interest payments are made. Cash flows from these interest rate swap contracts are reported in cash flows from operating activities in NEP's condensed consolidated statements of cash flows.

During 2015 and 2016, NEP entered into certain foreign currency exchange contracts to economically hedge its cash flows from foreign currency rate fluctuations. As of September 30, 2016 and December 31, 2015, the notional amount of the foreign currency contracts was approximately $60 million and $54 million, respectively. During the three months ended September 30, 2016 and 2015, NEP recorded less than $1 million and approximately $1 million of gains, respectively, related to the foreign currency contracts in other - net in the condensed consolidated statements of income. During the nine months ended September 30, 2016 and 2015, NEP recorded approximately $2 million of losses and approximately $1 million of gains, respectively, related to the foreign currency contracts in other - net in the condensed consolidated statements of income.

Fair Value of Derivative Instruments - The tables below present NEP's gross derivative positions at September 30, 2016 and December 31, 2015, as required by disclosure rules, as well as the location of the net derivative position on the condensed consolidated balance sheets.

	September 30, 2016
	Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Total Derivatives Combined - Net Basis
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
	(millions)
Interest rate contracts	$	—	$	—	$	—	$	133	$	—	$	133
Total fair values	$	—	$	—	$	—	$	133	$	—	$	133
Net fair value by balance sheet line item:
Other current assets									$	—
Other non-current assets									—
Current derivative liabilities											$	21
Other non-current liabilities											112
Total derivatives									$	—	$	133

	December 31, 2015
	Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Total Derivatives Combined - Net Basis
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
	(millions)
Interest rate contracts	$	1	$	22	$	1	$	46	$	5	$	71
Foreign currency contracts	—		—		2		—		2		—
Total fair values	$	1	$	22	$	3	$	46	$	7	$	71
Net fair value by balance sheet line item:
Other current assets									$	2
Other non-current assets									5
Current derivative liabilities											$	22
Other non-current liabilities											49
Total derivatives									$	7	$	71

Financial Statement Impact of Derivative Instruments - Gains (losses) related to NEP's interest rate contracts are recorded in NEP's condensed consolidated financial statements as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
	(millions)
Interest rate contracts:
Losses recognized in other comprehensive income	$	—		$	(19	)	$	—		$	(20	)
Losses reclassified from AOCI to interest expense	$	(2	)	$	(1	)	$	(6	)	$	(5	)
Gains (losses) recognized in interest expense	$	1		$	—		$	(85	)	$	—

16

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

5. VARIABLE INTEREST ENTITIES

In February 2015, the Financial Accounting Standards Board (FASB) issued a new accounting standard that modified consolidation guidance. The standard made changes to both the variable interest entity model and the voting interest entity model, including modifying the evaluation of whether limited partnerships or similar legal entities are VIEs or voting interest entities and amending the guidance for assessing how relationships of related parties affect the consolidation analysis of VIEs. NEP adopted the standard retrospectively beginning January 1, 2016.

As a result of the new standard, NEP has identified NEP OpCo as a VIE. NEP OpCo is a limited partnership with a general partner and limited partners. NEP has consolidated the results of NEP OpCo and its subsidiaries because of its controlling interest in the general partner of NEP OpCo. At September 30, 2016, NEP owned an approximately 34.8% limited partner interest in NEP OpCo and NEE Equity owned a noncontrolling 65.2% limited partner interest in NEP OpCo. The assets and liabilities of NEP OpCo as well as the operations of NEP OpCo represent substantially all of NEP's assets and liabilities and its operations.

In addition, at September 30, 2016, NEP consolidated four VIEs related to certain subsidiaries which have sold differential membership interests in entities which own and operate six wind electric generation facilities. Certain investors that have no equity at risk in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of these wind electric generation facilities, including certain tax attributes. The assets and liabilities of the VIEs, consisting primarily of property, plant and equipment - net and deferral related to differential membership interests, totaled approximately $1,669 million and $947 million at September 30, 2016, respectively, and $1,693 million and $1,248 million at December 31, 2015, respectively.

In April 2015, a subsidiary of NEP made an equity method investment in three NEER solar projects that were under construction in California. The solar projects reached full commercial operations in June 2016. Through a series of transactions, a subsidiary of NEP issued 1,000,000 NEP OpCo Class B Units, Series 1 and 1,000,000 NEP OpCo Class B Units, Series 2, to NEER for approximately 50% of the ownership interests in the three solar projects (non-economic ownership interests). NEER, as holder of the Class B Units, will retain 100% of the economic rights in the projects to which the respective Class B Units relate, including the right to all distributions paid by the project subsidiaries that own the projects to NEP OpCo. NEER has agreed to indemnify NEP against all risks relating to NEP’s ownership of the projects until NEER offers to sell economic interests to NEP and NEP accepts such offer, if NEP chooses to do so. NEER has also agreed to continue to manage the operation of the projects at its own cost, and to contribute to the projects any capital necessary for the operation of the projects, until NEER offers to sell economic interests to NEP and NEP accepts such offer. At September 30, 2016 and December 31, 2015, NEP's equity method investment related to the non-economic ownership interests totaled approximately $10 million and $22 million, respectively, and is reflected as investments in equity method investees on the condensed consolidated balance sheets. All equity in earnings of these equity method investees is allocated to net income attributable to noncontrolling interest. NEP is not the primary beneficiary and therefore does not consolidate these entities because it does not control any of the ongoing activities of these entities, was not involved in the initial design of these entities and does not have a controlling interest in these entities.

6. CAPITALIZATION

Debt - Significant long-term debt issuances and borrowings by subsidiaries of NEP during the nine months ended September 30, 2016 were as follows:

Date Issued	Debt Issuances/Borrowings	Interest Rate	Principal Amount			Maturity Date
			(millions)
January - March 2016	Construction loan credit facility	Variable(a)	$	41	(b)	2022
February 2016	Senior secured revolving credit facility	Variable(a)	$	75	(c)	2019
June 2016	Limited-recourse term loan	Variable(a)	$	355	(b)	2022
July 2016	Senior secured term loan	Variable(a)	$	100		2019
July 2016	Limited-recourse revolving credit facility	Variable(a)	$	100	(d)	2020

————————————

(a) Variable rate is based on an underlying index plus a margin.

(b) In March 2016, the construction loan credit facility converted to a term loan. In June 2016, this term loan was amended and approximately $72 million of additional net borrowings ($355 million of issuances net of $283 million of retirements) resulted in an outstanding term loan balance of $604 million at September 30, 2016.

(c) In September 2016, the borrowings under this credit facility were repaid. At September 30, 2016, no amounts were outstanding under this revolving credit facility.

(d) In October 2016, $50 million of the borrowings under this credit facility were repaid.

The long-term debt agreements listed above are secured by liens on certain assets and contain provisions which, under certain conditions, could restrict the payment of distributions or related party fee payments. At October 31, 2016, NEP's subsidiaries were in compliance with all financial debt covenants under their project financings.

17

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

Equity - During the nine months ended September 30, 2016, NEP issued 552,210 common units under the at-the-market equity issuance program (ATM program) for gross proceeds of approximately $16 million. Fees related to the ATM program totaled less than $1 million in 2016.

In February and March 2016, NEP completed the sale of 11,155,000 common units representing limited partnership interests in NEP in a public offering for an aggregate purchase price of approximately $287 million, or $25.76 per common unit. NEP used the proceeds to fund, together with borrowings under the senior secured revolving credit facility, the purchase price payable in the March 2016 acquisition discussed in Note 1.

In September 2016, NEP completed the sale of 11,962,300 common units representing limited partner interests in NEP in a public offering for an aggregate purchase price of approximately $342 million, or $28.56 per common unit. NEP used the proceeds to fund the purchase price payable in the October 2016 acquisition discussed in Note 1 and intends to use the remaining proceeds for general partnership purposes. The issuance of common units during the nine months ended September 30, 2016 resulted in an increase of NEP's limited partner interest in NEP OpCo to approximately 34.8% at September 30, 2016.

On October 31, 2016, the board of directors of NEP GP authorized a distribution of $0.34125 per common unit payable on November 14, 2016 to its unitholders of record on November 8, 2016.

7. ACCUMULATED OTHER COMPREHENSIVE LOSS

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Three months ended September 30, 2016
Balances, June 30, 2016	$	(8	)	$	(101	)	$	(109	)
Other comprehensive loss before reclassification	—			(1		)	(1		)
Amounts reclassified from AOCI to interest expense	2			—			2
Net other comprehensive income (loss)	2			(1		)	1
Balances, September 30, 2016	$	(6	)	$	(102	)	$	(108	)
AOCI attributable to noncontrolling interest	$	(6	)	$	(98	)	$	(104	)
AOCI attributable to NEP	$	—		$	(4	)	$	(4	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Gains (Losses) on Foreign Currency Translation			Total
	(millions)
Nine months ended September 30, 2016
Balances, December 31, 2015	$	(11	)	$	(108	)	$	(119	)
Other comprehensive income before reclassification	—			6			6
Amounts reclassified from AOCI to interest expense	5			—			5
Net other comprehensive income	5			6			11
Balances, September 30, 2016	$	(6	)	$	(102	)	$	(108	)
AOCI attributable to noncontrolling interest	$	(6	)	$	(98	)	$	(104	)
AOCI attributable to NEP	$	—		$	(4	)	$	(4	)

18

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Three months ended September 30, 2015
Balances, June 30, 2015	$	(1	)	$	(92	)	$	(93	)
Other comprehensive loss before reclassification	(16		)	(11		)	(27		)
Amounts reclassified from AOCI to interest expense	1			—			1
Net other comprehensive loss	(15		)	(11		)	(26		)
Balances, September 30, 2015	$	(16	)	$	(103	)	$	(119	)
AOCI attributable to noncontrolling interest	$	(13	)	$	(99	)	$	(112	)
AOCI attributable to NEP	$	(3	)	$	(4	)	$	(7	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Nine months ended September 30, 2015
Balances, December 31, 2014	$	(4	)	$	(66	)	$	(70	)
Other comprehensive loss before reclassification	(16		)	(37		)	(53		)
Amounts reclassified from AOCI to interest expense	4			—			4
Net other comprehensive loss	(12		)	(37		)	(49		)
Balances, September 30, 2015	$	(16	)	$	(103	)	$	(119	)
AOCI attributable to noncontrolling interest	$	(13	)	$	(99	)	$	(112	)
AOCI attributable to NEP	$	(3	)	$	(4	)	$	(7	)

8. RELATED PARTY TRANSACTIONS

Each project entered into O&M agreements and ASAs with subsidiaries of NEER whereby the projects pay a certain annual fee plus actual costs incurred in connection with certain O&M and administrative services performed under these agreements. These services are reflected as operations and maintenance - related party in NEP's condensed consolidated statements of income. Additionally, a NEP subsidiary pays an affiliate for transmission services which are reflected as operations and maintenance - related party in NEP's condensed consolidated statements of income. At September 30, 2016 and December 31, 2015, the net payables for these services, as well as for payroll and other payments made on behalf of these projects, were approximately $4 million and $9 million, respectively, and are included in due to related parties on NEP's condensed consolidated balance sheets. Certain projects have also entered into various types of agreements including those related to shared facilities and transmission lines, transmission line easements, technical support and construction coordination with subsidiaries of NEER whereby certain fees or cost reimbursements are paid to, or received by, certain subsidiaries of NEER.

Management Services Agreement - Effective July 1, 2014, subsidiaries of NEP entered into a MSA with indirect wholly owned subsidiaries of NEE, under which operational, management and administrative services are provided to NEP, including managing NEP’s day to day affairs and providing individuals to act as NEP GP’s executive officers and directors, in addition to those services that are provided under the existing O&M agreements and ASAs described above between NEER subsidiaries and NEP subsidiaries. NEP OpCo will pay NEE an annual management fee equal to the greater of 1% of the sum of NEP OpCo’s net income plus interest expense, income tax expense and depreciation and amortization expense less certain non-cash, non-recurring items for the most recently ended fiscal year and $4 million (as adjusted for inflation beginning in 2016), which will be paid in quarterly installments with an additional payment each January to the extent 1% of the sum of NEP OpCo’s net income plus interest expense, income tax expense and depreciation and amortization expense less certain non-cash, non-recurring items for the preceding fiscal year exceeds $4 million (as adjusted for inflation beginning in 2016). NEP OpCo will also make certain payments to NEE based on the achievement by NEP OpCo of certain target quarterly distribution levels to its unitholders. NEP’s operations and maintenance -

19

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

related party for the three and nine months ended September 30, 2016 include approximately $12 million and $28 million, respectively, and for the three and nine months ended September 30, 2015 include $1 million and $3 million, respectively, related to the MSA.

Cash Sweep and Credit Support Agreement - Effective July 1, 2014, NEP OpCo entered into a CSCS agreement with NEER, under which NEER and certain of its subsidiaries may provide credit support in the form of letters of credit and guarantees to satisfy NEP’s subsidiaries’ contractual obligations. NEP OpCo will pay NEER an annual credit support fee based on the level and cost of the credit support provided, payable in quarterly installments. NEP’s operations and maintenance - related party for the three and nine months ended September 30, 2016 include $1 million and $2 million, respectively, and for the three and nine months ended September 30, 2015 include $1 million and $2 million, respectively, related to the CSCS agreement.

NEER and certain of its subsidiaries may withdraw funds (Project Sweeps) received by NEP OpCo under the CSCS agreement, or its subsidiaries in connection with certain of the long-term debt agreements, and hold those funds in accounts belonging to NEER or its subsidiaries to the extent the funds are not required to pay project costs or otherwise required to be maintained by NEP's subsidiaries. NEER and its subsidiaries may keep the funds until the financing agreements permit distributions to be made, or, in the case of NEP OpCo, until such funds are required to make distributions or to pay expenses or other operating costs or NEP OpCo otherwise demands the return of such funds. If NEER fails to return withdrawn funds when required by NEP's subsidiaries’ financing agreements, the lenders will be entitled to draw on credit support provided by NEER in the amount of such withdrawn funds. If NEER or one of its affiliates realizes any earnings on the withdrawn funds prior to the return of such funds, it will be permitted to retain those earnings. The cash sweep amounts held in accounts belonging to NEER or its subsidiaries as of September 30, 2016 and December 31, 2015 were approximately $346 million and $66 million, respectively, and are included in due from related parties on NEP’s condensed consolidated balance sheets.

Guarantees and Letters of Credit Entered into by Related Parties - Certain PPAs include requirements of the project entities to meet certain performance obligations. NEECH has provided letters of credit or guarantees for certain of these performance obligations and payment of any obligations from the transactions contemplated by the PPAs. In addition, certain of the financing agreements require cash and cash equivalents to be reserved for various purposes. In accordance with the terms of these financing agreements, guarantees from NEECH have been substituted in place of these cash and cash equivalents reserve requirements. Also, under certain financing agreements, indemnifications have been provided by NEECH. In addition, certain interconnection agreements and site certificates require letters of credit or a bond to secure certain payment or restoration obligations related to those agreements. NEECH also guarantees the Project Sweep amounts held in accounts belonging to NEER as described above. As of September 30, 2016, NEECH guaranteed or provided indemnifications, letters of credit or bonds totaling approximately $704 million related to these obligations. Agreements related to the sale of differential membership interests require NEER to guarantee payment of construction-related expenses that were not yet paid before the sale of the differential membership interests in VIEs as well as payments due by the VIEs and the indemnifications to the VIEs' respective investors. As of September 30, 2016, NEER guaranteed a total of approximately $144 million related to these obligations.

Due to Related Party - Non-current amounts due to related party on NEP's condensed consolidated balance sheets represent amounts owed by certain of NEP's wind projects to NEER to refund NEER for certain transmission costs paid on behalf of the wind projects. Amounts will be paid to NEER as the wind projects receive payments from third parties for related notes receivable recorded in other non-current assets on NEP’s condensed consolidated balance sheets.

Pursuant to a purchase and sale agreement, NEER paid approximately $16 million to a subsidiary of NEP in May 2016 for the right to receive CITC proceeds that otherwise would have been retained by the NEP subsidiary. At September 30, 2016, the $16 million was included in due to related parties on NEP’s condensed consolidated balance sheets. In October 2016, a subsidiary of NEP received substantially all of the CITC proceeds and paid those proceeds to NEER.

Development, Engineering and Construction Commitments - During the nine months ended September 30, 2015, NEER purchased and contributed approximately $24 million under several engineering, procurement and construction contracts related to the procurement of materials and services for certain NEP assets which were acquired while under construction and for which costs were capitalized in construction work in progress. There were no such purchases or contributions during the three and nine months ended September 30, 2016 or the three months ended September 30, 2015.

Transportation and Fuel Management Agreements - In connection with the acquisition of the Texas pipeline business described in Note 1, a subsidiary of NEP assigned to a subsidiary of NEER certain gas commodity agreements in exchange for entering into transportation agreements and a fuel management agreement whereby the benefits of the gas commodity agreements (net of transportation paid to the NEP subsidiary) are passed back to the NEP subsidiary. During the three and nine months ended September 30, 2016, NEP recognized approximately $2 million and $8 million, respectively, in revenues related to the transportation and fuel management agreements. At September 30, 2016 and December 31, 2015, approximately $1 million and $2 million, respectively, included in due from related parties reflects amounts due from the NEER subsidiary under the transportation and fuel management agreements.

20

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

(unaudited)

9. SUMMARY OF SIGNIFICANT ACCOUNTING AND REPORTING POLICIES

Leases - In February 2016, the FASB issued an accounting standard update which requires, among other things, that lessees recognize a lease liability, initially measured at the present value of the future lease payments, and a right-of-use asset, for all leases (with the exception of short-term leases). The standards update will be effective for NEP beginning January 1, 2019. Early adoption is permitted. Lessees and lessors must apply a modified retrospective approach for all leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. NEP is currently evaluating the effect the adoption of this standard update will have on its consolidated financial statements.

10. COMMITMENTS AND CONTINGENCIES

Land Use Commitments - The project owners are parties to various agreements that provide for payments to landowners for the right to use the land upon which the projects are located. These leases and easements can typically be renewed by the project owners for various periods. The annual fees range from minimum rent payments varying by lease to maximum rent payments of a certain percentage of gross revenues, varying by lease. Total lease expense was approximately $4 million and $5 million for the three months ended September 30, 2016 and 2015, respectively, and $15 million and $14 million for the nine months ended September 30, 2016 and 2015, respectively, and is included in operations and maintenance expenses in NEP's condensed consolidated statements of income.

The total minimum non-cancelable rental commitments at September 30, 2016 under these land use agreements are as follows:

	Land Use Commitments
	(millions)
Remainder of 2016	$	2
2017	10
2018	10
2019	10
2020	10
Thereafter	286
Total minimum land use payments	$	328

One of NEP’s solar project's land leases includes a right-of-way lease/grant that provides for payments to the BLM for the right to use the public lands upon which the project is located. The lease may be renewed at expiration at the solar project's option and will be subject to the regulations existing at the time of renewal. In connection with the terms of this lease, the solar project obtained a surety bond from a non-affiliated party in favor of the BLM for approximately $23 million. The surety bond remains in effect until the BLM is satisfied that there is no outstanding liability on the bond or satisfactory replacement bond coverage is furnished. Certain varying lease payments are considered contingent rent and, therefore, expense is recognized as incurred.

Letter of Credit Facilities - Two of NEP’s projects entered into letter of credit (LOC) facilities under which the LOC lenders may issue standby letters of credit not to exceed approximately $119 million in the aggregate. These LOC facilities have maturity dates of August 2017 and March 2022. Approximately $104 million of LOCs are outstanding as of September 30, 2016 primarily related to debt service reserves and security for certain of the projects' agreements, including a PPA.

Canadian FIT Contracts -The FIT contracts relating to NEP's wind projects located in Canada (Canadian projects) require suppliers to source a minimum percentage of their equipment and services from Ontario resident suppliers to meet the minimum required domestic content level (MRDCL). The MRDCL for two projects is 25% and the MRDCL for the other two projects is 50%. Following their respective CODs, the Canadian projects submitted reports to the Independent Electricity System Operator (IESO) summarizing how they achieved the MRDCL for their respective projects (domestic content reports) and the IESO issued letters to the Canadian projects acknowledging the completeness of their domestic content reports. The IESO has the right to audit the Canadian projects for a period of up to 7 years post-COD to confirm that they complied with the domestic content requirements under their respective FIT contracts and achieved their respective MRDCLs. The failure by any of these projects to achieve its MRDCL could result in a default by such project under its FIT contract, which default may not be possible to cure and could result in a termination of its FIT contract, without compensation, by the IESO. A termination of the FIT contract for any of these Canadian projects could negatively affect revenues generated by such project and have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.

21

NEXTERA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Concluded)

(unaudited)

Acquisition Holdbacks - At September 30, 2016 and December 31, 2015, NEP's condensed consolidated balance sheets include acquisition holdbacks related to certain contingent payments for the acquisition of the Texas pipeline business. The acquisition purchase price is subject to (i) a $200 million holdback payable, in whole or in part, upon satisfaction of financial performance and capital expenditure thresholds relating to planned expansion projects (contingent holdback) and (ii) a $200 million holdback retained to satisfy any indemnification obligations of the sellers through April 2017 (indemnity holdback). See Note 3 - Contingent Consideration for further discussion of the contingent holdback.

22

Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations

Overview

NEP is a growth-oriented limited partnership formed by NEE to acquire, manage and own contracted clean energy projects with stable long-term cash flows. At September 30, 2016, NEP owns a controlling, non-economic general partner interest and an approximately 34.8% limited partner interest in NEP OpCo. Through NEP OpCo, NEP owns a portfolio of contracted renewable generation assets consisting of wind and solar projects and, since October 1, 2015, a portfolio of seven long-term contracted natural gas pipeline assets.

This discussion should be read in conjunction with the Notes contained herein and Management's Discussion and Analysis of Financial Condition and Results of Operations appearing in the 2015 Form 10-K. The results of operations for an interim period generally will not give a true indication of results for the year. In the following discussions, all comparisons are with the corresponding items in the prior year period.

NEP acquired projects during the nine months ended September 30, 2016 as further described in Note 1. The common control acquisitions were a transfer of assets between entities under common control, which required them to be accounted for as if the transfers occurred since the inception of common control, with prior periods retrospectively adjusted to furnish comparative information. Accordingly, the accompanying condensed consolidated financial statements have been retrospectively adjusted to include the historical results and financial position of the common control acquisitions prior to their respective acquisition dates.

On October 28, 2016, a subsidiary of NEP completed the acquisition of an indirect 24% interest in Desert Sunlight from NEER (see Note 1).

Results of Operations

	Three Months Ended   September 30,						Nine Months Ended   September 30,
	2016			2015(a)			2016			2015(a)
	(millions)
Statement of Operations Data:
OPERATING REVENUES	$	186		$	115		$	539		$	348
OPERATING EXPENSES
Operations and maintenance	34			22			101			62
Operations and maintenance - related party	17			4			41			13
Depreciation and amortization	51			38			151			111
Taxes other than income taxes and other	5			3			14			10
Total operating expenses	107			67			307			196
OPERATING INCOME	79			48			232			152
OTHER INCOME (DEDUCTIONS)
Interest expense	(41		)	(31		)	(203		)	(85		)
Benefits associated with differential membership interests - net	13			5			41			17
Equity in losses of equity method investees	—			—			(20		)	(1		)
Revaluation of contingent consideration	101			—			118			—
Other - net	—			(4		)	(4		)	(4		)
Total other income (deductions) - net	73			(30		)	(68		)	(73		)
INCOME BEFORE INCOME TAXES	152			18			164			79
INCOME TAXES	25			5			15			12
NET INCOME	$	127		$	13		$	149		$	67

_________________________

(a) Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

23

Three Months Ended September 30, 2016 Compared to Three Months Ended September 30, 2015

Operating Revenues

Operating revenues primarily consist of income from the sale of energy under PPAs and services provided under natural gas transportation agreements. Operating revenues increased approximately $71 million during the three months ended September 30, 2016 primarily due to revenues of approximately $47 million related to the acquisition of the Texas pipelines in October 2015, stronger wind and solar resource and revenues of approximately $10 million related to the commencement of commercial operations at two wind facilities in December 2015.

	Three Months Ended   September 30,
	2016		2015
	(dollars in millions)
Operating revenues	$	186	$	115
Generation	1,906 GWh		1,575 GWh

Operating Expenses

Operations and Maintenance

O&M expense (including related party) includes interconnection costs, labor expenses, turbine servicing costs, lease royalty payments, property taxes, insurance, materials, supplies, shared services and administrative expenses attributable to NEP's projects, and costs and expenses under the MSA, ASAs and O&M agreements (see Note 8). O&M expenses also include the cost of maintaining and replacing certain parts for the projects in the portfolio to maintain, over the long-term, operating income or operating capacity. O&M expense (including related party) increased approximately $25 million during the three months ended September 30, 2016 primarily due to an increase of $13 million related to the acquisition of the Texas pipelines in October 2015 and an increase of $10 million in IDR fees related to growth in NEP's distributions to its unitholders.

Depreciation and Amortization

Depreciation and amortization expense reflects costs associated with depreciation and amortization of NEP's assets, based on consistent depreciable asset lives and depreciation methodologies. For certain of NEP's renewable energy projects in the U.S., CITCs have been elected and are recorded as a reduction in property, plant and equipment - net on the condensed consolidated balance sheets and amortized as a reduction to depreciation and amortization expense over the estimated life of the related property. Depreciation and amortization expense also includes a provision for wind and solar facility dismantlement, asset removal costs and accretion related to asset retirement obligations and the amortization of finite-lived intangible assets.

Depreciation and amortization expense increased approximately $13 million during the three months ended September 30, 2016 primarily due to $9 million of depreciation and amortization related to the acquisition of the Texas pipelines in October 2015 and $4 million related to the commencement of commercial operations at two wind facilities in December 2015.

Other Income (Deductions)

Interest Expense

Interest expense primarily consists of interest on long-term debt and mark-to-market losses on interest rate swaps, partially offset by interest capitalization on qualified expenditures. Interest expense increased approximately $10 million during the three months ended September 30, 2016 primarily due to additional borrowings to fund project acquisitions and the debt assumed in the acquisition of the Texas pipelines in October 2015.

Benefits Associated with Differential Membership Interests - net

Benefits associated with differential membership interests - net reflect benefits recognized by NEP as third-party investors received their portion of the economic attributes of the underlying wind projects, including income tax attributes, net of associated costs. The increase in benefits of approximately $8 million during the three months ended September 30, 2016 relates to lower interest costs of approximately $4 million primarily associated with the ongoing paydown of the differential membership interest obligations and increased wind resource at the underlying projects and $4 million of benefits related to differential membership interests sold in December 2015.

Revaluation of Contingent Consideration

For the three months ended September 30, 2016, revaluation of contingent consideration reflects a fair value adjustment of approximately $101 million to decrease the contingent holdback associated with the acquisition of the Texas pipelines. See Note 3 - Contingent Consideration.

24

Income Taxes

For periods after the NEP acquisition date, income taxes include NEP's applicable ownership share of U.S. taxes and 100% of Canadian taxes. Net income or loss attributable to noncontrolling interest includes no U.S. taxes and NEER's applicable ownership share of Canadian taxes. Net income attributable to NEP includes NEP's applicable ownership share of U.S. and Canadian taxes.

For the three months ended September 30, 2016, NEP recorded income tax expense of approximately $25 million, resulting in an effective tax rate of approximately 16%. The tax expense is comprised primarily of income tax expense of approximately $53 million at the statutory rate of 35%, $4 million of state income taxes and $5 million due to earnings mix, partly offset by $37 million of income tax benefit attributable to noncontrolling interest.

For the three months ended September 30, 2015, NEP recorded income tax expense of approximately $5 million resulting in an effective tax rate of approximately 28%. The tax expense is comprised primarily of income tax expense of approximately $6 million at the statutory rate of 35% and a deferred tax adjustment of $2 million, partly offset by $4 million of income tax benefit attributable to noncontrolling interest.

Due to the transition from predecessor to successor method of accounting for income taxes, comparing current period results to the same period in the prior year does not provide meaningful information. See Note 2.

Nine Months Ended September 30, 2016 Compared to Nine Months Ended September 30, 2015

Operating Revenues

Operating revenues increased approximately $191 million during the nine months ended September 30, 2016 primarily due to revenues of approximately $138 million related to the acquisition of the Texas pipelines in October 2015, stronger wind and solar resource and revenues of $27 million related to the commencement of commercial operations at two wind facilities in December 2015.

	Nine Months Ended   September 30,
	2016		2015
	(dollars in millions)
Operating revenues	$	539	$	348
Generation	6,176 GWh		5,218 GWh

Operating Expenses

Operations and Maintenance

O&M expense (including related party) increased approximately $67 million during the nine months ended September 30, 2016 primarily due to approximately $32 million of expenses related to the acquisition of the Texas pipelines in October 2015 and an increase in IDR fees of approximately $24 million related to growth in NEP's distributions to its unitholders.

Depreciation and Amortization

Depreciation and amortization expense increased approximately $40 million during the nine months ended September 30, 2016 primarily due to $26 million of depreciation and amortization related to the acquisition of the Texas pipelines in October 2015 and $12 million related to the commencement of commercial operations at two wind facilities in December 2015.

Other Income (Deductions)

Interest Expense

Interest expense increased approximately $118 million during the nine months ended September 30, 2016 primarily due to mark-to-market losses on interest rate swaps for which hedge accounting was discontinued in January 2016, additional borrowings to fund project acquisitions and the debt assumed in the acquisition of the Texas pipelines in October 2015.

Benefits Associated with Differential Membership Interests - net

The increase in benefits associated with differential membership interests - net of approximately $24 million during the nine months ended September 30, 2016 primarily relates to lower interest costs of approximately $16 million associated with the ongoing paydown of the differential membership interest obligations and increased wind resource at the underlying projects and $8 million in benefits related to differential membership interests sold in December 2015.

25

Equity in losses of equity method investees

The increase of approximately $19 million in equity in losses of equity method investees primarily reflects an increase in interest expense recorded at the equity method investees primarily due to mark-to-market losses on interest rate swaps for which hedge accounting was discontinued in January 2016.

Revaluation of Contingent Consideration

For the nine months ended September 30, 2016, revaluation of contingent consideration reflects a fair value adjustment of approximately $118 million to decrease the contingent holdback associated with the acquisition of the Texas pipelines. See Note 3 - Contingent Consideration.

Income Taxes

For the nine months ended September 30, 2016, NEP recorded income tax expense of approximately $15 million, resulting in an effective tax rate of approximately 9%. The tax expense is comprised primarily of income tax expense of approximately $57 million at the statutory rate of 35%, $5 million of state income taxes and $4 million due to earnings mix, partly offset by income tax benefits of approximately $12 million related to the reorganization of Canadian assets (see Note 2) and $41 million of income tax benefit attributable to noncontrolling interest.

For the nine months ended September 30, 2015, NEP recorded income tax expense of approximately $12 million resulting in an effective tax rate of approximately 15%. The tax expense is comprised primarily of income tax expense of approximately $27 million at the statutory rate of 35%, partly offset by income tax benefits of $4 million related to valuation allowance changes and $14 million of income tax benefit attributable to noncontrolling interest.

Due to the transition from predecessor to successor method of accounting for income taxes, comparing current period results to the same period in the prior year does not provide meaningful information. See Note 2.

Liquidity and Capital Resources

NEP’s ongoing operations use cash to fund O&M expenses, maintenance capital expenditures, debt service payments and distributions to common unit holders. NEP expects to satisfy these requirements primarily with internally generated cash flow. In addition, as a growth-oriented limited partnership, NEP expects from time to time to make acquisitions and other investments. These acquisitions and investments are expected to be funded with cash on hand, cash generated from operations, borrowings under NEP's credit facilities or term loans, issuances of indebtedness and issuances of additional NEP common units.

These sources of funds are expected to be adequate to provide for NEP's short-term and long-term liquidity and capital needs, although its ability to make future acquisitions, expand existing projects and increase its distributions to common unitholders will depend on its ability to access the capital markets on acceptable terms.

As a normal part of its business, depending on market conditions, NEP expects from time to time to consider opportunities to repay, redeem, repurchase or refinance its indebtedness. In addition, NEP expects from time to time to consider potential investments in new acquisitions. These events may cause NEP to seek additional debt or equity financing, which may not be available on acceptable terms or at all. Debt financing, if available, could impose operating restrictions, additional cash payment obligations and additional covenants.

NEP OpCo has agreed to allow NEER or one of its affiliates to withdraw funds received by NEP OpCo or its subsidiaries and to hold those funds in accounts of NEER or one of its affiliates to the extent the funds are not required to pay project costs or otherwise required to be maintained by NEP's subsidiaries, until the financing agreements permit distributions to be made, or, in the case of NEP OpCo, until such funds are required to make distributions or to pay expenses or other operating costs. NEP OpCo will have a claim for any funds that NEER fails to return:

• when required by its or its subsidiaries’ financings;

• when its subsidiaries’ financings otherwise permit distributions to be made to NEP OpCo;

• when funds are required to be returned to NEP OpCo; or

• when otherwise demanded by NEP OpCo.

In addition, NEER and certain of its subsidiaries may withdraw funds in connection with certain long-term debt agreements and hold those funds in accounts belonging to NEER or its subsidiaries and provide credit support in the amount of such withdrawn funds. If NEER fails to return withdrawn funds when required by NEP's subsidiaries’ financings, the lenders will be entitled to draw on credit support provided by NEER in the amount of such withdrawn funds.

If NEER or one of its affiliates realizes any earnings on the withdrawn funds prior to the return of such funds, it will be permitted to retain those earnings.

26

Liquidity Position

At September 30, 2016 and December 31, 2015, NEP's liquidity position was approximately $794 million and $719 million, respectively. The table below provides the components of NEP’s liquidity position:

	September 30, 2016				December 31, 2015
	(millions)
Cash and cash equivalents	$	133			$	164
Amounts due under the CSCS agreement	346				66
Revolving credit facilities	400				400
Less borrowings	(100		)	(a)	(29		)
Construction loan credit facility	—				604
Less borrowings	—				(491		)
Letter of credit facilities	119				83
Less letters of credit	(104		)		(78		)
Total(b)	$	794			$	719

____________________

(a) In October 2016, $50 million of such borrowings were repaid.

(b) Excludes current restricted cash of approximately $33 million and $16 million at September 30, 2016 and December 31, 2015, respectively.

Management believes that NEP's liquidity position and cash flows from operations will be adequate to finance O&M, capital expenditures, distributions to its unitholders and liquidity commitments. Management continues to regularly monitor NEP's financing needs consistent with prudent balance sheet management.

Financing Arrangements

Revolving Credit Facilities

During the nine months ended September 30, 2016, a subsidiary of NEP borrowed $75 million under its revolving credit facility and repaid all of the outstanding borrowings under such facility. As of September 30, 2016, there were no amounts due under this revolving credit facility.

During the nine months ended September 30, 2016, a subsidiary of NEP borrowed approximately $41 million under a construction loan credit facility which, in March 2016, converted to a term loan. In June 2016, the limited-recourse term loan was amended and an additional $72 million was borrowed. In July 2016, an indirect subsidiary of NEP borrowed $100 million under an existing revolving credit facility entered into in December 2015. See Note 6 - Debt.

Project Financings and Term Loans

Most of the projects in the portfolio are subject to project financings that contain certain financial covenants and distribution tests, including debt service coverage ratios. In general, these project financings contain covenants customary for these types of financings, including limitations on investments and restricted payments. Certain of NEP's project financings provide for interest payable at a fixed interest rate. However, certain of NEP's project financings accrue interest at variable rates based on the London InterBank Offered Rate and two projects accrue interest at a variable rate based upon the three-month Canadian Dealer Offered Rate. Interest rate swaps were entered into for certain of these financings to hedge against interest rate movements with respect to interest payments on the financing. Under the project financings, each project will be permitted to pay distributions out of available cash on a semi-annual basis so long as certain conditions are satisfied, including that reserves are funded with cash or credit support, no default or event of default under the applicable financings has occurred and is continuing at the time of such distribution or would result therefrom, and each project is otherwise in compliance with the project financing’s covenants and the applicable minimum debt service coverage ratio is satisfied. The minimum debt service coverage ratio that must be satisfied under all of NEP's project financings is 1.20:1.00. At October 31, 2016, NEP's subsidiaries were in compliance with all financial debt covenants under their project financings.

In July 2016, an indirect subsidiary of NEP entered into and borrowed $100 million under a variable rate senior secured term loan agreement that matures in June 2019. See Note 6 - Debt.

Equity Arrangements

During the nine months ended September 30, 2016, NEP issued 552,210 common units under the ATM program for gross proceeds of approximately $16 million. At September 30, 2016, NEP may issue up to approximately $109 million in additional common units under the ATM program.

27

In February and March 2016, NEP completed the sale of 11,155,000 common units representing limited partner interests in NEP in a public offering for an aggregate purchase price of approximately $287 million, or $25.76 per common unit. In September 2016, NEP completed the sale of 11,962,300 common units representing limited partner interests in NEP in a public offering for an aggregate purchase price of approximately $342 million, or $28.56 per common unit. See Note 6 - Equity. The issuance of additional common units during the nine months ended September 30, 2016 resulted in an increase of NEP's limited partner interest in NEP OpCo to approximately 34.8% at September 30, 2016.

If at any time, NEP GP and its affiliates own more than 80% of the sum of NEP's outstanding common units and special voting units, NEP GP will have the right, but not the obligation, to purchase all of the outstanding common units, other than those owned by NEP GP and its affiliates, at a price not less than the greater of the then-current market price of such common units and the highest price paid by NEP GP or its affiliates for such units during the preceding 90-day period. At September 30, 2016, NEP GP and its affiliates controlled approximately 65.2% of the voting power of NEP's outstanding common units.

Contractual Obligations

NEP's contractual obligations as of September 30, 2016 were as follows:

	Remainder of 2016		2017		2018		2019		2020		Thereafter		Total
	(millions)
Debt, including interest(a)	$	48	$	238	$	861	$	346	$	531	$	2,967	$	4,991
Contractual obligations(b)	3		212		14		14		13		51		307
Revolving credit facility fees	—		1		1		1		—		—		3
Asset retirement activities(c)	—		—		—		—		—		274		274
MSA and credit support(d)	2		7		7		7		7		100		130
Land lease payments(e)	2		10		10		10		10		286		328
Total	$	55	$	468	$	893	$	378	$	561	$	3,678	$	6,033

____________________

(a) Includes principal, interest and interest rate swaps. Variable rate interest was computed using September 30, 2016 rates.

(b) Includes obligations related to the indemnity holdback discussed in Note 10 and estimated cash payments related to the acquisition of certain development rights and differential membership interests. Excludes the contingent holdback discussed in Note 3.

(c) Represents expected cash payments adjusted for inflation for estimated costs to perform asset retirement activities.

(d) Represents minimum fees under the MSA and CSCS agreement. See Note 8.

(e) Represents various agreements that provide for payments to landowners for the right to use the land upon which the projects are located.

Capital Expenditures

Annual capital spending plans are developed based on projected requirements by the projects. Capital expenditures primarily represent the estimated cost of capital improvements, including construction expenditures that are expected to increase NEP OpCo’s operating income or operating capacity over the long-term. Capital expenditures for projects that have already commenced commercial operations are generally not significant because most expenditures relate to repairs and maintenance and are expensed when incurred. For the nine months ended September 30, 2016 and 2015, NEP had capital expenditures of approximately $285 million and $407 million, respectively, primarily related to construction prior to the NEP acquisition date. At September 30, 2016, estimated capital expenditures for NEP's renewable energy projects for the remainder of 2016 and 2017 total approximately $15 million and $2 million, respectively. Planned capital expenditures associated with the Texas pipelines for the remainder of 2016 and 2017 total approximately $24 million and $150 million, respectively, and primarily relate to the planned expansion projects contemplated in the acquisition. There are no significant additional planned capital expenditures for the remainder of 2016 through 2020 other than costs that may be incurred as acquisition opportunities arise. These estimates are subject to continuing review and adjustment and actual capital expenditures may vary significantly from these estimates.

Cash Distributions to Unitholders

NEP's partnership agreement requires it to distribute available cash quarterly. Generally, available cash is all cash on hand at the date of determination relating to that quarter (including any expected distributions from NEP OpCo), less the amount of cash reserves established by NEP GP. NEP currently expects that cash reserves would be established solely to provide for the payment of income taxes by NEP, if any. Cash flow is generated from distributions NEP receives from NEP OpCo each quarter and, during the purchase price adjustment period, which is expected to extend into the fourth quarter of 2016, from NEE Equity, which payments will be funded solely by any distributions NEE Equity receives from NEP OpCo with respect to such quarter. Although, as described above, NEP currently expects that cash reserves would be established by NEP GP solely to provide for the payment of any NEP's income taxes, NEP expects NEP OpCo to establish cash reserves prior to making distributions to NEP to pay costs and expenses of NEP's subsidiaries, in addition to NEP's expenses, as well as any debt service requirements and future capital expenditures. During the purchase price adjustment period, should NEP OpCo not make a quarterly distribution in an amount at least equal to the minimum quarterly distribution of $0.1875 per common unit, the purchase price paid for NEP OpCo's common units under the purchase agreement will be reduced by the difference for such quarter and NEE Equity will pay NEP a purchase price adjustment equal to

28

such shortfall, provided that NEE Equity will not be required to pay a purchase price adjustment in any quarter in excess of the distribution actually received by NEP OpCo.

NEP OpCo's partnership agreement requires it to distribute all of its available cash to its common unitholders, including NEP, each quarter. Generally, NEP OpCo's available cash is all cash on hand at the date of determination relating to that quarter, plus any funds borrowed from NEER, less the amount of cash reserves established by NEE Operating GP. The majority of such available cash will be derived from the operations of the projects. The cash available for distribution is likely to fluctuate from quarter to quarter, and in some cases significantly, as a result of the performance of the projects, seasonality, fluctuating wind resource, maintenance and outage schedules, timing of debt service and other factors.

During the nine months ended September 30, 2016, NEP distributed approximately $37 million to its unitholders. On October 31, 2016, the board of directors of NEP GP authorized a distribution of $0.34125 per common unit payable on November 14, 2016 to its unitholders of record on November 8, 2016.

Cash Flows

Nine Months Ended September 30, 2016 Compared to Nine Months Ended September 30, 2015

The following table reflects the changes in cash flows for the comparative periods:

	2016			2015			Change
	(millions)
Nine Months Ended September 30,
Net cash provided by operating activities	$	247		$	181		$	66
Net cash used in investing activities	$	(1,220	)	$	(620	)	$	(600	)
Net cash provided by financing activities	$	940		$	1,048		$	(108	)

Net Cash Provided by Operating Activities

Changes in net cash provided by operating activities were primarily driven by the operating results of the Texas pipelines acquired in October 2015, the commencement of commercial operations at two wind facilities in December 2015 and stronger wind resource.

Net Cash Used in Investing Activities

The increase in net cash used in investing activities was driven by payments to related parties under the CSCS agreement in 2016 compared to payments from related parties in 2015, increased capital expenditures related to construction activities and increases in restricted cash balances related to the timing of construction payments, partly offset by fewer project acquisitions in 2016.

	2016			2015
	(millions)
Nine Months Ended September 30,
Acquisition of membership interests in subsidiaries	$	(641	)	$	(716	)
Capital expenditures	(276		)	(149		)
Changes in restricted cash	(23		)	66
Payments (to) from related parties under CSCS agreement - net	(280		)	179
Net cash used in investing activities	$	(1,220	)	$	(620	)

Net Cash Provided by Financing Activities

Changes in net cash provided by financing activities primarily reflect increased issuances of additional NEP common units, reduced issuances of debt to acquire additional projects, retirements of long-term debt and member contributions (distributions) - net. Additionally, in the nine months ended September 30, 2015, NEP OpCo issued common units to noncontrolling interests primarily to acquire additional projects.

	2016			2015
	(millions)
Nine Months Ended September 30,
Proceeds from issuance of common units - net	$	645		$	319
Issuances of long-term debt - net	194			368
Member contributions (distributions) - net	97			(324		)
Proceeds from (repayments of) short-term debt - net	(12		)	12
Change in amounts due to related parties	17			(20		)
Proceeds from issuance of NEP OpCo common units to noncontrolling interest	—			702
Other	(1		)	(9		)
Net cash provided by financing activities	$	940		$	1,048

29

New Accounting Rules and Interpretations

Leases - In February 2016, the FASB issued an accounting standards update which requires, among other things, that lessees recognize a lease liability and a right-of-use asset for all leases. See Note 9.

Quantitative and Qualitative Disclosures about Market Risk

NEP is exposed to several market risks in its normal business activities. Market risk is the potential loss that may result from market changes associated with its business. The types of market risks include interest rate, counterparty credit and foreign currency risks.

Interest Rate Risk

NEP is exposed to risk resulting from changes in interest rates associated with current and future issuances of debt. The debt of some of its subsidiaries accrues interest at fixed rates and the debt of some of its other subsidiaries accrues interest at variable rates. NEP manages interest rate exposure by monitoring current interest rates, entering into interest rate swap contracts and using a combination of fixed rate and variable rate debt. Interest rate swaps are used to mitigate or adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.

NEP has long-term debt instruments that subject it to the risk of loss associated with movements in market interest rates. As of September 30, 2016, approximately 25% of the long-term debt, including current maturities, was exposed to such risk while the remaining balance was either financially hedged or comprised of fixed rate debt. As of September 30, 2016, the estimated fair value and the carrying value of NEP's long-term debt was approximately $3.9 billion and $3.7 billion, respectively. Based upon a hypothetical 10% decrease in interest rates, which is a reasonable near-term market change, the fair value of NEP's long-term debt, including current maturities, would increase by approximately $52 million.

Counterparty Credit Risk

Risks surrounding counterparty performance and credit risk could ultimately impact the amount and timing of expected cash flows. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties under the terms of their contractual obligations. NEP monitors and manages credit risk through credit policies that include a credit approval process and the use of credit mitigation measures such as prepayment arrangements in certain circumstances. NEP also seeks to mitigate counterparty risk by having a diversified portfolio of counterparties. In addition, the projects in NEP's portfolio are contracted under long-term contracts that have an average remaining contract term of approximately 19 years as of September 30, 2016, weighted based on forecasted contributions to earnings.

Foreign Currency Risk

Because NEP has Canadian operations, it is exposed to foreign currency exchange gains and losses. Since the functional currency of NEP's Canadian operations is in their local currency, the currency effects of translating the financial statements of those Canadian subsidiaries, which operate in local currency environments, are included in the accumulated other comprehensive loss component of consolidated equity and do not impact earnings. However, gains and losses related to foreign currency transactions not in NEP's subsidiaries’ functional currency do impact earnings and resulted in less than $1 million of gains or losses in the three and nine months ended September 30, 2016 and 2015.

30

Item 3.  Quantitative and Qualitative Disclosures About Market Risk

See Management's Discussion - Quantitative and Qualitative Disclosures About Market Risk.

Item 4.  Controls and Procedures

(a) Evaluation of Disclosure Controls and Procedures

As of September 30, 2016, NEP had performed an evaluation, under the supervision and with the participation of its management, including the chief executive officer and chief financial officer of NEP GP, the general partner of NEP, of the effectiveness of the design and operation of NEP's disclosure controls and procedures (as defined in the Securities Exchange Act of 1934 Rules 13a-15 (e) and 15d-15(e)). Based upon that evaluation, the chief executive officer and the chief financial officer of NEP GP concluded that NEP's disclosure controls and procedures were effective at a reasonable assurance level to ensure that information required to be disclosed in reports that are filed or submitted under the Securities Exchange Act of 1934 are recorded, processed, summarized and reported within time periods specified in SEC rules and forms, as of September 30, 2016. Management recognizes that any controls and procedures, no matter how well designed and operated, can provide only a reasonable assurance of achieving their objectives and management necessarily applies its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

(b) Changes in Internal Control Over Financial Reporting

NEP is continuously seeking to improve the efficiency and effectiveness of its operations and of its internal controls. This results in refinements to processes throughout NEP. There has been no change in NEP's internal control over financial reporting (as defined in the Securities Exchange Act of 1934 Rules 13a-15(f) and 15d-15(f)) that occurred during NEP's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, NEP's internal control over financial reporting other than the development of certain process level controls related to the acquisition of the Texas pipeline business.

In October 2015, a subsidiary of NEP acquired the Texas pipeline business. NEP’s management elected to exclude from its assessment of internal control over financial reporting as of September 30, 2016 the Texas pipeline business, whose financial statements reflect total assets and operating revenues representing approximately 29% and 26%, respectively, of NEP’s consolidated total assets and operating revenues as of and for the nine months ended September 30, 2016. NEP is in the process of evaluating the impact of the Texas pipeline business on NEP’s internal control over financial reporting and will include the Texas pipeline business in its assessment as of December 31, 2016.

31

PART II - OTHER INFORMATION

Item 1A. Risk Factors

There have been no material changes from the risk factors disclosed in the 2015 Form 10-K. The factors discussed in Part I, Item 1A. Risk Factors in the 2015 Form 10-K, as well as other information set forth in this report, which could materially adversely affect NEP's business, financial condition, results of operations, cash available for distribution and prospects should be carefully considered. The risks described in the 2015 Form 10-K are not the only risks facing NEP. Additional risks and uncertainties not currently known to NEP, or that are currently deemed to be immaterial, also may materially adversely affect NEP's business, financial condition, results of operations, cash available for distribution and prospects.

Item 6. Exhibits

Exhibit Number	Description
10.1	NextEra Energy Partners, LP Compensation Summary for Independent Non-Employee Director of NextEra Energy Partners GP, Inc. effective January 1, 2016
10.2*	Amendment No. 1 to Exchange Agreement by and among NextEra Energy Equity Partners, LP, NextEra Energy Operating Partners, LP, NextEra Energy Partners GP, Inc. and NextEra Energy Partners, LP dated as of July 5, 2016 (filed as Exhibit 10 to Form 10-Q for the quarter ended June 30, 2016 File No. 1-36518)
12	Computation of Ratios
31(a)	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer of NextEra Energy Partners GP, Inc.
31(b)	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer of NextEra Energy Partners GP, Inc.
32	Section 1350 Certification of NextEra Energy Partners, LP
101.INS	XBRL Instance Document
101.SCH	XBRL Schema Document
101.PRE	XBRL Presentation Linkbase Document
101.CAL	XBRL Calculation Linkbase Document
101.LAB	XBRL Label Linkbase Document
101.DEF	XBRL Definition Linkbase Document

____________________

* Incorporated herein by reference.

NEP agrees to furnish to the SEC upon request any instrument with respect to long-term debt that NEP has not filed as an exhibit pursuant to the exemption provided by Item 601(b)(4)(iii)(A) of Regulation S-K.

32

SIGNATURES

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

Date:  October 31, 2016

NEXTERA ENERGY PARTNERS, LP
(Registrant)
By:	NextEra Energy Partners GP, Inc., its general partner
TERRELL KIRK CREWS, II
Terrell Kirk Crews, II Controller and Chief Accounting Officer (Principal Accounting Officer)

33

EX-10.1

Exhibit 10.1

NEXTERA ENERGY PARTNERS, LP

COMPENSATION SUMMARY FOR INDEPENDENT NON-EMPLOYEE DIRECTOR OF

NEXTERA ENERGY PARTNERS GP, INC.

(Effective January 1, 2016)

Annual Retainer     (payable quarterly)	$55,000
Committee Chair retainer (annual)     (payable quarterly)	$15,000
Annual grant of restricted common units      (under 2014 Long-Term Incentive Plan)	That number of common units determined by dividing $105,000 by closing price of NextEra Energy Partners, LP common units on effective date of grant (rounded up to the nearest 10 common units)
Miscellaneous	Travel and Accident Insurance (including spouse coverage)

EX-12

Exhibit 12

NEXTERA ENERGY PARTNERS, LP

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES AND

RATIO OF EARNINGS TO COMBINED FIXED CHARGES AND PREFERRED UNIT DISTRIBUTIONS^(a) 

	Nine Months Ended   September 30, 2016
	(millions of dollars)
Earnings, as defined:
Net income	$	149
Income tax expense	15
Fixed charges included in the determination of net income, as below	209
Amortization of capitalized interest	4
Distributed income of equity method investees	—
Less:  Equity in earnings (loss) of equity method investees	(20		)
Total earnings, as defined	$	397
Fixed charges, as defined:
Interest expense	$	203
Rental interest factor	6
Fixed charges included in the determination of net income	209
Capitalized interest	—
Total fixed charges, as defined	$	209
Ratio of earnings to fixed charges and ratio of earnings to combined fixed charges and preferred unit distributions(a)	1.90

————————————

(a) NextEra Energy Partners, LP has no preference equity securities outstanding; therefore, the ratio of earnings to fixed charges is the same as the ratio of earnings to combined fixed charges and preferred unit distributions.

EX-31.A

Exhibit 31(a)

Rule 13a-14(a)/15d-14(a) Certification

I, James L. Robo, certify that:

1. I have reviewed this Form 10-Q for the quarterly period ended September 30, 2016 of NextEra Energy Partners, LP (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: October 31, 2016

JAMES L. ROBO

James L. Robo

Chairman and Chief Executive Officer

of NextEra Energy Partners GP, Inc.

EX-31.B

Exhibit 31(b)

Rule 13a-14(a)/15d-14(a) Certification

I, John W. Ketchum, certify that:

1. I have reviewed this Form 10-Q for the quarterly period ended September 30, 2016 of NextEra Energy Partners, LP (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: October 31, 2016

JOHN W. KETCHUM

John W. Ketchum

Chief Financial Officer

of NextEra Energy Partners GP, Inc.

EX-32

Exhibit 32

Section 1350 Certification

We, James L. Robo and John W. Ketchum, certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Quarterly Report on Form 10-Q of NextEra Energy Partners, LP (the registrant) for the quarterly period ended September 30, 2016 (Report) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

Dated: October 31, 2016

JAMES L. ROBO

James L. Robo

Chairman and Chief Executive Officer

of NextEra Energy Partners GP, Inc.

JOHN W. KETCHUM

John W. Ketchum

Chief Financial Officer

of NextEra Energy Partners GP, Inc.

A signed original of this written statement required by Section 906 has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section 906 of the Sarbanes-Oxley Act of 2002 and, accordingly, is not being filed with the Securities and Exchange Commission as part of the Report and is not to be incorporated by reference into any filing of the registrant under the Securities Act of 1933 or the Securities Exchange Act of 1934 (whether made before or after the date of the Report, irrespective of any general incorporation language contained in such filing).

XML

Document and Entity Information	9 Months Ended
	Sep. 30, 2016 shares
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q3
Entity Registrant Name	NEXTERA ENERGY PARTNERS, LP
Entity Central Index Key	0001603145
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	54,236,995

XML

Condensed Consolidated Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	[1]	Sep. 30, 2016		Sep. 30, 2015	[1]
Income Statement [Abstract]
OPERATING REVENUES		$ 186	$ 115		$ 539		$ 348
OPERATING EXPENSES
Operations and maintenance		34	22		101		62
Operations and maintenance - related party		17	4		41		13
Depreciation and amortization		51	38		151		111	[2]
Taxes other than income taxes and other		5	3		14		10
Total operating expenses		107	67		307		196
OPERATING INCOME		79	48		232		152
OTHER INCOME (DEDUCTIONS)
Interest expense		(41)	(31)		(203)		(85)
Benefits associated with differential membership interests - net		13	5		41		17	[2]
Equity in losses of equity method investees		0	0		(20)		(1)
Revaluation of contingent consideration		101	0		118		0
Other - net		0	(4)		(4)		(4)
Total other income (deductions) - net		73	(30)		(68)		(73)
INCOME BEFORE INCOME TAXES		152	18		164		79
INCOME TAXES		25	5		15		12
NET INCOME		127	13	[3]	149	[4],[5]	67	[2],[3],[4],[5]
Less net income attributable to noncontrolling interest(b)	[6]	100	12		109		61
NET INCOME ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP		$ 27	$ 1		$ 40		$ 6
Weighted average number of common units outstanding - basic and assuming dilution (in shares)		44.3	22.6		40.3		20.5
Earnings per common unit attributable to NextEra Energy Partners, LP - basic and assuming dilution (in dollars per share)		$ 0.62	$ 0.05		$ 0.99		$ 0.28
Distributions per common unit (in dollars per unit)		$ 0.3300	$ 0.2350		$ 0.9563		$ 0.635

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[2] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[3] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[4] Net income attributable to noncontrolling interest includes the pre-acquisition net income of the common control acquisitions. See Note 1.

[5] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[6] The calculation of net income attributable to noncontrolling interest includes the pre-acquisition net income of the common control acquisitions. See Note 1.

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	[2]	Sep. 30, 2016		Sep. 30, 2015	[2]
Statement of Comprehensive Income [Abstract]
NET INCOME		$ 127	$ 13	[1]	$ 149	[3],[4]	$ 67	[1],[3],[4],[5]
Net unrealized gains (losses) on cash flow hedges:
Effective portion of net unrealized losses (net of $3 and $4 tax benefit, respectively)		0	(16)		0		(16)
Reclassification from accumulated other comprehensive loss to net income (net of less than $1 tax benefit, less than $1, $1, and $1 tax expense, respectively)		2	1		5		4
Net unrealized gains (losses) on foreign currency translation (net of less than $1 and $1 tax benefit, $1 tax expense, and $2 tax benefit, respectively)		(1)	(11)		6		(37)
Total other comprehensive income (loss), net of tax		1	(26)		11	[4]	(49)	[4]
COMPREHENSIVE INCOME (LOSS)		128	(13)		160		18
Less comprehensive income (loss) attributable to noncontrolling interest	[6]	100	(10)		118		16
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP		$ 28	$ (3)		$ 42		$ 2

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[2] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[3] Net income attributable to noncontrolling interest includes the pre-acquisition net income of the common control acquisitions. See Note 1.

[4] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[5] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[6] The calculation of comprehensive income (loss) attributable to noncontrolling interest includes the pre-acquisition comprehensive income (loss) of the common control acquisitions. See Note 1.

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parentheticals) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	[1]	Sep. 30, 2016	Sep. 30, 2015	[1]
Statement of Comprehensive Income [Abstract]
Effective portion of net unrealized gains (losses), tax expense (benefit)	$ 3	$ 4		$ 3	$ 4
Reclassification from accumulated other comprehensive income to net income, tax expense	1	1		1	1
Unrealized gains (losses) on foreign currency translation, tax benefit	$ 1	$ 1		$ 1	$ 1

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

XML

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions		Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents		$ 133	$ 164	[1]
Accounts receivable		91	80	[1]
Due from related parties		349	70	[1]
Restricted cash		33	16	[1]
Other current assets		22	24	[1]
Total current assets		628	354	[1]
Non-current assets:
Property, plant and equipment - net		5,098	5,122	[1]
Deferred income taxes		261	176	[1]
Intangible assets - customer relationships		683	696	[1]
Goodwill		628	622	[1]
Investments in equity method investees		10	22
Other non-current assets		61	61	[1]
Total non-current assets		6,741	6,699	[1]
TOTAL ASSETS		7,369	7,053	[1]
Current liabilities:
Accounts payable and accrued expenses		15	303	[1]
Short-term debt		0	12	[1]
Due to related parties		29	17	[1]
Current maturities of long-term debt		78	101	[1]
Acquisition holdbacks		267	0	[1]
Accrued interest		20	28	[1]
Derivatives		21	22	[1]
Other current liabilities		29	29	[1]
Total current liabilities		459	512	[1]
Non-current liabilities:
Long-term debt		3,586	3,334	[1]
Deferral related to differential membership interests		897	929	[1]
Acquisition holdbacks		0	375	[1]
Deferred income taxes		37	43	[1]
Asset retirement obligation		49	41	[1]
Non-current due to related party		21	19	[1]
Other non-current liabilities		151	82	[1]
Total non-current liabilities		4,741	4,823	[1]
TOTAL LIABILITIES		5,200	5,335	[1]
COMMITMENTS AND CONTINGENCIES				[1]
EQUITY
Limited partners (common units issued and outstanding 54.2 and 30.6, respectively)		1,706	935	[1]
Accumulated other comprehensive loss		(4)	(6)	[1]
Noncontrolling interest		467	789	[1]
TOTAL EQUITY	[2]	2,169	1,718	[1]
TOTAL LIABILITIES AND EQUITY		$ 7,369	$ 7,053	[1]

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[2] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - shares shares in Millions	Sep. 30, 2016	Dec. 31, 2015	[1]
Statement of Financial Position [Abstract]
Common units outstanding	54.2	30.6
Common units issued	54.2	30.6

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2016		Sep. 30, 2015	[5]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	[1],[2]	$ 149		$ 67	[3],[4]
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		151		111	[3]
Amortization of deferred financing costs		6		4
Accretion of acquisition holdbacks		10		0
Change in value of derivative contracts		75		0
Deferred income taxes		15		7
Benefits associated with differential membership interests - net		(41)		(17)	[3]
Equity in losses of equity method investees		20		0
Change in fair value of contingent consideration for pipeline acquisition		(118)		0
Other - net		0		2
Changes in operating assets and liabilities:
Accounts receivable		(10)		0
Other current assets		1		16
Other non-current assets		(1)		(6)
Accounts payable and accrued expenses		0		4
Due to related parties		(5)		(1)
Other current liabilities		(8)		(3)
Other non-current liabilities		3		(3)
Net cash provided by operating activities		247		181
CASH FLOWS FROM INVESTING ACTIVITIES
Acquisition of membership interests in subsidiaries		(641)		(716)
Capital expenditures		(276)		(149)
Changes in restricted cash		(23)		66
Payments (to) from related parties under CSCS agreement - net		(280)		179
Net cash used in investing activities		(1,220)		(620)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common units - net		645		319
Issuances of long-term debt		671		558
Retirements of long-term debt		(477)		(190)
Deferred financing costs		(10)		(10)
Partners/Members' contributions		251		136
Partners/Members' distributions		(154)		(460)
Proceeds from differential membership investors		18		5
Payments to differential membership investors		(9)		(4)
Proceeds from short-term debt		0		325
Repayments of short-term debt		(12)		(313)
Change in amounts due to related parties		17		(20)
Proceeds from issuance of NEP OpCo common units to noncontrolling interest		0		702
Net cash provided by financing activities		940		1,048
Effect of exchange rate changes on cash		2		(3)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		(31)		606
CASH AND CASH EQUIVALENTS - BEGINNING OF PERIOD		164	[6]	111
CASH AND CASH EQUIVALENTS - END OF PERIOD		133		717
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Partners/Members' noncash distributions		31		21
Members’ noncash contributions for construction costs and other		90		285
Change in accounts receivable for CITCs		2		13
Change in investments in equity method investees - net		7		1
Asset retirement obligation additions		7		0
Change in accrued but not paid for capital expenditures		3		265
Noncash member distribution upon transition from predecessor method		3		3
Change in goodwill related to change in purchase accounting valuation		$ 6		$ 0

[1] Net income attributable to noncontrolling interest includes the pre-acquisition net income of the common control acquisitions. See Note 1.

[2] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[3] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[4] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[5] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[6] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Condensed Consolidated Statements of Changes in Equity (Unaudited) - USD ($) shares in Millions, $ in Millions		Total		Units [Member]	Limited Partners [Member]		Accumulated Other Comprehensive Loss [Member]		Noncontrolling Interest [Member]
Beginning balance, units at Dec. 31, 2014				18.7
Beginning balance at Dec. 31, 2014		$ 1,788	[1]		$ 551		$ (3)	[1]	$ 1,240	[1]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Acquisition of membership interests in subsidiaries	[1]	(716)							(716)
Limited partners/related party contribution and transition		37	[1]		34	[2]			3	[1],[3]
Issuance of common units, units				11.0
Issuance of common units		319	[1]		319
Net income	[4]	67	[1],[5],[6],[7]		6				61	[1]
Other comprehensive income (loss)		(49)	[1],[6]				(4)		(45)	[1]
Proceeds from issuance of NEP OpCo common units to noncontrolling interest	[1]	702							702
Related party contributions	[1]	422							422
Related party distributions	[1]	(470)							(470)
Distributions to unitholders		(13)	[1]		(13)
Ending balance, units at Sep. 30, 2015				29.7
Ending balance at Sep. 30, 2015		$ 2,087	[1]		897		(7)	[1]	1,197	[1]
Beginning balance, units at Dec. 31, 2015		30.6	[8]	30.6
Beginning balance at Dec. 31, 2015		$ 1,718	[1],[8]		935		(6)	[1]	789	[1]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Acquisition of membership interests in subsidiaries	[1]	(641)							(641)
Limited partners/related party contribution and transition		120	[1]		123	[2]			(3)	[1],[3]
Issuance of common units, units				23.6
Issuance of common units		645	[1]		645
Related party note receivable	[1]	(24)							(24)
Net income	[4]	149	[1]		40				109	[1]
Other comprehensive income (loss)	[1]	11					2		9
Related party contributions	[1]	350							350
Related party distributions	[1]	(122)							(122)
Distributions to unitholders		$ (37)	[1]		(37)
Ending balance, units at Sep. 30, 2016		54.2		54.2
Ending balance at Sep. 30, 2016		$ 2,169	[1]		$ 1,706		$ (4)	[1]	$ 467	[1]

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[2] Deferred tax asset recognized by NEP related to NEP equity issuances and acquisition of subsidiary membership interests.

[3] Related party noncash contribution (distribution), net, upon transition from predecessor accounting method.

[4] Net income attributable to noncontrolling interest includes the pre-acquisition net income of the common control acquisitions. See Note 1.

[5] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[6] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[7] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[8] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Acquisitions Acquisitions

9 Months Ended

Sep. 30, 2016

Business Combinations [Abstract]

Acquisitions

ACQUISITIONS

On March 1, 2016, a subsidiary of NEP completed the acquisition from NEER of Seiling Wind Investments, LLC, which indirectly owns two wind generation facilities, Seiling I and Seiling II, with a combined generating capacity of approximately 299 MW, located in Dewey and Woodward counties, Oklahoma, for approximately $323 million, plus working capital of $3 million and the assumption of $257 million in existing liabilities related to differential membership interests. As part of this acquisition and included in the cash consideration, a subsidiary of NEP acquired an approximately $25 million receivable from a subsidiary of NEER (related party note receivable) relating to operational performance issues at this facility. The related party note receivable is intended to compensate NEP for the operational performance issues and is supported in full by corrective actions or compensation expected from an equipment vendor under an undertaking the vendor has with NEER. The related party note receivable can be settled, in part or in whole, to the extent the operational performance issues are improved or resolved by the vendor by the end of 2016. This receivable bears interest at 7.1% per annum, is payable by NEER in equal semi-annual installments and matures in December 2035. The related party note receivable, interest and related payments are reflected in noncontrolling interest on the condensed consolidated financial statements.

On July 5, 2016, a subsidiary of NEP completed the acquisition from NEER of Bayhawk Wind Holdings, LLC for approximately $312 million, plus working capital of $6 million and the assumption of $253 million in existing liabilities related to differential membership interests. Bayhawk Wind Holdings, LLC indirectly owns two wind generation facilities that commenced commercial operations in December 2015, Cedar Bluff Wind and Golden Hills Wind, with a combined generating capacity of approximately 285 MW, located in Ellis, Ness, Rush and Trego counties, Kansas, and Alameda county, California, respectively.

The 2016 acquisitions discussed above and the acquisitions from NEER completed in 2015 (collectively, the common control acquisitions), were transfers of assets between entities under common control, which required them to be accounted for as if the transfers occurred since the inception of common control, with prior periods retrospectively adjusted to furnish comparative information. Accordingly, the accompanying condensed consolidated financial statements have been retrospectively adjusted to include the historical results and financial position of the common control acquisitions prior to their respective acquisition dates.

On October 28, 2016, a subsidiary of NEP completed the acquisition from NEER of an indirect 24% interest in Desert Sunlight Investment Holdings, LLC (Desert Sunlight) for $218 million, plus an adjustment of approximately $9 million related to working capital (subject to post-closing adjustments). Desert Sunlight owns two project entities, which together make up the Desert Sunlight Solar Energy Center, a 550 MW solar generation plant located in Riverside County, California. NEER retained an interest in Desert Sunlight and will remain the managing member.

On October 1, 2015, NEP acquired 100% of the membership interests in the Texas pipeline business, a developer, owner and operator of a portfolio of seven long-term contracted natural gas pipeline assets located in Texas. Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on the acquisition date based on their estimated fair value. During the nine months ended September 30, 2016, NEP recorded adjustments to the purchase price allocation which increased goodwill by approximately $6 million, decreased property, plant and equipment - net by $4 million and increased noncontrolling interest by $2 million.

Supplemental Pro forma Results of Operations

NEP’s pro forma results of operations had the acquisition of the Texas pipeline business been completed on January 1, 2014 are as follows:

	Three Months Ended   September 30, 2015			Nine Months Ended   September 30, 2015
	(millions)
Pro forma results of operations:
Pro forma revenues	$	140		$	425
Pro forma operating income	$	62		$	188
Pro forma net income	$	1		$	57
Pro forma net income (loss) attributable to NEP	$	(1	)	$	4

The pro forma consolidated results of operations include adjustments to:

• reflect the historical results of the Texas pipeline business beginning on January 1, 2014, excluding certain operations which were not acquired by NEP;

• reflect the estimated depreciation and amortization expense based on the estimated fair value of property, plant and equipment - net and the intangible assets - customer relationships;

• reflect additional interest expense related to financing transactions to fund the acquisition; and

• reflect related income tax effects.

The pro forma information is not necessarily indicative of the results of operations that would have occurred had the transaction been completed on January 1, 2014 or the future results of the consolidated operations.

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Income Taxes

9 Months Ended

Sep. 30, 2016

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

For periods prior to the date a project is acquired by NEP (NEP acquisition date), income taxes are calculated on the predecessor method using the separate return method for each of the projects acquired from NEER which are structured as limited liability companies or corporations. Income taxes are not included for entities that are structured as flow through entities (partnerships) electing to be taxed as partnerships.

For periods after the NEP acquisition date, income taxes are calculated on the successor method where taxes are calculated for NEP as a single taxpaying entity for U.S. federal and state income tax purposes. Because NEP OpCo is a limited partnership electing to be taxed as a partnership for U.S. federal and state income tax purposes, NEP only recognizes in income its applicable ownership share of U.S. income taxes related to both U.S. and Canadian projects, allocated to NEP OpCo. The Canadian subsidiaries are all Canadian taxpayers subject to Canadian income tax and, therefore, NEP recognizes in income all of the Canadian taxes.

Consequently for periods after the NEP acquisition date, income taxes include NEP's applicable ownership share of U.S. taxes and 100% of Canadian taxes. Net income or loss attributable to noncontrolling interest includes no U.S. taxes and NEER's applicable ownership share of Canadian taxes. Net income attributable to NEP includes NEP's applicable ownership share of U.S. and Canadian taxes.

The effective tax rates for the three months ended September 30, 2016 and 2015 were approximately 16% and 28%, respectively, and for the nine months ended September 30, 2016 and 2015 were approximately 9% and 15%, respectively. The effective tax rate is affected by recurring items, such as the relative amount of income earned in jurisdictions (earnings mix), valuation allowances on deferred tax assets, taxes attributable to the noncontrolling interest and the taxation of Canadian income in both Canada and the U.S.

Additionally, the effective tax rate for the nine months ended September 30, 2016 was affected by an April 2016 court decision approving a reorganization of certain of NEP's Canadian assets that provided for tax bases in certain of these assets. NEP recorded approximately $12 million of the associated income tax benefits during the nine months ended September 30, 2016.

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Fair Value Measurements

9 Months Ended

Sep. 30, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS

The fair value of assets and liabilities are determined using either unadjusted quoted prices in active markets (Level 1) or pricing inputs that are observable (Level 2) whenever that information is available and using unobservable inputs (Level 3) to estimate fair value only when relevant observable inputs are not available. NEP uses several different valuation techniques to measure the fair value of assets and liabilities relying primarily on the market approach of using prices and other market information for identical or comparable assets and liabilities for those assets and liabilities that are measured at fair value on a recurring basis. Certain financial instruments may be valued using multiple inputs including discount rates, counterparty credit ratings and credit enhancements. NEP’s assessment of the significance of any particular input to the fair value measurement requires judgment and may affect the fair value measurement of its assets and liabilities and the placement of those assets and liabilities within the fair value hierarchy levels. Non-performance risk, including the consideration of a credit valuation adjustment, is also considered in the determination of fair value for all assets and liabilities measured at fair value. All transfers between fair value hierarchy levels occur at the beginning of the period in which the transfer occurred.

Cash Equivalents and Restricted Cash Equivalents - Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less, and are included in cash and cash equivalents, restricted cash and other non-current assets on the condensed consolidated balance sheets. NEP primarily holds these investments in money market funds and estimates the fair value of these funds using a market approach based on current observable market prices.

Interest Rate and Foreign Currency Contracts - NEP estimates the fair value of its derivatives using an income approach, or a discounted cash flows valuation technique, based on the net amount of estimated future cash inflows and outflows related to the agreements. The primary inputs used in the fair value measurements include the contractual terms of the derivative agreements, current interest rates, foreign currency exchange rates and credit spreads. The significant inputs for the resulting fair value measurement are market-observable inputs and the measurements are reported as Level 2 in the fair value hierarchy.

NEP’s financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	September 30, 2016						December 31, 2015
	Level 1		Level 2		Total		Level 1		Level 2		Total
	(millions)
Assets:
Cash equivalents	$	52	$	—	$	52	$	63	$	—	$	63
Restricted cash equivalents	29		—		29		5		—		5
Interest rate contracts	—		—		—		—		2		2
Foreign currency contracts	—		—		—		—		2		2
Total assets	$	81	$	—	$	81	$	68	$	4	$	72
Liabilities:
Interest rate contracts	$	—	$	133	$	133	$	—	$	68	$	68
Total liabilities	$	—	$	133	$	133	$	—	$	68	$	68

Financial Instruments Recorded at Other than Fair Value - The carrying amounts of accounts receivable, accounts payable, certain accrued expenses and short-term debt approximate their fair values. The carrying amounts and estimated fair values of other financial instruments, excluding those recorded at fair value and disclosed above, are as follows:

	September 30, 2016				December 31, 2015
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(millions)
Long-term debt, including current maturities(a)	$	3,664	$	3,876	$	3,435	$	3,532

____________________

(a) Fair value is estimated based on the borrowing rates as of each date for similar issues of debt with similar remaining maturities (Level 2).

Contingent Consideration - NEP recorded a liability related to a contingent holdback as part of the Texas pipelines acquisition. See Note 10 - Acquisition Holdbacks. The contingent holdback will be payable if the Texas pipelines enter into one or more written contracts by December 31, 2016 related to certain financial performance and capital expenditure thresholds. Contingent consideration is required to be reported at fair value at each reporting date. NEP determined this fair value measurement based on management's probability assessment. The significant inputs and assumptions used in the fair value measurement included the estimated probability of executing contracts related to financial performance and capital expenditure thresholds as well as the appropriate discount rate. At September 30, 2016 and December 31, 2015, the estimated fair value of the contingent holdback was approximately $70 million and $186 million, respectively, and is recorded as acquisition holdbacks on the condensed consolidated balance sheets. During the three and nine months ended September 30, 2016, NEP recorded approximately $101 million and $118 million, respectively, of fair value adjustments to decrease the contingent holdback based on updated estimates associated with management's probability assessment. The fair value adjustments are included in NEP's condensed consolidated statements of income.

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Derivative Instruments and Hedging Activity

9 Months Ended

Sep. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activity

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITY

NEP recognizes all derivative instruments, when required to be marked to market, on the balance sheet as either assets or liabilities and measures them at fair value each reporting period. In connection with certain of its debt financings, NEP entered into interest rate contracts to manage interest rate cash flow risk. These agreements allow NEP to offset the variability of its floating-rate loan interest cash flows with the variable interest cash flows received from the interest rate contracts. In January 2016, NEP discontinued hedge accounting for its cash flow hedges related to interest rate swaps and, therefore, essentially all changes in the fair value of the interest rate swaps are recognized in interest expense in NEP's condensed consolidated statements of income. The commencement and termination dates of the interest rate swap agreements and the related hedging relationship coincide with the corresponding dates of the underlying variable-rate debt instruments, with maturity dates through 2033. As of September 30, 2016 and December 31, 2015, the combined notional amounts of the interest rate contracts were approximately $1,435 million and $1,277 million, respectively.

At September 30, 2016, NEP's accumulated other comprehensive loss (AOCI) included amounts related to discontinued cash flow hedges which have expiration dates through 2033. Approximately $8 million of net losses included in AOCI at September 30, 2016, is expected to be reclassified into interest expense within the next 12 months as interest payments are made. Cash flows from these interest rate swap contracts are reported in cash flows from operating activities in NEP's condensed consolidated statements of cash flows.

During 2015 and 2016, NEP entered into certain foreign currency exchange contracts to economically hedge its cash flows from foreign currency rate fluctuations. As of September 30, 2016 and December 31, 2015, the notional amount of the foreign currency contracts was approximately $60 million and $54 million, respectively. During the three months ended September 30, 2016 and 2015, NEP recorded less than $1 million and approximately $1 million of gains, respectively, related to the foreign currency contracts in other - net in the condensed consolidated statements of income. During the nine months ended September 30, 2016 and 2015, NEP recorded approximately $2 million of losses and approximately $1 million of gains, respectively, related to the foreign currency contracts in other - net in the condensed consolidated statements of income.

Fair Value of Derivative Instruments - The tables below present NEP's gross derivative positions at September 30, 2016 and December 31, 2015, as required by disclosure rules, as well as the location of the net derivative position on the condensed consolidated balance sheets.

	September 30, 2016
	Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Total Derivatives Combined - Net Basis
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
	(millions)
Interest rate contracts	$	—	$	—	$	—	$	133	$	—	$	133
Total fair values	$	—	$	—	$	—	$	133	$	—	$	133
Net fair value by balance sheet line item:
Other current assets									$	—
Other non-current assets									—
Current derivative liabilities											$	21
Other non-current liabilities											112
Total derivatives									$	—	$	133

	December 31, 2015
	Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Total Derivatives Combined - Net Basis
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
	(millions)
Interest rate contracts	$	1	$	22	$	1	$	46	$	5	$	71
Foreign currency contracts	—		—		2		—		2		—
Total fair values	$	1	$	22	$	3	$	46	$	7	$	71
Net fair value by balance sheet line item:
Other current assets									$	2
Other non-current assets									5
Current derivative liabilities											$	22
Other non-current liabilities											49
Total derivatives									$	7	$	71

Financial Statement Impact of Derivative Instruments - Gains (losses) related to NEP's interest rate contracts are recorded in NEP's condensed consolidated financial statements as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
	(millions)
Interest rate contracts:
Losses recognized in other comprehensive income	$	—		$	(19	)	$	—		$	(20	)
Losses reclassified from AOCI to interest expense	$	(2	)	$	(1	)	$	(6	)	$	(5	)
Gains (losses) recognized in interest expense	$	1		$	—		$	(85	)	$	—

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Variable Interest Entities

9 Months Ended

Sep. 30, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Variable Interest Entities

VARIABLE INTEREST ENTITIES

In February 2015, the Financial Accounting Standards Board (FASB) issued a new accounting standard that modified consolidation guidance. The standard made changes to both the variable interest entity model and the voting interest entity model, including modifying the evaluation of whether limited partnerships or similar legal entities are VIEs or voting interest entities and amending the guidance for assessing how relationships of related parties affect the consolidation analysis of VIEs. NEP adopted the standard retrospectively beginning January 1, 2016.

As a result of the new standard, NEP has identified NEP OpCo as a VIE. NEP OpCo is a limited partnership with a general partner and limited partners. NEP has consolidated the results of NEP OpCo and its subsidiaries because of its controlling interest in the general partner of NEP OpCo. At September 30, 2016, NEP owned an approximately 34.8% limited partner interest in NEP OpCo and NEE Equity owned a noncontrolling 65.2% limited partner interest in NEP OpCo. The assets and liabilities of NEP OpCo as well as the operations of NEP OpCo represent substantially all of NEP's assets and liabilities and its operations.

In addition, at September 30, 2016, NEP consolidated four VIEs related to certain subsidiaries which have sold differential membership interests in entities which own and operate six wind electric generation facilities. Certain investors that have no equity at risk in the VIEs hold differential membership interests, which give them the right to receive a portion of the economic attributes of these wind electric generation facilities, including certain tax attributes. The assets and liabilities of the VIEs, consisting primarily of property, plant and equipment - net and deferral related to differential membership interests, totaled approximately $1,669 million and $947 million at September 30, 2016, respectively, and $1,693 million and $1,248 million at December 31, 2015, respectively.

In April 2015, a subsidiary of NEP made an equity method investment in three NEER solar projects that were under construction in California. The solar projects reached full commercial operations in June 2016. Through a series of transactions, a subsidiary of NEP issued 1,000,000 NEP OpCo Class B Units, Series 1 and 1,000,000 NEP OpCo Class B Units, Series 2, to NEER for approximately 50% of the ownership interests in the three solar projects (non-economic ownership interests). NEER, as holder of the Class B Units, will retain 100% of the economic rights in the projects to which the respective Class B Units relate, including the right to all distributions paid by the project subsidiaries that own the projects to NEP OpCo. NEER has agreed to indemnify NEP against all risks relating to NEP’s ownership of the projects until NEER offers to sell economic interests to NEP and NEP accepts such offer, if NEP chooses to do so. NEER has also agreed to continue to manage the operation of the projects at its own cost, and to contribute to the projects any capital necessary for the operation of the projects, until NEER offers to sell economic interests to NEP and NEP accepts such offer. At September 30, 2016 and December 31, 2015, NEP's equity method investment related to the non-economic ownership interests totaled approximately $10 million and $22 million, respectively, and is reflected as investments in equity method investees on the condensed consolidated balance sheets. All equity in earnings of these equity method investees is allocated to net income attributable to noncontrolling interest. NEP is not the primary beneficiary and therefore does not consolidate these entities because it does not control any of the ongoing activities of these entities, was not involved in the initial design of these entities and does not have a controlling interest in these entities.

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Capitalization

9 Months Ended

Sep. 30, 2016

Debt Disclosure [Abstract]

Capitalization

CAPITALIZATION

Debt - Significant long-term debt issuances and borrowings by subsidiaries of NEP during the nine months ended September 30, 2016 were as follows:

Date Issued	Debt Issuances/Borrowings	Interest Rate	Principal Amount			Maturity Date
			(millions)
January - March 2016	Construction loan credit facility	Variable(a)	$	41	(b)	2022
February 2016	Senior secured revolving credit facility	Variable(a)	$	75	(c)	2019
June 2016	Limited-recourse term loan	Variable(a)	$	355	(b)	2022
July 2016	Senior secured term loan	Variable(a)	$	100		2019
July 2016	Limited-recourse revolving credit facility	Variable(a)	$	100	(d)	2020

————————————

(a) Variable rate is based on an underlying index plus a margin.

(b) In March 2016, the construction loan credit facility converted to a term loan. In June 2016, this term loan was amended and approximately $72 million of additional net borrowings ($355 million of issuances net of $283 million of retirements) resulted in an outstanding term loan balance of $604 million at September 30, 2016.

(c) In September 2016, the borrowings under this credit facility were repaid. At September 30, 2016, no amounts were outstanding under this revolving credit facility.

(d) In October 2016, $50 million of the borrowings under this credit facility were repaid.

The long-term debt agreements listed above are secured by liens on certain assets and contain provisions which, under certain conditions, could restrict the payment of distributions or related party fee payments. At October 31, 2016, NEP's subsidiaries were in compliance with all financial debt covenants under their project financings.

Equity - During the nine months ended September 30, 2016, NEP issued 552,210 common units under the at-the-market equity issuance program (ATM program) for gross proceeds of approximately $16 million. Fees related to the ATM program totaled less than $1 million in 2016.

In February and March 2016, NEP completed the sale of 11,155,000 common units representing limited partnership interests in NEP in a public offering for an aggregate purchase price of approximately $287 million, or $25.76 per common unit. NEP used the proceeds to fund, together with borrowings under the senior secured revolving credit facility, the purchase price payable in the March 2016 acquisition discussed in Note 1.

In September 2016, NEP completed the sale of 11,962,300 common units representing limited partner interests in NEP in a public offering for an aggregate purchase price of approximately $342 million, or $28.56 per common unit. NEP used the proceeds to fund the purchase price payable in the October 2016 acquisition discussed in Note 1 and intends to use the remaining proceeds for general partnership purposes. The issuance of common units during the nine months ended September 30, 2016 resulted in an increase of NEP's limited partner interest in NEP OpCo to approximately 34.8% at September 30, 2016.

On October 31, 2016, the board of directors of NEP GP authorized a distribution of $0.34125 per common unit payable on November 14, 2016 to its unitholders of record on November 8, 2016.

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Accumulated Other Comprehensive Loss

9 Months Ended

Sep. 30, 2016

Equity [Abstract]

Accumulated Other Comprehensive Loss

ACCUMULATED OTHER COMPREHENSIVE LOSS

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Three months ended September 30, 2016
Balances, June 30, 2016	$	(8	)	$	(101	)	$	(109	)
Other comprehensive loss before reclassification	—			(1		)	(1		)
Amounts reclassified from AOCI to interest expense	2			—			2
Net other comprehensive income (loss)	2			(1		)	1
Balances, September 30, 2016	$	(6	)	$	(102	)	$	(108	)
AOCI attributable to noncontrolling interest	$	(6	)	$	(98	)	$	(104	)
AOCI attributable to NEP	$	—		$	(4	)	$	(4	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Gains (Losses) on Foreign Currency Translation			Total
	(millions)
Nine months ended September 30, 2016
Balances, December 31, 2015	$	(11	)	$	(108	)	$	(119	)
Other comprehensive income before reclassification	—			6			6
Amounts reclassified from AOCI to interest expense	5			—			5
Net other comprehensive income	5			6			11
Balances, September 30, 2016	$	(6	)	$	(102	)	$	(108	)
AOCI attributable to noncontrolling interest	$	(6	)	$	(98	)	$	(104	)
AOCI attributable to NEP	$	—		$	(4	)	$	(4	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Three months ended September 30, 2015
Balances, June 30, 2015	$	(1	)	$	(92	)	$	(93	)
Other comprehensive loss before reclassification	(16		)	(11		)	(27		)
Amounts reclassified from AOCI to interest expense	1			—			1
Net other comprehensive loss	(15		)	(11		)	(26		)
Balances, September 30, 2015	$	(16	)	$	(103	)	$	(119	)
AOCI attributable to noncontrolling interest	$	(13	)	$	(99	)	$	(112	)
AOCI attributable to NEP	$	(3	)	$	(4	)	$	(7	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Nine months ended September 30, 2015
Balances, December 31, 2014	$	(4	)	$	(66	)	$	(70	)
Other comprehensive loss before reclassification	(16		)	(37		)	(53		)
Amounts reclassified from AOCI to interest expense	4			—			4
Net other comprehensive loss	(12		)	(37		)	(49		)
Balances, September 30, 2015	$	(16	)	$	(103	)	$	(119	)
AOCI attributable to noncontrolling interest	$	(13	)	$	(99	)	$	(112	)
AOCI attributable to NEP	$	(3	)	$	(4	)	$	(7	)

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Related Party Transactions

9 Months Ended

Sep. 30, 2016

Related Party Transactions [Abstract]

Related Party Transactions

RELATED PARTY TRANSACTIONS

Each project entered into O&M agreements and ASAs with subsidiaries of NEER whereby the projects pay a certain annual fee plus actual costs incurred in connection with certain O&M and administrative services performed under these agreements. These services are reflected as operations and maintenance - related party in NEP's condensed consolidated statements of income. Additionally, a NEP subsidiary pays an affiliate for transmission services which are reflected as operations and maintenance - related party in NEP's condensed consolidated statements of income. At September 30, 2016 and December 31, 2015, the net payables for these services, as well as for payroll and other payments made on behalf of these projects, were approximately $4 million and $9 million, respectively, and are included in due to related parties on NEP's condensed consolidated balance sheets. Certain projects have also entered into various types of agreements including those related to shared facilities and transmission lines, transmission line easements, technical support and construction coordination with subsidiaries of NEER whereby certain fees or cost reimbursements are paid to, or received by, certain subsidiaries of NEER.

Management Services Agreement - Effective July 1, 2014, subsidiaries of NEP entered into a MSA with indirect wholly owned subsidiaries of NEE, under which operational, management and administrative services are provided to NEP, including managing NEP’s day to day affairs and providing individuals to act as NEP GP’s executive officers and directors, in addition to those services that are provided under the existing O&M agreements and ASAs described above between NEER subsidiaries and NEP subsidiaries. NEP OpCo will pay NEE an annual management fee equal to the greater of 1% of the sum of NEP OpCo’s net income plus interest expense, income tax expense and depreciation and amortization expense less certain non-cash, non-recurring items for the most recently ended fiscal year and $4 million (as adjusted for inflation beginning in 2016), which will be paid in quarterly installments with an additional payment each January to the extent 1% of the sum of NEP OpCo’s net income plus interest expense, income tax expense and depreciation and amortization expense less certain non-cash, non-recurring items for the preceding fiscal year exceeds $4 million (as adjusted for inflation beginning in 2016). NEP OpCo will also make certain payments to NEE based on the achievement by NEP OpCo of certain target quarterly distribution levels to its unitholders. NEP’s operations and maintenance - related party for the three and nine months ended September 30, 2016 include approximately $12 million and $28 million, respectively, and for the three and nine months ended September 30, 2015 include $1 million and $3 million, respectively, related to the MSA.

Cash Sweep and Credit Support Agreement - Effective July 1, 2014, NEP OpCo entered into a CSCS agreement with NEER, under which NEER and certain of its subsidiaries may provide credit support in the form of letters of credit and guarantees to satisfy NEP’s subsidiaries’ contractual obligations. NEP OpCo will pay NEER an annual credit support fee based on the level and cost of the credit support provided, payable in quarterly installments. NEP’s operations and maintenance - related party for the three and nine months ended September 30, 2016 include $1 million and $2 million, respectively, and for the three and nine months ended September 30, 2015 include $1 million and $2 million, respectively, related to the CSCS agreement.

NEER and certain of its subsidiaries may withdraw funds (Project Sweeps) received by NEP OpCo under the CSCS agreement, or its subsidiaries in connection with certain of the long-term debt agreements, and hold those funds in accounts belonging to NEER or its subsidiaries to the extent the funds are not required to pay project costs or otherwise required to be maintained by NEP's subsidiaries. NEER and its subsidiaries may keep the funds until the financing agreements permit distributions to be made, or, in the case of NEP OpCo, until such funds are required to make distributions or to pay expenses or other operating costs or NEP OpCo otherwise demands the return of such funds. If NEER fails to return withdrawn funds when required by NEP's subsidiaries’ financing agreements, the lenders will be entitled to draw on credit support provided by NEER in the amount of such withdrawn funds. If NEER or one of its affiliates realizes any earnings on the withdrawn funds prior to the return of such funds, it will be permitted to retain those earnings. The cash sweep amounts held in accounts belonging to NEER or its subsidiaries as of September 30, 2016 and December 31, 2015 were approximately $346 million and $66 million, respectively, and are included in due from related parties on NEP’s condensed consolidated balance sheets.

Guarantees and Letters of Credit Entered into by Related Parties - Certain PPAs include requirements of the project entities to meet certain performance obligations. NEECH has provided letters of credit or guarantees for certain of these performance obligations and payment of any obligations from the transactions contemplated by the PPAs. In addition, certain of the financing agreements require cash and cash equivalents to be reserved for various purposes. In accordance with the terms of these financing agreements, guarantees from NEECH have been substituted in place of these cash and cash equivalents reserve requirements. Also, under certain financing agreements, indemnifications have been provided by NEECH. In addition, certain interconnection agreements and site certificates require letters of credit or a bond to secure certain payment or restoration obligations related to those agreements. NEECH also guarantees the Project Sweep amounts held in accounts belonging to NEER as described above. As of September 30, 2016, NEECH guaranteed or provided indemnifications, letters of credit or bonds totaling approximately $704 million related to these obligations. Agreements related to the sale of differential membership interests require NEER to guarantee payment of construction-related expenses that were not yet paid before the sale of the differential membership interests in VIEs as well as payments due by the VIEs and the indemnifications to the VIEs' respective investors. As of September 30, 2016, NEER guaranteed a total of approximately $144 million related to these obligations.

Due to Related Party - Non-current amounts due to related party on NEP's condensed consolidated balance sheets represent amounts owed by certain of NEP's wind projects to NEER to refund NEER for certain transmission costs paid on behalf of the wind projects. Amounts will be paid to NEER as the wind projects receive payments from third parties for related notes receivable recorded in other non-current assets on NEP’s condensed consolidated balance sheets.

Pursuant to a purchase and sale agreement, NEER paid approximately $16 million to a subsidiary of NEP in May 2016 for the right to receive CITC proceeds that otherwise would have been retained by the NEP subsidiary. At September 30, 2016, the $16 million was included in due to related parties on NEP’s condensed consolidated balance sheets. In October 2016, a subsidiary of NEP received substantially all of the CITC proceeds and paid those proceeds to NEER.

Development, Engineering and Construction Commitments - During the nine months ended September 30, 2015, NEER purchased and contributed approximately $24 million under several engineering, procurement and construction contracts related to the procurement of materials and services for certain NEP assets which were acquired while under construction and for which costs were capitalized in construction work in progress. There were no such purchases or contributions during the three and nine months ended September 30, 2016 or the three months ended September 30, 2015.

Transportation and Fuel Management Agreements - In connection with the acquisition of the Texas pipeline business described in Note 1, a subsidiary of NEP assigned to a subsidiary of NEER certain gas commodity agreements in exchange for entering into transportation agreements and a fuel management agreement whereby the benefits of the gas commodity agreements (net of transportation paid to the NEP subsidiary) are passed back to the NEP subsidiary. During the three and nine months ended September 30, 2016, NEP recognized approximately $2 million and $8 million, respectively, in revenues related to the transportation and fuel management agreements. At September 30, 2016 and December 31, 2015, approximately $1 million and $2 million, respectively, included in due from related parties reflects amounts due from the NEER subsidiary under the transportation and fuel management agreements.

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Summary of Significant Accounting and Reporting Policies

9 Months Ended

Sep. 30, 2016

Accounting Policies [Abstract]

Summary of Significant Accounting and Reporting Policies

SUMMARY OF SIGNIFICANT ACCOUNTING AND REPORTING POLICIES

Leases - In February 2016, the FASB issued an accounting standard update which requires, among other things, that lessees recognize a lease liability, initially measured at the present value of the future lease payments, and a right-of-use asset, for all leases (with the exception of short-term leases). The standards update will be effective for NEP beginning January 1, 2019. Early adoption is permitted. Lessees and lessors must apply a modified retrospective approach for all leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. NEP is currently evaluating the effect the adoption of this standard update will have on its consolidated financial statements.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Land Use Commitments - The project owners are parties to various agreements that provide for payments to landowners for the right to use the land upon which the projects are located. These leases and easements can typically be renewed by the project owners for various periods. The annual fees range from minimum rent payments varying by lease to maximum rent payments of a certain percentage of gross revenues, varying by lease. Total lease expense was approximately $4 million and $5 million for the three months ended September 30, 2016 and 2015, respectively, and $15 million and $14 million for the nine months ended September 30, 2016 and 2015, respectively, and is included in operations and maintenance expenses in NEP's condensed consolidated statements of income.

The total minimum non-cancelable rental commitments at September 30, 2016 under these land use agreements are as follows:

	Land Use Commitments
	(millions)
Remainder of 2016	$	2
2017	10
2018	10
2019	10
2020	10
Thereafter	286
Total minimum land use payments	$	328

One of NEP’s solar project's land leases includes a right-of-way lease/grant that provides for payments to the BLM for the right to use the public lands upon which the project is located. The lease may be renewed at expiration at the solar project's option and will be subject to the regulations existing at the time of renewal. In connection with the terms of this lease, the solar project obtained a surety bond from a non-affiliated party in favor of the BLM for approximately $23 million. The surety bond remains in effect until the BLM is satisfied that there is no outstanding liability on the bond or satisfactory replacement bond coverage is furnished. Certain varying lease payments are considered contingent rent and, therefore, expense is recognized as incurred.

Letter of Credit Facilities - Two of NEP’s projects entered into letter of credit (LOC) facilities under which the LOC lenders may issue standby letters of credit not to exceed approximately $119 million in the aggregate. These LOC facilities have maturity dates of August 2017 and March 2022. Approximately $104 million of LOCs are outstanding as of September 30, 2016 primarily related to debt service reserves and security for certain of the projects' agreements, including a PPA.

Canadian FIT Contracts -The FIT contracts relating to NEP's wind projects located in Canada (Canadian projects) require suppliers to source a minimum percentage of their equipment and services from Ontario resident suppliers to meet the minimum required domestic content level (MRDCL). The MRDCL for two projects is 25% and the MRDCL for the other two projects is 50%. Following their respective CODs, the Canadian projects submitted reports to the Independent Electricity System Operator (IESO) summarizing how they achieved the MRDCL for their respective projects (domestic content reports) and the IESO issued letters to the Canadian projects acknowledging the completeness of their domestic content reports. The IESO has the right to audit the Canadian projects for a period of up to 7 years post-COD to confirm that they complied with the domestic content requirements under their respective FIT contracts and achieved their respective MRDCLs. The failure by any of these projects to achieve its MRDCL could result in a default by such project under its FIT contract, which default may not be possible to cure and could result in a termination of its FIT contract, without compensation, by the IESO. A termination of the FIT contract for any of these Canadian projects could negatively affect revenues generated by such project and have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.

Acquisition Holdbacks - At September 30, 2016 and December 31, 2015, NEP's condensed consolidated balance sheets include acquisition holdbacks related to certain contingent payments for the acquisition of the Texas pipeline business. The acquisition purchase price is subject to (i) a $200 million holdback payable, in whole or in part, upon satisfaction of financial performance and capital expenditure thresholds relating to planned expansion projects (contingent holdback) and (ii) a $200 million holdback retained to satisfy any indemnification obligations of the sellers through April 2017 (indemnity holdback). See Note 3 - Contingent Consideration for further discussion of the contingent holdback.

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Summary of Significant Accounting and Reporting Policies (Policies)

9 Months Ended

Sep. 30, 2016

Accounting Policies [Abstract]

Recently Issued Accounting Guidance

SUMMARY OF SIGNIFICANT ACCOUNTING AND REPORTING POLICIES

Leases - In February 2016, the FASB issued an accounting standard update which requires, among other things, that lessees recognize a lease liability, initially measured at the present value of the future lease payments, and a right-of-use asset, for all leases (with the exception of short-term leases). The standards update will be effective for NEP beginning January 1, 2019. Early adoption is permitted. Lessees and lessors must apply a modified retrospective approach for all leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. NEP is currently evaluating the effect the adoption of this standard update will have on its consolidated financial statements.

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Acquisitions (Tables)

9 Months Ended

Sep. 30, 2016

Business Combinations [Abstract]

Pro Forma Information

NEP’s pro forma results of operations had the acquisition of the Texas pipeline business been completed on January 1, 2014 are as follows:

	Three Months Ended   September 30, 2015			Nine Months Ended   September 30, 2015
	(millions)
Pro forma results of operations:
Pro forma revenues	$	140		$	425
Pro forma operating income	$	62		$	188
Pro forma net income	$	1		$	57
Pro forma net income (loss) attributable to NEP	$	(1	)	$	4

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2016

Fair Value Disclosures [Abstract]

Schedule of financial assets and liabilities and other fair value measurements on a recurring basis

NEP’s financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:

	September 30, 2016						December 31, 2015
	Level 1		Level 2		Total		Level 1		Level 2		Total
	(millions)
Assets:
Cash equivalents	$	52	$	—	$	52	$	63	$	—	$	63
Restricted cash equivalents	29		—		29		5		—		5
Interest rate contracts	—		—		—		—		2		2
Foreign currency contracts	—		—		—		—		2		2
Total assets	$	81	$	—	$	81	$	68	$	4	$	72
Liabilities:
Interest rate contracts	$	—	$	133	$	133	$	—	$	68	$	68
Total liabilities	$	—	$	133	$	133	$	—	$	68	$	68

Schedule of other financial instrument, carrying amounts and estimated fair values

The carrying amounts and estimated fair values of other financial instruments, excluding those recorded at fair value and disclosed above, are as follows:

	September 30, 2016				December 31, 2015
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(millions)
Long-term debt, including current maturities(a)	$	3,664	$	3,876	$	3,435	$	3,532

____________________

(a) Fair value is estimated based on the borrowing rates as of each date for similar issues of debt with similar remaining maturities (Level 2).

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Derivative Instruments and Hedging Activity (Tables)

9 Months Ended

Sep. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of the fair values of derivative instruments designated as cash flow hedging instruments included in balance sheets

Fair Value of Derivative Instruments - The tables below present NEP's gross derivative positions at September 30, 2016 and December 31, 2015, as required by disclosure rules, as well as the location of the net derivative position on the condensed consolidated balance sheets.

	September 30, 2016
	Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Total Derivatives Combined - Net Basis
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
	(millions)
Interest rate contracts	$	—	$	—	$	—	$	133	$	—	$	133
Total fair values	$	—	$	—	$	—	$	133	$	—	$	133
Net fair value by balance sheet line item:
Other current assets									$	—
Other non-current assets									—
Current derivative liabilities											$	21
Other non-current liabilities											112
Total derivatives									$	—	$	133

	December 31, 2015
	Fair Values of Derivatives Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Fair Values of Derivatives Not Designated as Hedging Instruments for Accounting Purposes - Gross Basis				Total Derivatives Combined - Net Basis
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
	(millions)
Interest rate contracts	$	1	$	22	$	1	$	46	$	5	$	71
Foreign currency contracts	—		—		2		—		2		—
Total fair values	$	1	$	22	$	3	$	46	$	7	$	71
Net fair value by balance sheet line item:
Other current assets									$	2
Other non-current assets									5
Current derivative liabilities											$	22
Other non-current liabilities											49
Total derivatives									$	7	$	71

Schedule of gains (losses) related to interest rate contracts

Gains (losses) related to NEP's interest rate contracts are recorded in NEP's condensed consolidated financial statements as follows:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2016			2015			2016			2015
	(millions)
Interest rate contracts:
Losses recognized in other comprehensive income	$	—		$	(19	)	$	—		$	(20	)
Losses reclassified from AOCI to interest expense	$	(2	)	$	(1	)	$	(6	)	$	(5	)
Gains (losses) recognized in interest expense	$	1		$	—		$	(85	)	$	—

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Capitalization (Tables)

9 Months Ended

Sep. 30, 2016

Debt Disclosure [Abstract]

Schedule of Long Term Debt

Significant long-term debt issuances and borrowings by subsidiaries of NEP during the nine months ended September 30, 2016 were as follows:

Date Issued	Debt Issuances/Borrowings	Interest Rate	Principal Amount			Maturity Date
			(millions)
January - March 2016	Construction loan credit facility	Variable(a)	$	41	(b)	2022
February 2016	Senior secured revolving credit facility	Variable(a)	$	75	(c)	2019
June 2016	Limited-recourse term loan	Variable(a)	$	355	(b)	2022
July 2016	Senior secured term loan	Variable(a)	$	100		2019
July 2016	Limited-recourse revolving credit facility	Variable(a)	$	100	(d)	2020

————————————

(a) Variable rate is based on an underlying index plus a margin.

(b) In March 2016, the construction loan credit facility converted to a term loan. In June 2016, this term loan was amended and approximately $72 million of additional net borrowings ($355 million of issuances net of $283 million of retirements) resulted in an outstanding term loan balance of $604 million at September 30, 2016.

(c) In September 2016, the borrowings under this credit facility were repaid. At September 30, 2016, no amounts were outstanding under this revolving credit facility.

(d) In October 2016, $50 million of the borrowings under this credit facility were repaid.

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Accumulated Other Comprehensive Loss (Tables)

9 Months Ended

Sep. 30, 2016

Equity [Abstract]

Schedule of accumulated other comprehensive income (loss)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Three months ended September 30, 2016
Balances, June 30, 2016	$	(8	)	$	(101	)	$	(109	)
Other comprehensive loss before reclassification	—			(1		)	(1		)
Amounts reclassified from AOCI to interest expense	2			—			2
Net other comprehensive income (loss)	2			(1		)	1
Balances, September 30, 2016	$	(6	)	$	(102	)	$	(108	)
AOCI attributable to noncontrolling interest	$	(6	)	$	(98	)	$	(104	)
AOCI attributable to NEP	$	—		$	(4	)	$	(4	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Gains (Losses) on Foreign Currency Translation			Total
	(millions)
Nine months ended September 30, 2016
Balances, December 31, 2015	$	(11	)	$	(108	)	$	(119	)
Other comprehensive income before reclassification	—			6			6
Amounts reclassified from AOCI to interest expense	5			—			5
Net other comprehensive income	5			6			11
Balances, September 30, 2016	$	(6	)	$	(102	)	$	(108	)
AOCI attributable to noncontrolling interest	$	(6	)	$	(98	)	$	(104	)
AOCI attributable to NEP	$	—		$	(4	)	$	(4	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Three months ended September 30, 2015
Balances, June 30, 2015	$	(1	)	$	(92	)	$	(93	)
Other comprehensive loss before reclassification	(16		)	(11		)	(27		)
Amounts reclassified from AOCI to interest expense	1			—			1
Net other comprehensive loss	(15		)	(11		)	(26		)
Balances, September 30, 2015	$	(16	)	$	(103	)	$	(119	)
AOCI attributable to noncontrolling interest	$	(13	)	$	(99	)	$	(112	)
AOCI attributable to NEP	$	(3	)	$	(4	)	$	(7	)

	Accumulated Other Comprehensive Loss
	Net Unrealized Losses on Cash Flow Hedges			Net Unrealized Losses on Foreign Currency Translation			Total
	(millions)
Nine months ended September 30, 2015
Balances, December 31, 2014	$	(4	)	$	(66	)	$	(70	)
Other comprehensive loss before reclassification	(16		)	(37		)	(53		)
Amounts reclassified from AOCI to interest expense	4			—			4
Net other comprehensive loss	(12		)	(37		)	(49		)
Balances, September 30, 2015	$	(16	)	$	(103	)	$	(119	)
AOCI attributable to noncontrolling interest	$	(13	)	$	(99	)	$	(112	)
AOCI attributable to NEP	$	(3	)	$	(4	)	$	(7	)

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Minimum rental commitments under land use agreements

The total minimum non-cancelable rental commitments at September 30, 2016 under these land use agreements are as follows:

	Land Use Commitments
	(millions)
Remainder of 2016	$	2
2017	10
2018	10
2019	10
2020	10
Thereafter	286
Total minimum land use payments	$	328

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Acquisitions - Additional Information (Details) $ in Millions	Oct. 28, 2016 USD ($) MW	Jul. 05, 2016 USD ($) MW	Mar. 01, 2016 USD ($) MW	Sep. 30, 2016 USD ($)	Dec. 31, 2015 USD ($)	[1]	Oct. 01, 2015
Business Acquisition [Line Items]
Goodwill				$ 628	$ 622
NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Ownership interests percentage							100.00%
Dewey and Woodward counties, Oklahoma [Member] | Seiling I and Seiling II Wind Energy Centers [Member]
Business Acquisition [Line Items]
Renewable energy assets, power capacity (megawatts) | MW			299
Consideration transferred			$ 323
Working capital			3
Liabilities assumed in consideration transfer			257
Subsidiaries [Member] | Bayhawk Wind Holdings, LLC [Member]
Business Acquisition [Line Items]
Renewable energy assets, power capacity (megawatts) | MW		285
Consideration transferred		$ 312
Working capital		6
Liabilities assumed in consideration transfer		$ 253
Subsidiaries [Member] | Desert Sunlight Investment Holdings, LLC [Member] | Subsequent Event [Member]
Business Acquisition [Line Items]
Renewable energy assets, power capacity (megawatts) | MW	550
Ownership interests percentage	24.00%
Consideration transferred	$ 218
Working capital	$ 9
Subsidiaries [Member] | Dewey and Woodward counties, Oklahoma [Member] | Seiling I and Seiling II Wind Energy Centers [Member]
Business Acquisition [Line Items]
Receivable acquired in consideration transfer			$ 25
Annual interest rate percentage for receivable			7.10%
Restatement Adjustment [Member] | NET Holdings Management, LLC [Member]
Business Acquisition [Line Items]
Goodwill				6
Decrease in property, plant and equipment				4
Increase in noncontrolling interest				$ 2

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Acquisitions - Pro Forma Information (Details) - NET Holdings Management, LLC [Member] - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2015
Business Acquisition [Line Items]
Pro forma revenues	$ 140	$ 425
Pro forma operating income	62	188
Pro forma net income	1	57
Pro forma net income (loss) attributable to NEP	$ (1)	$ 4

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Income Taxes - Additional Disclosures (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Effective tax rate	16.00%	28.00%	9.00%	15.00%
Income tax benefit from settlement of reorganization of Canadian assets			$ 12

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Fair Value Measurements - Assets and Liabilities Measured on a Recurring Basis (Details) - Recurring Basis [Member] - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Assets:
Cash equivalents	$ 52	$ 63
Restricted cash equivalents	29	5
Interest rate contracts	0	2
Foreign currency contracts	0	2
Total assets	81	72
Liabilities:
Interest rate contracts	133	68
Total liabilities	133	68
Level 1 [Member]
Assets:
Cash equivalents	52	63
Restricted cash equivalents	29	5
Interest rate contracts	0	0
Foreign currency contracts	0	0
Total assets	81	68
Liabilities:
Interest rate contracts	0	0
Total liabilities	0	0
Level 2 [Member]
Assets:
Cash equivalents	0	0
Restricted cash equivalents	0	0
Interest rate contracts	0	2
Foreign currency contracts	0	2
Total assets	0	4
Liabilities:
Interest rate contracts	133	68
Total liabilities	$ 133	$ 68

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Fair Value Measurements - Carrying Value and Fair Value of Other Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Carrying Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current maturities	$ 3,664	$ 3,435
Level 2 [Member] | Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, including current maturities	$ 3,876	$ 3,532

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Fair Value Measurements - Additional Information (Details) - NET Holdings Management, LLC [Member] - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Contingent holdback	$ 70	$ 70	$ 186
Decrease in contingent consideration	$ 101	$ 118

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Derivative Instruments and Hedging Activity - Additional Disclosures (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Interest Rate Swap [Member]
Derivative [Line Items]
Notional amount	$ 1,435		$ 1,435		$ 1,277
Net losses included in AOCI expected to be reclassified into interest expense within the next 12 months	8		8
Foreign Currency Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Notional amount	60		60		$ 54
Gains (losses) related to foreign currency contract	$ 1	$ 1	$ (2)	$ 1

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Derivative Instruments and Hedging Activity - Fair Value of Derivative Instruments Included in Balance Sheets (Details) - Cash Flow Hedges [Member] - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	$ 0	$ 7
Fair value of derivative instruments, liabilities	133	71
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	0	2
Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	0	5
Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, liabilities	112	49
Current Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, liabilities	21	22
Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	0	5
Fair value of derivative instruments, liabilities	133	71
Foreign Currency Contract [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets		2
Fair value of derivative instruments, liabilities		0
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	0	1
Fair value of derivative instruments, liabilities	0	22
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	0	1
Fair value of derivative instruments, liabilities	0	22
Designated as Hedging Instrument [Member] | Foreign Currency Contract [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets		0
Fair value of derivative instruments, liabilities		0
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	0	3
Fair value of derivative instruments, liabilities	133	46
Not Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets	0	1
Fair value of derivative instruments, liabilities	$ 133	46
Not Designated as Hedging Instrument [Member] | Foreign Currency Contract [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative instruments, assets		2
Fair value of derivative instruments, liabilities		$ 0

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Derivative Instruments and Hedging Activity - Gains (Losses) Related to Cash Flow Hedges (Details) - Interest Rate Contract [Member] - Designated as Hedging Instrument [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Losses recognized in other comprehensive income	$ 0	$ (19)	$ 0	$ (20)
Losses reclassified from AOCI to interest expense	(2)	(1)	(6)	(5)
Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) recognized in interest expense	$ 1	$ 0	$ (85)	$ 0

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Variable Interest Entities (Details) $ in Millions	Apr. 30, 2015 equity_investment shares	Sep. 30, 2016 USD ($) variable_interest_entity	Dec. 31, 2015 USD ($)
Variable Interest Entity [Line Items]
Number of entities consolidated | variable_interest_entity		4
Property, plant and equipment - net		$ 5,098	$ 5,122	[1]
Deferral related to differential membership interests		897	929	[1]
Investments in equity method investees		$ 10	22
NEP OpCo [Member]
Variable Interest Entity [Line Items]
Limited partner interest percentage		34.80%
Noncontrolling limited partner interest percentage		65.20%
NextEra Energy Operating Partners, LP [Member]
Variable Interest Entity [Line Items]
Ownership interests percentage	50.00%
Class B Units, Series 1 [Member] | NextEra Energy Partners, LP [Member] | NextEra Energy Operating Partners, LP [Member]
Variable Interest Entity [Line Items]
Number of units issued (in units) | shares	1,000,000
Class B Units, Series 2 [Member] | NextEra Energy Partners, LP [Member] | NextEra Energy Operating Partners, LP [Member]
Variable Interest Entity [Line Items]
Number of units issued (in units) | shares	1,000,000
Palo Duro WInd Project Holdings, LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Property, plant and equipment - net		$ 1,669	1,693
Deferral related to differential membership interests		$ 947	$ 1,248
Adelanto I, Adelanto II and McCoy [Member] | Subsidiaries [Member]
Variable Interest Entity [Line Items]
Number of investments | equity_investment	3
Econominc rights percentage	100.00%

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Capitalization (Details)	Sep. 30, 2016 USD ($)
Revolving Credit Facility [Member] | Construction Loan Credit Facility Due 2022 [Member]
Line of Credit Facility [Line Items]
Principal Amount	$ 41,000,000
Revolving Credit Facility [Member] | Senior Secured Revolving Credit Facility Due 2019 [Member]
Line of Credit Facility [Line Items]
Principal Amount	75,000,000
Revolving Credit Facility [Member] | Limited-Recourse Revolving Credit Facility Due 2020 [Member]
Line of Credit Facility [Line Items]
Principal Amount	100,000,000
Term Loan [Member] | Limited-Recourse Term Loan Due 2022 [Member]
Line of Credit Facility [Line Items]
Principal Amount	355,000,000
Term Loan [Member] | Senior Secured Term Loan Due 2019 [Member]
Line of Credit Facility [Line Items]
Principal Amount	$ 100,000,000

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Capitalization - Additional Information (Details) - USD ($)			1 Months Ended			2 Months Ended	9 Months Ended
		Oct. 31, 2016	Oct. 31, 2016	Sep. 30, 2016	Mar. 31, 2016	Mar. 31, 2016	Sep. 30, 2016	Sep. 30, 2015
Schedule of Capitalization, Long-term Debt [Line Items]
Issuance of common units	[1]						$ 645,000,000	$ 319,000,000
Number of units sold				11,962,300		11,155,000
Proceeds from sale of units				$ 342,000,000		$ 287,000,000
Subsequent Event [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Distribution per common unit payable		$ 0.34125
ATM Program [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Issuance of common units, units							552,210
Issuance of common units							$ 16,000,000
Stock issuance costs							$ 1,000,000
Public Offering [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Price per common unit				$ 28.56	$ 25.76	$ 25.76	$ 28.56
NEP OpCo [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Limited partner interest percentage				34.80%			34.80%
Term Loan [Member] | Amended Limited-Recourse Term Loan [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Additional net borrowings					$ 72,000,000	$ 72,000,000
Additional borrowings issued					355,000,000	$ 355,000,000
Retirement/extinguishment of debt					$ 283,000,000
Credit facility, amount outstanding				$ 604,000,000			$ 604,000,000
Line of Credit [Member] | Senior Secured Revolving Credit Facility Due 2019 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Credit facility, amount outstanding				$ 0			$ 0
Line of Credit [Member] | Limited-Recourse Revolving Credit Facility Due 2020 [Member] | Subsequent Event [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Retirement/extinguishment of debt			$ 50,000,000

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015		Sep. 30, 2016		Sep. 30, 2015		Dec. 31, 2015	[3]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, beginning of period	$ (109)	$ (93)		$ (119)		$ (70)
Other comprehensive income (loss) before reclassification	(1)	(27)		6		(53)
Amounts reclassified from AOCI to interest expense	2	1		5		4
Net other comprehensive income (loss)	1	(26)	[1]	11	[2]	(49)	[1],[2]
Balance, end of period	(108)	(119)		(108)		(119)
AOCI attributable to noncontrolling interest	(104)	(112)		(104)		(112)
AOCI attributable to NextEra Energy Partners	(4)	(7)		(4)		(7)		$ (6)
Net Unrealized Gains (Losses) on Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, beginning of period	(8)	(1)		(11)		(4)
Other comprehensive income (loss) before reclassification	0	(16)		0		(16)
Amounts reclassified from AOCI to interest expense	(2)	(1)		(5)		(4)
Net other comprehensive income (loss)	2	(15)		5		(12)
Balance, end of period	(6)	(16)		(6)		(16)
AOCI attributable to noncontrolling interest	(6)	(13)		(6)		(13)
AOCI attributable to NextEra Energy Partners	0	(3)		0		(3)
Net Unrealized Gains (Losses) on Foreign Currency Translation [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, beginning of period	(101)	(92)		(108)		(66)
Other comprehensive income (loss) before reclassification	(1)	(11)		6		(37)
Amounts reclassified from AOCI to interest expense	0	0		0		0
Net other comprehensive income (loss)	(1)	(11)		6		(37)
Balance, end of period	(102)	(103)		(102)		(103)
AOCI attributable to noncontrolling interest	(98)	(99)		(98)		(99)
AOCI attributable to NextEra Energy Partners	$ (4)	$ (4)		$ (4)		$ (4)

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[2] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

[3] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Related Party Transactions (Details) - USD ($)	1 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended
	May 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Related Party Transaction [Line Items]
Due from related parties		$ 349,000,000		$ 349,000,000		$ 70,000,000	[1]
Transportation and Fuel Management Agreement [Member]
Related Party Transaction [Line Items]
Revenue from related parties		2,000,000		8,000,000
Subsidiaries of NEER [Member] | Operations, Maintenance,and Administrative Services, as well as Payroll and Other Payments [Member]
Related Party Transaction [Line Items]
Expenses from transactions with related party				4,000,000		9,000,000
Subsidiaries of NEER [Member] | Transportation and Fuel Management Agreement [Member]
Related Party Transaction [Line Items]
Due from related parties		1,000,000		1,000,000		2,000,000
NextEra Energy, Inc. [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Expenses from transactions with related party		12,000,000	$ 1,000,000	28,000,000	$ 3,000,000
NEER [Member] | Cash Sweep and Credit Support Agreement [Member]
Related Party Transaction [Line Items]
Interest expense		1,000,000	1,000,000	2,000,000	2,000,000
Due from related parties		$ 346,000,000		346,000,000		$ 66,000,000
NEP OpCo [Member] | NextEra Energy, Inc. [Member] | Management Services Agreement [Member]
Related Party Transaction [Line Items]
Management fee, percent of EBITDA		1.00%
Annual management fee		$ 4,000,000
Management fee, additional payment threshold, minimum EBITDA		4,000,000
NextEra Energy Capital Holdings [Member] | Guarantees and Letters of Credit [Member]
Related Party Transaction [Line Items]
Total amount of letters of credit		704,000,000		704,000,000
NEER [Member] | Guarantees [Member]
Related Party Transaction [Line Items]
Related party obligations		144,000,000		144,000,000
NEER [Member] | Engineering, Procurement, and Construction Contracts [Member]
Related Party Transaction [Line Items]
Related party transaction		0	$ 0	0	$ 24,000,000
NEER [Member] | Subsidiary of NEP [Member] | Right to Receive CITC Proceeds [Member]
Related Party Transaction [Line Items]
Related party obligations		$ 16,000,000		$ 16,000,000
Related party transaction	$ 16,000,000

[1] Prior-period financial information has been retrospectively adjusted as discussed in Note 1.

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Commitments and Contingencies - Commitments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Oct. 01, 2015
Operating Leased Assets [Line Items]
Lease expense	$ 4	$ 5	$ 15	$ 14
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
Remainder of 2016	2		2
2017	10		10
2018	10		10
2019	10		10
2020	10		10
Thereafter	286		286
Total minimum land use payments	328		328
NET Holdings Management, LLC [Member]
Operating Leased Assets [Line Items]
Contingent holdback	70		70		$ 186
Genesis [Member] | Surety Bond [Member]
Operating Leased Assets [Line Items]
Surety bond	$ 23		$ 23
Subsidiaries [Member] | NET Holdings Management, LLC [Member]
Operating Leased Assets [Line Items]
Contingent holdback						$ 200

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Commitments and Contingencies - Letters of Credit (Details) - Genesis [Member] - Standby Letters of Credit [Member] $ in Millions	Sep. 30, 2016 USD ($)
Line of Credit Facility [Line Items]
Credit facility, maximum borrowing capacity	$ 119
Credit facility, amount outstanding	$ 104