NEP may not be able to extend, renew or replace expiring or terminated PPAs, natural gas transportation agreements or other customer contracts at favorable rates or on a long-term basis.
NEP's ability to extend, renew or replace its existing PPAs, natural gas transportation agreements or other customer contracts depends on a number of factors beyond its control, including, but not limited to:
If NEP is not able to extend, renew or replace on acceptable terms existing PPAs before contract expiration, or if such agreements are otherwise terminated prior to their expiration, NEP may be required to sell the energy on an uncontracted basis at prevailing market prices, which could be materially lower than under the applicable contract. If there is no satisfactory market for a project’s uncontracted energy, NEP may decommission the project before the end of its useful life. If the portion of its pipelines' capacity covered by long-term firm transportation agreements decline, NEP's revenues and contract volumes would be exposed to increased volatility. Any failure to extend, renew or replace a significant portion of NEP's existing PPAs, natural gas transportation agreements or other customer contracts, or extending, renewing or replacing them at lower prices or with other unfavorable terms, or the
decommissioning of a project could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
If the energy production by or availability of NEP's renewable energy projects is less than expected, they may not be able to satisfy minimum production or availability obligations under their PPAs.
NEP's energy production or its renewable energy projects’ availability could be less than expected due to various factors, including, but not limited to, wind or solar conditions, natural disasters, equipment underperformance, operational issues, changes in law or regulations or actions taken by third parties. The PPAs contain provisions that require NEP to produce a minimum amount of energy or be available a minimum percentage of time over periods specified in the PPAs. A failure to produce sufficient energy or to be sufficiently available to meet NEP's commitments under its PPAs could result in the payment of damages or the termination of PPAs and could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP's growth strategy depends on locating and acquiring interests in additional projects consistent with its business strategy at favorable prices.
NEP intends to pursue opportunities to acquire contracted clean energy projects, including partial ownership interests, that are either operational or in limited circumstances, under construction, from NEER and third parties consistent with its business strategy. NEP's ability to grow through acquisitions and increase distributions to its common unitholders is dependent in part on its ability to identify attractive candidates and make acquisitions that result in an increase in cash distributions per common unit. Such acquisitions may not be available to NEP on acceptable terms or at all. Various factors could affect the availability of such projects to grow NEP's business, including, but not limited to, the following factors and those described in more detail in the additional risk factors below:
Any of these above factors could limit NEP's acquisition opportunities and prevent it from executing, or diminish its ability to execute, its growth strategystrategy. Additionally, factors could materially and adversely impact the extent to which suitable acquisition opportunities are made available from NEER, including, but not limited to, NEER's financial position, the risk profile of an opportunity, the fit with NEP's operations and other factors. Furthermore, as planned. Further,NEER's ownership interest in NEP is reduced, NEER may be less willing to sell projects to NEP. An inability by NEP to identify, or a failure by NEER to make available, suitable acquisition opportunities could hinder NEP's growth and materially adversely impact its business, financial condition, results of operations and ability to make cash distributions to its unitholders.
Reductions in demand for natural gas in the United States or Mexico and low market prices of natural gas could materially adversely affect NEP's pipeline operations and cash flows.
The price of natural gas fluctuates in response to changes in supply and demand, market uncertainty and additional factors that are beyond NEP's control. These factors include worldwide economic conditions; weather conditions and seasonal trends; the levels
of domestic and Mexican natural gas production and consumer demand; fluctuations in demand from electric power generators and industrial customers; the availability of imported liquid natural gas (LNG); the ability to export LNG; the availability of transportation systems with adequate capacity; the volatility and uncertainty of regional pricing differences; the price and availability of alternative fuels; the effect of energy efficiency and conservation measures; the nature and extent of governmental regulation and taxation; worldwide political events, including, but not limited to, actions taken by foreign natural gas producing nations and changes in international trade laws, regulations, agreements, treaties or policies of the U.S. or other countries; and the anticipated future prices of natural gas, LNG and other commodities. These events are beyond NEP's control and could impair its ability to execute its long-term strategy. Lower overall economic output could reduce the volume of natural gas transported or gathered, resulting in lower revenues and cash flows. Transmission revenues could be affected by long-term economic declines which could result in the non-renewal of long-term contracts. Any of these events could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
Government laws, regulations and policies providing incentives and subsidies for clean energy could be changed, reduced or eliminated at any time and such changes may negatively impact NEP's growth strategy.
NEP's strategy to grow its business through the acquisition of clean energy projects partly depends on current laws, regulations and policies that promote and support clean energy and enhance the economic viability of owning clean energy projects. Clean energy projects currently benefit from various U.S. federal, state and local governmental incentives, such as PTCs, ITCs, CITCs, loan guarantees, RPS, MACRS for depreciation and other incentives, accelerated cost recovery deductions and other commercially oriented incentives. These laws, regulations and policies have had a significant impact on the development of clean energy and they could be changed, reduced or eliminated at any time. These incentives make the development of clean energy projects more competitive by providing tax credits or grants and accelerated depreciation for a portion of the development costs, decreasing the costs and risks associated with developing such projects or creating demand for renewable energy assets through RPS programs. The elimination of, loss of or reduction in such incentives, or the imposition of additional taxes, tariffs, duties or other assessments on clean energy or the equipment necessary to generate or deliver it, such as policies in place to limit certain imports from China and other Southeast Asian countries, could decrease the attractiveness of clean energy projects to developers, including, but not limited to, NEE, which could reduce NEP's acquisition opportunities. Such an elimination, loss or reduction could also reduce NEP's willingness to pursue or develop certain renewable energy projects due to higher operating costs or decreased revenues under its PPAs.
If these laws, regulations and policies are not continued or renewed, the market for future renewable energy PPAs may be smaller and the prices for future clean energy PPAs may be lower. If the IRS issues guidance that limitslaws, regulations or policies limit the availability of the PTC or the ITC, the projects could generate reduced revenues and reduced economic returns, experience increased financing costs and encounter difficulty obtaining financing on acceptable terms.
Additionally, some states with RPS targets have met, or in the near future will meet, their renewable energy targets. If, as a result of achieving these targets, these and other U.S. states do not increase their targets in the near future, demand for additional renewable energy could decrease. To the extent other states decrease their RPS targets, programs or goals, demand for renewable energy could decrease in the future. Any of the foregoing 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'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.
Project development is a capital intensive business that relies heavily on the availability of debt and equity financing sources to fund projected construction and other capital expenditures. As a result, in order to successfully develop a project, development companies, including, but not limited to, other affiliates of NEE, must obtain sufficient financing to complete the development phase of their projects. Any significant disruption in the credit and capital markets or a significant increase in interest rates could make it difficult for development companies to raise funds when needed to secure capital financing, which would limit a project’s ability to complete the construction of a project that NEP may seek to acquire.
Project developers, including, but not limited to, other affiliates of NEE, develop, construct, manage, own and operate clean energy generation facilities and energy transmission facilities. A key component of their businesses is their ability to construct and operate generation and transmission facilities to meet customer needs. As part of these activities, project developers must periodically apply for licenses and permits from various regulatory authorities and abide by their respective conditions and requirements. If project developers, including, but not limited to, other affiliates of NEE, are unsuccessful in obtaining necessary licenses or permits on acceptable terms or encounter delays in obtaining or renewing such licenses or permits, or if regulatory authorities initiate any associated investigations or enforcement actions or impose penalties or reject projects, the potential number of projects that may be available for NEP to acquire may be reduced or potential transaction opportunities may be delayed.
If the challenges of developing projects increase for project developers, including, but not limited to, other affiliates of NEE, NEP's pool of available opportunities may be limited, which 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.
Acquisitions of existing clean energy projects involve numerous risks.
NEP's strategy includes growing its business through the acquisition of existing clean energy projects.projects, including partial ownership interests. The acquisition of existing clean energy projects involves numerous risks, including, but not limited to, exposure to existing liabilities and unanticipated post-acquisition costs associated with the pre-acquisition activities by the project, difficulty in integrating the acquired projects into NEP's business and, if the projects are in new markets, the risks of entering markets where NEP has limited experience. Additionally, NEP risks overpaying for such projects or not making acquisitions on an accretive basis. Although NEP performs due diligence on prospective acquisitions, NEP may not discover all potential risks, operational issues or other issues in such projects. Further, the integration and consolidation of acquisitions require substantial human, financial and other resources and, ultimately, NEP's acquisitions may divert NEP's management’s attention from its existing business concerns, disrupt its ongoing business or not be successfully integrated. Future acquisitions might not perform as expected or the returns from such acquisitions might not support the financing utilized to acquire or maintain them. A failure to achieve the financial returns NEP expects when NEP acquires clean energy projects 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.
Each U.S. state has its own renewable energy regulations and policies. Renewable energy developers must anticipate the future policy direction in each state and secure viable projects before they can bid to procure a PPA or other contract through often highly competitive auctions. A failure to anticipate accurately the future policy direction in a state or to secure viable projects could have a material adverse effect on NEP's ability to grow its business and make cash distributions to its unitholders.
NEP may continue to acquire other sources of clean energy and may expand to include other types of assets. Any further acquisition of non-renewable energy projects may present unforeseen challenges and result in a competitive disadvantage relative to NEP's more-established competitors.
NEP may continue to acquire other sources of clean energy, including, but not limited to, contracted natural gas and nuclear projects, and other types of assets, including, but not limited to, transmission projects. NEP may be unable to identify attractive non-renewable energy or transmission acquisition opportunities or acquire such projects at prices and on terms that are attractive. In addition, the consummation of such acquisitions could expose NEP to increased operating costs, unforeseen liabilities and additional risks including, but not limited to, regulatory and environmental issues associated with entering new sectors of the energy industry. This could require a disproportionate amount of NEP's management’s attention and resources, which could have an adverse impact on NEP's business and place NEP at a competitive disadvantage relative to more established non-renewable energy market participants. A failure to successfully integrate such acquisitions 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,utility holding companies, developers, IPPs, pension funds and private equity funds for opportunities in North America.
NEP believes its primary competitors for opportunities in North America are regulated utilities,utility holding companies, developers, IPPs, pension funds and private equity funds. NEP competes with these companies to acquire projects and pipelines with projected stable cash flows. NEP also competes for personnel with requisite industry knowledge and experience. Furthermore, the industry has experienced and may experience volatile demand for wind turbines, solar panels, pipeline equipment and related components. If demand for this equipment increases, suppliers may give priority to other market participants, including, but not limited to, NEP's competitors, who may have greater resources than NEP. An inability to effectively compete with regulated utilities,utility holding companies, developers, IPPs, pension funds and private equity funds for opportunities in North America could have a material adverse effect on NEP's ability to grow its business and to make cash distributions to its unitholders.
The natural gas pipeline industry is highly competitive, and increased competitive pressure could adversely affect NEP's business.
NEP's pipelines compete with other energy midstream enterprises, some of which are much larger and have significantly greater financial resources and operating experience in its areas of operation. The pipelines’ competitors may expand or construct infrastructure that competes with the services it provides to customers. The ability to renew or replace existing contracts with the pipelines’ customers at rates sufficient to maintain current revenues and cash flows could be adversely affected by the activities of NEP's competitors and customers. All of these competitive pressures could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
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.acquisitions and pursue other growth opportunities.
Since NEP expects, from time to time, to finance acquisitions ofinvestments in clean energy projects partially or wholly through the issuance of additional securities of NEP, NEP OpCo and their subsidiaries, NEP needs to be able to access capital on commercially reasonable terms when acquisition or other growth opportunities arise. NEP’s ability to access capital is dependent on, among other factors, the overall state of the capital markets and investor appetite for investment in clean energy projects in general and NEP, NEP OpCo or their subsidiaries securities or securities convertible into, or settleable with, NEP common units in particular. Investor demand for securities of NEP or securities convertible into, or settleable with, NEP common units may be impacted by the amount of securities outstanding that are convertible into, or settleable with, NEP common units, the possibility of further sales of such securities, the timing of any issuance of NEP common units upon conversion or settlement, and any subsequent sales of such units by investors. Disruptions, uncertainty or volatility in those capital and credit markets, related to, among other factors, inflation, rising interest rates, geopolitical events and the planned phase out of the London Inter-Bank Offered Rate or the reform or replacement of other benchmark interest rates, could increase NEP's cost of capital and affect its ability to fund its liquidity and capital needs. An inability to obtain financing on commercially reasonable terms could significantly limit NEP’s ability to consummate future acquisitions and to effectuate itspursue other growth strategy.opportunities. In addition, the issuance of additionalNEP common units and securities convertible into, or settleable with, NEP common units or other securities in connection with acquisitions could cause significant common unitholder dilution and reduce the cash distribution per common unit ifunit. Issuances of additional securities, or the acquisitionspossibility that these issuances may occur, including following the conversion or settlement of securities convertible into, or settleable with, NEP common units, could make it more difficult for NEP to sell NEP common units, or securities convertible into, or settleable with, NEP common units, in the future, as well as affect NEP's decision whether and when to issue common units to purchase previously issued securities of NEP OpCo subsidiaries that are not sufficiently accretive.settleable with NEP common units.
Furthermore, there may not be sufficient availability under NEP OpCo’s subsidiaries’ revolving credit facility or the ability to obtain other financing arrangements on commercially reasonable terms when acquisition or other growth opportunities arise. An inability to obtain the required or desired financing could significantly limit NEP's ability to consummate acquisitions and effectuate itspursue other growth strategy.opportunities. If financing is available, it may be available only on terms that could significantly increase NEP's interest expense, impose additional or more restrictive covenants and reduce cash distributions to its unitholders. NEP's inability to effectively consummate future acquisitions or pursue other growth opportunities could have a material adverse effect on NEP's ability to grow its business and make cash distributions to its unitholders.
Restrictions in NEP and its subsidiaries' financing agreements could adversely affect NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP and its subsidiaries have entered into financing agreements which contain various covenants and restrictive provisions that may limit their ability to, among other things:
•incur or guarantee additional debt;
•make distributions on or redeem or repurchase common units;
•make certain investments and acquisitions;
•incur certain liens or permit them to exist;
•enter into certain types of transactions with affiliates;
•merge or consolidate with another company; and
•transfer, sell or otherwise dispose of projects.
Certain of the financing agreements also contain covenants requiring NEP OpCo and its subsidiaries to maintain certain financial ratios, including, but not limited to, as a condition to making cash distributions to NEP and its other unitholders. NEP OpCo's and its subsidiaries' ability to meet those financial ratios can be affected by events beyond NEP's control, and NEP OpCo may be unable to meet those ratios and tests and, therefore, may be unable to make cash distributions to its unitholders, including, but not limited to, NEP. As a result, NEP may be unable to make distributions to its unitholders. In
addition, the financing agreements contain events of default provisions, including, but not limited to, provisions relating to certain changes in ownership of NEP or its subsidiaries and other customary provisions.
The provisions of the financing agreements may affect NEP's ability to obtain future financing and pursue attractive business opportunities and NEP's flexibility in planning for, and reacting to, changes in business conditions. A failure to comply with the provisions of the applicable financing agreement could result in an event of default, which could enable the lenders to declare, subject to the terms and conditions of the applicable financing agreement any outstanding principal of that debt, together with accrued and unpaid interest, to be immediately due and payable and entitle lenders to enforce their security interest. If the payment of the debt is accelerated and NEP or one of its subsidiariesa subsidiary fails to repay the debt, pursuant to their guarantees, the revenue from the projects may be insufficient to repay such debt in full, the lenders could enforce their security interest and NEP's unitholders could experience a partial or total loss of their investment.
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 or other financing agreements.
NEP intends to pay quarterly cash distributions on all of its outstanding common units and NEP OpCo intends to pay quarterly cash distributions on its outstanding units (except for its non-economic Class B units). However, in any period, NEP's and NEP OpCo’s ability to pay cash distributions to their respective unitholders depends on, among other things, the performance of NEP's subsidiaries. The ability of NEP's subsidiaries to make distributions to NEP and NEP OpCo may be restricted by, among other things, the provisions of existing and future indebtedness andor other financing agreements.
The agreements governing NEP's subsidiaries’ project-level debt contain financial tests and covenants that NEP's subsidiaries must satisfy prior to making distributions and restrict the subsidiaries from making more than one distribution per quarter or per six-month period. If any of NEP's subsidiaries is unable to satisfy these tests and covenants or is otherwise in default under such agreements, it would be prohibited from making distributions that could, in turn, affect the amount of cash distributed by NEP OpCo, and ultimately limit NEP's ability to pay cash distributions to its unitholders. Additionally, such agreements require NEP's projects to establish a number of reserves out of their revenues, including, but not limited to, reserves to service NEP OpCo's debt and reserves for O&M expenses. These cash reserves will affect the amount of cash distributed by NEP OpCo, which ultimately will affect the amount of cash distributions NEP is able to make to its unitholders. Also, upon the occurrence of certain events, including, but not limited to,
NEP's subsidiaries’ inability to satisfy distribution conditions for an extended period of time, NEP's subsidiaries’ revenues may be swept into one or more accounts for the benefit of the lenders under the subsidiaries’ debt agreements and the subsidiaries may be required to prepay indebtedness.
Under certain other financing agreements, noncontrolling Class B investors own interests in certain NEP subsidiaries and receive a portion of the related NEP subsidiaries’ cash distributions specified in the applicable limited liability company agreements. NEP has the option (buyout right), subject to certain limitations, to purchase 100% of the noncontrolling Class B interests during specified periods. If NEP does not exercise the buyout rights during the specified periods, or if NEP only partially exercises the buyout rights during the specified periods, the portion of the NEP subsidiaries’ cash distribution allocated to the noncontrolling Class B investors would significantly increase. Any increase in the portion of NEP subsidiaries’ cash distributions allocated to the noncontrolling Class B investors would reduce the amount of cash distributions allocated to NEP OpCo and NEP.
Provisions preventing or reducing NEP's subsidiaries’ cash distributions could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
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.
NEP's subsidiaries’ substantial indebtedness could have important consequences. For example,
•failure to comply with the covenants in the agreements governing these obligations could result in an event of default under those agreements, which could be difficult to cure, result in bankruptcy or, with respect to subsidiary debt, result in loss of NEP OpCo's ownership interest in one or more of its subsidiaries or in some or all of their assets as a result of foreclosure;
•NEP's subsidiaries’ debt service obligations require them to dedicate a substantial portion of their cash flow to pay principal and interest on their debt, thereby reducing their cash available for distribution to NEP;
•NEP's subsidiaries’ substantial indebtedness could limit NEP's ability to fund operations of any projects acquired in the future and NEP's financial flexibility, which could reduce its ability to plan for and react to unexpected opportunities or challenges;
•NEP's subsidiaries’ substantial debt service obligations make NEP vulnerable to adverse changes in general economic, credit markets, capital markets, industry, competitive conditions and government regulation that could place NEP at a disadvantage compared to competitors with less debt; and
•NEP's subsidiaries’ substantial indebtedness could limit NEP's ability to obtain financing for working capital, including, but not limited to, collateral postings, capital expenditures, debt service requirements, acquisitions and general partnership or other purposes.
If NEP's subsidiaries, including but not limited to, NEP OpCo, do not comply with their obligations under their debt instruments, they may be requiredneed to refinance all or a part of their indebtedness, which they may not be able to do on similar terms or at all. Increases in interest rates and changes in debt covenants may reduce the amounts that NEP and its subsidiaries can borrow, reduce NEP's cash flows and increase the equity investment NEP may be required to make in any projects NEP may acquire. In addition, the project-level financing for projects that NEP may acquire that are under construction may prohibit distributions until such project commences operations. If NEP's subsidiaries are not able to generate sufficient operating cash flow to repay their outstanding indebtedness or otherwise are unable to comply with the terms of their indebtedness, NEP could be required to reduce overhead costs, reduce the scope of its projects, sell some or all of its projects or delay construction of projects NEP may acquire, all of which could have a material adverse effect on its business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP is exposed to risks inherent in its use of interest rate swaps.
Some of NEP's subsidiaries’ indebtedness accrues interest at variable rates, and some of its subsidiaries use interest rate swaps to try to protect against market volatility. The use of interest rate swaps, however, does not eliminate the possibility of fluctuations in the value of a position or prevent losses if the value of a position declines. Such transactions may also limit the opportunity for gain if the value of a position increases. In addition, to the extent that actively-quoted market prices and pricing information from external sources are not available, the valuation of these contracts involves judgment or the use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these contracts. If the values of these financial contracts change in a manner that NEP does not anticipate, or if a counterparty fails to perform under a contract, it could have a material adverse effect on its business, financial condition, results of operations and ability to make cash distributions to its unitholders.
Widespread public health crises and epidemics or pandemics may have material adverse impacts on NEP’s business, financial condition, liquidity, results of operations and ability to make cash distributions to its unitholders.
NEP is subject to the impacts of widespread public health crises, epidemics and pandemics, including, but not limited to, impacts on the global, national or local economy, capital and credit markets, NEP's customers and suppliers or the services NEER provides to NEP. The ultimate severity, duration and impact of public health crises, epidemics and pandemics cannot be predicted. Actions taken in response to such crises by federal, state and local government or regulatory agencies may impact NEP’s ability to access capital and could have a material adverse impact on NEP's business, financial condition, liquidity, results of operations and ability to make cash distributions to its unitholders.
Risks Related to NEP's Relationship with NEE
NEE has influence over NEP.
Under NEP’s partnership agreement, the board oversees and directs the operations and policies of NEP and exercises management oversight over NEP. At each annual meeting, four of NEP’s seven directors will be elected by NEP’s limited partners. Three directors will be appointed by NEP GP, in its sole discretion. The directors appointed by NEP GP will be, and one director elected by holders of NEP’s common units may be, officers or employees of NEE or its affiliates. In addition, NEE holds voting power over certain matters that require NEP unitholder approval. NEE Management, pursuant to the terms of the MSA, will designate the officers of NEP so long as NEE or one of its affiliates is the manager under the MSA.
The attorneys, independent accountants and others who perform services for NEP will be selected by the board, which may be affiliated with NEE, or its conflicts committee and may perform services for NEE or its affiliates. NEP may retain separate counsel for itself or the holders of common units in the event of a conflict of interest between NEE and its affiliates, on the one hand, and NEP or the holders of common units, on the other, depending on the nature of the conflict. NEP does not intend to do so in most cases.
Under the CSCS agreement, NEP receives 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.
Under the CSCS agreement, guarantees and letters of credit that have been provided by NEECH, NEER and other NEE affiliates to counterparties on behalf of NEP's subsidiaries to satisfy NEP's subsidiaries’ contractual obligations to provide credit support, including, but not limited to, under PPAs. These NEE affiliates also have provided credit support to lenders to fund reserve accounts and to cover the risk that CITC proceeds received by any U.S. project entity are later recaptured by the U.S. Department of Treasury.accounts. NEP expects NEECH, NEER and other NEE affiliates, upon NEP's request and at NEER’s option, to provide credit support on behalf of any projects NEP may acquire in the future on similar terms but they are under no obligation to do so. Any failure of NEP's subsidiaries to maintain acceptable credit support or credit support providers to honor their obligations under their respective credit support arrangements could cause, among other things, events of default to arise under NEP's subsidiaries’ PPAs and financing agreements. Such events of default could entitle customers to terminate their contracts with NEP's subsidiaries or could entitle lenders to accelerate indebtedness owed to them, which could result in the insolvency of NEP's subsidiaries. In addition, if beneficiaries draw on credit support provided by NEECH, NEER and these other NEE affiliates, then NEP OpCo may be required to reimburse them for the amounts drawn, which could reduce NEP OpCo’s cash distributions. These events could decrease NEP's revenues, restrict distributions from its subsidiaries, or result in a sale of or foreclosure on its assets. Further, NEE affiliates may not provide credit support in respect of new projects on the same terms on which they currently provide credit support for NEP’s existing projects, which may require NEP to obtain credit support from third parties on less favorable terms and may prevent NEP from acquiring additional projects. All of the foregoing events, including, but not limited to, a failure of NEP OpCo to have sufficient funds to satisfy its reimbursement obligations, could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEER or oneand certain of its affiliates isare permitted to borrow funds received by NEP'sNEP OpCo or its subsidiaries 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.
Under the CSCS agreement, NEER or oneand certain of its affiliates isare permitted to withdraw funds received by NEP'sNEP OpCo under the CSCS agreement, or NEP OpCo's subsidiaries including, but not limited to, NEP OpCo,in connection with certain long-term debt agreements, and hold them in an account of NEER or one of its affiliates to the extent the funds are not required to pay NEP's or its subsidiaries’project costs or otherwise not required to be retained by itsNEP's subsidiaries, until the financing agreements of its subsidiaries permit distributions to be made, to NEP OpCo or, in the case of NEP OpCo, until a minimum quarterly distribution is scheduledsuch funds are required to be paid. Further, NEER will notmake distributions or to pay expenses or other operating costs or NEP any interest or additional consideration forOpCo otherwise demands the usereturn of thesesuch funds. If NEER or one of its affiliates realizes any earnings on NEP OpCo’s or its subsidiaries’the withdrawn funds prior to the return of such funds, it iswill be permitted to retain those earnings for its own account.earnings. The failure of NEER to return funds to NEP's subsidiaries for any reason could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP may not be able to consummate future acquisitions.
NEP's ability to grow through acquisitions and increase distributions to its unitholders is dependent in part on its ability to make acquisitions that result in an increase in cash distributions per common unit. Such acquisitions may not be available to NEP on acceptable terms or at all. The consummation and timing of future acquisitions, whether from NEER or any third parties, will depend upon, among other things, whether:
NEP is able to identify attractive acquisition candidates;
NEP is able to negotiate acceptable purchase agreements;
NEP is able to obtain financing for these acquisitions on economically acceptable terms; and
NEP is outbid by competitors.
Additionally, several factors could materially and adversely impact the extent to which suitable acquisition opportunities are made available from NEER, including, but not limited to, an assessment by NEER relating to its liquidity position, the risk profile of an opportunity, its fit with NEP's operations and other factors. Furthermore, if NEER reduces its ownership interest in NEP, it may be less willing to sell NEER projects to NEP. An inability by NEER to identify, or a failure by NEER to make available, suitable acquisition opportunities could hinder NEP's growth and materially adversely impact its business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP may not be able to successfully consummate future acquisitions, whether from NEER or any third parties. Any acquisitions that may be available to NEP may require that it be able to access the debt and equity markets. However, NEP may be unable to access such markets on attractive terms or at all. If NEP is unable to make future acquisitions, its future growth and ability to increase distributions to its unitholders will be limited. Furthermore, even if NEP does consummate acquisitions that NEP believes will be accretive, they may in fact result in a decrease in cash distributions per common unit as a result of incorrect assumptions in NEP's evaluation of such acquisitions or unforeseen consequences or other external events beyond its control. Acquisitions involve numerous risks, including, but not limited to, difficulties in integrating acquired businesses, inefficiencies and unexpected costs and liabilities. These events could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEER's right of first refusal may adversely affect NEP's ability to consummate future sales or to obtain favorable sale terms.
NEP and NEP OpCo have entered into a ROFR agreement with NEER granting NEER and its subsidiaries (other than NEP OpCo and its subsidiaries) a right of first refusal on any proposed sale of any of the NEP OpCo ROFR assets. The obligations of NEP OpCo under the ROFR agreement may discourage a third party from pursuing a transaction with NEP OpCo. Even if such third party is able to acquire the applicable asset, NEP OpCo’s compliance with its obligations under the ROFR agreement could result in delays and transaction costs, as well as a reduced sales price. In addition, since the number of third parties willing to make an offer for a NEP OpCo ROFR asset may be limited due to the ROFR agreement, NEP OpCo may consummate the sale of any NEP OpCo ROFR asset on less favorable terms, or may not be able to sell such asset, which could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP GP and its affiliates may have conflicts of interest with NEP and have limited duties to NEP and its unitholders.
The board will appoint officers of NEP (including its chief executive officer) designated by the manager in accordance with the terms of the MSA. As a result, all of NEP’s executive officers could be, and currently are, officers of NEE or one of its affiliates. NEP’s partnership agreement provides contractual standards governing the duties of directors and officers, and directors and officers will not have fiduciary duties to NEP or its unitholders. Conflicts of interest exist and may arise as a result of the relationships between NEE and the directors and officers of NEP affiliated with NEE, on the one hand, and NEP and NEP's limited partners, on the other hand. To the extent any directors or officers of NEP are also officers of NEE, such directors and officers will have fiduciary duties to both NEE and NEP, and the interests of NEE and NEP may be different or in conflict. In resolving such conflicts of interest, the directors and officers of NEP affiliated with NEE may favor NEE's interests and the interests of NEE's affiliates over the interests of NEP and its unitholders. These conflicts include the following situations, among others:
•No agreement requires NEE or its affiliates to pursue a business strategy that favors NEP or uses NEP's projects or dictates what markets to pursue or grow.
•NEE and its affiliates are not limited in their ability to compete with NEP, and neither NEP GP nor its affiliates have any obligation to present business opportunities to NEP.
•So long as the officers of NEP are officers of NEE or its affiliates, they will also devote significant time to the business of NEE or its affiliates and will be compensated by NEE or its affiliates.
•The board may cause NEP to borrow funds in order to permit the payment of cash distributions, even if the purpose or effect of the borrowing is to make a payment of the IDR fee.
•NEP's partnership agreement replaces the fiduciary duties that would otherwise be owed by NEP GP and the directors and officers of NEP with contractual standards governing their duties and limits NEP GP’s and such directors’ and officers' liabilities and the remedies available to NEP's unitholders for actions that, without these limitations, might constitute breaches of fiduciary duty under applicable Delaware law.
•Except in limited circumstances, the board has the power and authority to conduct NEP's business without the approval of NEP GP or NEP's unitholders.
•Actions taken by the board may affect the amount of cash available to pay distributions to NEP's unitholders.
•NEP GP has limited liability regarding NEP's contractual and other obligations.
•The board controls the exercise of the rights of NEP against NEE and its affiliates, and the enforcement of the obligations that NEE and its affiliates owe to NEP.
NEP may choose not to retain counsel, independent accountants or other advisors separate from those retained by NEP GP or NEE to perform services for NEP or for the holders of common units.
As a result of the overlapping nature of the management of NEP and NEE and its affiliates, effectively managing these actual, perceived and potential conflicts may require substantial attention, and there is no assurance that all relevant actual, perceived or potential conflicts will be identified or that such conflicts will be adequately addressed. A decision by NEP GP or the board to favor
its own interests or the interests of NEE over NEP's interests and the interests of its unitholders could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP GP and its affiliates and the directors and officers of NEP are not restricted in their ability to compete with NEP, whose business is subject to certain restrictions.
NEP’s partnership agreement provides that its general partner is restricted from engaging in any business activities other than acting as NEP GP and those activities incidental to its ownership of interests in NEP. Affiliates of NEP GP, including, but not limited to, NEE and its other subsidiaries, are not prohibited from owning projects or engaging in businesses that compete directly or indirectly with NEP. NEE currently holds interests in, and may make investments in and purchases of, entities that acquire, own and operate clean energy projects. NEER is under no obligation to make any acquisition opportunities available to NEP. In addition, pursuant to NEP’s partnership agreement, its subsidiaries generally will not have any power or authority to solicit, review, respond to or otherwise participate in certain activities or lines of business.
Under the terms of NEP’s partnership agreement, the doctrine of corporate opportunity, or any analogous doctrine, does not apply to NEP GP and its affiliates, including, but not limited to, NEE or to NEP's directors or officers. Any such person or entity that becomes aware of a potential transaction, agreement, arrangement or other matter that may be an opportunity for NEP will not have any duty to communicate or offer such opportunity to NEP. Any such person or entity will not be liable to NEP or to any limited partner for breach of any fiduciary duty or other duty by reason of the fact that such person or entity pursues or acquires such opportunity for itself, directs such opportunity to another person or entity or does not communicate such opportunity or information to NEP. This may create actual and potential conflicts of interest between NEP and affiliates of NEP GP and result in less than favorable treatment of NEP and holders of its common units.
NEP may only terminate the MSA under certain specified conditions.limited circumstances.
The MSA provides that NEP and certain affiliates may terminate the agreement only upon 90 days' prior written notice to NEE Management upon the occurrence of any of the following:
NEE Management defaults in the performance or observance of any material term, condition or covenant contained therein in a manner that results in material harm to NEP or its affiliates and the default continues unremedied for a period of 90 days after written notice thereof is given to NEE Management;
NEE Management engages in any act of fraud, misappropriation of funds or embezzlement that results in material harm to NEP or its affiliates;
NEE Management is reckless in the performance of its duties under the agreement and such recklessness results in material harm to NEP or its affiliates;
upon the happening of certain events relating to the bankruptcy or insolvency of NEP or certain of its affiliates; or
NEE Management intentionally or willfully takes any action that materially conflicts with or directly contravenes any resolution or other determination of the board relating to certain significant activities of NEP, such action has caused, or would reasonably be expected to cause, material harm to NEP and its subsidiaries, and such action continues unremedied for a period of 90 days after written notice thereof is given to NEE Management.
NEP is not able to terminate the agreement for any other reason, including, but not limited to, if NEE Management experiences a change of control or if a majority of the directors of NEP are not affiliates of NEE.circumstances. The agreement continues until January 1, 2068 and thereafter renews for successive five-year periods unless NEP OpCo or NEE Management provides written notice to the other that it does not wish for the agreement to be renewed. If NEE Management’s performance does not meet the expectations of investors and NEP is unable to terminate the MSA, the market price of NEP's common units could suffer. In addition, even if the MSA is terminated, it may not terminate in respect of provisions relating to the payment of the IDR fee payable to NEE Management under that agreement, which could result in NEE or its affiliates receiving payments that could otherwise be distributed to NEP's unitholders even though NEE Management would be no longer obligated to provide services to NEP under the MSA.
If the agreements with NEE Management or NEER are terminated, NEP may be unable to contract with a substitute service provider on similar terms.
NEE's affiliates provide, or arrange for the provision of, administrative, O&M and construction management services under agreements with NEE Management and NEER, respectively. Any failure by NEE Management or NEER to perform their administrative, O&M and construction management services obligations or the failure by NEP to identify and contract with replacement service providers, if required, could materially impact the successful operation of its projects. Under these agreements, certain NEE employees provide services to NEP. These services are not the primary responsibility of these employees, nor are these employees required to act for NEP alone. The agreements do not require any specific individuals to be provided by NEE and NEE has the discretion to determine which of its employees perform services required to be provided to NEP.
NEE Management and NEER have agreed to provide NEP with management services under the MSA and the management sub-contract, respectively, and NEP does not have independent executive or senior management personnel. Each of the MSA and the management sub-contract, respectively, provides that NEE Management and NEER, respectively, may terminate the applicable agreement upon 180 days’ prior written notice of termination to NEP if NEP defaults in the performance or observance of any material
term, condition or covenant contained in the agreement in a manner that results in material harm to NEE Management or its affiliates other than NEP or its subsidiaries, and the default continues unremedied for a period of 90 days after written notice thereof is given to NEP or upon the happening of certain specified events. If NEE Management terminates the MSA, if NEER terminates the management sub-contract or if either of them defaults in the performance of its obligations under the respective agreement, NEP may be unable to contract with a substitute service provider on similar terms, and the costs of substituting service providers may be substantial. If NEP cannot locate a service provider that is able to provide NEP with substantially similar services as NEE Management and NEER provide under the MSA and the management sub-contract, respectively, on similar terms, it would likely have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
NEP's arrangements with NEE limit NEE’s potential 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.
Under the MSA, NEE Management and its affiliates do not assume any responsibility other than to provide or arrange for the provision of the services described in the MSA in good faith. Additionally, under the MSA, the liability of NEE Management and its affiliates is limited to the fullest extent permitted
by law to conduct involving bad faith, fraud, willful misconduct or recklessness or, in the case of a criminal matter, to action that was known to have been unlawful. NEP has agreed, and will cause certain affiliates to, indemnify NEE Management and its affiliates and any of their directors, officers, agents, members, partners, stockholders and employees and other representatives of NEE Management and its affiliates to the fullest extent permitted by law from and against any claims, liabilities, losses, damages, costs or expenses incurred by an indemnified person or threatened in connection with NEP's, NEP OpCo GP's, NEP OpCo's and certain affiliates' operations, investments and activities or in respect of or arising from the MSA or the services provided thereunder by NEE Management and its affiliates, except to the extent that the claims, liabilities, losses, damages, costs or expenses are determined to have resulted from the conduct in respect of which such persons have liability as described above. Additionally, the maximum amount of the aggregate liability of NEE Management or any of its affiliates in providing services under the MSA or otherwise (including, but not limited to, NEER under the management sub-contract), or of any director, officer, employee, contractor, agent, advisor or other representative of NEE Management or any of its affiliates, will be equal to the base management fee previously paid by NEP in the most recent calendar year under the MSA but in no event less than $4 million.MSA. These protections may result in NEE Management and its affiliates tolerating greater risks when making decisions than otherwise would be the case, including, but not limited to, when determining whether to use leverage in connection with acquisitions. The indemnification arrangements to which NEE Management and its affiliates are a party may also give rise to legal claims for indemnification, which could have a material adverse effect on NEP's business, financial condition, results of operations and ability to make cash distributions to its unitholders.
Risks Related to Ownership of NEP's 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.
NEP's cash flow is generated from distributions NEP receives from NEP OpCo, which will consist primarily of cash distributions that NEP OpCo has received from its subsidiaries. The amount of cash that NEP OpCo’s subsidiaries will be able to distribute to NEP OpCo each quarter principally depends upon the amount of cash such subsidiaries generate from their operations and investments. NEP OpCo may not have sufficient available cash each quarter to continue paying distributions at its current level or at all. If NEP OpCo reduces its per unit distribution, because of reduced operating cash flow, higher expenses, capital requirements or otherwise, NEP will have less cash to distribute to its unitholders and would likely be required to reduce its per common unit distribution.
The amount of cash that NEP OpCo can distribute to its limited partners, including NEP, each quarter principally depends upon the amount of cash it generates from its operations which will fluctuate from quarter to quarter based on among other things:
such things as the amount of power generated from its projects and the amount of natural gas transported in its pipelines, and the prices received therefor;
its operating and capital costs;
payment of interest and principal amortization, which depends on the amount of its indebtedness and the interest payable thereon;
and the ability of NEP OpCo’s subsidiaries to distribute cash under their respective financing agreements;agreements.
the completion of any ongoing construction activities on time and on budget;
its capital expenditures; and
if NEP OpCo acquires a project prior to its COD, timely completion of future construction projects.
In addition, the amount of cash that NEP OpCo will have available for distribution will depend on other factors, some of which are beyond its control, including, but not limited to:such as:
availability of borrowings under its subsidiaries' credit facility to pay distributions;
the costs of acquisitions, if any;
fluctuations in its working capital needs;
timing and collectability of receivables;
restrictions on distributions contained in its subsidiaries' credit facility and other financing documents;
prevailing economic conditions;
access to credit or capital markets; and
•the amount of cash reserves established by NEP OpCo GP, NEP OpCo’s general partner, for the proper conduct of its business.business;
•timing and collectability of receivables;
•fluctuations in its working capital needs;
•availability of borrowings under its subsidiaries' credit facility to pay distributions; and
•access to credit or capital markets.
Because of these factors, NEP OpCo may not have sufficient available cash each quarter to pay its minimuma quarterly distribution per common unit or any other amount. Furthermore, the amount of cash that NEP OpCo has available for distribution depends primarily upon its cash flow, including, but not limited to, cash flow from financial reserves and working capital borrowings, and is not solely a function of profitability, which will be affected by non-cash items. As a result, NEP OpCo may be able to make cash distributions during periods when it records net losses and may not be able to make cash distributions during periods when it records net income.
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.
The IDR fee is an expense of NEP OpCo that reduces the amount of cash distributions by NEP OpCo to NEP OpCo's unitholders, including NEP. The IDR fee is not reduced for NEP's income tax liabilities. Instead, NEP must use the cash proceeds of any distributions NEP receives from NEP OpCo to satisfy NEP's income tax liabilities. Any such payments of income taxes by NEP will reduce the amount of cash distributions by NEP to its unitholders. As a result, if NEP incurs material income 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 units may be subject to voting restrictions.
Under NEP’s partnership agreement, limited partners are allowed to vote for four of the seven members of the board. Moreover, any person, together with the members of any related group, who beneficially owns 5% or more of the outstanding units will be permitted to vote not more than 5% of such outstanding units in an election or removal of certain directors. Further, if, after giving effect to the 5% limitation, any person, together with the members of any related group, still has the power to cast votes equal to or greater than 10% of the units present and actually voted on any matter (including an election or removal of certain directors), such person will be entitled to direct the voting of only the units held by such person representing not more than 9.99% of the units actually voted on such matter, and any units held by such person equal to 10% or more of such voting power will be voted proportionally with the votes cast by other unitholders on such matter. However, if such person is NEP's general partner or any of its affiliates, the 9.99% limitation on voting power applies only to the election or removal of certain directors.
NEP’s partnership agreement replaces the fiduciary duties that NEP GP and NEP’s directors and officers might have to holders of its common units with contractual standards governing their duties.duties and the NYSE does not require a publicly traded limited partnership like NEP to comply with certain of its corporate governance requirements.
NEP’s partnership agreement contains provisions that eliminate the fiduciary standards to which NEP GP or any of NEP’s directors and officers would otherwise be held by state fiduciary duty law and replaces those standards with several different contractual standards.
For example, NEP’s partnership agreement permits the board to make some decisions in its sole discretion, free of any duties to NEP or its unitholders other than the implied contractual covenant of good faith and fair dealing (which means that a court will enforce the reasonable expectations of the partners where the language of the partnership agreement does not provide for a clear course of action). These provisions entitle the board to consider only the interests and factors that the board desires and relieves the board of any duty or obligation to give any consideration to any interest of, or factors affecting, NEP, its affiliates or NEP's limited partners.
NEP’s partnership agreement permits NEP GP to make a number of decisions in its individual capacity, as opposed to in its capacity as NEP's general partner, free of any duties to NEP or its unitholders other than the implied contractual covenant of good faith and fair dealing. These provisions entitle NEP GP and its affiliates to consider only the interests and factors that they desire and relieve them of any duty or obligation to give any consideration to any interest of, or factors affecting, NEP, its affiliates or NEP's limited partners. Examples of decisions that NEP GP and its affiliates may make in their individual capacities include:
•appointment of three directors of NEP;
•how to exercise voting rights with respect to the units NEP GP or its affiliates own in NEP OpCo and NEP;
•whether to exchange NEP OpCo common units owned by NEE Equity for NEP common units or, with the approval of the conflicts committee, to have NEP OpCo redeem NEP OpCo common units owned by NEE Equity for cash; and
•whether to consent to, among other things, NEP’s participation in certain activities or lines of business, the sale of all or substantially all of the assets of NEP, any merger, consolidation or conversion of NEP, dissolution of NEP, or an amendment to NEP OpCo’s partnership agreement.
Additionally, as NEP is a publicly traded limited partnership listed on the NYSE, it is not required to have, and it does not currently have, a majority of independent directors on the board and is not required to establish a compensation committee or a nominating and corporate governance committee.
NEP’s partnership agreement restricts the remedies available to holders of NEP's common units for actions taken by NEP’s directors or NEP GP that might otherwise constitute breaches of fiduciary duties.
NEP’s partnership agreement contains provisions that restrict the remedies available to its unitholders for actions taken by NEP’s directors or NEP GP that might otherwise constitute breaches of fiduciary duties under state law. For example, NEP’s partnership agreement provides that:
•whenever NEP GP or the board, or any director or any committee of the board (including, but not limited to, the conflicts committee), makes a determination or takes, or declines to take, any other action in its respective capacity, they are required to act in good faith;
•NEP GP will not have any liability to NEP or its unitholders for decisions made in its capacity as a general partner so long as such decisions are made in good faith;
•NEP GP and its officers and directors and the officers and directors of NEP will not be liable for monetary damages to NEP or NEP's limited partners resulting from any act or omission unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining such persons acted in bad faith or engaged in fraud or willful misconduct or, in the case of a criminal matter, acted with knowledge that the conduct was criminal; and
•NEP GP and its affiliates and NEP’s directors will not be in breach of their obligations under NEP’s partnership agreement (including, but not limited to, any duties to NEP or its unitholders) if a transaction with an affiliate or the resolution of a conflict of interest is:
• approved by the conflicts committee of the board, although the board is not obligated to seek such approval;
• approved by the vote of a majority of the outstanding common units, excluding any common units owned by NEP GP and its affiliates if the conflict involves NEP GP or any of its affiliates;
• determined by the board to be on terms no less favorable to NEP than those generally being provided to or available from unrelated third parties; or
• determined by the board to be fair and reasonable to NEP, taking into account the totality of the relationships among the parties involved, including, but not limited to, other transactions that may be particularly favorable or advantageous to NEP.
In connection with a situation involving a transaction with an affiliate or a conflict of interest, any determination by NEP GP or the board, or the conflicts committee of the board, must be made in good faith. If an affiliate transaction or the resolution of a conflict of interest is not approved by NEP's unitholders or the conflicts committee and the board determines that the resolution or course of action taken with respect to the affiliate transaction or conflict of interest satisfies either of the standards set forth in the third and fourth sub-bullets above, then it will be presumed that, in making its decision, the board acted in good faith, and in any proceeding brought by or on behalf of any limited partner or NEP challenging such determination, the person bringing or prosecuting such proceeding will have the burden of overcoming such presumption.
Certain of NEP’s actions require the consent of NEP GP.
Under NEP’s partnership agreement, NEP GP's consent is required for certain actions of NEP, in addition to approval by NEP’sthe board or unitholders, as applicable. Because NEP GP is indirectly owned by NEE, NEE can cause NEP GP to exercise certain protective rights. NEP’s partnership agreement provides that NEP GP may grant or withhold its consent in its sole discretion. To the extent NEP GP withholds its consent, NEP unitholders and the board will be prevented from taking actions which they may consider beneficial to NEP or its unitholders.
Holders of NEP's common units and preferred units currently cannot remove NEP GP without NEE’s consent.consent and provisions in NEP's partnership agreement may discourage or delay an acquisition of NEP that NEP unitholders may consider favorable.
The vote of the holders of at least 66 2⁄3% of all outstanding common units, preferred units and special voting units voting together as a single class is required to remove NEP's general partner. Further, the vote of the holders of at least a majority of all outstanding common units, preferred units and special voting units voting together as a single class is required to name a new general partner of NEP. Given NEP GP and its affiliates current voting power with respect to NEP’s outstanding units, a vote to remove NEP’s general partner would currently require NEE’s consent.
In addition, certain provisions in NEP's partnership agreement, including limitations upon the ability of unitholders to make binding proposals of other business to be considered at annual meetings or to request special meetings, may discourage unitholders from attempting to remove the general partner or otherwise change NEP's management. These provisions may have the effect of limiting the ability of a third party to acquire control of NEP that might involve a premium to the market price of NEP's common units or otherwise be in the unitholders' best interests.
NEE’s interest in NEP GP and the control of NEP GP may be transferred to a third party without unitholder consent.
NEP’s partnership agreement does not restrict the ability of NEE to transfer all or a portion of its ownership interest in NEP GP to a third party. NEP’s partnership agreement also does not restrict the ability of NEP GP to issue equity securities in a public or private transaction. A new owner of all or a portion of an ownership interest in NEP GP could then be in a position to designate its own representatives to the board.
The IDR fee may be assigned to a third party without unitholder consent.
Under the MSA, NEE, through NEE Management, may assign the IDR fee, or may sell a portion of the affiliate that has the right to receive the IDR fee to an unaffiliated third party, at any time. If NEE, through NEE Management, transfers the right to receive the IDR fee to a third party, NEE, through NEE Management, may not have the same incentive to provide services necessary to carry out NEP's operations and grow NEP's business so as to increase quarterly distributions to unitholders over time as it would if it had retained ownership of the IDR fee.
NEP may issue additional units without unitholder approval, which would dilute unitholder interests.
NEP’s partnership agreement does not limit the number of additional limited partnership interests, including, but not limited to, limited partnership interests that rank senior to the common units, which NEP may issue at any time without the approval of its unitholders. The issuance by NEP of additional common units or other equity securities of equal or senior rank will have the following effects:
NEP's existing unitholders’ proportionate ownership interest in NEP will decrease;
the amount of cash distributions per common unit may decrease;
because the IDR fee is based on a percentage of total available cash, the IDR fee will increase if total available cash increases even if the per unit distribution on common units remains the same;
the relative voting strength of each previously outstanding unit may be diminished; and
the market price of the common units may decline.
Reimbursements and fees owed to NEP GP and its affiliates for services provided to NEP or on NEP's behalf will reduce cash distributions from NEP OpCo and from NEP to NEP's unitholders, and there are no limits on the amount that NEP OpCo may be required to pay.
Under NEP OpCo’s partnership agreement, prior to making any distributions on its units, NEP OpCo will reimburse NEP GP and its affiliates, including, but not limited to, NEE, for out-of-pocket expenses they incur and payments they make on NEP's behalf and for certain payments made under credit support
arrangements provided by NEER on behalf of NEP's subsidiaries. NEP OpCo will also pay certain fees and reimbursements under the MSA and the CSCS agreement prior to making any distributions on its units. The reimbursement of expenses and certain payments made under credit support arrangements and payment of fees, if any, to NEP GP and its affiliates will reduce the amount of available cash NEP OpCo has to pay cash distributions to NEP and the amount that NEP has available to pay distributions to NEP's unitholders. Under NEP OpCo’s partnership agreement, there is no limit on the fees and expense reimbursements NEP OpCo may be required to pay.
Discretion in establishing cash reserves by NEP OpCo GP may reduce the amount of cash distributions to unitholders.
NEP OpCo’s partnership agreement requires its general partner, NEP OpCo GP, to deduct from operating surplus cash reserves that it determines are necessary to fund NEP OpCo’s future operating expenditures. In addition, NEP OpCo's partnership agreement permits its general partner to reduce available cash by establishing cash reserves for the proper conduct of NEP OpCo’s business, to comply with applicable law or agreements to which NEP OpCo is a party or to provide funds for future distributions to partners. These cash reserves will affect the amount of cash distributed by NEP OpCo, which ultimately will affect the amount of cash distributions to NEP's unitholders.
NEP OpCo can borrow money to pay distributions, which would reduce the amount of credit available to operate NEP's business.
NEP OpCo’s partnership agreement allows it to make working capital borrowings to pay distributions to its unitholders. Accordingly, if NEP OpCo has available borrowing capacity, it can make distributions on its units even though cash generated by its operations may not be sufficient to pay such distributions. Any working capital borrowings by NEP OpCo to make distributions will reduce the amount of working capital borrowings it can make for NEP OpCo’s operations.
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.
Interest rates on future credit facilities and debt offerings could be higher than current levels, causing NEP's financing costs to increase accordingly. NEP's common unit price is impacted by the level of its cash distributions and implied distribution yield. The distribution yield is used by investors to compare yield-oriented securities for investment decision-making purposes. Therefore, changes in interest rates, either positive or negative, may affect the yield requirements of investors who invest in NEP's common units, and a rising interest rate environment 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 liability of holders of NEP's 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.
A general partner of a limited partnership generally has unlimited liability for the obligations of the limited partnership except for those contractual obligations of the limited partnership that are expressly made without recourse to the general partner. NEP is organized under Delaware law and NEP conducts business in a number of other states. The limitations on the liability of holders of limited partnership interests for the obligations of a limited partnership have not been clearly established in some of the other states in which NEP does business. A unitholder could be liable for any and all of NEP's obligations as if the unitholder were a general partner if a court or government agency were to determine that:
•NEP was conducting business in a state but had not complied with that particular state ’sstate’s limited partnership statute; or
•the unitholder’s right to act with other unitholders to remove or replace NEP GP, to approve some amendments to NEP's partnership agreement or to take other actions under NEP's partnership agreement constitute “control” of NEP's business.
Unitholders may have liability to repay distributions that were wrongfully distributed to them.
Under certain circumstances, unitholders may have to repay amounts wrongfully returned or distributed to them. Under Delaware law, NEP may not make a distribution to its unitholders if the distribution would cause NEP's liabilities to exceed the fair value of its assets. Delaware law provides that for a period of three years from the date of an impermissible distribution, limited partners who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the limited partnership for the distributed amount. Transferees of common units are liable both for the obligations of the transferor to make contributions to the partnership that were known to the transferee at the time of transfer and for those obligations that were unknown if the liabilities could have been determined from the partnership agreement. Neither liabilities to partners on account of their partnership interest nor liabilities that are non-recourse to the partnership are counted for purposes of determining whether a distribution is permitted.
Provisions in NEP’s partnership agreement may discourage or delay an acquisition of NEP that NEP unitholders may consider favorable, which could decrease the value of NEP's common units, and could make it more difficult for NEP unitholders to change the board.
NEP’s partnership agreement contains provisions that make it difficult for a third party to acquire NEP without the consent of the board. For example, NEP's partnership agreement provides that, with respect to annual meetings of limited partners, limited partners cannot nominate persons for election to the board unless such nominations are included in the proxy statement of NEP in accordance with the proxy access provisions of NEP’s partnership agreement, and the limited partners cannot make any binding proposals of other business to be considered at any annual meeting of limited partners. In addition, limited partners may request a special meeting of limited partners only if the request is made by limited partners holding 20% or more of the units then outstanding and only for the removal of certain directors for cause or NEP's general partner. These provisions may have the effect of limiting the ability of a third party to acquire control of NEP that might involve a premium to the market price of NEP's common units or otherwise be in the unitholders' best interests.
The NYSE does not require a publicly traded limited partnership like NEP to comply with certain of its corporate governance requirements.
NEP's common units are listed on the NYSE. Because NEP is a publicly traded limited partnership, the NYSE does not require NEP to have, and it does not have, a majority of independent directors on the board or to establish a compensation committee or a nominating and corporate governance committee. Accordingly, unitholders do not have the same protections afforded to corporations that are subject to all of the NYSE corporate governance requirements.
The issuance of preferredcommon units, or other limited partnership interests, or securities convertible into, or settleable with, common units, may affect the market price for NEP's common units,and any subsequent conversion or settlement, will dilute common unitholders’ ownership in NEP, and may decrease the amount of cash available for distribution for each common unit.unit, will impact the relative voting strength of outstanding NEP common units and issuance of such securities, or the possibility of issuance of such securities, as well as the resale, or possible resale following conversion or settlement, may result in a decline in the market price for NEP's common units.
NEP's partnership agreement does not limit the number of additional limited partnership interests, including, but not limited to, limited partnership interests that rank senior to the common units, which NEP may issue at any time without the approval of its unitholders.
NEP has issued preferred units and outstanding convertible notes in 2017 and certain NEP OpCo subsidiaries have issued and outstanding noncontrolling Class B interests in certaintheir subsidiaries that may be settled in whole or in part as specified in the related limited liability company agreement, at NEP's election with NEP OpCo subsidiariescommon units, and may issue similar securities in 2018 and 2019.the future. Subject to certain limitations, the preferred units and convertible notes are convertible into common unitsmay be converted by the holders of such units and notes, or,with NEP paying cash up to the aggregate principal amount of the notes being converted. NEP will have the option to deliver NEP common units for the preferred units, at NEP’s option under certain circumstances.remainder, if any, of NEP's conversion obligation in excess of the aggregate principal amount of the notes being converted. NEP will havehas the option, subject to certain limitations and extensions, to purchase the noncontrolling Class B interests.interests in those NEP OpCo subsidiaries. If exercised, NEP has the right to pay all or a portion of the buyout price in NEP non-voting common units (convertible into NEP common units) or NEP common units, as specified in the related limited liability company agreement, issued at the then-current market price of NEP common units, subject to certain limitations. If holders of the preferred units or noncontrolling Class B interests, convertible notes or any convertible securities issued in the future, were to dispose of a substantial portion of these common units in the public market following such a conversion or settlement, whether in a single transaction or series of transactions, it could adversely affect the market price for NEP's common units. These sales,The holders of the noncontrolling Class B interests generally have certain registration rights that would facilitate such dispositions promptly and NEP cannot guarantee that these holders will not dispose of a substantial portion or all of their common units promptly upon conversion or settlement.
Any issuance of NEP common units, or other NEP limited partnership interests, securities convertible into, or settleable with, common units as well as the issuance of NEP non-voting common units or NEP common units, as the case may be, upon conversion or settlement, will or may have the following effects:
•an existing common unitholder’s proportionate ownership interest in NEP may decrease;
•the amount of cash distributions per common unit may decrease; and
•the relative voting strength of each previously outstanding common unit may be diminished.
In addition, any issuance, or the possibility that these salesof issuance, of the securities described in the preceding sentence, as well as the resale, or possibility of resale, of NEP common units following conversion or settlement may occur,result in a decline in the market price of NEP common units and could make it more difficult for NEP to sell NEP's common units in the future.
In addition, the terms of the preferred units permit NEP, in certain circumstances and subject to certain limitations, to pay the quarterly distributions on the preferred units in the form of additional convertible preferred units (PIK Units). Pursuant to the terms of the
preferred units, such quarterly distributions may be paid, at NEP’s option, in (i) PIK Units, (ii) cash, or (iii) a combination of PIK Units and cash.
Any issuance of preferred units or other securities convertible into common units and/or the payment of quarterly distributions on the preferred units in PIK Units will or may have the following effects:
an existing unitholder’s proportionate ownership interest in NEP will decrease;
the amount of cash available for distribution on each common unit may decrease;
the relative voting strength of each previously outstanding common unit will be diminished; and
the market price of NEP's common units may decline.
The preferred units have rights, preferences and privileges that are not held by, and are preferential to the rights of, holders of the common units.
The preferred units rank senior to the common units with respect to distribution rights. These preferences could adversely affect the market price of the common units, or could make it more difficult for NEP to sell common units in the future.
NEP’s obligation to pay distributions on the preferred units, or on the common units issued following the conversion of such preferred units, could impact NEP's liquidity and reduce the amount of cash available for working capital, capital expenditures, growth opportunities, acquisitions, and other general partnership purposes. NEP’s obligations to the holders of the preferred units could also limit its ability to obtain additional financing or increase NEP's borrowing costs, which could have an adverse effect on NEP’s financial condition.
Taxation Risks
NEP's future tax liability may be greater than expected if NEP does not generate NOLsnet operating losses (NOLs) sufficient to offset taxable income
or if tax authorities challenge certain of NEP's tax positions.
Even though NEP is organized as a limited partnership under state law, itNEP is treated as a corporation for U.S. federal income tax purposes and thus is subject to U.S. federal income tax at regular corporate rates on NEP's net taxable income. NEP expects to generate NOLs and NOL carryforwards that it can use to offset future taxable income. As a result, NEP does not expect to pay meaningful U.S. federal income tax for over 15 years. This estimate is based upon assumptions NEP has made regarding, among other things, NEP OpCo's income, capital expenditures, cash flows, net working capital and cash distributions. Further, the IRS or other tax authorities could challenge one or more tax positions NEP or NEP OpCo takes, such as the classification of assets under the income tax depreciation rules, the characterization of expenses (including, but not limited to, NEP's share of the IDR fee) for income tax purposes, the extent to which sales, use or goods and services tax applies to operations in a particular state or the availability of property tax exemptions with respect to NEP's projects. Further, any change in tax law may affect NEP's tax position, including changes in corporate income tax laws, regulations and policies applicable to NEP. While NEP expects that its NOLs and NOL carryforwards will be available to NEP as a future benefit, in the event that they are not generated as expected, are successfully challenged by the IRS (in a tax audit or otherwise) or are subject to future limitations as described below, NEP's ability to realize these benefits may be limited.
NEP's federal, state, local or Canadian tax positions may be challenged by the relevant tax authority. The process and costs, including, but not limited to, potential penalties for nonpayment of disputed amounts, of appealing such challenges, administratively or judicially, regardless of the merits, could be material. A reduction in NEP's expected NOLs, a limitation on NEP's ability to use such losses, or other tax attributes, such as tax credits, and future tax audits or a challenge by tax authorities to NEP's tax positions may result in a material increase in NEP's estimated future income taxes or other tax liabilities, which would negatively impact the amount of after-tax cash distributions to NEP's unitholders and its financial condition.
NEP's ability to use NOLs to offset future income may be limited.
NEP's ability to use its NOLs to offset future taxable income could be substantially limited if NEP’s unitholders that own 5% or more of NEP’s outstanding common units, as defined under Code Section 382, increase their ownership in NEP by more than 50 percentage points over a rolling three-year period through, among other things, additional purchases of NEP's common units and certain types of reorganization transactions. Any NOLs that exceed this limitation may be carried forward and used to offset taxable income for the remainder of the carryforward period (i.e., 20 years from the year in which such NOL was generated for NOLs generated prior to January 1, 2018 and no carryforward limitation for any subsequently generated NOLs). Based on NEP’s most recent annual assessment, NEP does not expect the Section 382 limitation to impact its ability to utilize any of its NOLs to offset future taxable income. However, potentialAdditionally, valuation allowances may be needed for deferred tax assets that NEP estimates are more likely than not to be unusable, based on available evidence at the time the estimate is made. Potential changes in the tax law or in NEP’s projections could impact this assessment.NEP's assessment and valuation allowance estimates, which could have a material adverse impact on NEP's financial condition and results of operations.
NEP will not have complete control over NEP's tax decisions.
NEP and/or NEP OpCo may be included in the combined or unitary tax returns of NEE or one or more of its subsidiaries for U.S. state or local income tax purposes. NEP is a party to a tax sharing arrangement which determines the share of taxes that NEP will pay to, or receive from, NEE. In addition, by virtue of NEP's inclusion in NEE’s combined or unitary income tax returns, NEE will effectively control all of NEP's state and local tax decisions in connection with any combined or unitary income tax returns in which NEP is included. NEE will have sole authority to respond to and conduct all tax proceedings (including, but not limited to, tax audits)
related to NEP, to file all state and local income tax returns on NEP's behalf, and to determine the amount of NEP's liability to, or entitlement to payment from, NEE in connection with any combined or unitary income tax returns in which NEP is included. This may result in conflicts of interest between NEE and NEP.
A valuation allowance may be required for NEP's deferred tax assets.
NEP's expected NOLs will be reflected as a deferred tax asset as they are generated until used to offset taxable income. Additional valuation allowances may be needed for deferred tax assets that NEP estimates are more likely than not to be unusable, based on available evidence at the time the estimate is made. Valuation allowances related to deferred tax assets can be affected by changes to tax laws, statutory tax rates and future taxable income levels and based on input from NEP's tax advisors or regulatory authorities. In the event that NEP were to determine that it would not be able to realize all or a portion of NEP's net deferred tax assets in the future, NEP would reduce such amounts through a charge to income tax expense in the period in which that determination was made, which could have a material adverse impact on NEP's financial condition and results of operations and NEP's ability to maintain profitability.
Distributions to unitholders may be taxable as dividends.
Even though NEP is organized as a limited partnership under state law, NEP is treated as a corporation for U.S. federal income tax purposes. Accordingly, if NEP makes distributions from current or accumulated earnings and profits as computed for U.S. federal income tax purposes, such distributions will generally be taxable to unitholders as ordinary dividend income for U.S. federal income tax purposes. Distributions paid to non-corporate U.S. unitholders will be subject to U.S. federal income tax at preferential rates, provided that certain holding period and other requirements are satisfied. However, it is difficult to predict whether NEP will generate earnings and profits as computed for U.S. federal income tax purposes in any given tax year, and although NEP expects that a portion of its distributions to unitholders may exceed its current and accumulated earnings and profits as computed for U.S. federal income tax purposes and therefore constitute a non-taxable return of capitalreturn-of-capital distribution to the extent of a unitholder’s basis in its units, this may not occur. In addition, although return-of-capital distributions are generally non-taxable to the extent of a unitholder’s basis in its units, such distributions will reduce the unitholder’s adjusted tax basis in its units, which will result in an increase in the amount of gain (or a decrease in the amount of loss) that will be recognized by the unitholder on a future disposition of NEP's common units, and to the extent any return-of-capital distribution exceeds a unitholder’s basis, such distributions will be treated as gain on the sale or exchange of the units.
Item 1B. Unresolved Staff Comments
None
Item 2. Properties
NEP and its subsidiaries maintain properties consisting of renewable generation projects and natural gas pipeline assets which are adequate for their operations; the principal properties are described in Item 1. Business, which description is incorporated herein by reference.
Character of Ownership
The majority of NEP's generating facilities and pipelines are owned by NEP subsidiaries and are currently subject to NEE Equity's 60.8%53.8% noncontrolling limited partner interest in NEP OpCo. In addition, a subsidiary of Pemex owns a 10% interest in the NET Mexico pipeline, NEER owns an approximately 50% noncontrolling ownership interestinterests in Silver Statecertain NEP OpCo subsidiaries and other third-party investors own noncontrolling interests in certain NEP OpCo subsidiaries. See Item 1. Certain of the generating facilities and all of the pipelines are encumbered by liens securing various financings. Additionally, some of the generating facilities and pipelines occupy or use real property that is not owned by NEP subsidiaries, primarily through various easements, leases, rights-of-way, permits or licenses from private landowners or governmental entities.
Item 3. Legal Proceedings
NoneWith regard to environmental proceedings to which a governmental authority is a party, NEP's policy is to disclose any such proceeding if it is reasonably expected to result in monetary sanctions of greater than or equal to $1 million.
Item 4. Mine Safety Disclosures
Not applicable
PART II
Item 5. Market for Registrant's Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities
Common Unit Data. NEP's common units are traded on the NYSE under the symbol "NEP".
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 the board. 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. Although, as described above, NEP currently expects that cash reserves would be established by the board solely to provide for the payment of NEP's income taxes, if any, 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.
NEP OpCo's partnership agreement requires it to distribute all of its available cash to its common and preferred 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, less the amount of cash reserves established by NEP OpCo GP. The majority of such available cash is expected to be derived from the operations of the projects. The cash available for distribution is likely tocould fluctuate from quarter to quarter, and in some cases significantly, as a result of the performance of the projects, seasonality, fluctuating wind and solar resource, maintenance and outage schedules, timing of debt service and other factors. See Note 15 - PG&E Bankruptcy for a discussion of events of default that continue to limit future cash distributions from certain projects.
In February 2020,2023, NEP paid a distribution of $0.5350$0.8125 per common unit to its unitholders of record on February 6, 2020.2023. See Management's Discussion -– Liquidity and Capital Resources -– Financing Arrangements and Note 11 - Debt12 with respect to distribution restrictions. There are currently no restrictions in effect that limit NEP's ability to pay dividendsdistributions to its unitholders.
At the closeAs of business on January 31, 2019,2023, there were 1113 holders of record of NEP's common units.
Preferred Unit Data. In November 2017, NEP issued and sold 14,021,561 preferred units for an aggregate purchase price of approximately $550 million. In both July and November 2019, NEP converted approximately 4,673,852 preferred units into NEP common units. Holders of preferred units receive cumulative quarterly distributions equal to $0.4413 per unit for quarters ending on or before November 15, 2020, which was prorated for the fourth quarter of 2017 and which may be paid, at NEP’s election, in cash, in kind or a combination thereof. For quarters ending after November 15, 2020, holders will receive cumulative quarterly distributions equal to the greater of $0.4413 per unit and the amount that the preferred units would have received if they had converted into common units at the then-applicable conversion rate (see Note 11 - Equity), and NEP may elect to pay up to 1/9th of the subsequent distribution period amounts in kind. The quarterly distribution amount and portion of the distribution that may be paid in kind will be prorated for the fourth quarter of 2020. If NEP fails to pay a distribution during a subsequent distribution period, NEP would be unable to pay any distributions on or redeem or repurchase any junior securities, including the common units, prior to paying the unpaid cash component of the quarterly distribution, including any previously accrued and unpaid cash distributions. During 2019, NEP paid approximately $21 million of preferred distributions and accrued approximately $2 million of preferred unit distributions which were paid in February 2020. In connection with the sale of the preferred units, NEP entered into a registration rights agreement with the purchasers pursuant to which, among other things, beginning on January 1, 2021, the purchasers will have certain rights to require NEP, under certain circumstances, to initiate underwritten offerings for the common units that are issuable upon conversion of the preferred units.
Incentive Distribution Rights Fee. IDRs represent the right to receive a fee calculated based on the amount of adjusted available cash from operating surplus, as defined in the MSA, that NEP OpCo would be able to distribute to its common
unitholders after specified minimum quarterly and target quarterly distribution levels have been achieved. The right to receive the IDR fee is currently held by NEE Management, but may be assigned, subject to restrictions in the MSA. The following discussion assumes that NEE Management continues to own the IDRs.
Under the MSA, for any quarter in which NEP OpCo has adjusted available cash at least equal to a base incentive amount (total common units outstanding multiplied by $0.3525, plus approximately $14 million paid to NEE Management quarterly for IDRs) any excess adjusted available cash will be split 75% to NEP OpCo common unitholders and 25% to NEE Management for IDRs. The IDR fee paid by NEP is capped at $39.25 million per quarter ($157 million per year) if quarterly distributions to NEP OpCo unitholders are at or above $0.7625 ($3.05 on an annualized basis) per NEP OpCo common unit.
If NEP OpCo's adjusted available cash for any quarter falls below the base incentive amount, the IDRs will be paid using the target quarterly distribution levels below calculated using the number of NEP OpCo common units outstanding on January 26, 2017, subject to certain adjustments for repurchases, splits and combinations:
| | | | | | | | | | | | | | | | | | | | |
| | Total Quarterly Distribution per NEP OpCo Common Unit Target Amount | | Marginal Percentage Interest in Adjusted Available Cash |
| | | NEP OpCo Common Unitholders | | NEE Management |
Minimum Quarterly Distribution | | $0.1875 | | 100% | | —% |
First Target Quarterly Distribution | | Above $0.1875 up to $0.215625 | | 100% | | —% |
Second Target Quarterly Distribution | | Above $0.215625 up to $0.234375 | | 85% | | 15% |
Third Target Quarterly Distribution | | Above $0.234375 up to $0.281250 | | 75% | | 25% |
Thereafter | | Above $0.281250 | | 50% | | 50% |
During 2019, 20182022, 2021 and 2017,2020, NEP paid IDR fees of approximately $86$152 million, $72$129 million and $60$104 million, respectively.
Unregistered Sales of Equity Securities and Use of Proceeds. On January 31, 2023, NEE Equity, a wholly owned subsidiary of NEE, delivered a written notice to NEP OpCo in accordance with the exchange agreement, dated as of July 1, 2014 (as amended, the exchange agreement), by and among NEE Equity, NEP OpCo, NEP GP and NEP. Pursuant to such written notice, NEE Equity has elected to exchange 860,000 NEP OpCo common units held by NEE Equity for the same number of NEP common units. In accordance with the exchange agreement, 860,000 NEP common units will be delivered to NEE Equity on or about April 3, 2023. Upon exchange of NEP OpCo common units for NEP common units, a corresponding number of NEP special voting units will be cancelled in accordance with NEP’s partnership agreement. The NEP common units will be issued to NEE Equity in reliance upon an exemption from the registration requirements of the Securities Act of 1933, as amended, provided by Section 4(a)(2) thereof.
Purchases of Equity Securities by Affiliated Purchaser. In October 2015, NEP was advised that NEE authorized a program to purchase, from time to time, up to $150 million of NEP's outstanding common units. Under the program, purchases may be made in amounts, at prices and at such times as NEE or its subsidiaries deem appropriate, all subject to market conditions and other considerations. The common unit purchase program does not require NEE to acquire any specific number of common units and may be modified or terminated by NEE at any time. The purpose of the program is not to cause NEP’s common units to be delisted from the NYSE or to cause the common units to be deregistered with the SEC. During 2019, 20182022, 2021 and 2017,2020, there were no purchases under the program. At December 31, 2019,2022, the dollar value of units that may yet be purchased under the program was approximately $114 million.
Item 6. Selected Financial Data
The selected financial data below is presented using the basis of accounting relevant to each period. For all periods prior to 2018, the selected financial data represents the consolidated financial results of NEP, including the acquisitions from NEER prior to 2018 (the common control acquisitions). 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 consolidated financial data has been retrospectively adjusted to include the historical results and financial position of the common control acquisitions prior to their respective acquisition dates. All years presented reflect the October 2015 Texas pipelines acquisition. The years ended December 31, 2019 and 2018 also reflect an acquisition in December 2018 and the year ended December 31, 2019 reflects acquisitions in June 2019 and November 2019. See Note 3.
|
| | | | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 | | 2016 | | 2015 |
SELECTED DATA OF NEP (millions, except per unit and GWh amounts): | | | | | | | | | |
Operating revenues | $ | 855 |
| | $ | 771 |
| | $ | 807 |
| | $ | 772 |
| | $ | 501 |
|
Net income (loss)(a) | $ | (404 | ) | | $ | 267 |
| | $ | 114 |
| | $ | 383 |
| | $ | 107 |
|
Net income (loss) attributable to NEP(a) | $ | (88 | ) | | $ | 167 |
| | $ | (64 | ) | | $ | 83 |
| | $ | 10 |
|
Earnings (loss) per common unit attributable to NEP - basic(a) | $ | (1.51 | ) | | $ | 3.05 |
| | $ | (1.18 | ) | | $ | 1.90 |
| | $ | 0.46 |
|
Earnings (loss) per common unit attributable to NEP - assuming dilution(a) | $ | (1.51 | ) | | $ | 2.91 |
| | $ | (1.18 | ) | | $ | 1.90 |
| | $ | 0.46 |
|
Distributions paid per common unit | $ | 1.9675 |
| | $ | 1.7125 |
| | $ | 1.4900 |
| | $ | 1.2975 |
| | $ | 0.9050 |
|
Total assets | $ | 12,256 |
| | $ | 9,405 |
| | $ | 8,425 |
| | $ | 8,691 |
| | $ | 8,237 |
|
Long-term debt, excluding current maturities | $ | 4,132 |
| | $ | 2,728 |
| | $ | 4,218 |
| | $ | 3,508 |
| | $ | 3,334 |
|
GWh generated | 16,687 |
| | 11,471 |
| | 11,117 |
| | 10,215 |
| | 7,373 |
|
______________________
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | |
| |
(a) | The year ended December 31, 2019 reflects higher losses related to NEP's derivative instruments (see Note 7 - Financial Statement Impact of Derivative Instruments). The year ended December 31, 2018 reflects a gain of approximately $153 million (see Note 2 - Disposal of Canadian Holdings). The year ended December 31, 2017 reflects an income tax charge of approximately $100 million, all of which was attributable to NEP, related to tax reform (see Note 5). The year ended December 31, 2016 reflects a favorable fair value adjustment of approximately $189 million. | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
Item 6.Reserved
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations
This discussion should be read in conjunction with the Notes to Consolidated Financial Statements contained herein. All comparisons are with the corresponding items in the prior year.
Overview
Company Description
NEP is a growth-oriented limited partnership formed to acquire, manage and own contracted clean energy projects with stable long-term cash flows. NEP consolidates the results of NEP OpCo and its subsidiaries through its controlling interest in the general partner of NEP OpCo. At December 31, 2019,2022, NEP owned an approximately 39.2%46.2% limited partner interest in NEP OpCo and NEE Equity owned a noncontrolling 60.8%53.8% limited partner interest in NEP OpCo. See Part II, Item 5 – Unregistered Sales of Equity Securities and Use of Proceeds. Through NEP OpCo, NEP has ownership interests in a portfolio of contracted renewable generation assets consisting of wind, solar and solarbattery storage projects and a portfolio of contracted natural gas pipeline assets. NEP's financial results are shown on a consolidated basis with financial results attributable to NEE Equity reflected in noncontrolling interests.
During 2019, 20182022, 2021 and 2017,2020, NEP acquired interests in various projects from NEER as discussed in Note 3. The acquisitions from NEER prior to 2018 (common control acquisitions) were considered 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 consolidated financial statements were retrospectively adjusted to include the historical results and financial position of the common control acquisitions prior to their respective acquisition dates. Beginning in January 2018, acquisitions from NEER are no longer treated as common control acquisitions. In addition, on November 13, 2019, a subsidiary ofDuring 2022, NEP acquired an equity method investmentsold its ownership interests in a natural gas pipeline locatedand in Pennsylvania from third parties. See Note 3.
In June 2018, a subsidiary ofearly January 2023 NEP completedclosed on the sale of Canadian Holdings which owned foura 62 MW wind generation facilities and two solar generation facilitiesproject located in Ontario, Canada with a generating capacity totaling approximately 396 MW. SeeNorth Dakota (see Note 2 -– Disposal of Canadian Holdings.Pipeline and – Disposal of Wind Project).
In late January 2019, PG&E, a significant customer of NEP, filed a voluntary petition for reorganization under Chapter 11 of the U.S. Bankruptcy Code. See Note 15 - PG&E Bankruptcy.
Results of Operations
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
| (millions) |
| | | |
OPERATING REVENUES | | | | | |
Renewable energy sales | $ | 966 | | | $ | 720 | | | $ | 703 | |
Texas pipelines service revenues | 245 | | | 262 | | | 214 | |
Total operating revenues | 1,211 | | | 982 | | | 917 | |
OPERATING EXPENSES | | | | | |
Operations and maintenance | 571 | | | 419 | | | 363 | |
Depreciation and amortization | 430 | | | 288 | | | 271 | |
Taxes other than income taxes and other | 49 | | | 36 | | | 28 | |
Total operating expenses – net | 1,050 | | | 743 | | | 662 | |
GAINS (LOSSES) ON DISPOSAL OF BUSINESSES/ASSETS – NET | 36 | | | (5) | | | (2) | |
OPERATING INCOME | 197 | | | 234 | | | 253 | |
OTHER INCOME (DEDUCTIONS) | | | | | |
Interest expense | 853 | | | 47 | | | (620) | |
Equity in earnings of equity method investees | 183 | | | 160 | | | 108 | |
Equity in earnings (losses) of non-economic ownership interests | 56 | | | 27 | | | (3) | |
Other – net | 3 | | | 4 | | | 5 | |
Total other income (deductions) – net | 1,095 | | | 238 | | | (510) | |
INCOME (LOSS) BEFORE INCOME TAXES | 1,292 | | | 472 | | | (257) | |
INCOME TAX EXPENSE (BENEFIT) | 171 | | | 48 | | | (19) | |
NET INCOME (LOSS) | 1,121 | | | 424 | | | (238) | |
NET INCOME ATTRIBUTABLE TO PREFERRED DISTRIBUTIONS | — | | | — | | | (5) | |
NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS | (644) | | | (287) | | | 188 | |
NET INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP | $ | 477 | | | $ | 137 | | | $ | (55) | |
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
STATEMENT OF INCOME (LOSS) DATA: | | | |
OPERATING REVENUES | | | | | |
Renewable energy sales | $ | 645 |
| | $ | 551 |
| | $ | 613 |
|
Texas pipelines service revenue | 210 |
| | 220 |
| | 194 |
|
Total operating revenues | 855 |
| | 771 |
| | 807 |
|
OPERATING EXPENSES | | | | | |
Operations and maintenance | 336 |
| | 257 |
| | 248 |
|
Depreciation and amortization | 259 |
| | 203 |
| | 226 |
|
Taxes other than income taxes and other | 27 |
| | 21 |
| | 21 |
|
Gain on disposal of Canadian Holdings | — |
| | (153 | ) | | — |
|
Total operating expenses | 622 |
| | 328 |
| | 495 |
|
OPERATING INCOME | 233 |
| | 443 |
| | 312 |
|
OTHER INCOME (DEDUCTIONS) | | | | | |
Interest expense | (702 | ) | | (248 | ) | | (199 | ) |
Benefits associated with differential membership interests - net | — |
| | — |
| | 119 |
|
Equity in earnings of equity method investees | 38 |
| | 41 |
| | 40 |
|
Equity in earnings (losses) of non-economic ownership interests | (4 | ) | | 15 |
| | 11 |
|
Other - net | 5 |
| | 22 |
| | (2 | ) |
Total other deductions - net | (663 | ) | | (170 | ) | | (31 | ) |
INCOME (LOSS) BEFORE INCOME TAXES | (430 | ) | | 273 |
| | 281 |
|
INCOME TAX EXPENSE (BENEFIT) | (26 | ) | | 6 |
| | 167 |
|
NET INCOME (LOSS) | (404 | ) | | 267 |
| | 114 |
|
Net income attributable to preferred distributions | (17 | ) | | (25 | ) | | (3 | ) |
Net loss (income) attributable to noncontrolling interests | 333 |
| | (75 | ) | | (175 | ) |
NET INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP | $ | (88 | ) | | $ | 167 |
| | $ | (64 | ) |
20192022 Compared to 20182021
Operating Revenues
Operating revenues primarily consist of income from the sale of energy under NEP's PPAs and services provided under natural gas transportation agreements, partly offset by the net amortization of intangible assets -– PPAs and intangible liabilities – PPAs (see Note 2 -– Intangible Assets -– PPAs and – Intangible Liabilities – PPAs). Operating revenues increased $84$229 million during the year ended December 31, 2019.2022. The increase in renewable energy sales of approximately $246 million primarily reflects an increase of approximately $170$214 million related to the projects acquired in December 2018the second half of 2021 and June 2019,2022 (see Note 3), as well as favorable resource and higher availability due to fewer maintenance outages in 2022. The decrease in Texas pipeline service revenues of $17 million primarily reflects lower revenues of approximately $30 million associated with transportation and fuel management agreements revenues which were higher in 2021 due to extreme weather in February 2021 (see Note 14 – Transportation and Fuel Management Agreements), partly offset by a decrease of $78 million as a result of the sale of Canadian Holdings. Texas pipelines service revenues decreased by approximately $10 million primarily due to the absence of certain deferred revenue recognized in 2018 related to new contracts.higher volumes.
Wind and solar resource levels, weather conditions and the performance of NEP's renewable energy portfolio represent significant factors that could affect its operating results because these variables impact energy sales. Additionally, project acquisitions or expansion opportunities could impact future revenues.
Operating Expenses
Operations and Maintenance
O&M expenses include interconnection costs, labor expenses, turbine servicing costs, land payments, 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 13)14). 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 expenses increased $79$152 million during the year ended December 31, 20192022 primarily due to increases of approximately $53$92 million related to the projects acquired in December 2018the second half of 2021 and June 20192022, $24 million of higher repair and $23maintenance costs and $24 million in higher other corporate expenses, including higher IDR fees of $23 million related to growth in NEP's distributions to its common unitholders. In June 2022, the MSA was amended to cap the IDR fee paid by NEP at $39.25 million per quarter ($157 million per year) if quarterly distributions to NEP OpCo unitholders are at or above $0.7625 ($3.05 on an annualized basis) per NEP OpCo common unit. See Part II, Item 5 – Incentive Distribution Rights Fee.
O&M expenses related to the existing portfolio are expected to remain relatively stable from year to year. However, NEP's O&M expenses are likely to increase as NEP acquires new projects.
Depreciation and Amortization
Depreciation and amortization expense reflects costs associated with depreciation and amortization of NEP's assets, based on depreciable asset lives and consistent depreciation methodologies. For certain of the renewable energy projects, CITCs are recorded as a reduction in property, plant and equipment -– net on the 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 $56$142 million during the year ended December 31, 20192022 primarily as a result of approximately $61 million ofdue to depreciation related to projects acquired in December 2018the second half of 2021 and June 2019.2022.
GainGains (Losses) on Disposal of Canadian HoldingsBusinesses/Assets – Net
During
The $36 million net gains on disposal of businesses/assets recognized during the year ended December 31, 2018, a subsidiary of NEP completed2022 primarily reflects the gain recorded for the sale of Canadian Holdings and NEP recognizedNEP's interests in a pre-tax gain of approximately $153 million.pipeline in Texas. See Note 2 -– Disposal of Canadian Holdings.Pipeline.
Other Income (Deductions)
Interest Expense
Interest expense primarily consists of interest under long-term debt agreements and mark-to-market gains and losses on interest rate contracts. In 2019, interest expense also reflects approximately $153 million of costs, including cash payments and the write-off of debt issuance costs, primarily related to the retirement of debt associated with Genesis (see Note 15 - PG&E Bankruptcy) and certain wind projects that are being repowered. Interest expense increaseddecreased approximately $454$806 million during the year ended December 31, 20192022 primarily reflecting $865 million of favorable mark-to-market activity ($1,033 million of gains recorded in 2022 compared to $168 million of gains recorded in 2021), offset by higher interest expense due to unfavorable mark-to-market activityincreased average debt outstanding and higher interest rates. See Note 12 and Note 5 – Financial Statement Impact of $315 million. Interest expense also reflects decreases in interest expense associated with the absence of interest associated with the sale of Canadian Holdings as well as other debt retired in 2019 as discussed above, mostly offset by increases in interest expense related to debt incurred in 2019 (see Note 11 - Debt).Derivative Instruments.
Equity in Earnings (Losses) of Non-Economic Ownership InterestsEquity Method Investees
The decrease in equityEquity in earnings (losses) for non-economic ownership interestsof equity method investees increased $23 million for the year ended December 31, 2019 reflects lower2022 primarily due to earnings at the related projects.to NEP's investment in projects in October 2021 (see Note 3).
Other - netEquity in Earnings of Non-Economic Ownership Interests
Equity in other - netearnings of non-economic ownership interests increased $29 million for the year ended December 31, 20192022 primarily reflects the absence of 2018 gainsreflecting favorable mark-to-market activity on foreign currency exchangeinterest rate contracts (see Note 7).in 2022.
Income Taxes
NEP recognizes in income its applicable ownership share of U.S. income taxes due to the disregarded tax status of substantially all of the U.S. projects under NEP OpCo. Prior to the sale of Canadian Holdings, NEP's former Canadian subsidiaries were all Canadian taxpayers, and therefore NEP recognized in income all of the Canadian taxes. Net income or loss attributable to noncontrolling interests includes minimal U.S. taxes and NEER's applicable ownership share of Canadian taxes.
For periods through December 31, 2017, when NEP acquired a NEER project, income taxes were calculated on the predecessor method using the separate return method applied to the group of renewable energy projects acquired. As a result of the governance changes discussed in Note 3, beginning in January 1, 2018, acquisitions from NEER are no longer treated as common control acquisitions, and income taxes are calculated on the successor method under which taxes are calculated for NEP as a single taxpaying corporation for U.S. federal and state income taxes (based on its election to be taxed as a corporation).
For the year ended December 31, 2019,2022, NEP recorded income tax benefitexpense of $26$171 million on lossincome before income taxes of $430$1,292 million, resulting in an effective tax rate of approximately 6%. The income tax benefit is primarily comprised of income tax benefit of approximately $90 million at the statutory rate of 21% and $5 million of state income tax benefit, partly offset by income tax expense of $70 million related to income tax attributable to noncontrolling interests. See Note 5.
For the year ended December 31, 2018, NEP recorded income tax expense of $6 million on income before income taxes of $273 million, resulting in an effective tax rate of approximately 2%13%. The income tax expense is primarily comprised of income tax expense of approximately $57$271 million at the statutory rate of 21%, $17 million of federal income tax expense related to an adjustment to differential membership interests as a result of the change in federal corporate income tax rates due to tax reform (see Note 2 - Noncontrolling Interests) and $10$35 million of state income taxes,tax expense, partly offset by income tax benefitsbenefit of $67$135 million related to the disposal of Canadian Holdings and $17 million of income tax attributable to noncontrolling interests. See Note 5.7.
For the year ended December 31, 2021, NEP recorded income tax expense of $48 million on income before income taxes of $472 million, resulting in an effective tax rate of approximately 10%. The income tax expense is primarily comprised of income tax expense of approximately $99 million at the statutory rate of 21% and $12 million of state income tax expense, partly offset by income tax benefit of $59 million related to income tax attributable to noncontrolling interests. See Note 7.
Net Loss (Income) Attributable to Noncontrolling Interests
For 2018 and 2019, net
Net loss (income) attributable to noncontrolling interests primarily reflects the net income or loss attributable to NEE Equity's noncontrolling interest in NEP OpCo, a non-affiliated party's interest in one of the Texas pipelines, anda non-affiliated party's interest in Star Moon Holdings, LLC, the loss allocated to differential membership interest investors. Additionally, for 2019, net income attributable to noncontrolling interests reflectsinvestors, the income allocated to Class B noncontrolling ownership interests and NEER's noncontrolling ownership interestinterests in Silver State.State South Solar, LLC and Sunlight Renewables Holdings, LLC. Net income attributable to noncontrolling interests increased $357 million during the year ended December 31, 2022 primarily reflecting a higher net income allocation to NEE Equity's noncontrolling interest due to an increase in net income as compared to 2021, partly offset by higher losses allocated to differential membership interest investors due to higher wind resource resulting in higher PTCs. See Note 2 -– Noncontrolling Interests and Note 13 – Class B Noncontrolling Interests.
20182021 Compared to 20172020
The comparison of the results of operations for the years ended December 31, 20182021 and 2017 are2020 is included in Management's Discussion in NEP's Annual Report on Form 10-K for the year ended December 31, 2018.2021.
Liquidity and Capital Resources
NEP’s ongoing operations use cash to fund O&M expenses, including related party fees discussed in Note 14, maintenance capital expenditures, debt service payments and related derivative obligations (see Note 12 and Note 5), distributions to common and preferred unitholders, and distributions to the holders of noncontrolling interests.interests and the payment of any cash portion of the purchase price payable in connection with the exercise of a buyout right (see Note 13 and Note 2 – Noncontrolling Interests). 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.investments (see Note 3). These acquisitions and investments are expected to be funded with borrowings under credit facilities or term loans, issuances of indebtedness, issuances of additional NEP common units or preferred units, capital raised pursuant to other financing structures, cash on hand and cash generated from operations. NEP may issue common units to fund NEP's conversion obligation in excess of the aggregate principal amount of the convertible notes being converted and expects to issue common units, or non-voting common units (convertible into common units), to fund the payment of the equity portion of the purchase price payable in connection with the exercise of buyout rights associated with certain noncontrolling interests (see Note 12, Note 13 and Note 2 – Noncontrolling Interests).
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, expandfund additional expansion or repowerrepowering of existing projects, fund the purchase price payable in connection with the exercise of buyout rights and increase its distributions to common unitholders will depend on its ability to access capital 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.indebtedness or equity arrangements. In addition, NEP expects from time to time to consider potential investments in new acquisitions.acquisitions and the expansion or repowering of existing projects. These events may cause NEP to seek additional debt or equity financing, which may not be available on acceptable terms or at all. Additional 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 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 affiliates may withdraw funds in connection with certain long-term debt agreements and hold those funds in accounts belonging to NEER or its affiliates and provide credit support in the amount of such withdrawn funds. If NEER fails to return withdrawn funds when required by NEP's subsidiaries’ financing agreements, the lenders will be entitled to draw on any 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.
Liquidity Position
At December 31, 2019,2022, NEP's liquidity position was approximately $758$3,093 million. The table below provides the components of NEP’s liquidity position:
|
| | | | | |
| December 31, 2019 | | Maturity Date |
| (millions) | | |
Cash and cash equivalents | $ | 128 |
| | |
Amounts due under the CSCS agreement | 12 |
| | |
Revolving credit facilities(a) | 1,250 |
| | 2024(b) |
Less borrowings(b) | (510 | ) | | |
Less issued letters of credit | (122 | ) | | |
Total(c) | $ | 758 |
| |
|
____________________
| | | | | | | | | | | |
(a) | Excludes credit facilities discussed below due to restrictions on the use of the borrowings. See Note 11 - Debt. |
| |
(b) | In February 2020, an additional $50 million was borrowed under the NEP OpCo credit facility and the maturity date was extended until 2025.December 31, 2022 | | Maturity Date |
| (millions) | | |
(c)Cash and cash equivalents(a) | Excludes current restricted cash$ | 235 | | | |
Amounts due under the CSCS agreement | 298 | | | |
Revolving credit facilities(b) | 2,500 | | | 2027(c) |
| | | |
| | | |
| | | |
Less issued letters of approximately $3 million and $8 million at December 31, 2019 and 2018, respectively. See Note 2 - Restricted Cash.credit | (118) | | | |
NEP Renewables IV final funding(d) | 178 | | | |
Total | $ | 3,093 | | |
|
____________________
(a) In January 2023, NEP bought out differential membership investors with ownership interests in two wind projects for approximately $187 million. See Note 2 – Noncontrolling Interests.
(b) Excludes a credit facility due to restrictions on the use of the borrowings. See Note 12.
(c) At December 31, 2022, approximately $50 million had a maturity date in 2025. In February 2023, approximately $50 million was borrowed under the NEP OpCo credit facility and the maturity date for substantially all of the NEP OpCo credit facility was extended until 2028.
(d) See Note 13 – Class B Noncontrolling Interests for a discussion of the final funding related to the sale of Class B noncontrolling interests in NEP Renewables IV.
Management believes that NEP's liquidity position and cash flows from operations will be adequate to finance O&M, maintenance capital expenditures, distributions to its unitholders and to the holders of noncontrolling interests and liquidity commitments. Management continues to regularly monitor NEP's financing needs consistent with prudent balance sheet management.
Financing Arrangements
NEP OpCo and its direct subsidiary are parties to a $1,250$2,500 million revolving credit facility (NEP OpCo credit facility) maturing in February 2025.2028. During 2019, $1,1502022, $951 million was drawn under the NEP OpCo credit facility and $640$1,505 million of the outstanding borrowings under this facility were repaid with proceeds from other financing activities discussed in Note 11.repaid. At December 31, 2019, $510 million was2022, no amounts were outstanding under the NEP OpCo credit facility. For a discussion of the NEP OpCo credit facility, see Note 11 - Debt.12.
During 2019,2022, NEP issued $500 million in aggregate principal amount of 2.5% convertible senior notes due in 2026. See Note 12.
During 2021, NEP issued $500 million in aggregate principal amount of 0% convertible senior notes due in 2024 and an indirect subsidiary of NEP entered into a credit agreement which provides $205borrowed $644 million under a limited-recourse senior secured variable rate term loan and provides up to $270 million under a revolving credit facility (STX Holdings revolving credit facility). Proceeds from any borrowings under the STX Holdings revolving credit facility are available exclusively to fund the cash portion of NEP's repurchase, if any, of the Class B noncontrolling interests related to STX Midstream (seematuring in 2028. See Note 11), subject to certain limitations. At December 31, 2019, $270 million remains available under the STX Holdings revolving credit facility.12.
During 2017,2020, NEP issued $300$600 million in aggregate principal amount of 0% convertible notes and NEP OpCo issued $550 million in aggregate principal amount of 4.25% senior notes due September 2024in 2025 and $550 million in aggregate principal amount of 4.50% senior notes due September 2027. During 2019, NEP OpCo issued $700 million in aggregate principal amount of 4.25% senior notes due July 2024 andutilized proceeds to repay $500 million in aggregate principal amount of 3.875%outstanding 4.25% senior unsecured notes due October 2026.2024 that were issued in September 2017. See Note 11 - Debt.12.
In 2019, indirect subsidiaries of NEP entered into a credit agreement (Meade credit agreement) which provides up to $915 million under three limited-recourse senior secured variable rate term loans to finance a portion of the Meade acquisition and the expansion (see Note 3). At December 31, 2019, approximately $90 million remains available under the Meade credit agreement to fund the expansion. See Note 11 - Debt.
NEP OpCo and certain indirect subsidiaries are subject to financings that contain financial covenants and distribution tests, including debt service coverage ratios. In general, these financings contain covenants customary for these types of financings, including limitations on investments and restricted payments. Certain of NEP's financings provide for interest payable at a fixed interest rate. However, certain of NEP's financings accrue interest at variable rates based on an underlying index plus a margin. Interest rate contracts were entered into for certain of these financings to hedge against interest rate movements with respect to interest payments on the related borrowings. In addition, under the project-level financings, each project will be permitted to pay
distributions out of available cash 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-level financing’s covenants. For the majority of the projectproject-level financings, minimum debt service coverage ratios must be satisfied in order to make a distribution. For one project financing, the project must maintain a leverage ratio and an interest coverage ratio in order to make a distribution. At December 31, 2019,2022, NEP's subsidiaries were in compliance with all financial debt covenants under their financings other than as discussed in Note 15 - PG&E Bankruptcy.financings.
Equity Arrangements
In 2019,Certain NEP converted approximately 9.35 million Series A convertible preferred units into NEP common units on a one-for-one basis. See Note 11 - Equity.
In 2019 and 2018, NEPOpCo subsidiaries have issued and sold noncontrolling Class B interests in certain of itstheir subsidiaries. NEP has buyout rights, subject to certain limitations andand/or extensions, under which NEP has the right to pay a portion of the buyout price with respect to the Class B interests in NEP non-voting common units or NEP common units, as specified in the related limited liability company agreement. The Class B investors receive a specified allocation of the related subsidiaries' distributable cash, which couldwould increase if certain minimum buyout rights are not exercised or are not exercisedprior to specified deadlines. While NEP has the right to exercise the buyout right to purchase the noncontrolling Class B interests during a certain period.specified period of time as set forth in the related limited liability company agreement and may exercise the buyout right by paying cash, NEP may exercise, or begin to exercise if exercisable only in part, the buyout right on or at the beginning of the buyout period, and that the buyout price may consist of the maximum percentage of NEP non-voting common units or NEP common units, as specified in the related limited liability company agreement. See Note 11 - Equity.13 – Class B Noncontrolling Interests. Because of the increase in distributable cash that the Class B investors would receive if NEP does not exercise its buyout rights prior to the specified deadlines, NEP generally plans to exercise its buyout rights prior to such deadlines.
In 2021, NEP paid aggregate consideration of approximately $885 million, consisting of approximately 7.3 million NEP common units and $265 million in cash, for the buyout of the Class B noncontrolling membership interests in NEP Renewables. See Note 13 – Class B Noncontrolling Interests. In 2020, NEP issued approximately 4.67 million NEP common units upon the conversion of the remaining convertible preferred units on a one-for-one basis. See Note 13 – Preferred Units. Also in 2020, NEP issued approximately 5.7 million NEP common units upon the conversion of approximately $300 million principal amount of convertible notes. See Note 12.
NEP establishedhas an at-the-market equity issuance program (ATM program), which was renewed in 20152021, pursuant to which NEP may issue, from time to time, up to $150$300 million of its common units. During 2022 and 2021, NEP issued approximately 1.8 million common units which gives NEPand 0.7 million common units under the flexibility to issue new units when the price is acceptable. In July 2018, NEP implemented a $150 million ATM program which replaced its prior program. Atfor gross proceeds of approximately $145 million and $50 million, respectively. As of December 31, 2019,2022, NEP may issue up to approximately $64$155 million in additional common units under the ATM program. See Note 13 – ATM Program.
In 2022, NEP issued 0.8 million NEP common units upon NEE Equity's exchange of NEP OpCo common units on a one-for-one basis. In January 2023, NEE Equity delivered notice to NEP OpCo of its election to exchange 0.9 million NEP OpCo common units for NEP common units on a one-for-one basis. The exchange of common units, and related issuance of NEP common units, is expected to occur in the second quarter of 2023.
In July 2018,2021, NEP filed a shelf registration statement with the SEC, which became effective upon filing, for an unspecified amount of securities. The amount of securities issuable by NEP is established from time to time by its board of directors.the board. Securities that may be issued under the registration statement include common units, preferred units, warrants, rights, debt securities, equity purchase contracts and equity purchase units.
Contractual Obligations
NEP's contractual obligations at December 31, 2019 were as follows:
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2020 | | 2021 | | 2022 | | 2023 | | 2024 | | Thereafter | | Total |
| (millions) |
Debt, including interest(a) | $ | 476 |
| | $ | 169 |
| | $ | 170 |
| | $ | 372 |
| | $ | 1,908 |
| | $ | 2,045 |
| | $ | 5,140 |
|
Other contractual obligations(b) | 235 |
| | 45 |
| | 25 |
| | 13 |
| | 14 |
| | 139 |
| | 471 |
|
Asset retirement activities(c) | — |
| | — |
| | — |
| | — |
| | — |
| | 566 |
| | 566 |
|
MSA and credit support(d) | 8 |
| | 8 |
| | 8 |
| | 8 |
| | 8 |
| | 182 |
| | 222 |
|
Total | $ | 719 |
| | $ | 222 |
| | $ | 203 |
| | $ | 393 |
| | $ | 1,930 |
| | $ | 2,932 |
| | $ | 6,399 |
|
____________________
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| |
(a) | Includes principal, interest, fees on credit facilities and interest rate swaps. Variable rate interest was computed using December 31, 2019 rates. Such amounts reflect scheduled payments under the financing agreements for debt in default as the lenders have not issued any acceleration notices. See Note 11 - Debt. |
| | | | | | | | | | | |
(b) | Primarily reflects commitments related to construction activities (see Note 15 - Development, Engineering and Construction Commitments), lease payment obligations (see Note 14) and payments related to the acquisition of certain development rights. |
| | | | | | | | | | | |
(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 13. | | | | | | | | | | | | |
| | | | | | | | | | | | | |
Capital Expenditures
Annual capital spending plans are developed based on projected requirements byfor 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 years ended December 31, 20192022 and 2018,2021, NEP had capital expenditures, of approximately $93 million and $23 million, respectively, excluding the purchase prices of acquired projects. Subjectprojects, of approximately $1,351 million and $113 million, respectively, primarily reflecting costs associated with the three facilities acquired from NEER in December 2021 that were under construction, of which costs of $1,161 million and $15 million, respectively, were reimbursed by NEER through December 2022 (see Note 3), and expansion projects at certain pipelines. NEP made investments in CPL related to regulatory approvals,an expansion that was completed in the fourth quarter of 2021. In the first quarter of 2022, the three facilities acquired from NEER in December 2021 were placed in service. NEP expects to have capital expenditures totaling approximately $128 million related to a potential expansion investment at one of the Texas pipelines expected to be in-service during the fourth quarter of 2020 and $90 million of additional investment in CPL related to an expansion scheduled for commercial operation by mid-2022. In addition, NEP expects to have capital expenditures totaling approximately $200 million2023 related to the repowering investments at two wind generationnewly constructed renewable energy facilities, expected toas well as the project that is under construction which was acquired from NEER in December 2022. Such expenditures will be completedreimbursed by NEER as contemplated in 2020. Seethe acquisition (see Note 15 - Development, Engineering and Construction Commitments3). These estimates are subject to continuing review and adjustmentadjustments 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 the board. 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. Although, as described above, NEP currently expects that cash reserves would be established by the board solely to provide for the payment of NEP's income taxes, if any, 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.
NEP OpCo's partnership agreement requires it to distribute all of its available cash to its common and preferred 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, less the amount of cash reserves established by NEP OpCo GP. The majority of such available cash is
expected to be derived from the operations of the projects. The cash available for distribution is likely tocould fluctuate from quarter to quarter, and in some cases significantly, as a result of the performance of the projects, seasonality, fluctuating wind and solar resource, maintenance and outage schedules, timing of debt service and other factors. See Note 15 - PG&E Bankruptcy for a discussion of events of default that continue to limit future cash distributions from certain projects.
During 20192022 and 2018,2021, NEP distributed approximately $115$254 million and $94$198 million, respectively, to its common unitholders. In addition, NEP paid approximately $35$70 million in distributions to its common unitholders and $2 million in distributions to its preferred unitholders in February 2020.2023.
Credit Ratings
NEP’s liquidity, ability to access credit and capital markets and cost of borrowings is dependent on its credit ratings. AtAs of February 18, 2020,22, 2023, Moody’s Investors Service, Inc. (Moody’s), S&P Global Ratings (S&P) and Fitch Ratings, Inc. (Fitch) had assignedcontinue to assign the following credit ratings to NEP:
|
| | | | | | | | | | | | | | | | |
| Moody's(a) | | S&P(a) | | Fitch(a) |
NEP corporate credit rating(b) | Ba1 | | BB | | BB+ |
_________________________
| |
(a) | (a) A security rating is not a recommendation to buy, sell or hold securities and should be evaluated independently of any other rating. The rating is subject to revision or withdrawal at any time by the assigning rating organization. |
| |
(b) | The outlook indicated by each of Moody's, S&P and Fitch is stable. |
(b) The outlook indicated by each of Moody's, S&P and Fitch is stable.
Cash Flows
The following table reflects the changes in cash flows for the comparative periods:
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
| (millions) |
Net cash provided by operating activities | $ | 776 | | | $ | 677 | | | $ | 665 | |
Net cash used in investing activities | $ | (1,194) | | | $ | (2,301) | | | $ | (681) | |
Net cash provided by (used in) financing activities | $ | 551 | | | $ | 1,663 | | | $ | (4) | |
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
Net cash provided by operating activities | $ | 346 |
| | $ | 362 |
| | $ | 413 |
|
Net cash used in investing activities | $ | (2,349 | ) | | $ | (763 | ) | | $ | (1,368 | ) |
Net cash provided by financing activities | $ | 1,969 |
| | $ | 371 |
| | $ | 959 |
|
Net Cash Provided by Operating Activities
The increase in net decrease in cash provided by operating activities in 20192022 compared to 20182021 was primarily driven by higher cash from operations associated with the 2018 sale of Canadian Holdings, the absence of distributions from the equity method investment in Desert Sunlight and higher corporate operating expenses, including higher IDR fees. This decrease was partly offset by cash flows from the investmentsownership interests in projects acquired in December 2018, June 2019the second half of 2021 and November 2019.2022 and the timing of transactions impacting working capital.
Net Cash Used in Investing Activities
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
Acquisitions of membership interests in subsidiaries - net | $ | (2,322 | ) | | $ | (1,283 | ) | | $ | (1,074 | ) |
Capital expenditures | (93 | ) | | (25 | ) | | (349 | ) |
Proceeds from the sale of Canadian Holdings - net | — |
| | 517 |
| | — |
|
Proceeds from CITCs | — |
| | 3 |
| | 77 |
|
Payments from (to) related parties under CSCS agreement - net | 54 |
| | 21 |
| | (22 | ) |
Other | 12 |
| | 4 |
| | — |
|
Net cash used in investing activities | $ | (2,349 | ) | | $ | (763 | ) | | $ | (1,368 | ) |
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
| (millions) |
Acquisitions of membership interests in subsidiaries – net | $ | (989) | | | $ | (2,352) | | | $ | (378) | |
Capital expenditures and other investments | (1,351) | | | (113) | | | (334) | |
Proceeds from CITCs | — | | | 75 | | | — | |
Proceeds from the sale of a business | 204 | | | — | | | — | |
Payments from (to) related parties under CSCS agreement – net | (240) | | | (47) | | | 2 | |
Distributions from equity method investee | 15 | | | 1 | | | 8 | |
Distributions from non-economic ownership interests | — | | | 90 | | | — | |
Reimbursements from related parties for capital expenditures | 1,161 | | | 15 | | | — | |
Other | 6 | | | 30 | | | 21 | |
Net cash used in investing activities | $ | (1,194) | | | $ | (2,301) | | | $ | (681) | |
The increasedecrease in net cash used in investing activities during 20192022 was primarily driven by the 2019lower net cash used for acquisitions described in 2022 compared to 2021 (see Note 3, the absence of the3), higher reimbursement from NEER subsidiaries for capital expenditures and proceeds from the 2018 sale of Canadian Holdingsinterests in a natural gas pipeline (see Note 2 -– Disposal of Canadian Holdings) andPipeline), partly offset by higher capital expenditures in 2022 primarily related to completion of certain construction activities (see Note 15 - Development, EngineeringCapital Expenditures discussed above), higher payments to NEER subsidiaries (net of amounts received) under the CSCS agreement, no distributions from non-economic ownership interests received in 2022 (amounts distributed back to the non-economic ownership interests are reflected in partner distributions within financing activities) and Construction Commitments).no CITC proceeds received in 2022.
Net Cash Provided by (Used in) Financing Activities
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
| (millions) |
Proceeds from issuance of common units – net | $ | 147 | | | $ | 50 | | | $ | 2 | |
| | | | | |
Issuances of long-term debt, including premiums and discounts | 1,505 | | | 2,880 | | | 695 | |
Retirements of long-term debt | (1,544) | | | (1,159) | | | (1,166) | |
Partner contributions | 2 | | | 2 | | | 9 | |
Partner distributions | (636) | | | (619) | | | (442) | |
Proceeds related to differential membership interests – net | 202 | | | 87 | | | 243 | |
Proceeds related to Class B noncontrolling interests – net | 952 | | | 548 | | | 705 | |
Debt issuance costs | (17) | | | (12) | | | (1) | |
Capped call transactions – net | (31) | | | (31) | | | (33) | |
Payment of CITC obligation to third party | — | | | (65) | | | — | |
Other | (29) | | | (18) | | | (16) | |
Net cash provided by (used in) financing activities | $ | 551 | | | $ | 1,663 | | | $ | (4) | |
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
Proceeds from issuance of common units – net | $ | 2 |
| | $ | 86 |
| | $ | — |
|
Proceeds from issuance of preferred units – net | — |
| | — |
| | 548 |
|
Issuances (retirements) of long-term debt – net | 588 |
| | (233 | ) | | 695 |
|
Partners/Members' contributions | 14 |
| | 36 |
| | 316 |
|
Partners/Members' distributions | (362 | ) | | (281 | ) | | (307 | ) |
Proceeds related to differential membership interests - net | 36 |
| | 35 |
| | 8 |
|
Payment of acquisition holdback | — |
| | — |
| | (186 | ) |
Proceeds related to Class B noncontrolling interests - net | 1,765 |
| | 750 |
| | — |
|
Debt issuance costs | (48 | ) | | — |
| | (24 | ) |
Other | (26 | ) | | (22 | ) | | (91 | ) |
Net cash provided by financing activities | $ | 1,969 |
| | $ | 371 |
| | $ | 959 |
|
The increasechange in net cash provided by financing activities in 20192022 compared to 2021 is primarily due to lower issuances of long-term debt and higher retirements of long-term debt in 2022 compared to 2021, partly offset by higher net proceeds related to Class B noncontrolling interests (see Note 2 – Noncontrolling Interests and debt issuances in 2019 comparedNote 13 – Class B Noncontrolling Interests), higher net proceeds related to debt retirements in 2018, partly offset bydifferential membership interests and higher distributions and lower proceeds from the issuance of common units.
The comparison of the cash flows for the years ended December 31, 20182021 and 20172020 are included in Management's Discussion in NEP's Annual Report on Form 10-K for the year ended December 31, 2018.2021.
New Accounting Rules and Interpretations
Reference Rate Reform –In March 2020, the Financial Accounting Standards Board issued an accounting standards update which provides certain options to apply accounting guidance on contract modifications and hedge accounting as companies transition from the London Inter-Bank Offered Rate and other interbank offered rates to alternative reference rates. See Note 2 – Reference Rate Reform.
Critical Accounting Policies and Estimates
NEP's significant accounting policies are described in Note 2 to the consolidated financial statements, which were prepared under generally accepted accounting principles in the U.S. Critical accounting policies are those that NEP believes are both most important to the portrayal of its financial condition and results of operations, and require complex, subjective judgments, often as a result of the need to make estimates and assumptions about the effect of matters that are inherently uncertain. Judgments and uncertainties affecting the application of those policies may result in materially different amounts being reported under different conditions or using different assumptions. The following policies are those considered to be the most critical in understanding the judgments that are involved in preparing the consolidated financial statements.
Income Taxes
Deferred income taxes arise from temporary differences between the tax and financial statement recognition of revenue and expense. In evaluating NEP's ability to recover its deferred tax assets individually by entity and by taxing jurisdiction, NEP considers all available positive and negative evidence, including scheduled reversals of deferred tax liabilities, projected future taxable income, tax planning strategies and recent financial operations. In projecting future taxable income, NEP begins with historical results and incorporates assumptions including the amount of future state, federal and foreign pretax operating income, the reversal of temporary differences and the implementation of feasible and prudent tax planning strategies. These assumptions require significant judgment about the forecasts of future taxable income and are consistent with the plans and estimates NEP is using to manage the underlying businesses.
ASC 740 provides that a tax benefit from an uncertain tax position will be recognized when it is more likely than not that the position will be sustained upon examination, including resolutions of any related appeals or litigation processes, based on the technical merits. ASC 740 also provides guidance on measurement, derecognition, classification, interest and penalties, accounting in interim periods, and disclosure and transition.
NEP recognizes tax liabilities in accordance with ASC 740 and adjusts these liabilities when its judgment changes as a result of the evaluation of new information not previously available. Because of the complexity of some of these uncertainties, the ultimate resolution may result in a payment that is materially different from NEP's current estimate of the tax liabilities. These differences will be reflected as increases or decreases to income tax expense in the period in which they are determined.
Acquisitions from NEER in Periods Prior to January 1, 2018
The projects located in the U.S. (U.S. projects) acquired from NEER presented in these financial statements were historically included in the consolidated federal income tax return of NEE. Income taxes as presented herein attributed current and deferred income taxes to the U.S. projects acquired from NEER in a manner that is systematic, rational and consistent with the asset and liability method prescribed by Accounting Standards Codification Topic (ASC) 740, Accounting for Income Taxes. Accordingly, with regard to periods prior to the NEP acquisition date, income taxes were calculated on the predecessor method using the separate return method applied to the group of renewable energy projects acquired. The separate return method applies ASC 740 as if each
group of renewable energy projects were a separate taxpayer. Accordingly, the sum of the amounts allocated to the U.S. projects’ provisions may not equal the income taxes that would have resulted from a consolidated filing.
The projects located in Canada were not included in the consolidated U.S. tax filing of NEE, as they were excluded from the U.S. federal income tax group. Canadian corporations that filed separate Canadian income tax returns had taxes provided herein on that basis. Canadian entities that were Canadian limited partnerships from which virtually all of the tax attributes flow through to the owner, a Canadian corporation, which was not a predecessor entity, had no taxes provided for the period before acquisition. None of the income nor any tax attributes of the flow through entities flow through to a U.S. taxpayer and were not reflected in any U.S. tax return. No U.S. income taxes were provided with regard to these entities for periods prior to the NEP acquisition date.
See Note 5.7.
Impairment of Long-Lived Assets
NEP evaluates long-lived assets, including finite-lived intangible assets, for impairment when events or changes in circumstances indicate that the carrying amount may not be recoverable.
An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset. The impairment loss to be recognized is the amount by which the carrying value of the long-lived asset exceeds the asset’s fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate.
The amount of future net cash flows, the timing of such cash flows and the determination of an appropriate interest rate all involve estimates and judgments about future events. In particular, the aggregate amount of cash flows determines whether an impairment exists, and the timing of the cash flows is critical in determining fair value for the purposes of determining the impairment loss to be recognized. Because each assessment is based on the facts and circumstances associated with each long-lived asset, the effects of changes in assumptions cannot be generalized. See Note 15 - PG&E Bankruptcy
Carrying Value of Equity Method Investments
NEP evaluates its equity method investments for impairment when events or changes in circumstances indicate that the fair value of the investment is less than the carrying value and the investment may be other-than-temporarily impaired.
Indicators of a discussionpotential impairment include, but are not limited to, a series of operating losses of an investee, the absence of an ability to recover the carrying amount of the investment, the inability of the investee to sustain an earnings capacity and a current fair value of an investment that may be less than its carrying value. If indicators of impairment analysis relatedexist, an estimate of the investment’s fair value will be calculated. Approaches for estimating fair value include, among others, an income approach using a probability-weighted discounted cash flows model and a market approach using an earnings before interest, taxes, depreciation and amortization (EBITDA) multiple model. The probability assigned to each scenario as well as the cash flows and EBITDA multiple identified are critical in determining fair value.
An impairment loss is required to be recognized if the impairment is deemed to be other than temporary. Assessment of whether an investment is other-than-temporarily impaired involves, among other factors, consideration of the length of time that the fair value is below the carrying value, current expected performance relative to the PG&E bankruptcy filing.expected performance when the investment was
initially made, performance relative to peers, industry performance relative to the economy, credit rating, regulatory actions and legal and permitting challenges. If management is unable to reasonably assert that an impairment is temporary or believes that there will not be full recovery of the carrying value of its investment, then the impairment is considered to be other than temporary. Investments that are other-than-temporarily impaired are written down to their estimated fair value and cannot subsequently be written back up for increases in estimated fair value. Impairment losses, if any, would be recorded in equity in earnings (losses) of equity method investees in NEP’s consolidated statements of income.
Business Combinations
Certain assumptions and estimates are employed in determining the fair value of assets acquired evaluating the fair value ofand liabilities assumed as well asand, for business acquisitions, in determining the allocation of goodwill to a reporting unit. These estimates may be affected by factors such as changing market conditions, technological advances in the energy industry or changes in regulations governing that industry. Other key inputs that require judgment include discount rates, comparable market transactions, estimated useful lives and probability of future transactions. The most significant assumptions requiring the most judgment involve identifying and estimating the fair value of intangible assets and property, plant and equipment and the associated useful lives for establishing amortization periods. To finalize purchase accounting for significant transactions, NEP may utilize the services of independent valuation specialists to assist in the determination of the fair value of acquired intangible assets and property, plant and equipment. TheFor business acquisitions, the allocation of the purchase price may be modified up to one year from the date of the acquisition if new information is obtained about the fair value of assets acquired and liabilities assumed. See Note 3.
Goodwill and Other Intangible Assets
Goodwill acquired in connection with business combinations represents the excess of consideration over the fair value of net assets acquired. For goodwill and intangible assets with indefinite lives, an assessment for impairment is performed annually or whenever an event indicating impairment may have occurred. NEP completes the annual impairment test for goodwill and indefinite-lived intangibles using an assessment date of October 1. Goodwill is reviewed for impairment by comparing the carrying value of a reporting unit’s net assets, including allocated goodwill, to the estimated fair value of a reporting unit. NEP estimates the fair value of a reporting unit using a combination of the income, market and cost approaches. Determining the fair value of a reporting unit requires judgment and the use of significant estimates and assumptions. Such estimates and assumptions include revenue growth rates, future operating margins, the weighted average cost of capital, and future market conditions, among others. If a reporting unit’s carrying value is greater than its fair value, a second step is performed whereby the implied fair value of goodwill is estimated by allocating the fair value of a reporting unit in a hypothetical purchase price allocation analysis. A goodwill impairment charge would be recognized for the amount by which the carrying value of goodwill exceeds its reassessed fair value. NEP performed its annual goodwill impairment test in October 20192022 and determined, based on the results, that no goodwill impairment charge was required.
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 and counterparty credit risks.
Interest Rate Risk
NEP is exposed to risk resulting from changes in interest rates associated with outstanding and expected future debt issuances and borrowings. 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 and adjust interest rate exposure when deemed appropriate based upon market conditions or when required by financing agreements.agreements (see Note 5).
NEP has long-term debt instruments that subject it to the risk of loss associated with movements in market interest rates. At December 31, 2019,2022, approximately 12%99% of the long-term debt, including current maturities, was not exposed to fluctuations in interest expense as the remaining balanceit was either fixed rate debt or financially hedged. At December 31, 2019,2022, the estimated fair value of NEP's long-term debt was approximately $4.2$5.1 billion and the carrying value of the long-term debt was $4.1$5.3 billion. See Note 6 -– Financial Instruments Recorded at Other than Fair Value. 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 would increase by approximately $87$36 million at December 31, 2019.2022.
At December 31, 2019,2022, NEP had interest rate contracts with a net notional amount of approximately $6.9$7.8 billion related to managing exposure to the variability of cash flows associated with outstanding and expected future debt issuances and borrowings. Based upon a hypothetical 10% decrease in rates, NEP’s net derivative liabilities at December 31, 20192022 would increase by approximately $300$183 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. See Note 15 - PG&E Bankruptcy for a discussion of risks related to PG&E.
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
See Management's Discussion -– Quantitative and Qualitative Disclosures About Market Risk.
Item. 8 Financial Statements and Supplementary Data
MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
NextEra Energy Partners, LP's (NEP) management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in the Securities Exchange Act of 1934 Rules 13a-15(f) and 15d-15(f). The consolidated financial statements, which in part are based on informed judgments and estimates made by management, have been prepared in conformity with generally accepted accounting principles applied on a consistent basis.
To aid in carrying out this responsibility, we, along with all other members of management, maintain a system of internal accounting control which is established after weighing the cost of such controls against the benefits derived. In the opinion of management, the overall system of internal accounting control provides reasonable assurance that the assets of NEP and its subsidiaries are safeguarded and that transactions are executed in accordance with management's authorization and are properly recorded for the preparation of financial statements. In addition, management believes the overall system of internal accounting control provides reasonable assurance that material errors or irregularities would be prevented or detected on a timely basis by employees in the normal course of their duties. Any system of internal accounting control, no matter how well designed, has inherent limitations, including the possibility that controls can be circumvented or overridden and misstatements due to error or fraud may occur and not be detected. Also, because of changes in conditions, internal control effectiveness may vary over time. Accordingly, even an effective system of internal control will provide only reasonable assurance with respect to financial statement preparation and reporting.
The system of internal accounting control is supported by written policies and guidelines, the selection and training of qualified employees, an organizational structure that provides an appropriate division of responsibility and a program of internal auditing. NEP's written policies include a Code of Business Conduct & Ethics that states management's policy on conflicts of interest and ethical conduct. Compliance with the Code of Business Conduct & Ethics is confirmed annually by key personnel.
The Board of Directors pursues its oversight responsibility for financial reporting and accounting through its Audit Committee. This Committee, which is comprised entirely of independent directors, meets regularly with management, the internal auditors and the independent auditors to make inquiries as to the manner in which the responsibilities of each are being discharged. The independent auditors and the internal audit staff have free access to the Committee without management's presencemanagement present to discuss auditing, internal accounting control and financial reporting matters.
Management assessed the effectiveness of NEP's internal control over financial reporting as of December 31, 2019,2022, using the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in the Internal Control -– Integrated Framework (2013). Based on this assessment, management believes that NEP's internal control over financial reporting was effective as of December 31, 2019.2022.
NEP's independent registered public accounting firm, Deloitte & Touche LLP, is engaged to express an opinion on NEP's consolidated financial statements and an opinion on NEP's internal control over financial reporting. Their reports are based on procedures believed by them to provide a reasonable basis to support such opinions. These reports appear on the following pages.
|
| | | | | | | |
JAMES L. ROBOJOHN W. KETCHUM | | REBECCA J. KUJAWATERRELL KIRK CREWS II |
James L. Robo
John W. Ketchum Chairman of the Board and Chief Executive Officer NextEra Energy Partners, LP
| | Rebecca J. Kujawa
Terrell Kirk Crews II Chief Financial Officer NextEra Energy Partners, LP
|
|
| | | | | | | |
JAMES M. MAY | | |
James M. May Controller and Chief Accounting Officer NextEra Energy Partners, LP | | |
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the unitholders and the Board of Directors of NextEra Energy Partners, LP
Opinion on Internal Control over Financial Reporting
We have audited the internal control over financial reporting of NextEra Energy Partners, LP and subsidiaries (NEP) as of December 31, 2019,2022, based on criteria established in Internal Control —– Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, NEP maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019,2022, based on criteria established in Internal Control —– Integrated Framework (2013) issued by COSO.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 20192022 of NEP and our report dated February 18, 202022, 2023, expressed an unqualified opinion on those financial statements.
Basis for Opinion
NEP’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on NEP's internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to NEP in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and Limitations of Internal Control over Financial Reporting
A company's internal control over financial reporting is a process designed 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. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
DELOITTE & TOUCHE LLP
Boca Raton, Florida
February 18, 202022, 2023
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the unitholders and the Board of Directors of NextEra Energy Partners, LP
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of NextEra Energy Partners, LP and subsidiaries (NEP) as of December 31, 20192022 and 2018,2021, the related consolidated statements of income (loss), comprehensive income (loss), changes in equity and cash flows for each of the three years in the period ended December 31, 2019,2022, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the consolidated financial position of NEP as of December 31, 20192022 and 2018,2021, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019,2022, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), NEP’s internal control over financial reporting as of December 31, 2019,2022, based on criteria established in Internal Control —– Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 18, 202022, 2023 expressed an unqualified opinion on NEP’s internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of NEP’s management. Our responsibility is to express an opinion on NEP's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to NEP in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Noncontrolling Interest, Income Allocation and Asset Valuation -Acquisitions — Refer to Notes 2,Note 3 and 11 to the financial statements
Critical Audit Matter Description
In March 2019,As discussed in Note 3 to the financial statements, in December 2022, an indirect subsidiary of NEP and its affiliates entered into a Membership Interest Purchase Agreement with a third party to financecompleted the acquisition of ownership interests (December 2022 acquisition) in a portfolio of wind and solar assetssolar-plus-storage generation facilities from subsidiaries of NextEra Energy Inc. (NEE).Resources, LLC (NEER), a related party. The third-party investor (Class B Investor) contributed $900 million for 100% of a noncontrolling Class B membership interest in NEP Renewable II, LLC. The joint venture agreement contained cash and income allocations that differ from the ownership percentages which results in accounting that requires the application of hypothetical liquidation of book value (HLBV) accounting. The application of HLBV required significantpurchase price included total consideration of the allocations between NEPapproximately $805 million, plus working capital and the Class B Investor over the lifeother adjustments of approximately $8 million (subject to certain post-closing adjustments) and NEP's share of the agreement,portfolio’s existing noncontrolling interests related to differential membership investors of approximately $1.4 billion at the call option and the liquidation provisionstime of the agreement to determine the appropriate methodology for allocating income between the parties. NEP’s allocation of theclosing. The purchase price amongfor the asset acquisition was allocated to the assets acquired and liabilities assumed, including the noncontrolling interests, based on their estimated fair value. All fair value measurements of assets required management to makeacquired and liabilities assumed were based on significant estimates and assumptions, related to the future cash flows and the discount rate in determining and assigning fair value.including Level 3 (unobservable) inputs, which require judgment.
The accounting and reporting for this transactionthese transactions required an increased extent of audit effort and specialized skill and knowledge with respect to the appropriateness of the accounting model based on the provisions of the agreement.knowledge. Auditing the unobservable inputs used by management to estimate the fair value of the acquired assets involved subjective judgments and an increased extent of effort, including the need to involve our fair valuefirm specialists.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures included the following, among others:
| |
• | We tested the effectiveness of controls over purchase accounting, including NEP’s review of the third-party specialist’s valuation report.
|
We tested the effectiveness of NEP’s controls over thepurchase accounting, and reporting for the transaction and the Class B
Investor’s non-controlling interest (NCI) and income allocation.
We read the joint venture agreement to evaluate the business purposeincluding management’s review of the transaction.third-party specialist’s valuation report.
We used our firm specialist resources to assist in auditing management’s conclusions through an accounting consultation. The accounting consultation included evaluation of the terms of the agreement to determine the appropriateness of the accounting conclusions reached regarding the application of HLBV accounting.
We tested the initial recording of the NCI balance related to the Class B Investor and the income allocation to the Class B Investor for the period.
•We evaluated the competency of the third partythird-party specialist engaged by NEPmanagement to perform the valuation.valuations. We read and tested the third partythird-party valuation report.
•We assessed the reasonableness of management’s forecasts of future cash flows by comparing the projections to historical results and similar companiesgeneration facilities acquired in previous years.
•We evaluated whether the estimated future cash flows were consistent with evidence obtainedused personnel in other areas of the audit.our firm who specialize in energy transacting to assist in testing certain inputs in management's fair value models.
•With the assistance of our fair value specialists, we (1) evaluated the reasonableness of the (1) valuation methodology, and (2) evaluated the reasonableness of the discount rate,rates, including testing the source information underlying the determination of the discount rate, testingrates, assessing the mathematical accuracy of the calculation, and developing a range of independent estimates and comparing those to the discount raterates selected by management.management, and (3) assessed the mathematical accuracy of significant calculations in the valuation schedules.
•We evaluated NEP’s disclosures related to the acquisition, including balances recorded and significant assumptions.
DELOITTE & TOUCHE LLP
Boca Raton, Florida
February 18, 202022, 2023
We have served as NEP's auditor since 2014.
NEXTERA ENERGY PARTNERS, LP
CONSOLIDATED STATEMENTS OF INCOME (LOSS)
(millions, except per unit amounts)
| | | Years Ended December 31, | | Years Ended December 31, |
| 2019 | | 2018 | | 2017 | | 2022 | | 2021 | | 2020 |
OPERATING REVENUES | | | | | | OPERATING REVENUES | | | | | |
Renewable energy sales | $ | 645 |
| | $ | 551 |
| | $ | 613 |
| Renewable energy sales | $ | 966 | | | $ | 720 | | | $ | 703 | |
Texas pipelines service revenue | 210 |
| | 220 |
| | 194 |
| |
Texas pipelines service revenues | | Texas pipelines service revenues | 245 | | | 262 | | | 214 | |
Total operating revenues(a) | 855 |
| | 771 |
| | 807 |
| Total operating revenues(a) | 1,211 | | | 982 | | | 917 | |
OPERATING EXPENSES | | | | | | OPERATING EXPENSES | | | | | |
Operations and maintenance(b) | 336 |
| | 257 |
| | 248 |
| Operations and maintenance(b) | 571 | | | 419 | | | 363 | |
Depreciation and amortization | 259 |
| | 203 |
| | 226 |
| Depreciation and amortization | 430 | | | 288 | | | 271 | |
Taxes other than income taxes and other | 27 |
| | 21 |
| | 21 |
| Taxes other than income taxes and other | 49 | | | 36 | | | 28 | |
Gain on disposal of Canadian Holdings | — |
| | (153 | ) | | — |
| |
Total operating expenses | 622 |
| | 328 |
| | 495 |
| |
Total operating expenses – net | | Total operating expenses – net | 1,050 | | | 743 | | | 662 | |
GAINS (LOSSES) ON DISPOSAL OF BUSINESSES/ASSETS – NET | | GAINS (LOSSES) ON DISPOSAL OF BUSINESSES/ASSETS – NET | 36 | | | (5) | | | (2) | |
OPERATING INCOME | 233 |
| | 443 |
| | 312 |
| OPERATING INCOME | 197 | | | 234 | | | 253 | |
OTHER INCOME (DEDUCTIONS) | | | | | | OTHER INCOME (DEDUCTIONS) | | | | | |
Interest expense | (702 | ) | | (248 | ) | | (199 | ) | Interest expense | 853 | | | 47 | | | (620) | |
Benefits associated with differential membership interests - net | — |
| | — |
| | 119 |
| |
Equity in earnings of equity method investees | 38 |
| | 41 |
| | 40 |
| Equity in earnings of equity method investees | 183 | | | 160 | | | 108 | |
Equity in earnings (losses) of non-economic ownership interests | (4 | ) | | 15 |
| | 11 |
| Equity in earnings (losses) of non-economic ownership interests | 56 | | | 27 | | | (3) | |
Other - net | 5 |
| | 22 |
| | (2 | ) | |
Total other deductions - net | (663 | ) | | (170 | ) | | (31 | ) | |
Other – net | | Other – net | 3 | | | 4 | | | 5 | |
Total other income (deductions) – net | | Total other income (deductions) – net | 1,095 | | | 238 | | | (510) | |
INCOME (LOSS) BEFORE INCOME TAXES | (430 | ) | | 273 |
| | 281 |
| INCOME (LOSS) BEFORE INCOME TAXES | 1,292 | | | 472 | | | (257) | |
INCOME TAX EXPENSE (BENEFIT) | (26 | ) | | 6 |
| | 167 |
| INCOME TAX EXPENSE (BENEFIT) | 171 | | | 48 | | | (19) | |
NET INCOME (LOSS) | (404 | ) | | 267 |
| | 114 |
| NET INCOME (LOSS) | 1,121 | | | 424 | | | (238) | |
Net income attributable to preferred distributions | (17 | ) | | (25 | ) | | (3 | ) | |
Net loss (income) attributable to noncontrolling interests(c) | 333 |
| | (75 | ) | | (175 | ) | |
NET INCOME ATTRIBUTABLE TO PREFERRED DISTRIBUTIONS | | NET INCOME ATTRIBUTABLE TO PREFERRED DISTRIBUTIONS | — | | | — | | | (5) | |
NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS | | NET LOSS (INCOME) ATTRIBUTABLE TO NONCONTROLLING INTERESTS | (644) | | | (287) | | | 188 | |
NET INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP | $ | (88 | ) | | $ | 167 |
| | $ | (64 | ) | NET INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP | $ | 477 | | | $ | 137 | | | $ | (55) | |
| | | | | | | | | | | |
Earnings (loss) per common unit attributable to NextEra Energy Partners, LP - basic | $ | (1.51 | ) | | $ | 3.05 |
| | $ | (1.18 | ) | |
Earnings (loss) per common unit attributable to NextEra Energy Partners, LP - assuming dilution | $ | (1.51 | ) | | $ | 2.91 |
| | $ | (1.18 | ) | |
Earnings (loss) per common unit attributable to NextEra Energy Partners, LP – basic | | Earnings (loss) per common unit attributable to NextEra Energy Partners, LP – basic | $ | 5.62 | | | $ | 1.77 | | | $ | (0.81) | |
Earnings (loss) per common unit attributable to NextEra Energy Partners, LP – assuming dilution | | Earnings (loss) per common unit attributable to NextEra Energy Partners, LP – assuming dilution | $ | 5.62 | | | $ | 1.77 | | | $ | (0.81) | |
____________________
| |
(a) | Includes related party revenues of approximately $8 million, $4 million and $9 million for 2019, 2018 and 2017,(a) Includes related party revenues of approximately $25 million, $42 million and $16 million for 2022, 2021 and 2020, respectively. |
| |
(b) | Includes operations and maintenance (O&M) expenses related to renewable energy projects of approximately $182 million, $128 million and $132 million and O&M expenses related to the Texas pipelines of $47 million, $45 million and $44 million for 2019, 2018 and 2017, respectively. Total O&M expenses presented includes related party amounts of approximately $116 million, $97 million and $88 million for 2019, 2018 and 2017, respectively. |
| |
(c) | For 2017, net income attributable to noncontrolling interests includes the pre-acquisition net income of the common control acquisitions. See Note 2 - Basis of Presentation. |
(b) Includes operations and maintenance (O&M) expenses related to renewable energy projects of approximately $342 million, $207 million and $201 million and O&M expenses related to the Texas pipelines of $45 million, $47 million and $40 million for 2022, 2021 and 2020, respectively. Total O&M expenses presented includes related party amounts of approximately $263 million, $214 million and $146 million for 2022, 2021 and 2020, respectively.
The accompanying Notes to Consolidated Financial Statements are an integral part of these consolidated financial statements.
NEXTERA ENERGY PARTNERS, LP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(millions)
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
NET INCOME (LOSS) | $ | 1,121 | | | $ | 424 | | | $ | (238) | |
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX | | | | | |
| | | | | |
| | | | | |
Other comprehensive income related to equity method investee (net of $0 tax expense, $0 tax benefit and $0 tax benefit, respectively) | 2 | | | 2 | | | 2 | |
Total other comprehensive income (loss), net of tax | 2 | | | 2 | | | 2 | |
| | | | | |
COMPREHENSIVE INCOME (LOSS) | 1,123 | | | 426 | | | (236) | |
Comprehensive income attributable to preferred distributions | — | | | — | | | (5) | |
Comprehensive loss (income) attributable to noncontrolling interests | (645) | | | (290) | | | 186 | |
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP | $ | 478 | | | $ | 136 | | | $ | (55) | |
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
NET INCOME (LOSS) | $ | (404 | ) | | $ | 267 |
| | $ | 114 |
|
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX | | | | | |
Reclassification from accumulated other comprehensive income (loss) to net income (net of $0 tax benefit, $1 tax expense and $2 tax expense, respectively) | (6 | ) | | 2 |
| | 5 |
|
Net unrealized gains (losses) on foreign currency translation (net of $0, $1 tax benefit and $1 tax expense, respectively) | — |
| | (6 | ) | | 7 |
|
Other comprehensive income related to equity method investee (net of $0 tax expense, $2 tax benefit and $1 tax benefit, respectively) | 2 |
| | 6 |
| | 5 |
|
Total other comprehensive income (loss), net of tax | (4 | ) | | 2 |
| | 17 |
|
Impact of disposal of Canadian Holdings (net of $0, $3 tax expense, and $0, respectively) | — |
| | 107 |
| | — |
|
COMPREHENSIVE INCOME (LOSS) | (408 | ) | | 376 |
| | 131 |
|
Comprehensive income attributable to preferred distributions | (17 | ) | | (25 | ) | | (3 | ) |
Comprehensive loss (income) attributable to noncontrolling interests(a) | 335 |
| | (192 | ) | | (188 | ) |
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO NEXTERA ENERGY PARTNERS, LP | $ | (90 | ) | | $ | 159 |
| | $ | (60 | ) |
____________________
| |
(a) | For 2017, comprehensive income attributable to noncontrolling interests includes the pre-acquisition comprehensive in
come of the common control acquisitions. See Note 2 - Basis of Presentation.
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these consolidated financial statements.
NEXTERA ENERGY PARTNERS, LP
CONSOLIDATED BALANCE SHEETS
(millions)
| | | | | | | | | | | |
| December 31, |
| 2022 | | 2021 |
ASSETS | | | |
Current assets: | | | |
Cash and cash equivalents | $ | 235 | | | $ | 147 | |
Accounts receivable | 137 | | 112 |
Other receivables | 41 | | 24 |
Due from related parties | 1,131 | | 1,061 |
Inventory | 51 | | 41 |
Derivatives | 65 | | — |
Other | 202 | | 25 |
Total current assets | 1,862 | | | 1,410 | |
Other assets: | | | |
Property, plant and equipment – net | 14,949 | | | 11,417 | |
Intangible assets – PPAs – net | 2,010 | | | 2,175 | |
Intangible assets – customer relationships – net | 526 | | | 593 | |
Derivatives | 369 | | | 7 | |
Goodwill | 891 | | | 891 | |
Investments in equity method investees | 1,917 | | | 1,896 | |
Deferred income taxes | 195 | | | 322 | |
Other | 333 | | | 265 | |
Total other assets | 21,190 | | | 17,566 | |
TOTAL ASSETS | $ | 23,052 | | | $ | 18,976 | |
LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY | | | |
Current liabilities: | | | |
Accounts payable and accrued expenses | $ | 868 | | | $ | 982 | |
Due to related parties | 92 | | | 104 | |
Current portion of long-term debt | 38 | | | 33 | |
Accrued interest | 28 | | | 26 | |
Derivatives | 12 | | | 26 | |
Accrued property taxes | 31 | | | 25 | |
Other | 257 | | | 65 | |
Total current liabilities | 1,326 | | | 1,261 | |
Other liabilities and deferred credits: | | | |
Long-term debt | 5,250 | | | 5,294 | |
Asset retirement obligations | 299 | | | 243 | |
Derivatives | 2 | | | 595 | |
Due to related parties | 54 | | | 41 | |
Intangible liabilities – PPAs – net | 1,153 | | | 179 | |
Other | 196 | | | 204 | |
Total other liabilities and deferred credits | 6,954 | | | 6,556 | |
TOTAL LIABILITIES | 8,280 | | | 7,817 |
COMMITMENTS AND CONTINGENCIES | | | |
REDEEMABLE NONCONTROLLING INTERESTS | 101 | | | 321 | |
EQUITY | | | |
| | | |
Common units (86.5 and 83.9 units issued and outstanding, respectively) | 3,332 | | | 2,985 | |
Accumulated other comprehensive loss | (7) | | | (8) | |
Noncontrolling interests | 11,346 | | | 7,861 | |
TOTAL EQUITY | 14,671 | | | 10,838 | |
TOTAL LIABILITIES, REDEEMABLE NONCONTROLLING INTERESTS AND EQUITY | $ | 23,052 | | | $ | 18,976 | |
|
| | | | | | | |
| December 31, |
| 2019 | | 2018 |
ASSETS | | | |
Current assets: | | | |
Cash and cash equivalents | $ | 128 |
| | $ | 147 |
|
Accounts receivable | 79 |
| | 63 |
|
Other receivables | 173 |
| | 17 |
|
Due from related parties | 17 |
| | 68 |
|
Other current assets | 36 |
| | 45 |
|
Total current assets | 433 |
| | 340 |
|
Non-current assets: | | | |
Property, plant and equipment - net | 6,970 |
| | 6,770 |
|
Intangible assets - PPAs - net | 1,655 |
| | 617 |
|
Intangible assets - customer relationships - net | 627 |
| | 644 |
|
Goodwill | 609 |
| | 584 |
|
Investments in equity method investees | 1,653 |
| | 214 |
|
Deferred income taxes | 172 |
| | 108 |
|
Other non-current assets | 137 |
| | 128 |
|
Total non-current assets | 11,823 |
| | 9,065 |
|
TOTAL ASSETS | $ | 12,256 |
| | $ | 9,405 |
|
LIABILITIES AND EQUITY | | | |
Current liabilities: | | | |
Accounts payable and accrued expenses | $ | 122 |
| | $ | 10 |
|
Due to related parties | 58 |
| | 45 |
|
Current portion of long-term debt | 12 |
| | 707 |
|
Accrued interest | 40 |
| | 31 |
|
Accrued property taxes | 21 |
| | 19 |
|
Other current liabilities | 48 |
| | 47 |
|
Total current liabilities | 301 |
| | 859 |
|
Non-current liabilities: | | | |
Long-term debt | 4,132 |
| | 2,728 |
|
Asset retirement obligation | 139 |
| | 95 |
|
Derivatives | 417 |
| | 104 |
|
Non-current due to related party | 34 |
| | 34 |
|
Other non-current liabilities | 167 |
| | 47 |
|
Total non-current liabilities | 4,889 |
| | 3,008 |
|
TOTAL LIABILITIES | 5,190 |
| | 3,867 |
|
COMMITMENTS AND CONTINGENCIES |
| |
|
EQUITY | | | |
Preferred units (4.7 and 14.0 units issued and outstanding, respectively) | 183 |
| | 548 |
|
Common units (65.5 and 56.1 units issued and outstanding, respectively) | 2,008 |
| | 1,804 |
|
Accumulated other comprehensive loss | (8 | ) | | (6 | ) |
Noncontrolling interests | 4,883 |
| | 3,192 |
|
TOTAL EQUITY | 7,066 |
| | 5,538 |
|
TOTAL LIABILITIES AND EQUITY | $ | 12,256 |
| | $ | 9,405 |
|
The accompanying Notes to Consolidated Financial Statements are an integral part of these consolidated financial statements.
NEXTERA ENERGY PARTNERS, LP
CONSOLIDATED STATEMENTS OF CASH FLOWS
(millions)
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
CASH FLOWS FROM OPERATING ACTIVITIES | | | | | |
Net income (loss) | $ | (404 | ) | | $ | 267 |
| | $ | 114 |
|
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
|
| |
|
| | |
Depreciation and amortization | 259 |
| | 203 |
| | 226 |
|
Intangible amortization - PPAs | 72 |
| | — |
| | — |
|
Change in value of derivative contracts | 323 |
| | 60 |
| | 11 |
|
Deferred income taxes | (26 | ) | | 23 |
| | 162 |
|
Benefits associated with differential membership interests - net | — |
| | — |
| | (119 | ) |
Equity in earnings of equity method investees, net of distributions received | (23 | ) | | 8 |
| | 7 |
|
Equity in losses (earnings) of non-economic ownership interests | 4 |
| | (15 | ) | | (11 | ) |
Gain on disposal of Canadian Holdings | — |
| | (153 | ) | | — |
|
Costs related to retirement of debt - net | 153 |
| | — |
| | — |
|
Other - net | 12 |
| | (4 | ) | | 11 |
|
Changes in operating assets and liabilities: | | | | | |
Other current assets | (17 | ) | | (10 | ) | | (6 | ) |
Other non-current assets | (1 | ) | | 5 |
| | (3 | ) |
Other current liabilities | (6 | ) | | (26 | ) | | 35 |
|
Other non-current liabilities | — |
| | 4 |
| | (14 | ) |
Net cash provided by operating activities | 346 |
| | 362 |
| | 413 |
|
CASH FLOWS FROM INVESTING ACTIVITIES | | | | | |
Acquisitions of membership interests in subsidiaries - net | (2,322 | ) | | (1,283 | ) | | (1,074 | ) |
Capital expenditures | (93 | ) | | (25 | ) | | (349 | ) |
Proceeds from the sale of Canadian Holdings - net | — |
| | 517 |
| | — |
|
Proceeds from CITCs | — |
| | 3 |
| | 77 |
|
Payments from (to) related parties under CSCS agreement - net | 54 |
| | 21 |
| | (22 | ) |
Other | 12 |
| | 4 |
| | — |
|
Net cash used in investing activities | (2,349 | ) | | (763 | ) | | (1,368 | ) |
CASH FLOWS FROM FINANCING ACTIVITIES | | | | | |
Proceeds from issuance of common units - net | 2 |
| | 86 |
| | — |
|
Proceeds from issuance of preferred units - net | — |
| | — |
| | 548 |
|
Issuances of long-term debt | 3,380 |
| | 750 |
| | 1,880 |
|
Retirements of long-term debt | (2,792 | ) | | (983 | ) | | (1,185 | ) |
Debt issuance costs | (48 | ) | | — |
| | (24 | ) |
Capped call transaction including fees | — |
| | — |
| | (13 | ) |
Partners/Members' contributions | 14 |
| | 36 |
| | 316 |
|
Partners/Members' distributions | (362 | ) | | (281 | ) | | (307 | ) |
Preferred unit distributions | (21 | ) | | (22 | ) | | — |
|
Proceeds on sale of Class B noncontrolling interests - net | 1,788 |
| | 750 |
| | — |
|
Payments to Class B noncontrolling interests investors | (23 | ) | | — |
| | — |
|
Proceeds from differential membership investors | 66 |
| | 56 |
| | 33 |
|
Payments to differential membership investors | (30 | ) | | (21 | ) | | (25 | ) |
Other, primarily change in amounts due to related parties | (5 | ) | | — |
| | (78 | ) |
Payment of acquisition holdback | — |
| | — |
| | (186 | ) |
Net cash provided by financing activities | 1,969 |
| | 371 |
| | 959 |
|
Effect of exchange rate changes on cash | — |
| | (2 | ) | | 3 |
|
NET INCREASE (DECREASE) IN CASH, CASH EQUIVALENTS, AND RESTRICTED CASH | (34 | ) | | (32 | ) | | 7 |
|
CASH, CASH EQUIVALENTS AND RESTRICTED CASH - BEGINNING OF YEAR | 166 |
| | 198 |
| | 191 |
|
CASH, CASH EQUIVALENTS AND RESTRICTED CASH - END OF YEAR | $ | 132 |
| | $ | 166 |
| | $ | 198 |
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: |
|
| |
|
| | |
Cash paid for interest, net of amounts capitalized | $ | 162 |
| | $ | 171 |
| | $ | 163 |
|
Cash paid for income taxes | $ | 1 |
| | $ | 5 |
| | $ | — |
|
Members’ noncash contributions for construction costs and other | $ | 11 |
| | $ | — |
| | $ | 13 |
|
Change in noncash investments in equity method investees - net | $ | 12 |
| | $ | 2 |
| | $ | 7 |
|
Partners/Members' noncash distributions | $ | 3 |
| | $ | 17 |
| | $ | — |
|
Asset retirement obligation additions | $ | — |
| | $ | — |
| | $ | 3 |
|
Accrued but not paid for capital and other expenditures | $ | 10 |
| | $ | 1 |
| | $ | 2 |
|
Noncash member contribution upon transition from predecessor method | $ | — |
| | $ | — |
| | $ | 3 |
|
Accrued preferred distributions | $ | 2 |
| | $ | 6 |
| | $ | 3 |
|
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
CASH FLOWS FROM OPERATING ACTIVITIES | | | | | |
Net income (loss) | $ | 1,121 | | | $ | 424 | | | $ | (238) | |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | | | | |
Depreciation and amortization | 430 | | | 288 | | | 271 | |
Intangible amortization – PPAs | 143 | | | 117 | | | 103 | |
Change in value of derivative contracts | (1,034) | | | (189) | | | 384 | |
Deferred income taxes | 171 | | | 46 | | | (26) | |
Equity in earnings of equity method investees, net of distributions received | 3 | | | 21 | | | 85 | |
Equity in losses (earnings) of non-economic ownership interests, net of distributions received | (50) | | | (21) | | | 3 | |
Losses (gains) on disposal of businesses/assets – net | (36) | | | 5 | | | 2 | |
Costs related to retirement of debt – net | — | | | — | | | 67 | |
Other – net | 10 | | | 11 | | | 13 | |
Changes in operating assets and liabilities: | | | | | |
Current assets | (43) | | | (6) | | | 6 | |
Noncurrent assets | (2) | | | (7) | | | (4) | |
Current liabilities | 63 | | | (10) | | | (1) | |
Noncurrent liabilities | — | | | (2) | | | — | |
Net cash provided by operating activities | 776 | | | 677 | | | 665 | |
CASH FLOWS FROM INVESTING ACTIVITIES | | | | | |
Acquisitions of membership interests in subsidiaries – net | (989) | | | (2,352) | | | (378) | |
Capital expenditures and other investments | (1,351) | | | (113) | | | (334) | |
Proceeds from CITCs | — | | | 75 | | | — | |
Proceeds from the sale of a business | 204 | | | — | | | — | |
Payments from (to) related parties under CSCS agreement – net | (240) | | | (47) | | | 2 | |
Distributions from equity method investee | 15 | | | 1 | | | 8 | |
Distributions from non-economic ownership interests | — | | | 90 | | | — | |
Reimbursements from related parties for capital expenditures | 1,161 | | | 15 | | | — | |
Other | 6 | | | 30 | | | 21 | |
Net cash used in investing activities | (1,194) | | | (2,301) | | | (681) | |
CASH FLOWS FROM FINANCING ACTIVITIES | | | | | |
Proceeds from issuance of common units – net | 147 | | | 50 | | | 2 | |
| | | | | |
Issuances of long-term debt, including premiums and discounts | 1,505 | | | 2,880 | | | 695 | |
Retirements of long-term debt | (1,544) | | | (1,159) | | | (1,166) | |
Debt issuance costs | (17) | | | (12) | | | (1) | |
Capped call settlement | — | | | — | | | 30 | |
Capped call transaction | (31) | | | (31) | | | (63) | |
Partner contributions | 2 | | | 2 | | | 9 | |
Partner distributions | (636) | | | (619) | | | (442) | |
Preferred unit distributions | — | | | — | | | (7) | |
Proceeds on sale of Class B noncontrolling interests – net | 1,115 | | | 893 | | | 750 | |
Payments to Class B noncontrolling interest investors | (163) | | | (80) | | | (45) | |
Buyout of Class B noncontrolling interest investors | — | | | (265) | | | — | |
Proceeds on sale of differential membership interests | 101 | | | 48 | | | 179 | |
Proceeds from differential membership investors | 137 | | | 74 | | | 94 | |
Payments to differential membership investors | (36) | | | (35) | | | (30) | |
| | | | | |
| | | | | |
Change in amounts due to related parties | (18) | | | (13) | | | (3) | |
Payment of CITC obligation to third party | — | | | (65) | | | — | |
| | | | | |
Other | (11) | | | (5) | | | (6) | |
Net cash provided by (used in) financing activities | 551 | | | 1,663 | | | (4) | |
| | | | | |
NET INCREASE (DECREASE) IN CASH, CASH EQUIVALENTS, AND RESTRICTED CASH | 133 | | | 39 | | | (20) | |
CASH, CASH EQUIVALENTS AND RESTRICTED CASH – BEGINNING OF YEAR | 151 | | | 112 | | | 132 | |
CASH, CASH EQUIVALENTS AND RESTRICTED CASH – END OF YEAR | $ | 284 | | | $ | 151 | | | $ | 112 | |
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | | | | |
Cash paid for interest, net of amounts capitalized | $ | 154 | | | $ | 126 | | | $ | 163 | |
Cash paid for income taxes | $ | — | | | $ | 2 | | | $ | 6 | |
| | | | | |
Change in noncash investments in equity method investees – net | $ | (1) | | | $ | 127 | | | $ | 12 | |
| | | | | |
Accrued property additions | $ | 846 | | | $ | 971 | | | $ | 32 | |
Conversion of 2017 convertible notes to common units | $ | — | | | $ | — | | | $ | 300 | |
| | | | | |
The accompanying Notes to Consolidated Financial Statements are an integral part of these consolidated financial statements.
NEXTERA ENERGY PARTNERS, LP
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(millions)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Preferred Units | | Common Units | | | | | | | | |
| Units | | Amount | | Units | | Amount | | Accumulated Other Comprehensive Income (Loss) | | Non-controlling Interests | | Total Equity | | Redeemable Non-controlling Interests |
Balances, December 31, 2019 | 4.7 | | | $ | 183 | | | 65.5 | | | $ | 2,008 | | | $ | (8) | | | $ | 4,883 | | | $ | 7,066 | | | $ | — | |
| | | | | | | | | | | | | | | |
Issuance of common units – net(a) | (4.7) | | | (183) | | | 10.4 | | | 543 | | | — | | | — | | | 360 | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Capped call settlement, including deferred taxes | — | | | — | | | — | | | 33 | | | — | | | — | | | 33 | | | — | |
Capped call transaction | — | | | — | | | — | | | (63) | | | — | | | — | | | (63) | | | — | |
Related party note receivable | — | | | — | | | — | | | — | | | — | | | 2 | | | 2 | | | — | |
Net income (loss) | — | | | 5 | | | — | | | (55) | | | — | | | (188) | | | (238) | | | — | |
Other comprehensive income | — | | | — | | | — | | | — | | | — | | | 2 | | | 2 | | | — | |
| | | | | | | | | | | | | | | |
Related party contributions | — | | | — | | | — | | | — | | | — | | | 7 | | | 7 | | | — | |
Related party distributions | — | | | — | | | — | | | — | | | — | | | (290) | | | (290) | | | — | |
Changes in non-economic ownership interests | — | | | — | | | — | | | — | | | — | | | (12) | | | (12) | | | — | |
Sale of differential membership interest | — | | | — | | | — | | | (3) | | | — | | | 179 | | | 176 | | | — | |
Other differential membership investment activity | — | | | — | | | — | | | — | | | — | | | 64 | | | 64 | | | — | |
Sale of Class B noncontrolling interest – net | — | | | — | | | — | | | (4) | | | — | | | 750 | | | 746 | | | — | |
Payments to Class B noncontrolling interest investors | — | | | — | | | — | | | — | | | — | | | (45) | | | (45) | | | — | |
Distributions to unitholders(b) | — | | | (5) | | | — | | | (154) | | | — | | | — | | | (159) | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Conversion option of 2020 convertible notes, including deferred taxes | — | | | — | | | — | | | 57 | | | — | | | — | | | 57 | | | — | |
Other – net | — | | | — | | | — | | | — | | | — | | | 1 | | | 1 | | | — | |
Balances, December 31, 2020 | — | | | — | | | 75.9 | | | 2,362 | | | (8) | | | 5,353 | | | 7,707 | | | — | |
| | | | | | | | | | | | | | | |
Issuance of common units – net | — | | | — | | | 0.7 | | | 56 | | | — | | | — | | | 56 | | | — | |
Acquisition of subsidiary with noncontrolling ownership interests | — | | | — | | | — | | | — | | | — | | | 2,494 | | | 2,494 | | | 321 | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Capped call transaction | — | | | — | | | — | | | (31) | | | — | | | — | | | (31) | | | — | |
Related party note receivable | — | | | — | | | — | | | — | | | — | | | 2 | | | 2 | | | — | |
Net income | — | | | — | | | — | | | 137 | | | — | | | 287 | | | 424 | | | — | |
Other comprehensive income | — | | | — | | | — | | | — | | | — | | | 2 | | | 2 | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Related party distributions | — | | | — | | | — | | | — | | | — | | | (424) | | | (424) | | | — | |
Changes in non-economic ownership interests | — | | | — | | | — | | | — | | | — | | | 127 | | | 127 | | | — | |
Sale of differential membership interest | — | | | — | | | — | | | — | | | — | | | 48 | | | 48 | | | — | |
Other differential membership investment activity | — | | | — | | | — | | | — | | | — | | | 39 | | | 39 | | | — | |
Sale of Class B noncontrolling interests – net | — | | | — | | | — | | | (3) | | | — | | | 893 | | | 890 | | | — | |
Payments to Class B noncontrolling interest investors | — | | | — | | | — | | | — | | | — | | | (80) | | | (80) | | | — | |
Distributions to unitholders(b) | — | | | — | | | — | | | (198) | | | — | | | — | | | (198) | | | — | |
| | | | | | | | | | | | | | | |
Adoption of accounting standards update | — | | | — | | | — | | | (57) | | | — | | | 1 | | | (56) | | | — | |
| | | | | | | | | | | | | | | |
Exercise of Class B noncontrolling interest buyout right(c) | — | | | — | | | 7.3 | | | 719 | | | — | | | (879) | | | (160) | | | — | |
Other – net | — | | | — | | | — | | | — | | | — | | | (2) | | | (2) | | | — | |
Balances, December 31, 2021 | — | | | — | | | 83.9 | | | 2,985 | | | (8) | | | 7,861 | | | 10,838 | | | 321 | |
| | | | | | | | | | | | | | | |
Issuance of common units – net(a) | — | | | — | | | 2.6 | | | 179 | | | — | | | — | | | 179 | | | — | |
| | | | | | | | | | | | | | | |
Acquisition of subsidiaries with differential membership interests and noncontrolling ownership interests | — | | | — | | | — | | | — | | | — | | | 2,012 | | | 2,012 | | | — | |
| | | | | | | | | | | | | | | |
Capped call transaction | — | | | — | | | — | | | (31) | | | — | | | — | | | (31) | | | — | |
Related party note receivable | — | | | — | | | — | | | — | | | — | | | 2 | | | 2 | | | — | |
Net income | — | | | — | | | — | | | 477 | | | — | | | 635 | | | 1,112 | | | 9 | |
Other comprehensive income | — | | | — | | | — | | | — | | | 1 | | | 1 | | | 2 | | | — | |
| | | | | | | | | | | | | | | |
Related party distributions | — | | | — | | | — | | | — | | | — | | | (382) | | | (382) | | | — | |
Changes in non-economic ownership interests | — | | | — | | | — | | | — | | | — | | | 1 | | | 1 | | | — | |
Sale of differential membership interest | — | | | — | | | — | | | — | | | — | | | — | | | — | | | 101 | |
Other differential membership investment activity | — | | | — | | | — | | | (21) | | | — | | | 264 | | | 243 | | | (330) | |
Sale of Class B noncontrolling interests – net | — | | | — | | | — | | | (3) | | | — | | | 1,115 | | | 1,112 | | | — | |
Payments to Class B noncontrolling interest investors | — | | | — | | | — | | | — | | | — | | | (163) | | | (163) | | | — | |
Distributions to unitholders(b) | — | | | — | | | — | | | (254) | | | — | | | — | | | (254) | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Balances, December 31, 2022 | — | | | $ | — | | | 86.5 | | | $ | 3,332 | | | $ | (7) | | | $ | 11,346 | | | $ | 14,671 | | | $ | 101 | |
____________________________ |
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Preferred Units | | Common Units | | | | | | |
| Units | | Amount | | Units | | Amount | | Accumulated Other Comprehensive Income (Loss) | | Non-controlling Interests | | Total Equity |
Balances, December 31, 2016 | — |
| | $ | — |
| | 54.2 |
| | $ | 1,747 |
| | $ | (3 | ) | | $ | 833 |
| | $ | 2,577 |
|
Limited partners/related party contribution and transition | — |
| | — |
| | — |
| | 51 |
| (a) | — |
| | (3 | ) | (b) | 48 |
|
Issuance of common units - net | — |
| | — |
| | 0.1 |
| | 1 |
| | — |
| | — |
| | 1 |
|
Acquisitions of membership interests in subsidiaries and equity method investee | — |
| | — |
| | — |
| | — |
| | — |
| | (1,074 | ) | | (1,074 | ) |
Issuance of preferred units - net | 14 |
| | 548 |
| | — |
| | — |
| | — |
| | — |
| | 548 |
|
Capped call transaction | — |
| | — |
| | — |
| | (13 | ) | | — |
| | — |
| | (13 | ) |
Related party note receivable | — |
| | — |
| | — |
| | — |
| | — |
| | 7 |
| | 7 |
|
Net income(c) | — |
| | 3 |
| | — |
| | (64 | ) | | — |
| | 175 |
| | 114 |
|
Other comprehensive income | — |
| | — |
| | — |
| | — |
| | 4 |
| | 13 |
| | 17 |
|
Related party contributions | — |
| | — |
| | — |
| | — |
| | — |
| | 321 |
| | 321 |
|
Related party distributions | — |
| | — |
| | — |
| | — |
| | — |
| | (226 | ) | | (226 | ) |
Changes in non-economic ownership interests | — |
| | — |
| | — |
| | — |
| | — |
| | (12 | ) | | (12 | ) |
Distributions to unitholders(d) | — |
| | (3 | ) | | — |
| | (81 | ) | | — |
| | — |
| | (84 | ) |
Balances, December 31, 2017 | 14 |
| | 548 |
| | 54.3 |
| | 1,641 |
| | 1 |
| | 34 |
| | 2,224 |
|
Limited partners/related party contribution and transition | — |
| | — |
| | — |
| | (3 | ) | (a) | 1 |
| | — |
| | (2 | ) |
Issuance of common units - net | — |
| | — |
| | 1.8 |
| | 86 |
| | — |
| | — |
| | 86 |
|
Acquisition of subsidiaries with differential membership interests | — |
| | — |
| | — |
| | — |
| | — |
| | 941 |
| | 941 |
|
Related party note receivable | — |
| | — |
| | — |
| | — |
| | — |
| | 31 |
| | 31 |
|
Net income | — |
| | 25 |
| | — |
| | 167 |
| | — |
| | 75 |
| | 267 |
|
Other comprehensive income (loss) | — |
| | — |
| | — |
| | — |
| | (10 | ) | | 12 |
| | 2 |
|
Related party contributions | — |
| | — |
| | — |
| | — |
| | — |
| | 4 |
| | 4 |
|
Related party distributions | — |
| | — |
| | — |
| | — |
| | — |
| | (204 | ) | | (204 | ) |
Changes in non-economic ownership interests | — |
| | — |
| | — |
| | — |
| | — |
| | (7 | ) | | (7 | ) |
Other differential membership investment activity | — |
| | — |
| | — |
| | — |
| | — |
| | 35 |
| | 35 |
|
Distributions to unitholders(d) | — |
| | (25 | ) | | — |
| | (94 | ) | | — |
| | — |
| | (119 | ) |
Sale of Class B noncontrolling interest - net | — |
| | — |
| | — |
| | — |
| | — |
| | 750 |
| | 750 |
|
Disposal of Canadian Holdings | — |
| | — |
| | — |
| | — |
| | 2 |
| | 105 |
| | 107 |
|
Adoption of accounting standards update | — |
| | — |
| | — |
| | 7 |
| | — |
| | 1,416 |
| | 1,423 |
|
Balances, December 31, 2018 | 14.0 |
| | 548 |
| | 56.1 |
| | 1,804 |
| | (6 | ) | | 3,192 |
| | 5,538 |
|
Issuance of common units - net(e) | (9.3 | ) | | (365 | ) | | 9.4 |
| | 407 |
| | — |
| | — |
| | 42 |
|
Acquisition of subsidiary with noncontrolling ownership interests | — |
| | — |
| | — |
| | — |
| | — |
| | 462 |
| | 462 |
|
Related party note receivable | — |
| | — |
| | — |
| | — |
| | — |
| | 2 |
| | 2 |
|
Net income (loss) | — |
| | 17 |
| | — |
| | (88 | ) | | — |
| | (333 | ) | | (404 | ) |
Other comprehensive loss | — |
| | — |
| | — |
| | — |
| | (2 | ) | | (2 | ) | | (4 | ) |
Related party contributions | — |
| | — |
| | — |
| | — |
| | — |
| | 23 |
| | 23 |
|
Related party distributions | — |
| | — |
| | — |
| | — |
| | — |
| | (249 | ) | | (249 | ) |
Changes in non-economic ownership interests | — |
| | — |
| | — |
| | — |
| | — |
| | (12 | ) | | (12 | ) |
Other differential membership investment activity | — |
| | — |
| | — |
| | — |
| | — |
| | 36 |
| | 36 |
|
Payments to Class B noncontrolling interest investors | — |
| | — |
| | — |
| | — |
| | — |
| | (23 | ) | | (23 | ) |
Distributions to unitholders(d) | — |
| | (17 | ) | | — |
| | (115 | ) | | — |
| | — |
| | (132 | ) |
Sale of Class B noncontrolling interests - net | — |
| | — |
| | — |
| | (2 | ) | | — |
| | 1,788 |
| | 1,786 |
|
Other - net | — |
| | — |
| | — |
| | 2 |
| | — |
| | (1 | ) | | 1 |
|
Balances, December 31, 2019 | 4.7 |
| | $ | 183 |
| | 65.5 |
| | $ | 2,008 |
| | $ | (8 | ) | | $ | 4,883 |
| | $ | 7,066 |
|
(a) In 2022, includes NEE Equity's exchange of NEP OpCo common units for NEP common units and includes deferred tax impact of approximately $14 million (see Note 13 - Common Unit Issuances). In 2020, NEP issued approximately 4.7 million NEP common units upon the conversion of preferred units on a one-for-one basis and issued 5.7 million NEP common units upon the conversion of $300 million of convertible notes (see Note 13 – Preferred Units and Note 12). NEP recognized a deferred tax asset of approximately $59 million related to the issuance of NEP common units.____________________________(b) Distributions per common unit were $2.9900, $2.6000 and $2.2625 for the years ended December 31, 2022, 2021 and 2020, respectively.
(c) Reflects the issuance of approximately 7.3 million NEP common units and recognition of a $105 million deferred tax asset in connection with the exercise of the Class B noncontrolling interest buyout right discussed in Note 13 – Class B Noncontrolling Interests.
|
| | | | | | | | | | | | |
(a) | Deferred tax asset recognized by NEP related to NEP equity issuances and/or acquisition of subsidiary membership interests. |
(b) | Related party noncash contributions, net, upon transition from predecessor accounting method. |
(c) | Net income attributable to noncontrolling interests includes the pre-acquisition net income of the common control acquisitions. See Note 2 - Basis of Presentation. |
(d) | Distributions per common unit were $1.9675, $1.7125 and $1.49 for the years ended December 31, 2019, 2018, and 2017, respectively. At December 31, 2019, approximately $2 million of preferred unit distributions were accrued and are payable in February 2020. |
(e) | In 2019, NEP converted approximately 9.3 million Series A convertible preferred units into NEP common units on a one-for-one basis and recognized a deferred tax asset of approximately $39 million related to the issuance of NEP common units. |
The accompanying Notes to Consolidated Financial Statements are an integral part of these consolidated financial statements.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Years Ended December 31, 2019, 20182022, 2021 and 20172020
1. Organization and Nature of Business
NextEra Energy Partners, LP (NEP) was formed as a Delaware limited partnership on March 6, 2014 as an indirect wholly owned subsidiary of NextEra Energy, Inc. (NEE), a Florida corporation. NEP was formed to be a growth-oriented limited partnership that would acquire, manage and own contracted clean energy projects with stable long-term cash flows.
On July 1, 2014, NEP completed its initial public offering (IPO). NEP used the proceeds from the IPO to purchase common units of NextEra Energy Operating Partners, LP (NEP OpCo) from NextEra Energy Equity Partners, LP (NEE Equity), a Delaware limited partnership formed under the laws of the State of Delaware and an indirect wholly owned subsidiary of NEE, and to purchase NEP OpCo common units from NEP OpCo.
NEP OpCo is a limited partnership with a general partner and limited partners. NEP consolidates the results of NEP OpCo and its subsidiaries because of its controlling interest in the general partner of NEP OpCo. At December 31, 2019,2022, NEP owned an approximately 39.2%46.2% limited partner interest in NEP OpCo's common units and NEE Equity owned a noncontrolling 60.8%53.8% limited partner interest in NEP OpCo's common units. See Note 13 - Common Unit Issuances.
In connection with the IPO, NEP acquired a portfolio of clean, contracted renewable energy assets including wind and solar energy generating facilities located in the United States (U.S.) and Canada.facilities. Subsequent to the IPO, NEP expanded its portfolio through the acquisition of additional interests in wind, solar and solar generating facilitiessolar-plus-storage projects primarily from NextEra Energy Resources, LLC (NEER), as well as the 2015 acquisition of interests in 7 natural gas pipeline assets located in Texas (Texas pipelines) and the 2019 acquisition of an interest in a natural gas pipeline located in Pennsylvania from third parties. See Note 3. In 2018, NEP's interests in wind and solar energy generating facilities located in Canada were sold to a third party. See Note 2 - Disposal of Canadian Holdings.
2. Summary of Significant Accounting and Reporting Policies
Basis of Presentation -– NEP’s consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the U.S.United States (U.S.), or GAAP. The consolidated financial statements include NEP’s accounts and operations and those of its subsidiaries in which NEP has a controlling interest. The acquisitions from NEER in 2017 described in Note 3 (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 consolidated financial statements were retrospectively adjusted to include the historical results of the common control acquisitions prior to their respective acquisition dates. Adjustments related to the historical results of the common control acquisitions were attributable to noncontrolling interests for all periods prior to the date the project was acquired by NEP.
All intercompany transactions have been eliminated in consolidation. Certain amounts included in prior years' consolidated financial statements have been reclassified to conform to the current year's presentation. The preparation of financial statements requires the use of estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates.
Disposal of Canadian Holdings - In June 2018, a subsidiary of NEP completed the sale of NextEra Energy Canada Partners Holdings, ULC and subsidiaries (Canadian Holdings) for cash proceeds of approximately CAD $740 million (USD $563 million at June 29, 2018), subject to post-closing working capital adjustments of approximately $1 million. In addition, the purchaser assumed approximately $676 million of existing debt. Canadian Holdings owned 4 wind generation facilities and 2 solar generation facilities located in Ontario, Canada with a generating capacity totaling approximately 396 megawatts (MW). NEP recognized a gain of approximately $153 million ($201 million after tax). Income before income taxes associated with Canadian Holdings, excluding the financial statement impacts resulting from the sale in 2018, was approximately $47 million and $68 million for the years ended December 31, 2018 and 2017, respectively.
Revenue Recognition -– Revenue is generated primarily from various non-affiliated parties under long-term power purchase agreements and prior to the sale of Canadian Holdings in 2018, Feed-in-Tariff agreements and Renewable Energy Standard Offer Program agreements (collectively, PPAs),(PPA) and natural gas transportation agreements. Revenue is recognized as energy and any related renewable energy attributes are delivered, which is when revenue is earned based on energy delivered at rates stipulated in the respective PPAs, or natural gas transportation services are performed. See Note 4.
In 2019, 20182022, 2021 and 2017,2020, approximately $125$155 million, $234$141 million and $275$122 million, respectively, of NEP's consolidated revenues were attributable to foreign countries primarily related to its contract with a Mexican counterparty and, prior to the sale of Canadian Holdings in 2018, its Canadian operations.counterparty.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Income Taxes -– NEP recognizes in income its applicable ownership share of U.S. income taxes due to the disregarded tax status of substantially all of the U.S. projects under NEP OpCo. Prior to the sale of Canadian Holdings, NEP's former Canadian subsidiaries were all Canadian taxpayers, and therefore NEP recognized in income all of the Canadian taxes. Net income or loss attributable to noncontrolling interests includes minimal U.S. taxes and, prior to the sale, NEER's applicable ownership share of Canadian taxes.
For periods through December 31, 2017, when NEP acquired a NEER project, income taxes were calculated on the predecessor method using the separate return method applied to the group of renewable energy projects acquired. As a result of the governance changes discussed in Note 3, beginning in January 2018, acquisitions from NEER are no longer treated as common control acquisitions, and income taxes are calculated on the successor method under which taxes are calculated for NEP as a single taxpaying corporation for U.S. federal and state income taxes (based on its election to be taxed as a corporation).
Foreign Operations and Currency Translation - NEP’s reporting currency is the U.S. dollar. Prior to the disposal of Canadian Holdings, the functional currency for the Canadian project companies was the Canadian dollar because Canada was the primary economic environment in which they conducted their Canadian operations. The assets and liabilities of the Canadian project companies were translated to U.S. dollars at exchange rates at the balance sheet date. The income and expenses of the Canadian project companies were translated to U.S. dollars at exchange rates in effect during each respective period. The translation adjustment was recorded in accumulated other comprehensive income (loss) (AOCI).
Equity -– Equity reflects the financial position of the parties with an ownership interest in the consolidated financial statements. NextEra Energy Partners GP, Inc. has a total equity interest in NEP of $10,000 at December 31, 20192022 and 2018.2021.
Limited partners' equity in common units at December 31, 20192022 and 20182021 reflects the investment of NEP common unitholders, changes to net income attributable to NEP, distributions of available cash to common unitholders and other contributions from or distributions to NEP common unitholders. Accumulated other comprehensive loss at December 31, 20192022 and 20182021 reflects other comprehensive income (loss) attributable to NEP.
Noncontrolling Interests -– Noncontrolling interests represents the portion of net assets in consolidated entities that are not owned by NEP and are reported as a component of equity on NEP’s consolidated balance sheets. At December 31, 20192022, noncontrolling interests on NEP's consolidated balance sheets primarily reflects NEE Equity's 60.8%53.8% noncontrolling interest in NEP OpCo, a non-affiliated party'sparties' 10% interest in 1one of the Texas pipelines and 50% interest in the renewable energy projects purchased from NEER in December 2021 (see Note 3), NEER's approximately 50% noncontrolling ownership interest in Silver State South Solar, LLC (Silver State), NEER's 33% noncontrolling interest in Sunlight Renewables Holdings, LLC (Sunlight Renewables Holdings) and NEER's 51% noncontrolling interest in Emerald Breeze Holdings, LLC (Emerald Breeze) (see Note 3), the interests related to differential membership interests discussed below and the Class B noncontrolling ownership interests discussed below are reflected as noncontrolling interests on NEP's consolidated balance sheets.below.
Prior to being acquired by NEP, certain
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Certain indirect subsidiaries of NEERNEP have sold Class B membership interests in entities that have ownership interests in 2037 wind projects and eight solar projects, including related battery storage facilities, (differential membership interests) to third-party investors. Although the third-party investors own equity interests in the wind, solar and battery storage projects, NEP retains a controlling interest in the entities as of December 31, 20192022 and therefore presents the differential membership interests as noncontrolling interests. NEP, through O&M and administrative services agreements with subsidiaries of NEER, operates and manages the wind, solar and battery storage projects, and consolidates the entities that directly and indirectly own the wind, solar and battery storage projects. The third-party investors are allocated earnings, tax attributes and cash flows in accordance with the respective limited liability company agreements. Those economics are allocated primarily to the third-party investors until they receive a targeted return (the flip date) and thereafter to NEP. NEP has the unilateral right to call the third-party interests at specified amounts if and when the flip date occurs. PursuantIn December 2022, NEP entered into agreements to previous accounting guidance, prior to 2018, the proceeds received on the sale of thebuy out differential membership investors with ownership interests were deferred and recorded as a liabilityin two wind projects for approximately $187 million, which amount is included in current other liabilities on NEP'sthe consolidated balance sheets. The deferred amount was being recognizedbuyouts closed in benefits associated with differential membership interests - net in NEP's consolidated statementsJanuary 2023. (see Note 10).
Subsidiaries of income (loss) as the third-party investors received their portion of the economic attributes. NEP operates and manages the 20 wind projects, and consolidates the entities that directly and indirectly own the 20 wind projects.
During 2018 and 2019, subsidiaries of NEPhave sold Class B noncontrolling membership interests in NEP Renewables, LLC (NEP Renewables), NEP Renewables II, LLC (NEP Renewables II), NextEra Energy Partners Pipelines, LLC (NEP Pipelines) and, South Texas Midstream, LLC (STX Midstream), Genesis Solar Holdings, LLC (Genesis Holdings), NEP Renewables III, LLC (NEP Renewables III) and NEP Renewables IV, LLC (NEP Renewables IV) (collectively, Class B noncontrolling ownership interests). In 2021, NEP exercised its buyout right for the Class B noncontrolling interests in NEP Renewables. See Note 11 - Equity.13 – Class B Noncontrolling Interests. The NEP subsidiaries selling the Class B noncontrolling ownership interests retain controlling interests in the related entities as of December 31, 20192022 and therefore NEP presents the Class B noncontrolling ownership interests as noncontrolling interests.
For the differential membership interests and Class B noncontrolling ownership interests, NEP has determined the allocation of economics between the controlling party and third-party investor should not follow the respective ownership percentages for each investment but rather the hypothetical liquidation of book value (HLBV) method based on the governing provisions in each respective limited liability company agreement. Under the HLBV method, the amounts of income and loss attributable to the noncontrolling interests reflects changes in the amount the owners would hypothetically receive at each balance sheet date under the respective liquidation provisions, assuming the net assets of these entities were liquidated at the recorded amounts, after taking into account any capital transactions, such as contributions and distributions, between the entities and the owners. At the point in time that the third-party,third party, in hypothetical liquidation, would achieve its targeted return, NEP attributes the additional hypothetical proceeds to the differential membership interests based on the call price.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
For the noncontrolling interests, other than the differential membership interests and the Class B noncontrolling interests, net income (loss) is allocated based on the respective ownership percentages. Thus, the impact of the net income (loss) attributable to the Class B noncontrolling ownership interests and the differential membership interests are allocated to NEE Equity's noncontrolling ownership interest and the net income attributable to NEP based on their respective ownership percentage of NEP OpCo. Distributions related to the noncontrolling interests, other than the differential membership interests and Class B noncontrolling interests, are reflected as Partners/Members'partner distributions in NEP's consolidated statements of cash flows. Details of the activity in noncontrolling interests for the years ended December 31, 20192022, 2021 and 20182020 are below:
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
| | | | | | | | | | | | Class B Noncontrolling Ownership Interests | | Differential Membership Interests | | NEE's Indirect Noncontrolling Ownership Interests(a) | | Other Noncontrolling Ownership Interests | | Total Noncontrolling Interests |
| | Class B Noncontrolling Ownership Interests | | Differential Membership Interests | | Noncontrolling Ownership Interests in NEP OpCo, Silver State and Texas pipeline | | Total Noncontrolling Interests | | (millions) |
Balances, December 31, 2019 | | Balances, December 31, 2019 | | $ | 2,628 | | | $ | 1,798 | | | $ | 389 | | | $ | 68 | | | $ | 4,883 | |
Sale of Class B noncontrolling interest – net | | Sale of Class B noncontrolling interest – net | | 750 | | | — | | | — | | | — | | | 750 | |
| | (millions) | |
Balances, December 31, 2017 | | $ | — |
| | $ | — |
| | $ | 34 |
| | $ | 34 |
| |
Sale of Class B noncontrolling interest - net | | 750 |
| | — |
| | — |
| | 750 |
| |
Acquisition of subsidiaries with differential membership interests | | — |
| | 941 |
| | — |
| | 941 |
| |
Related party note receivable | | — |
| | — |
| | 31 |
| | 31 |
| Related party note receivable | | — | | | — | | | 2 | | | — | | | 2 | |
Net income (loss) attributable to noncontrolling interests(a) | | 1 |
| | (370 | ) | | 444 |
| | 75 |
| |
Net income (loss) attributable to noncontrolling interests | | Net income (loss) attributable to noncontrolling interests | | 217 | | | (282) | | | (127) | | | 4 | | | (188) | |
Other comprehensive income | | — |
| | — |
| | 12 |
| | 12 |
| Other comprehensive income | | — | | | — | | | 2 | | | — | | | 2 | |
Related party contributions | | — |
| | — |
| | 4 |
| | 4 |
| Related party contributions | | — | | | — | | | — | | | 7 | | | 7 | |
Related party distributions | | — |
| | — |
| | (204 | ) | | (204 | ) | Related party distributions | | — | | | — | | | (281) | | | (9) | | | (290) | |
Changes in non-economic ownership interests | | — |
| | — |
| | (7 | ) | | (7 | ) | |
Changes in non-economic ownership interests, net of distributions | | Changes in non-economic ownership interests, net of distributions | | — | | | — | | | — | | | (12) | | | (12) | |
Differential membership investment contributions, net of distributions | | — |
| | 35 |
| | — |
| | 35 |
| Differential membership investment contributions, net of distributions | | — | | | 64 | | | — | | | — | | | 64 | |
Disposal of Canadian Holdings | | — |
| | — |
| | 105 |
| | 105 |
| |
Adoption of accounting standards update | | — |
| | 1,413 |
| | 3 |
| | 1,416 |
| |
Balances, December 31, 2018 | | 751 |
| | 2,019 |
| | 422 |
| | 3,192 |
| |
Sales of Class B noncontrolling interests - net | | 1,788 |
| | — |
| | — |
| | 1,788 |
| |
Payments to Class B noncontrolling interest investors | | Payments to Class B noncontrolling interest investors | | (45) | | | — | | | — | | | — | | | (45) | |
Sale of differential membership interest | | Sale of differential membership interest | | — | | | 179 | | | — | | | — | | | 179 | |
Other | | Other | | — | | | — | | | 1 | | | — | | | 1 | |
Balances, December 31, 2020 | | Balances, December 31, 2020 | | 3,550 | | | 1,759 | | | (14) | | | 58 | | | 5,353 | |
Sale of Class B noncontrolling interests – net | | Sale of Class B noncontrolling interests – net | | 893 | | | — | | | — | | | — | | | 893 | |
Acquisition of subsidiary with noncontrolling interests | | — |
| | — |
| | 462 |
| | 462 |
| Acquisition of subsidiary with noncontrolling interests | | — | | | 1,618 | | | 25 | | | 851 | | | 2,494 | |
Related party note receivable | | — |
| | — |
| | 2 |
| | 2 |
| Related party note receivable | | — | | | — | | | 2 | | | — | | | 2 | |
Net income (loss) attributable to noncontrolling interests | | 112 |
| | (257 | ) | | (188 | ) | | (333 | ) | Net income (loss) attributable to noncontrolling interests | | 298 | | | (313) | | | 269 | | | 33 | | | 287 | |
Other comprehensive loss | | — |
| | — |
| | (2 | ) | | (2 | ) | |
Related party contributions | | — |
| | — |
| | 23 |
| | 23 |
| |
Other comprehensive income | | Other comprehensive income | | — | | | — | | | 2 | | | — | | | 2 | |
| Related party distributions | | — |
| | — |
| | (249 | ) | | (249 | ) | Related party distributions | | — | | | — | | | (322) | | | (102) | | | (424) | |
Changes in non-economic ownership interests | | — |
| | — |
| | (12 | ) | | (12 | ) | |
Changes in non-economic ownership interests, net of distributions | | Changes in non-economic ownership interests, net of distributions | | — | | | — | | | — | | | 127 | | | 127 | |
Differential membership investment contributions, net of distributions | | — |
| | 36 |
| | — |
| | 36 |
| Differential membership investment contributions, net of distributions | | — | | | 39 | | | — | | | — | | | 39 | |
Payments to Class B noncontrolling interest investors | | (23 | ) | | — |
| | — |
| | (23 | ) | Payments to Class B noncontrolling interest investors | | (80) | | | — | | | — | | | — | | | (80) | |
Sale of differential membership interest | | Sale of differential membership interest | | — | | | 48 | | | — | | | — | | | 48 | |
Exercise of Class B noncontrolling interest buyout right | | Exercise of Class B noncontrolling interest buyout right | | (879) | | | — | | | — | | | — | | | (879) | |
Other | | — |
| | — |
| | (1 | ) | | (1 | ) | Other | | 1 | | | (1) | | | — | | | (1) | | | (1) | |
Balances, December 31, 2019 | | $ | 2,628 |
| | $ | 1,798 |
| | $ | 457 |
| | $ | 4,883 |
| |
Balances, December 31, 2021 | | Balances, December 31, 2021 | | 3,783 | | | 3,150 | | | (38) | | | 966 | | | 7,861 | |
Sale of Class B noncontrolling interests – net | | Sale of Class B noncontrolling interests – net | | 1,115 | | | — | | | — | | | — | | | 1,115 | |
Acquisition of subsidiaries with differential membership interests | | Acquisition of subsidiaries with differential membership interests | | — | | | 1,494 | | | — | | | — | | | 1,494 | |
Acquisition of subsidiaries with noncontrolling ownership interests | | Acquisition of subsidiaries with noncontrolling ownership interests | | — | | | — | | | 518 | | | — | | | 518 | |
Related party note receivable | | Related party note receivable | | — | | | — | | | 2 | | | — | | | 2 | |
Net income (loss) attributable to noncontrolling interests | | Net income (loss) attributable to noncontrolling interests | | 296 | | | (573) | | | 788 | | | 124 | | | 635 | |
Other comprehensive income | | Other comprehensive income | | — | | | — | | | 1 | | | — | | | 1 | |
| Related party distributions | | Related party distributions | | — | | | — | | | (346) | | | (36) | | | (382) | |
Changes in non-economic ownership interests, net of distributions | | Changes in non-economic ownership interests, net of distributions | | — | | | — | | | — | | | 1 | | | 1 | |
Differential membership investment contributions, net of distributions | | Differential membership investment contributions, net of distributions | | — | | | 101 | | | — | | | — | | | 101 | |
Payments to Class B noncontrolling interest investors | | Payments to Class B noncontrolling interest investors | | (163) | | | — | | | — | | | — | | | (163) | |
| Reclassification of redeemable noncontrolling interests | | Reclassification of redeemable noncontrolling interests | | — | | | 330 | | | — | | | — | | | 330 | |
Reclassification to current other liabilities(b) | | Reclassification to current other liabilities(b) | | — | | | (142) | | | (25) | | | — | | | (167) | |
Other | | Other | | — | | | (1) | | | (9) | | | 10 | | | — | |
Balances, December 31, 2022 | | Balances, December 31, 2022 | | $ | 5,031 | | | $ | 4,359 | | | $ | 891 | | | $ | 1,065 | | | $ | 11,346 | |
____________________
| |
(a) | Net loss attributable to differential membership interests includes approximately $231 million ($211 million after tax) related to the reduction of differential membership interests as a result of the change in federal corporate income tax rates effective January 1, 2018. |
(a) Primarily reflects NEE Equity's noncontrolling interest in NEP OpCo and NEER's noncontrolling interest in Silver State, Sunlight Renewables Holdings and Emerald Breeze.
(b) In December 2022, NEP entered into agreements to acquire certain differential membership interests, which resulted in the reclassification of the remaining noncontrolling interests to current other liabilities.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Redeemable Noncontrolling Interests – In connection with the December 2021 acquisition from NEER (see Note 3), NEP recorded redeemable noncontrolling interests of approximately $321 million relating to certain contingencies whereby NEP may have been obligated to either redeem interests of third-party investors in certain projects or return proceeds to third-party investors in certain projects. As the contingencies were resolved during 2022, NEP reclassified the recorded amounts to noncontrolling interests.
Subsequent to the acquisition in December 2022 from NEER (see Note 3), differential membership interests related to one of the acquired facilities, which is currently under construction, were sold to third-party investors. If, subject to certain contingencies, certain events occur that delay or prevent completion of the project, NEP could be obligated to reacquire all or a portion of the third-party investor's interests in the project for up to approximately $101 million. Prior to paying any amounts to the third-party investor related to this contingency, NEP would receive the full amount of any such payments from a subsidiary of NEER. As this potential redemption is outside of NEP’s control, the balances were classified as redeemable noncontrolling interests on NEP's consolidated balance sheet as of December 31, 2022. These contingencies are expected to be resolved during 2023.
Property, Plant and Equipment -– net -– Property, plant and equipment consists primarily of development, engineering and construction costs for the renewable energy assets, equipment, land, substations, transmission lines and pipeline facilities. Property, plant and equipment, excluding land and perpetual rights-of-way, is recorded at cost and depreciated on a straight-line basis over the estimated useful lives ranging from three to 50 years, commencing on the date the assets are placed in service or acquired. Seeacquired (see Note 8.8). Maintenance and repairs of property, plant and equipment are charged to O&M expense as incurred.
Property, plant and equipment -– net on NEP's consolidated balance sheets includes construction work in progress which reflects construction materials, other equipment, third-party engineering costs, capitalized interest and other costs directly associated with the development and construction of the various projects. Upon commencement of plant or pipeline operations, costs associated with construction work in progress are transferred to the appropriate category in property, plant and equipment -– net.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The American Recovery and Reinvestment Act of 2009, as amended, provided for an option to elect a cash grant (convertible investment tax credits) for certain renewable energy property. Convertible investment tax credits (CITCs) of approximately $703 million at both December 31, 2019 and 2018, are recorded as a reduction in property, plant and equipment -– net on NEP's consolidated balance sheets and are amortized as a corresponding reduction to depreciation expense over the estimated life of the related asset. At December 31, 2019, other receivables on NEP's consolidated balance sheets includes a CITC receivable2022 and 2021, CITCs, net of amortization, were approximately $124 million associated with one of its solar projects. At December 31, 2019, corresponding liabilities of approximately $100$451 million and $12$448 million, related to the CITC payments required to be paid to the third party who constructed the project are reflected as accounts payable and accrued expenses and other current liabilities, respectively, and $12 million of CITC payments to be paid to NEER are reflected as current due to related parties on NEP's consolidated balance sheets.respectively.
Cash and Cash Equivalents -– Cash equivalents consist of short-term, highly liquid investments with original maturities of three months or less. NEP primarily holds such investments in money market funds.
Accounts Receivable and Allowance for Doubtful Accounts -– Accounts receivable are reported at the invoiced or estimated amount adjusted for any write-offs and any estimated allowance for doubtful accounts on NEP's consolidated balance sheets. The allowance for doubtful accounts is reviewed periodically based on amounts past due and significance. There was 0no allowance for doubtful accounts recorded at December 31, 20192022 and 2018.2021.
Restricted Cash -– At December 31, 20192022 and 2018,2021, NEP had approximately $3$49 million and $8$4 million, respectively, of restricted cash included in current other current assets and, in 2018, approximately $11 million of restricted cash included in other non-current assets on NEP's consolidated balance sheets. Restricted cash at December 31, 20192022 and 2021 is primarily related to an operating cash reserve and collateral deposits from a counterparty, and, at December 31, 2018, is primarily related to amounts held by certain subsidiaries to pay for certain capital or operating expenditures, as well as to fund required equity contributions pursuant to restrictions contained in the subsidiaries' debt agreements.respectively. Restricted cash reported as current assets are recorded as such based on the anticipated use of these funds.
Concentration of Credit Risk -– Financial instruments which potentially subject NEP to concentrations of credit risk consist primarily of accounts receivable and derivative instruments. Accounts receivable are comprised primarily of amounts due from various non-affiliated parties who are counterparties to the PPAs or natural gas transportation agreements. The majority of NEP's counterparties are in the energy industry, and this concentration may impact the overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, industry or other conditions. If any of these customers’ receivable balances should be deemed uncollectible, it could have a material adverse effect on NEP’s consolidated results of operations and financial condition. Substantially all amounts due from such counterparties at December 31, 20192022 have been collected.
During 2019,2022, NEP derived approximately 16%14% and 15%13% of its consolidated revenue from its contracts with Pacific Gas and Electric Company (PG&E) and Mex Gas Supply S.L., respectively. See Note 15 - PG&E Bankruptcy.
Inventories -– Spare parts inventories are carried at the lower of weighted-average cost and net realizable value and are included in other current assets on NEP’s consolidated balance sheets. Spare parts inventories were approximately $20 million and $19 million at December 31, 2019 and 2018, respectively.value.
Impairment of Long-Lived Assets and Finite-Lived Intangible Assets -– Long-lived assets that are held and used and finite-lived intangible assets are reviewed for impairment when events or changes in circumstances indicate that the carrying amount may not be recoverable. An impairment loss is required to be recognized if the carrying value of the asset exceeds the undiscounted future net cash flows associated with that asset. The impairment loss to be recognized is the amount by which the carrying value
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
of the asset exceeds the asset's fair value. In most instances, the fair value is determined by discounting estimated future cash flows using an appropriate interest rate. During the years ended December 31, 20192022 and 2018, 02021, no impairment adjustments were necessary.
Business Combinations -– For projects acquired in a business combination, NEP allocates the cost of the acquisition to assets acquired and liabilities assumed based on fair values as of the acquisition date. Goodwill acquired in connection with business combinationsacquisitions represents the excess of consideration over the fair value of net assets acquired. Certain assumptions and estimates are employed in determining the fair value of assets acquired and evaluating the fair value of liabilities assumed. See Note 3.
Goodwill and Indefinite-Lived Intangible Assets -– Goodwill and indefinite-lived intangible assets are assessed for impairment at least annually by applying a fair value-based analysis. NEP completed the annual impairment test for goodwill and indefinite-lived intangibles using an assessment date of October 1 and determined, based on the results, that 0no goodwill impairment charge was required. As a result of the sale of Canadian Holdings discussed above, goodwill was reduced by approximately $44 million during 2018.
Intangible Asset -– Customer Relationships -– At December 31, 20192022 and 20182021, NEP's consolidated balance sheets reflect intangible asset -– customer relationships related to the acquisition of the Texas pipelines in 2015. Intangible asset -– customer relationships are amortized on a straight-line basis over the estimated useful life of approximately 40 years. ForAt December 31, 2022 and 2021, accumulated amortization related to the intangible asset – customer relationships was approximately $114 million and $107 million, respectively. Amortization expense for intangible asset – customer relationships was approximately $17 million for each of the years ended December 31, 2019,2022, 20182021 and 2017, amortization expense was approximately $17 million2020 and is expected to be approximately $17$16 million in each of the next five years.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Intangible Asset -– PPAs -– At December 31, 20192022 and 20182021, NEP's consolidated balance sheets reflect intangible asset -– PPAs primarily related to acquisitions in 2018 and 2019 and the acquisitions from NEERdiscussed in 2019 and 2018 (see Note 3).3. Intangible asset -– PPAs are amortized into operating revenues on a straight-line basis over the remaining contract terms of the related PPAs, which approximates the period giving rise to the value. At December 31, 2019,2022 and 2021, accumulated amortization ofrelated to the intangible asset -– PPAs was approximately $454 million and $295 million, respectively. Amortization expense for intangible assets – PPAs was approximately $160 million, $117 million and $103 million for the years ended December 31, 2022, 2021 and 2020, respectively, and is expected to be approximately $103$160 million in eachyears 2023 through 2027.
Intangible Liabilities – PPAs – At December 31, 2022 and 2021, NEP's consolidated balance sheets reflect intangible liabilities – PPAs primarily related to the December 2022 and December 2021 acquisitions from NEER discussed in Note 3 and will be amortized into operating revenues on a straight-line basis over the remaining contract terms of the next five years.PPAs, which approximates the period giving rise to the value. At December 31, 2022, accumulated amortization related to the intangible liabilities – PPAs was approximately $17 million. At December 31, 2021, there was no accumulated amortization related to the intangible liabilities – PPAs. Amortization expense for intangible liabilities – PPAs was approximately $17 million for the year ended December 31, 2022 and is expected to be approximately $77 million in 2023 and $80 million in the years 2024 through 2027.
Derivative Instruments and Hedging Activities -– Derivative instruments, when required to be marked to market, are recorded on NEP’s consolidated balance sheets as either an asset or a liability measured at fair value. See Note 7.5.
Fair Value Measurements -– 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 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. See Note 6.5.
Long-term Debt Costs -– NEP recognizes interest expense using the effective interest method over the life of the related debt. Certain of NEP’s debt obligations include escalating interest rates that are incorporated into the effective interest rate for the related debt. Deferred interest includes interest expense recognized in excess of the interest payments accrued for the related debt’s stated interest payments and is recorded in other non-current liabilities on NEP’s consolidated balance sheets. Debt issuance costs include fees and costs incurred to obtain long-term debt and are amortized over the life of the related debt using the effective interest rate established at debt issuance. NEP incurred approximately $42$13 million and $12 million of debt issuance costs during the yearyears ended December 31, 2019.2022 and 2021, respectively. The amortization of debt issuance costs totaled approximately $11$13 million, $12$11 million and $11 million for the years ended December 31, 2019, 20182022, 2021 and 2017,2020, respectively, and is included in interest expense in NEP’s consolidated statements of income (loss). In addition, NEP wrote-off approximately $22$4 million of debt issuance costs during 20192020 due to the retirement of the related debt. See Note 11 - Debt.12.
Asset Retirement Obligations -– Asset retirement obligations are those for which a legal obligation exists under laws, statutes, and written or oral contracts, including obligations arising under the doctrine of promissory estoppel, and for which the timing or
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
method of settlement may be conditioned on a future event.
NEP accounts for asset retirement obligations and conditional asset retirement obligations (collectively, AROs) under accounting guidance that requires a liability for the fair value of an ARO to be recognized in the period in which it is incurred if it can be reasonably estimated, with the offsetting associated asset retirement costs capitalized as part of the carrying amount of the long-lived asset. The asset retirement cost is subsequently allocated to expense using a systematic and rational method over the asset’s estimated useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense, which is included in depreciation and amortization expense in NEP’s consolidated statements of income (loss). Changes resulting from revisions to the timing or amount of the original estimate of cash flows are recognized as an increase or a decrease in the asset retirement cost, or income when the asset retirement cost is depleted.
NEP recorded accretion expense of approximately $6$12 million, $4$7 million and $4$7 million in the years ended December 31, 2019, 20182022, 2021 and 2017.2020, respectively. Additional AROs were established amounting to approximately $38$37 million and $101 million in 2019the years ended December 31, 2022 and $24 million in 20182021, respectively, related to the acquisitions from NEERin those periods (see Note 3), partly offset by a decrease. Additionally, in 20182022, NEP recorded additional AROs of $13approximately $8 million relatedfor revisions in estimated cash flows due to the sale of Canadian Holdings.revised cost estimates.
Investments in Unconsolidated Entities -– NEP accounts for the investments in its unconsolidated entities under the equity method. NEP’s share of earnings (losses) in the unconsolidated entities is included in equity in earnings of equity method investees and equity in earnings (losses) of non-economic ownership interests in NEP's consolidated statements of income (loss). NEP records losses of the unconsolidated entities only to the extent of its investment unless there is an obligation to provide further financial support for the investee. All equity in earnings (losses) of the non-economic ownership interests is allocated to net income attributable to noncontrolling interests. See Note 9 and Note 10. NEP evaluates its equity method investments for impairment when events or changes in circumstances indicate that the fair value of the investment is less than the carrying value and the investment may be other-than-temporarily impaired. An impairment loss is required to be recognized if the impairment is deemed to be other than temporary. Investments that are other-than-temporarily impaired are written down to their estimated fair value and cannot subsequently be written back up for increases in estimated fair value.
Variable Interest Entities (VIEs) -– An entity is considered to be a VIE when its total equity investment at risk is not sufficient to permit the entity to finance its activities without additional subordinated financial support, or its equity investors, as a group, lack the characteristics of having a controlling financial interest. A reporting company is required to consolidate a VIE as its primary beneficiary when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance, and the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. NEP evaluates whether an entity is a VIE whenever reconsideration events as defined by the accounting guidance occur. See Note 10.
Leases -– NEP determines if an arrangement is a lease at inception. NEP recognizes a right-of-use (ROU) asset and a lease liability for operating and finance leases by recognizing and measuring leases at the commencement date based on the present value of lease payments over the lease term. For sales-type leases, the book value of the leased asset is removed from the balance sheet and a net investment in sales-type lease is recognized based on fixed payments under the contract and the residual value of the asset being leased. NEP has elected not to apply the recognition requirements to short-term leases and not to separate nonlease
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
components from associated lease components for substantially all classes of underlying assets.assets except for purchase power agreements. ROU assets are included primarily in noncurrent other assets, and lease liabilities are included in current and noncurrent other liabilities and net investments in sales-type leases are included in current and noncurrent other assets on NEP's consolidated balance sheets. Operating lease expense is included in O&M expense, interest and amortization expense isassociated with finance leases are included in interest expense and depreciation and amortization expense, respectively, and rental income associated with operating leases and interest income associated with sales-type leases are included in operating revenues in NEP’s consolidated statements of income (loss). See Note 14.11.
Reference Rate Reform – In March 2020, the Financial Accounting Standards Board (FASB) issued an accounting standards update which provides certain options to apply GAAP guidance on contract modifications and hedge accounting as companies transition from the London Inter-Bank Offered Rate (LIBOR) and other interbank offered rates to alternative reference rates. NEP’s contracts that reference LIBOR or other interbank offered rates mainly relate to debt and derivative instruments. The standards update was effective upon issuance and can be applied prospectively through December 31, 2024. As agreements that reference LIBOR or other interbank offered rates as an interest rate benchmark are amended, NEP evaluates whether to apply the options provided by the standards update with regard to eligible contract modifications.
Distinguishing Liabilities and Equity – In August 2020, the FASB issued an accounting standards update which updates the accounting guidance for financial instruments with the characteristics of liabilities and equity, including debt with conversion options and other equity-linked instruments such as the $600 million in principal amount of convertible notes issued in December 2020 (2020 convertible notes) (see Note 12). NEP adopted this standard on January 1, 2021 by applying it retrospectively with
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
the cumulative effect recognized as of the date of initial application (modified retrospective approach). Upon adoption, NEP reclassified approximately $64 million related to the embedded conversion feature for the 2020 convertible notes from common units equity to long-term debt.
Disposal of Pipeline – In April 2022, subsidiaries of NEP sold all of their ownership interests in an approximately 156-mile, 16-inch pipeline that transports natural gas in Texas to a third party for total consideration of approximately $203 million, subject to working capital and other adjustments. Approximately $70 million of the cash proceeds from the sale were distributed to the third-party owner of Class B membership interests in STX Midstream (see Note 13 - Class B Noncontrolling Interests). In connection with the sale, NEP recorded a gain of approximately $20 million ($18 million after tax) in the second quarter of 2022 and $10 million ($9 million after tax) in the third quarter of 2022 upon resolution of a contingency.
Disposal of Wind Project – In June 2022, NEP received notification from the offtaker of NEP's 62 megawatt (MW) wind project located in Barnes County, North Dakota of its intent to exercise an option to acquire the wind project for approximately $50 million. As such, the carrying amounts of the major classes of assets related to the wind project that were classified as held for sale, which are included in current other assets on NEP's consolidated balance sheets, were approximately $51 million at December 31, 2022 and primarily represent property, plant and equipment – net. Liabilities associated with assets held for sale, which are included in current other liabilities on NEP's consolidated balance sheets, were approximately $1 million at December 31, 2022. The sale closed in early January 2023.
3. Acquisitions
In May 2017, an indirect subsidiary of NEP completed the acquisition from NEER of Golden West Wind Holdings, LLC for approximately $238 million, plus working capital of $4 million and the assumption of $184 million in existing liabilities related to differential membership interests. Golden West Wind Holdings, LLC indirectly owns an approximately 249 MW wind generation facility located in Colorado.
In November 2017,December 2020, a subsidiary of NEP completed the acquisition from NEER (2020 acquisition) of (1) Javelina100% of the membership interests in Wilmot Energy Center, LLC (Wilmot) and 100% of the Class C membership interests in Pine Brooke Class A Holdings, LLC (Pine Brooke Holdings). Wilmot is an approximately 100 MW solar generation facility and 30 MW battery storage facility located in Arizona which entered service in the second quarter of 2021. The Class C membership interests in Pine Brooke Holdings represent an indirect 40% noncontrolling ownership interest in each of:
•Soldier Creek Wind, Funding, LLC, which indirectlya project company that owns an approximately 250300 MW wind generation facility located in Texas; (2) NokotaKansas;
•Ponderosa Wind, Holdings, LLC, which indirectlya project company that owns 2an approximately 200 MW wind generation facilities with a combined generating capacity of 299 MWfacility located in North Dakota;Oklahoma;
•Blue Summit III Wind, LLC, a project company that owns an approximately 200 MW wind generation facility located in Texas;
•Saint Solar, LLC, a project company that owns an approximately 100 MW solar generation facility located in Arizona;
•Taylor Creek Solar, LLC, a project company that owns an approximately 75 MW solar generation facility located in Florida;
•Harmony Florida Solar, LLC, a project company that owns an approximately 75 MW solar generation facility located in Florida; and (3)
•Sanford Airport Solar, LLC, a project company that owns an additional indirect approximately 26% interest49 MW solar generation facility located in Desert Sunlight Investment Holdings, LLC (Desert Sunlight), forMaine.
The purchase price consisted of cash consideration of approximately $812$374 million, plus working capital and other adjustments of $20approximately $4 million. The purchase price was allocated primarily to investment in equity method investees of approximately $223 million, property, plant and equipment – net of $137 million and intangible assets – PPAs – net of $18 million based on the assumption of $459 million in existing liabilities related to differential membership interests. NEER retained an interest in Desert Sunlight which owns 2 project entities, that together make up the Desert Sunlight Solar Energy Center, a 550 MW solar generation plant located in California, and remains the managing member.
The acquisitions from NEER in 2017 discussed above are collectively referred to as the common control acquisitions. The common control acquisitions were transfersfair value of assets between entities under common control, which require 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, NEP's consolidated financial statements were retrospectively adjusted to include the historical resultsacquired and financial position of the common control acquisitions prior to their respective acquisition dates.liabilities assumed.
In 2017, NEP and NEP GP implemented governance changes that, among other things, enhanced NEP unitholder governance rights. The new governance structure established a NEP board of directors whereby NEP unitholders have the ability to nominate and elect board members, subject to certain limitations and requirements, which elected board members commenced service in January 2018. As a result of these governance changes, beginning in January 2018, acquisitions from NEER are no longer treated as common control acquisitions.
In December 2018, aAugust 2021, an indirect subsidiary of NEP completed the acquisition from NEER(August 2021 acquisition) of NEP Renewables, which owns (1) Breckinridge Wind Class A100% of the ownership interests in each of:
•Highview Power Holdings, LLC, which indirectly owns an approximately 98 MW wind generation facility located in Oklahoma, (2) Carousel Wind Holdings, LLC, which indirectly owns an approximatelya 150 MW wind generation facility located in Colorado, (3) Monarch Wind Holdings,California;
•Brookfield Windstar Holding, LLC, which indirectly owns 2a 120 MW wind generation facilities with a combined generating capacity of approximately 450 MWfacility located in TexasCalifornia;
•Brookfield Coram Wind Development, LLC, which indirectly owns a 22 MW wind generation facility located in California; and Oklahoma, (4) Mountain View Solar
•BAIF Granite Holdings, LLC, which indirectly owns a 2099 MW solarwind generation facility located in Nevada, (5) Pacific Plains Wind Class A Holdings, LLC, which indirectly owns 3 wind generation facilities with a combined generating capacity of approximately 255 MW, located in Indiana, Nebraska and California and (6) Palomino Wind Holdings, LLC, which indirectly owns 3 wind generation facilities located in Kansas with a combined generating capacity of approximately 415 MW. New Hampshire.
The purchase price included a base purchase price of approximately $1,275$733 million, in cash consideration plus closing adjustments primarily related to pre-acquisition debt make whole costs of $55 million and working capital of $29$27 million, and included the assumptionincluding cash of approximately $941 million in existing noncontrolling interests related to differential membership interests and $38 million of existing debt. NEP incurred approximately $1 million in acquisition-related costs during the year ended December 31, 2018 which are reflected in other - net in NEP's consolidated statements of income (loss).$18 million.
Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on December 20, 2018 based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed, including the noncontrolling interests, were based on significant estimates and assumptions, including Level 3 (unobservable) inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The amount by which the total net identifiable assets at fair value exceeded the total consideration transferred is reflected in other - net in NEP's consolidated statements of income (loss) during the year ended December 31, 2018.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The following table summarizes the amounts recognized by NEP for the estimated fair value of assets acquired and liabilities assumed for the acquisition of NEP Renewables:
|
| | | |
| As of December 20, 2018 |
| (millions) |
| |
Total consideration transferred | $ | 1,304 |
|
Identifiable assets acquired and liabilities assumed | |
Cash | $ | 17 |
|
Accounts receivable and prepaid expenses | 25 |
|
Property, plant and equipment - net | 1,675 |
|
Intangible assets – PPAs | 610 |
|
Other non-current assets | 13 |
|
Accounts payable, accrued expenses and other current liabilities | (13 | ) |
Long-term debt, including current portion | (37 | ) |
Other non-current liabilities | (38 | ) |
Noncontrolling interests at fair value | (941 | ) |
Total net identifiable assets, at fair value | $ | 1,311 |
|
The amounts of the NEP Renewables' revenues, operating income, net income and net income attributable to NEP included in NEP’s consolidated statements of income for the period from December 20, 2018 through December 31, 2018 were not material.
In June 2019, an indirect subsidiary of NEP completed the acquisition from NEER (June 2019 acquisition) of the following:
100% of the membership interests in Ashtabula Wind II, LLC, a project company that owns a 120 MW wind generation facility located in North Dakota;
100% of the membership interests in Garden Wind, LLC, a project company that owns a 150 MW wind generation facility (Story County II) located in Iowa;
100% of the membership interests in White Oak Energy Holdings, LLC, which owns 100% of the membership interests of White Oak Energy LLC, which owns a 150 MW wind generation facility located in Illinois;
100% of the Class C membership interests in Rosmar Holdings, LLC (Rosmar), which represents a 49.99% noncontrolling ownership interest in 2 solar generation facilities, Marshall and Roswell, with a total combined generating capacity of approximately 132 MW located in Minnesota and New Mexico, respectively; and
49.99% of the membership interests, representing a controlling ownership interest, in Silver State South Solar, LLC (Silver State), which indirectly owns a 250 MW solar generation facility located in Nevada.
NEER retained ownership interests in Rosmar and Silver State and remains the managing member of Rosmar. Thus, NEP's interest in Rosmar is reflected within investments in equity method investees on the consolidated balance sheets. NEER's remaining interest in Silver State is reflected within noncontrolling interests on the consolidated balance sheets (see Note 2 - Noncontrolling Interests).
The purchase price included approximately $1,020 million in cash consideration, plus working capital of $12 million. Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed on June 11, 2019 based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed were based on significant estimates and assumptions, including Level 3 (unobservable) inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices.
The excess of the purchase price over the estimated fair value of assets acquired and liabilities assumed was recognized
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
as goodwill at the acquisition date. The goodwill arising from the acquisition results largely from the assets being well-situated in strong markets with long-term renewables demand, providing long-term optionality for the assets. All of the goodwill is expected to be deductible for income tax purposes over a 15 year period.
The following table summarizes the preliminaryfinal amounts recognized by NEP for the estimated fair value of assets acquired and liabilities assumed in the June 2019August 2021 acquisition:
| | | | | |
| (millions) |
Total consideration transferred | $ | 815 | |
Identifiable assets acquired and liabilities assumed | |
Cash | $ | 18 | |
Accounts receivable, inventory and prepaid expenses | 14 | |
Property, plant and equipment – net | 191 | |
Intangible assets – PPAs | 432 | |
Goodwill | 179 | |
Noncurrent other assets | 1 | |
Accounts payable, accrued expenses and current other liabilities | (8) | |
| |
Noncurrent other liabilities | (12) | |
| |
Total net identifiable assets, at fair value | $ | 815 | |
|
| | | |
| As of June 11, 2019 |
| (millions) |
Total consideration transferred | $ | 1,032 |
|
Identifiable assets acquired and liabilities assumed | |
Cash | $ | 4 |
|
Accounts receivable, other receivables and prepaid expenses | 159 |
|
Property, plant and equipment – net | 400 |
|
Intangible assets – PPAs | 1,080 |
|
Goodwill | 14 |
|
Other non-current assets | 133 |
|
Accounts payable, accrued expenses and other current liabilities | (132 | ) |
Other non-current liabilities | (154 | ) |
Noncontrolling interest | (472 | ) |
Total net identifiable assets, at fair value | $ | 1,032 |
|
During 2019, NEP recorded adjustments to the preliminary purchase price allocation based on a final valuation report which increased intangible assets - PPAs, goodwill and other non-current liabilities by approximately $30 million, $11 million and $1 million, respectively, and decreased property, plant and equipment - net and noncontrolling interests by $50 million and $10 million, respectively.
In November 2019, Meade Pipeline Investment, LLC (the Meade purchaser),October 2021, an indirect subsidiary of NEP completed the acquisition of allownership interests (October 2021 acquisition) in a portfolio of wind and solar generation facilities with a combined net generating capacity totaling approximately 589 MW from subsidiaries of NEER for a purchase price consisting of cash consideration of approximately $563 million, plus working capital and other adjustments of $22 million. NEP's share of the entities' debt and noncontrolling interests related to differential membership investors was approximately $270 million at the time of closing. The acquisition included the following assets:
•100% of the membership interests in HW CA Holdings, LLC, that indirectly owns an approximately 162 MW wind generation facility located in California;
•100% of the membership interests in Dogwood Wind Holdings, LLC, that indirectly owns two wind generation facilities with a combined total generating capacity of approximately 300 MW located in North Dakota and Missouri;
•100% of the membership interests in Southwest Solar Holdings, LLC, that indirectly owns an approximately 5 MW solar generation facility located in New Mexico;
•33.3% of the membership interests in Shaw Creek Solar Holdings, LLC, that indirectly owns an approximately 75 MW solar generation facility located in South Carolina;
•33.3% of the membership interests in Nutmeg Solar Holdings, LLC, that indirectly owns an approximately 20 MW solar generation facility located in Connecticut; and
•100% of the Class C membership interests (which represents 33.3% of the total ownership interest in the underlying projects) in Solar Holdings Portfolio 12, LLC, that has indirect ownership interests in:
◦two solar generation facilities with a combined total generating capacity of approximately 40 MW located in California;
◦the DG Portfolio 2019 portfolio, that indirectly owns multiple distributed solar generation facilities with a combined total generating capacity of approximately 217 MW located in various states across the U.S.; and
◦the DG Waipio portfolio, that indirectly owns multiple distributed solar generation facilities with a combined total generating capacity of approximately 13 MW located in Hawaii.
Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed, including noncontrolling interests, based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed were based on significant estimates and assumptions, including Level 3 (unobservable) inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The excess of the purchase price over the estimated fair value of assets acquired and liabilities assumed was recognized as goodwill at the acquisition date. The goodwill arising from the acquisition results largely from the assets being well-situated in strong markets with long-term renewables demand, providing long-term optionality for the assets. All of the goodwill is expected to be deductible for income tax purposes over a 15 year period.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The following table summarizes the final amounts recognized by NEP for the estimated fair value of assets acquired and liabilities assumed in the October 2021 acquisition:
| | | | | |
| (millions) |
Total consideration transferred | $ | 585 | |
Identifiable assets acquired and liabilities assumed | |
Cash | $ | 4 | |
Accounts receivable, inventory and prepaid expenses | 11 | |
Property, plant and equipment – net | 560 | |
Intangible assets – PPAs | 42 | |
Goodwill | 33 | |
Investments in equity method investees | 66 | |
Noncurrent other assets | 19 | |
Accounts payable, accrued expenses and current other liabilities | (8) | |
| |
Noncurrent other liabilities | (20) | |
Noncontrolling interests | (122) | |
Total net identifiable assets, at fair value | $ | 585 | |
In December 2021, an indirect subsidiary of NEP completed the asset acquisition of 100% of the Class A membership interests in Star Moon Holdings, LLC (Star Moon Holdings) for a total consideration of approximately $849 million, plus working capital and other adjustments of approximately $6 million and NEP's share of the entities' noncontrolling interests related to differential membership investors of approximately $910 million at the time of closing.
NEP’s indirect ownership interest in Star Moon Holdings represents an indirect 50% controlling ownership interest in wind generation facilities and solar generation facilities, some of which include solar storage, consisting of the following:
•White Mesa Wind, an approximately 501 MW wind generation facility located in Texas;
•Irish Creek Wind, an approximately 301 MW wind generation facility located in Kansas;
•Hubbard Wind, an approximately 300 MW wind generation facility located in Texas;
•Cool Springs Solar, an approximately 213 MW solar generation and 40 MW solar storage facility located in Georgia;
•Little Blue Wind, an approximately 251 MW wind generation facility located in Nebraska;
•Dodge Flat Solar, an approximately 200 MW solar generation and 50 MW solar storage facility located in Nevada;
•Elora Solar, an approximately 150 MW solar generation facility located in Tennessee;
•Quitman II Solar, an approximately 150 MW solar generation facility located in Georgia;
•Fish Springs Ranch Solar, an approximately 100 MW solar generation and 25 MW solar storage facility located in Nevada;
•Minco Wind Energy III, an approximately 107 MW wind generation facility located in Oklahoma;
•Ensign Wind Energy, an approximately 99 MW wind generation facility located in Kansas;
•Borderlands Wind, an approximately 99 MW wind generation facility located in New Mexico; and
•Quinebaug Solar, an approximately 49 MW solar generation facility located in Connecticut.
The wind and solar generation facilities listed above were under construction by NEER when the acquisition was announced. At closing, three projects (Dodge Flat Solar, Elora Solar and Fish Springs Ranch Solar) remained under construction and NEER agreed to continue to manage the construction of such projects after the acquisition, at its own cost, and to contribute to those projects any capital necessary for the construction of the projects. Construction of the three projects was completed and the projects entered service during the first quarter of 2022. In December 2021, NEER sold the remaining 50% noncontrolling ownership interest in the wind and solar generation facilities to a third party, which is reflected as noncontrolling interests on NEP's consolidated balance sheets (see Note 2 - Noncontrolling Interests). NEER will operate the wind and solar generation facilities under O&M and administrative service agreements (see Note 14).
The purchase price for the asset acquisition was allocated to the assets acquired and liabilities assumed, including the noncontrolling interests, based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed were based on significant estimates and assumptions, including Level 3 (unobservable) inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The individual fair value measurements were adjusted for any difference between the total purchase price and the total estimated fair value of assets acquired and liabilities assumed.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
In connection with the asset acquisition of Star Moon Holdings, NEP recorded the following balances:
| | | | | |
| (millions) |
Total consideration transferred | $ | 855 | |
Identifiable assets acquired and liabilities assumed | |
Cash | $ | 21 | |
Accounts receivable, inventory and prepaid expenses | 14 | |
Due from related parties(a) | 1,015 | |
Property, plant and equipment – net | 3,695 | |
Intangible assets – PPAs | 107 | |
Noncurrent other assets | 48 | |
Accounts payable, accrued expenses and current other liabilities(a) | (1,038) | |
Asset retirement obligation | (70) | |
Intangible liabilities | (179) | |
Noncurrent other liabilities | (65) | |
Redeemable noncontrolling interests(b) | (321) | |
Noncontrolling interests | (2,372) | |
Total net identifiable assets | $ | 855 | |
____________________
(a) Due from related parties reflects the amounts due from NEER which were used to pay accounts payable and accrued expenses related to the construction of the projects acquired.
(b) See Note 2 - Redeemable Noncontrolling Interests.
In December 2021, an indirect subsidiary of NEP completed the acquisition (Coram II acquisition) of a 102 MW wind generation facility (Coram II) located in California for cash consideration of approximately $128 million, plus working capital of $8 million and the assumption of debt of approximately $155 million. Under the acquisition method, the purchase price was allocated to the assets acquired and liabilities assumed based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed were based on significant estimates and assumptions, including Level 3 (unobservable) inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The purchase price was allocated primarily to intangible assets – PPAs – net of approximately $133 million, property, plant and equipment – net of $72 million, long-term debt, including current portion, of $155 million and noncurrent other assets of $11 million. The excess of the purchase price over the estimated fair value of assets acquired and liabilities assumed was recognized as goodwill of approximately $70 million at the acquisition date. The goodwill arising from the acquisition results largely from the wind generation facility being well-situated in a strong market with long-term renewables demand, providing long-term optionality for the asset. All of the goodwill is expected to be deductible for income tax purposes over a 15 year period.
During 2021, NEP incurred approximately $12 million in acquisition-related costs which are reflected as operations and maintenance in the consolidated statements of income.
The amounts of revenues, operating income, net income and net income attributable to NEP included in NEP's consolidated statements of income related to the August 2021 acquisition, the October 2021 acquisition and the Coram II acquisition for the periods after the respective closings through December 31, 2021 are as follows:
| | | | | |
| (millions) |
Revenues | $ | 25 | |
Operating income | $ | 1 | |
Net income | $ | — | |
Net income attributable to NEP | $ | 3 | |
In September 2022, an indirect subsidiary of NEP acquired from NEER interests in Sunlight Renewables Holdings which represent an indirect 67% controlling ownership interest in a battery storage facility in California with storage capacity of 230 MW. The purchase price for the asset acquisition consisted of cash consideration of approximately $191 million, plus working capital and other adjustments of $2 million. The purchase price was allocated primarily to property, plant and equipment – net of approximately $435 million and noncontrolling interests of $242 million, including $147 million relating to differential membership interests, based on the fair value of assets acquired and liabilities assumed. NEER operates the battery storage facility under O&M and administrative service agreements (see Note 14).
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
In December 2022, an indirect subsidiary of NEP (the purchaser) completed the acquisition of ownership interests (December 2022 acquisition) in a portfolio of wind and solar-plus-storage generation facilities from subsidiaries of NEER (the seller) consisting of the following:
•100% of the Class A membership interests in Emerald Breeze, representing a 49% controlling ownership interest, which indirectly owns:
•Great Prairie Wind, an approximately 1,029 MW wind generation facility in Texas and Oklahoma.
•Appaloosa Run Wind, an approximately 172 MW wind generation facility in Texas.
•Yellow Pine Solar, a 125 MW solar generation and 65 MW storage facility in Nevada (Yellow Pine).
•100% of the membership interests in Sac County Wind Holdings, LLC and Elk City Sholes Holdings, LLC, which indirectly own:
•Sholes Wind, an approximately 160 MW wind generation facility located in Nebraska.
•Elk City Wind II, an approximately 107 MW wind generation facility located in Oklahoma.
•Sac County Wind, an approximately 80 MW wind generation facility located in Iowa.
Yellow Pine is currently under construction by NEER and NEER has agreed to continue to manage the construction of the project after acquisition, at its own cost, and to contribute to the project any capital necessary for the construction of the project. If Yellow Pine does not achieve commercial operation by November 30, 2023, the purchaser will have the right to require the seller to repurchase the ownership interests in Meade Pipeline Co LLC (Meade), which ownsthe project for the same purchase price paid by the purchaser. Upon receipt of certain regulatory approvals and achievement of commercial operations, Eight Point Wind, an approximately 39.2% aggregate ownership interest111 MW wind generation facility in New York, will be transferred to Emerald Breeze, which transfer is expected to happen in the Central Penn Line (CPL), a 185-mile natural gas pipeline that operates in Pennsylvania, and a 40% ownership interest in an expansion projectfirst quarter of the gas pipeline. 2023. See Note 13 - Class B Noncontrolling Interests.
The purchase price included cashtotal consideration of $1,280 million.approximately $805 million, plus working capital and other adjustments of approximately $8 million (subject to certain post-closing adjustments) and NEP's share of the portfolio’s existing noncontrolling interests related to differential membership investors of approximately $1.4 billion at the time of closing.
The purchase price for the asset acquisition was allocated to the assets acquired and liabilities assumed, including the noncontrolling interests, based on their estimated fair value. All fair value measurements of assets acquired and liabilities assumed were based on significant estimates and assumptions, including Level 3 (unobservable) inputs, which require judgment. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows and future market prices. The individual fair value measurements were adjusted for any difference between the total purchase price and the total estimated fair value of assets acquired and liabilities assumed.
In connection with the December 2022 asset acquisition, NEP recorded an investment in equity method investee of approximately $1,296 million after adjusting for working capital, other closing itemsthe following balances:
| | | | | |
| (millions) |
Total consideration transferred | $ | 813 | |
Identifiable assets acquired and liabilities assumed | |
Cash | $ | 14 | |
Accounts receivable, inventory and prepaid expenses | 12 | |
Due from related parties(a) | 836 | |
Current other assets(b) | 118 | |
Property, plant and equipment – net | 3,503 | |
| |
Noncurrent other assets | 16 | |
Accounts payable, accrued expenses and current other liabilities(a) | (771) | |
Due to related parties(c) | (80) | |
Long-term debt(d) | (46) | |
Asset retirement obligation | (27) | |
Intangible liabilities | (986) | |
Noncurrent other liabilities | (6) | |
| |
Noncontrolling interests | (1,770) | |
Total net identifiable assets | $ | 813 | |
____________________
(a) Due from related parties reflects the amounts due from NEER which will be used to pay accounts payable and direct acquisition costs. In addition, NEP expects to fund approximately $90 million of estimated future capital expendituresaccrued expenses related to the expansion project. NEP's indirect ownership interest in Meade, including Meade's ownership interestsconstruction of the projects acquired.
(b) Includes approximately $71 million deposit relating to Eight Point Wind which is expected to be transferred to Emerald Breeze in the CPL and thefirst quarter of 2023 as discussed above.
(c) Due to related expansion project, is reflected as investment in equity method investees.parties reflects amounts due to a NEE subsidiary related to construction costs, which costs are reimbursed by NEER.
(d) See Note 9.14 - Related Party Long-Term Debt.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Supplemental Unaudited Pro forma Results of Operations
NEP’s pro forma results of operations in the combined entity had the December 2018August 2021 acquisition, of NEP Renewablesthe October 2021 acquisition and the Coram II acquisition been completed on January 1, 20172020 are as follows:
| | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2021 | | 2020 | | | | |
| (millions) |
Unaudited pro forma results of operations: | | | | | | | |
Pro forma revenues | $ | 1,068 | | | $ | 1,028 | | | | | |
Pro forma operating income | $ | 248 | | | $ | 268 | | | | | |
Pro forma net income (loss) | $ | 412 | | | $ | (256) | | | | | |
Pro forma net income (loss) attributable to NEP | $ | 143 | | | $ | (48) | | | | | |
|
| | | | | | | |
| Years Ended December 31, |
| 2018 | | 2017 |
| (millions) |
Unaudited pro forma results of operations: | | | |
Pro forma revenues | $ | 878 |
| | $ | 892 |
|
Pro forma operating income | $ | 456 |
| | $ | 316 |
|
Pro forma net income | $ | 254 |
| | $ | 178 |
|
Pro forma net income (loss) attributable to NEP | $ | 219 |
| | $ | (62 | ) |
The unaudited pro forma consolidated results of operations include adjustments to:
•reflect the historical results of NEP Renewablesthe businesses acquired beginning on January 1, 2017;2020 assuming consistent operating performance over all periods;
•reflect the estimated depreciation and amortization expense based on the estimated fair value of property, plant and equipment -– net and the intangible assets -– PPAs;
•reflect allocations of income to noncontrolling interestsassumed interest expense related to funding the financing transaction to fund the acquisition;acquisitions; and
•reflect related income tax effects.
The unaudited pro forma information is not necessarily indicative of the results of operations that would have occurred had the transactiontransactions been made at the beginning of the periods presented or the future results of the consolidated operations.
4. Revenue
4. Revenue
Revenue is recognized when control of the promised goods or services is transferred to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. NEP's operating revenues are
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
generated primarily from various non-affiliated parties under PPAs and natural gas transportation agreements. NEP's operating revenues from contracts with customers are partly offset by the net amortization of intangible assets -asset – PPAs and intangible liabilities – PPAs. Revenue is recognized as energy and any related renewable energy attributes are delivered, based on rates stipulated in the respective PPAs, or natural gas transportation services are performed. NEP believes that the obligation to deliver energy and provide the natural gas transportation services is satisfied over time as the customer simultaneously receives and consumes benefits provided by NEP. In addition, NEP believes that the obligation to deliver renewable energy attributes is satisfied at multiple points in time, with the control of the renewable energy attribute being transferred at the same time the related energy is delivered. Included in NEP’s operating revenues for the years ended December 31, 20192022, 2021 and 20182020 is revenue from contracts with customers for renewable energy sales of approximately $624$941 million, $704 million and $513$684 million, respectively, and revenue from contracts with customers for natural gas transportation services of $207$241 million, $237 million and $215$212 million, respectively. NEP's accounts receivable are primarily associated with revenues earned from contracts with customers. Receivables represent unconditional rights to consideration and reflect the differences in timing of revenue recognition and cash collections. For substantially all of NEP's receivables, regardless of the type of revenue transaction from which the receivable originated, customer and counterparty credit risk is managed in the same manner and the terms and conditions of payment are similar.
NEP recognizes revenues as energy and any related renewable energy attributes are delivered or natural gas transportation services are performed, consistent with the amounts billed to customers based on rates stipulated in the respective PPAs.agreements. NEP considers the amount billed to represent the value of energy delivered or services provided to the customer. NEP’s customers typically receive bills monthly with payment due within 30 days.
The contracts with customers related to pipeline service revenues contain a fixed price related to firm natural gas transportation capacity with maturity dates ranging from 20202023 to 2035. At December 31, 2019,2022, NEP expects to record approximately $2.1$1.6 billion of revenues over the remaining terms of the related contracts as the capacity is provided. Revenues yet to be earned under contracts with customers to deliver energy and any related energy attributes, which have maturity dates ranging from 20302025 to 2046,2052, will vary based on the volume of energy delivered. At December 31, 2019,2022, NEP expects to record approximately $212$180 million of revenues related to the fixed price components of one PPA through 2039 as the energy is delivered.
5. Income Taxes
On December 22, 2017, the Tax Cuts and Jobs Act (tax reform) was signed into law which, among other things, reduced the federal corporate income tax rate from 35% to 21% effective January 1, 2018. As a result, NEP performed an analysis to preliminarily revalue its deferred income taxes and included an estimate of changes in the balances in NEP's December 31, 2017 financial statements. At December 31, 2017, the revaluation reduced NEP’s net deferred income tax assets by approximately $100 million, which decreased NEP’s 2017 net income and net income attributable to NEP. At December 31, 2018, NEP had completed the accounting for all of the enactment-date income tax effects of tax reform resulting in no material adjustments in 2018 to the initial provisional amounts recorded. The U.S. Department of Treasury has also released proposed regulations related to the business interest expense limitations and foreign tax credits associated with tax reform. These proposed regulations are not final and are subject to change in the regulatory review process.
The components of income (loss) before income taxes are as follows:
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
U.S. | $ | (430 | ) | | $ | 62 |
| | $ | 213 |
|
Foreign | — |
| | 211 |
| | 68 |
|
Income (loss) before income taxes | $ | (430 | ) | | $ | 273 |
| | $ | 281 |
|
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
5. Derivative Instruments and Hedging Activity
The componentsNEP uses derivative instruments (primarily interest rate swaps) to manage the interest rate cash flow risk associated with outstanding and expected future debt issuances and borrowings and to manage the physical and financial risks inherent in the sale of electricity. NEP records all derivative instruments that are required to be marked to market as either assets or liabilities on its consolidated balance sheets and measures them at fair value each reporting period. NEP does not utilize hedge accounting for its derivative instruments. All changes in the interest rate contract derivatives' fair value are recognized in interest expense and the equity method investees' related activity is recognized in equity in earnings of equity method investees in NEP's consolidated statements of income tax expense (benefit) are as follows:
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
Federal: | | | | | |
Current | $ | — |
| | $ | 4 |
| | $ | — |
|
Deferred | (20 | ) | | 47 |
| | 143 |
|
Total federal | (20 | ) | | 51 |
| | 143 |
|
State: | | | | | |
Current | — |
| | (21 | ) | | — |
|
Deferred | (6 | ) | | 33 |
| | 8 |
|
Total state | (6 | ) | | 12 |
| | 8 |
|
Foreign: | | | | | |
Current | — |
| | — |
| | 5 |
|
Deferred | — |
| | (57 | ) | | 11 |
|
Total foreign | — |
| | (57 | ) | | 16 |
|
Total income tax expense (benefit) | $ | (26 | ) | | $ | 6 |
| | $ | 167 |
|
A reconciliation of U.S. federal income tax at the statutory rate to the actual income taxes is as follows:
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
Income tax expense (benefit) at U.S. statutory rate of 21%, 21% and 35%, respectively | $ | (90 | ) | | $ | 57 |
| | $ | 98 |
|
Increases (reductions) resulting from: | | | | | |
Taxes attributable to noncontrolling interests | 70 |
| | (17 | ) | | (32 | ) |
Tax reform impact on differential membership interests | — |
| | 17 |
| | — |
|
State income taxes, net of federal tax benefit | (5 | ) | | 10 |
| | 6 |
|
Tax credits | (2 | ) | | (1 | ) | | (1 | ) |
Valuation allowance | — |
| | — |
| | (1 | ) |
Effect of flow through entities and foreign tax differential | — |
| | 3 |
| | (7 | ) |
U.S. taxes on foreign earnings | — |
| | 3 |
| | 7 |
|
Impact of tax reform | — |
| | — |
| | 100 |
|
Adjustments associated with Canadian assets | — |
| | (67 | ) | | — |
|
Other | 1 |
| | 1 |
| | (3 | ) |
Income tax expense (benefit) | $ | (26 | ) | | $ | 6 |
| | $ | 167 |
|
The effective tax rate was approximately 6%, 2% and 59% for the years ended December 31, 2019, 2018 and 2017, respectively.
Deferred income taxes reflect the net tax effects of temporary differences between the carrying amount of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. These items are stated at the enacted tax rates that are expected to be in effect when taxes are actually paid or recovered. NEP believes that it is more likely than not that the deferred tax assets at December 31, 2019 shown in the table below, net of the valuation allowances, will be realized due to sufficient future income.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The income tax effects of temporary differences giving rise to NEP's deferred income tax liabilities and assets are as follows:
|
| | | | | | | |
| December 31, |
| 2019 | | 2018 |
| (millions) |
Deferred tax liabilities: | | | |
Investment in partnership(a) | $ | (98 | ) | | $ | (133 | ) |
Total deferred tax liabilities | (98 | ) | | (133 | ) |
Deferred tax asset: | | | |
Net operating loss | 256 |
| | 228 |
|
Tax credit carryforwards | 6 |
| | 3 |
|
Valuation allowance | (2 | ) | | (2 | ) |
Total deferred tax asset | 260 |
| | 229 |
|
Net deferred tax asset | $ | 162 |
| | $ | 96 |
|
____________________
(a)(loss). At December 31, 2019, includes a deferred tax asset2022 and 2021, the net notional amounts of the interest rate contracts were approximately $7,836 million and $7,873 million, respectively. All changes in commodity contract derivatives' fair value are recognized in operating revenues in NEP's consolidated statements of income (loss). At December 31, 2022, NEP had derivative commodity contracts for power with net notional volumes of approximately $175.7 million ofMW hours. Cash flows from the interest limitation carryforward with an indefinite expiration period.
Deferred tax assetsrate and liabilities included oncommodity contracts are reported in cash flows from operating activities in NEP's consolidated balance sheets are as follows:statements of cash flows.
|
| | | | | | | |
| December 31, |
| 2019 | | 2018 |
| (millions) |
Deferred income taxes - assets | $ | 172 |
| | $ | 108 |
|
Other non-current liabilities | (10 | ) | | (12 | ) |
Net deferred income taxes | $ | 162 |
| | $ | 96 |
|
The components of deferred tax assets, before valuation allowance, relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2019 are as follows:
|
| | | | | |
| Amount | | Expiration Dates |
| (millions) | | |
Net operating loss carryforwards: | | | |
Federal | $ | 233 |
| | 2034 - 2037 |
State | 23 |
| | 2034 - 2039 |
Total net operating loss carryforwards | $ | 256 |
| (a) | |
Tax credit carryforwards | $ | 6 |
| | 2020 - 2039 |
____________________
(a) Includes approximately $79 million of net operating loss carryforwards with an indefinite expiration period.
The open tax years in all jurisdictions are 2014 through 2018.
6. Fair Value MeasurementsMeasurement of Derivative Instruments
– 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 and/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 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. Transfers between fair value hierarchy levels occur at the beginning of the period in which the transfer occurred.
Cash Equivalents and Restricted Cash Equivalents - The fair value of money market funds that are included in cash and cash equivalents, other current assets and other non-current assets on NEP's consolidated balance sheets is estimated using a market approach based on current observable market prices.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Interest Rate Contracts -NEP estimates the fair value of its derivativesderivative instruments using an income approach based on a discounted cash flows valuation technique utilizing 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 and credit profiles. The significant inputs for the resulting fair value measurement of interest rate contracts 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:
|
| | | | | | | | | | | | | | | | | | | | | | | |
| December 31, 2019 | | December 31, 2018 |
| Level 1 | | Level 2 | | Total | | Level 1 | | Level 2 | | Total |
| (millions) |
Assets: | | | | | | | | | | | |
Cash equivalents | $ | 16 |
| | $ | — |
| | $ | 16 |
| | $ | 71 |
| | $ | — |
| | $ | 71 |
|
Restricted cash equivalents(a) | — |
| | — |
| | — |
| | 12 |
| | — |
| | 12 |
|
Interest rate contracts | — |
| | 9 |
| | 9 |
| | — |
| | 24 |
| | 24 |
|
Total assets | $ | 16 |
| | $ | 9 |
| | $ | 25 |
| | $ | 83 |
| | $ | 24 |
| | $ | 107 |
|
Liabilities: | | | | | | | | | | | |
Interest rate contracts | $ | — |
| | $ | 427 |
| | $ | 427 |
| | $ | — |
| | $ | 116 |
| | $ | 116 |
|
Total liabilities | $ | — |
| | $ | 427 |
| | $ | 427 |
| | $ | — |
| | $ | 116 |
| | $ | 116 |
|
____________________
| |
(a) | At December 31, 2018, approximately $9 million of restricted cash equivalents are included in other non-current assets on NEP's consolidated balance sheets. |
Financial Instruments Recorded at Other than Fair Value - The carrying amounts and estimated fair values of other financial instruments recorded at other than fair value are as follows:
|
| | | | | | | | | | | | | | | |
| December 31, 2019 | | December 31, 2018 |
| Carrying Value | | Fair Value | | Carrying Value | | Fair Value |
| (millions) |
Long-term debt, including current maturities(a) | $ | 4,144 |
| | $ | 4,235 |
| | $ | 3,435 |
| | $ | 3,301 |
|
____________________
| |
(a) | At December 31, 2019 and December 31, 2018, approximately $4,211 million and $2,826 million respectively, of the fair value is estimated using a market approach based on quoted market prices for the same or similar issues (Level 2); the balance is estimated using an income approach utilizing a discounted cash flow valuation technique, considering the current credit profile of the debtor (Level 3). |
7. Derivative Instruments and Hedging Activity
NEP uses derivative instruments (primarily interest rate swaps) to manage the interest rate cash flow risk associated with outstanding and expected future debt issuances and borrowings. NEP records all derivative instruments that are required to be marked to market as either assets or liabilities on its consolidated balance sheets and measures them at fair value each reporting period. NEP does not utilize hedge accounting for its derivatives. All changes in the derivatives' fair value are recognized in interest expense in NEP's consolidated statements of income (loss). At December 31, 2019 and 2018, the net notional amounts of the interest rate contracts were approximately $6,859 million and $7,056 million, respectively.
During 2019, NEP reclassified approximately $6 million from AOCI to interest expense primarily because the related future transactions being hedged were no longer going to occur. At December 31, 2019, NEP's AOCI does not include any amounts related to discontinued cash flow hedges. Cash flows from the interest rate swap contracts are reported in cash flows from operating activities in NEP's consolidated statements of cash flows.
Prior to the sale of Canadian Holdings, NEP entered into certain foreign currency exchange contracts to economically hedge its cash flows from foreign currency rate fluctuations. During 2018 and 2017, NEP recorded approximately $13 million of gains and $4 million of losses, respectively, related to the foreign currency contracts in other - net in NEP's consolidated statements of income (loss).
Fair Value of Derivative Instruments - The tables below present NEP's gross derivative positions, based on the total fair value of each derivative instrument, at December 31, 20192022 and 2018,2021, as required by disclosure rules, as well as the location of the net derivative positions, based on the expected timing of future payments, on NEP's consolidated balance sheets.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | December 31, 2022 |
| | Level 1 | | Level 2 | | Level 3 | | Netting(a) | | Total |
| | (millions) |
Assets: | | | | | | | | | | |
Interest rate contracts | | $ | — | | | $ | 459 | | | $ | — | | | $ | (26) | | | $ | 433 | |
Commodity contracts | | $ | — | | | $ | — | | | $ | 3 | | | $ | (2) | | | 1 | |
Total derivative assets | | | | | | | | | | $ | 434 | |
Liabilities: | | | | | | | | | | |
Interest rate contracts | | $ | — | | | $ | 37 | | | $ | — | | | $ | (26) | | | $ | 11 | |
Commodity contracts | | $ | — | | | $ | — | | | $ | 5 | | | $ | (2) | | | 3 | |
Total derivative liabilities | | | | | | | | | | $ | 14 | |
| | | | | | | | | | |
Net fair value by balance sheet line item: | | | | | | | | | | |
Current derivative assets | | | | | | | | | | $ | 65 | |
Noncurrent derivative assets | | | | | | | | | | 369 | |
Total derivative assets | | | | | | | | | | $ | 434 | |
| | | | | | | | | | |
Current derivative liabilities | | | | | | | | | | $ | 12 | |
Noncurrent derivative liabilities | | | | | | | | | | 2 | |
Total derivative liabilities | | | | | | | | | | $ | 14 | |
| | | | | | | | | | |
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | December 31, 2021 |
| | | | | |
| | Level 1 | | Level 2 | | Level 3 | | Netting(a) | | Total |
| | (millions) |
Assets: | | | | | | | | | | |
Interest rate contracts | | $ | — | | | $ | 17 | | | $ | — | | | $ | (10) | | | $ | 7 | |
Liabilities: | | | | | | | | | | |
Interest rate contracts | | $ | — | | | $ | 631 | | | $ | — | | | $ | (10) | | | $ | 621 | |
| | | | | | | | | | |
Net fair value by balance sheet line item: | | | | | | | | | | |
Current derivative assets | | | | | | | | | | $ | — | |
Noncurrent derivative assets | | | | | | | | | | 7 | |
Total derivative assets | | | | | | | | | | $ | 7 | |
| | | | | | | | | | |
Current derivative liabilities | | | | | | | | | | $ | 26 | |
Noncurrent derivative liabilities | | | | | | | | | | 595 | |
Total derivative liabilities | | | | | | | | | | $ | 621 | |
|
| | | | | | | | | | | | | | | | |
| December 31, 2019 |
| | Gross Basis | | Net Basis |
| | Assets | | Liabilities | | Assets | | Liabilities |
| (millions) |
Interest rate contracts | | $ | 9 |
| | $ | 427 |
| | $ | — |
| | $ | 418 |
|
| | | | | | | | |
Net fair value by balance sheet line item: | | | | | | | | |
Other current assets | | | | | | $ | — |
| | |
Other non-current assets | | | | | | — |
| | |
Other current liabilities | | | | | | | | $ | 1 |
|
Derivatives | | | | | | | | 417 |
|
Total derivatives | | | | | | $ | — |
| | $ | 418 |
|
(a)Includes the effect of the contractual ability to settle contracts under master netting arrangements.
|
| | | | | | | | | | | | | | | | |
| December 31, 2018 |
| | Gross Basis | | Net Basis |
| | Assets | | Liabilities | | Assets | | Liabilities |
| (millions) |
Interest rate contracts | | $ | 24 |
| | $ | 116 |
| | $ | 13 |
| | $ | 105 |
|
| | | | | | | | |
Net fair value by balance sheet line item: | | | | | | | | |
Other current assets | | | | | | $ | 7 |
| | |
Other non-current assets | | | | | | 6 |
| | |
Other current liabilities | | | | | | | | $ | 1 |
|
Derivatives | | | | | | | | 104 |
|
Total derivatives | | | | | | $ | 13 |
| | $ | 105 |
|
Financial Statement Impact of Derivative Instruments -– Gains (losses) related to NEP's interest rate contractsderivatives are recorded in NEP's consolidated financial statements as follows:
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
| (millions) |
| |
| | | | | |
| | | | | |
Interest rate contracts – interest expense | $ | 1,033 | | | $ | 168 | | | $ | (395) | |
Commodity contracts – operating revenues | $ | 2 | | | $ | — | | | $ | — | |
|
| | | | | | | | | | | |
| Years Ended December 31, |
| 2019 | | 2018 | | 2017 |
| (millions) |
Interest rate contracts: | |
Gains (losses) reclassified from AOCI to interest expense | $ | 5 |
| | $ | (3 | ) | | $ | (7 | ) |
Losses recognized in interest expense | $ | (373 | ) | | $ | (58 | ) | | $ | (14 | ) |
Credit-Risk-Related Contingent Features -– Certain of NEP's derivative instruments contain credit-related cross-default and material adverse change triggers, none of which contain requirements to maintain certain credit ratings or financial ratios. At December 31, 20192022 and 2018,2021, the aggregate fair value of NEP's derivative instruments with credit-risk-related contingent risk features that were in a liability position was approximately $420$37 million and $108$608 million, respectively.
6. Non-Derivative Fair Value Measurements
Non-derivative fair value measurements consist of NEP's cash equivalents. The fair value of these financial assets is determined using the valuation techniques and inputs as described in Note 5 – Fair Value Measurements of Derivative Instruments. The fair value of money market funds that are included in cash and cash equivalents, current other assets and noncurrent other assets on NEP's consolidated balance sheets is estimated using a market approach based on current observable market prices.
Recurring Non-Derivative Fair Value Measurements – NEP’s financial assets and liabilities and other fair value measurements made on a recurring basis by fair value hierarchy level are as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| December 31, 2022 | | December 31, 2021 |
| Level 1 | | Level 2 | | Total | | Level 1 | | Level 2 | | Total |
| (millions) |
Assets: | | | | | | | | | | | |
Cash equivalents | $ | 5 | | | $ | — | | | $ | 5 | | | $ | 3 | | | $ | — | | | $ | 3 | |
| | | | | | | | | | | |
Total assets | $ | 5 | | | $ | — | | | $ | 5 | | | $ | 3 | | | $ | — | | | $ | 3 | |
| | | | | | | | | | | |
| | | | | | | | | | | |
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Financial Instruments Recorded at Other than Fair Value – The carrying amounts and estimated fair values of other financial instruments recorded at other than fair value are as follows:
| | | | | | | | | | | | | | | | | | | | | | | |
| December 31, 2022 | | December 31, 2021 |
| Carrying Value | | Fair Value | | Carrying Value | | Fair Value |
| (millions) |
Long-term debt, including current maturities(a) | $ | 5,288 | | | $ | 5,105 | | | $ | 5,327 | | | $ | 5,529 | |
____________________
(a)At December 31, 2022 and December 31, 2021, approximately $5,086 million and $5,506 million, respectively, of the fair value is estimated using a market approach based on quoted market prices for the same or similar issues (Level 2); the balance is estimated using an income approach utilizing a discounted cash flow valuation technique, considering the current credit profile of the debtor (Level 3). At December 31, 2022 and 2021, approximately $1,510 million and $1,188 million, respectively, of the fair value relates to the 2020 convertible notes, the 2021 convertible notes and, in 2022, the 2022 convertible notes and is estimated using Level 2.
7. Income Taxes
On August 16, 2022, the Inflation Reduction Act was signed into law which includes: (i) extensions for wind and solar tax credits on facilities that start construction before the later of 2034 or the end of the calendar year following the year in which greenhouse gas emissions from U.S. electric generation are reduced by 75% from 2022 levels; (ii) a new solar PTC and standalone battery ITC; (iii) the ability to transfer renewable energy tax credits to an unrelated transferee; and (iv) a 15% corporate profits minimum tax based on pre-tax income for years after 2022. This legislation does not require NEP to revalue its deferred income taxes given that there was no change to the corporate tax rate.
The components of income tax expense (benefit) are as follows:
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
| (millions) |
Federal: | | | | | |
Current | $ | — | | | $ | 1 | | | $ | 5 | |
Deferred | 127 | | | 32 | | | (21) | |
Total federal | 127 | | | 33 | | | (16) | |
State: | | | | | |
Current | — | | | 1 | | | 2 | |
Deferred | 44 | | | 14 | | | (5) | |
Total state | 44 | | | 15 | | | (3) | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
Total income tax expense (benefit) | $ | 171 | | | $ | 48 | | | $ | (19) | |
A reconciliation of U.S. federal income tax at the statutory rate to the actual income taxes is as follows:
| | | | | | | | | | | | | | | | | |
| Years Ended December 31, |
| 2022 | | 2021 | | 2020 |
| (millions) |
Income tax expense (benefit) at U.S. statutory rate of 21% | $ | 271 | | | $ | 99 | | | $ | (54) | |
Increases (reductions) resulting from: | | | | | |
Taxes attributable to noncontrolling interests | (135) | | | (59) | | | 41 | |
| | | | | |
State income taxes, net of federal tax benefit | 35 | | | 12 | | | (3) | |
Tax credits | (2) | | | (2) | | | (3) | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
Other | 2 | | | (2) | | | — | |
Income tax expense (benefit) | $ | 171 | | | $ | 48 | | | $ | (19) | |
The effective tax rate was approximately 13%, 10% and 7% for the years ended December 31, 2022, 2021 and 2020, respectively.
Deferred income taxes reflect the net tax effects of temporary differences between the carrying amount of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. These items are stated at the enacted tax rates that are expected to be in effect when taxes are actually paid or recovered. NEP believes that it is more likely than not that the deferred tax assets at December 31, 2022 shown in the table below, net of the valuation allowances, will be realized due to sufficient future income.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The income tax effects of temporary differences giving rise to NEP's deferred income tax liabilities and assets are as follows:
| | | | | | | | | | | |
| December 31, |
| 2022 | | 2021 |
| (millions) |
Deferred tax liabilities: | | | |
| | | |
Investment in partnership(a) | $ | (199) | | | $ | — | |
| | | |
| | | |
Total deferred tax liabilities | (199) | | | — | |
Deferred tax assets: | | | |
Net operating loss carryforwards | 363 | | | 284 | |
Investment in partnership(a) | — | | | 23 | |
| | | |
Tax credit carryforwards | 15 | | | 13 | |
| | | |
| | | |
| | | |
| | | |
Valuation allowance | (4) | | | (4) | |
Total deferred tax assets | 374 | | | 316 | |
Net deferred income taxes | $ | 175 | | | $ | 316 | |
____________________
(a) At December 31, 2022 and 2021, includes a deferred tax asset of approximately $18 million and $4 million, respectively, of interest limitation carryforward with an indefinite expiration period.
Deferred tax assets and liabilities included on NEP's consolidated balance sheets are as follows:
| | | | | | | | | | | |
| December 31, |
| 2022 | | 2021 |
| (millions) |
| | | |
Deferred income taxes – noncurrent assets | $ | 195 | | | $ | 322 | |
| | | |
Noncurrent other liabilities | (20) | | | (6) | |
Net deferred income taxes | $ | 175 | | | $ | 316 | |
The components of deferred tax assets, before valuation allowance, relating to net operating loss carryforwards and tax credit carryforwards at December 31, 2022 are as follows:
| | | | | | | | | | | |
| Amount | | Expiration Dates |
| (millions) | | |
Net operating loss carryforwards: | | | |
Federal | $ | 322 | | | 2034 – 2037 |
State | 41 | | | 2028 – 2042 |
| | | |
Total net operating loss carryforwards | $ | 363 | | (a) | |
Tax credit carryforwards | $ | 15 | | | 2023 – 2042 |
____________________
(a) Includes approximately $177 million and $5 million of federal and state, respectively, net operating loss carryforwards with an indefinite expiration period.
During 2022 and 2021, NEP recorded state tax liabilities of approximately $1 million and $1 million (net of federal tax benefit), respectively, related to unrecognized tax benefits of prior year state tax filing positions. The total amount of unrecognized tax benefit that, if recognized, would affect the effective tax rate is approximately $5 million (net of federal tax benefit). The open tax years in all jurisdictions are 2014 through 2021.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
8. Property, Plant and Equipment
Property, plant and equipment consists of the following at December 31:
| | | | | | | | | | | | | | | | | |
| 2022 | | 2021 | | Range of Useful Lives (in years) |
| (millions) | | |
Power-generation assets(a) | $ | 14,639 | | | $ | 10,439 | | | 3 – 35 |
Pipeline assets, including temporary rights-of-way | 877 | | | 957 | | | 25 – 50 |
Land improvements and buildings | 611 | | | 525 | | | 3 – 45 |
Land, including perpetual rights-of-way | 81 | | | 102 | | | |
Construction work in progress | 404 | | | 736 | | | |
Other depreciable assets | 427 | | | 365 | | | 3 – 35 |
Property, plant and equipment, gross | 17,039 | | | 13,124 | | | |
Accumulated depreciation | (2,090) | | | (1,707) | | | |
Property, plant and equipment – net | $ | 14,949 | | | $ | 11,417 | | | |
|
| | | | | | | | | |
| 2019 | | 2018 | | Range of Useful Lives (in years) |
| (millions) | | |
Power-generation assets(a) | $ | 6,553 |
| | $ | 6,262 |
| | 3 - 35 |
Pipeline assets, including temporary rights-of-way | 813 |
| | 810 |
| | 25 - 50 |
Land improvements and buildings | 385 |
| | 362 |
| | 7 - 35 |
Land, including perpetual rights-of-way | 60 |
| | 60 |
| | |
Construction work in progress | 80 |
| | 5 |
| | |
Other depreciable assets | 279 |
| | 237 |
| | 3 - 35 |
Property, plant and equipment, gross | 8,170 |
| | 7,736 |
| | |
Accumulated depreciation | (1,200 | ) | | (966 | ) | | |
Property, plant and equipment - net | $ | 6,970 |
| | $ | 6,770 |
| | |
________________________(a) Approximately 92% of power generation assets represent machinery and equipment used to generate electricity with a 35-year depreciable life.
___________________________
| |
(a) | Approximately 87% of power generation assets represent machinery and equipment used to generate electricity with a 35-year depreciable life. |
Depreciation expense for the years ended December 31, 2019, 20182022, 2021 and 20172020 was approximately $236$400 million, $199$263 million and $204$247 million, respectively. A number of NEP's generation and pipeline facilities are encumbered by liens securing various financings. The net book value of NEP's assets serving as collateral was approximately $3.6$5.1 billion at December 31, 20192022.
9. Equity Method Investments
At December 31, 2019,2022, investments in equity method investees primarily includes the approximately 50% ownership interest in Desert Sunlight's solar projects,Sunlight Investment Holdings, LLC, approximately 50% ownership interest in Rosmar andHoldings, LLC (Rosmar), the ownership interest in Meade Pipeline Co, LLC (Meade), including Meade's ownership interest in the CPLCentral Penn Line (CPL), the 40% ownership interest in Pine Brooke Holdings and related expansion project describedthe 33.3% ownership interests in certain projects acquired in October 2021 (see Note 3.3). 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 controlling interests in these entities.
Summarized information for these equity method investees is as follows:
| | | | 2022 | | 2021 | | 2020 |
| | | (millions) |
| | | 2019 | | 2018 | | 2017 | |
| (millions) | |
Revenues | $ | 213 |
| | $ | 208 |
| | $ | 207 |
| Revenues | $ | 376 | | | $ | 334 | | | $ | 244 | |
Operating income | $ | 124 |
| | $ | 129 |
| | $ | 127 |
| Operating income | $ | 136 | | | $ | 164 | | | $ | 142 | |
Net income(a) | $ | 67 |
| | $ | 84 |
| | $ | 80 |
| Net income(a) | $ | 308 | | | $ | 261 | | | $ | 151 | |
|
________________________
(a) Includes the earnings from equity method investee related to Meade's ownership interest in CPL.
| | | | | | | | | | | | | |
| December 31, 2022 | | December 31, 2021 | | |
| (millions) | | |
Current assets | $ | 163 | | | $ | 186 | | | |
Noncurrent assets(a) | $ | 4,969 | | | $ | 5,073 | | | |
Current liabilities | $ | 85 | | | $ | 85 | | | |
Noncurrent liabilities | $ | 1,355 | | | $ | 1,456 | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
NEP's share of underlying equity in the equity method investees | $ | 2,077 | | | $ | 2,063 | | | |
Difference between investment carrying amounts and underlying equity in net assets(b) | (160) | | | (167) | | | |
NEP's investment carrying amounts | $ | 1,917 | | | $ | 1,896 | | | |
________________________
(a) Includes the equity method investment related to Meade's ownership interest in CPL
(b) Substantially all of the difference between the investment carrying amount and the underlying equity in net assets is being amortized over the life of the related expansion subsequent to the Meade acquisition in November 2019.projects.
|
| | | | | | | |
| December 31, 2019 | | December 31, 2018 |
| (millions) |
Current assets | $ | 211 |
| | $ | 133 |
|
Non-current assets(a) | $ | 2,853 |
| | $ | 1,298 |
|
Current liabilities(b) | $ | 545 |
| | $ | 561 |
|
Non-current liabilities | $ | 497 |
| | $ | 459 |
|
| | | |
NEP's share of underlying equity in the equity method investees | $ | 1,668 |
| | $ | 206 |
|
Difference between investment carrying amounts and underlying equity in net assets(c) | (15 | ) | | 8 |
|
NEP's investment carrying amounts | $ | 1,653 |
| | $ | 214 |
|
________________________
| |
(a) | For 2019, includes the equity method investment related to Meade's ownership interests in the CPL and the related expansion project. |
| |
(b) | At December 31, 2019 and 2018, approximately $479 million and $503 million, respectively, of long-term debt is reflected as current liabilities as a result of being notified by the lender of an event of default under the related financing agreement. See Note 15 - PG&E Bankruptcy. |
| |
(c) | Substantially all of the difference between the investment carrying amount and the underlying equity in net assets is being amortized over the life of the related projects. |
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
10. Variable Interest Entities
NEP has identified NEP OpCo, a limited partnership with a general partner and limited partners, as a VIE. NEP has consolidated the results of NEP OpCo and its subsidiaries because of its controlling interest in the general partner of NEP OpCo. At December 31, 2019,2022, NEP owned an approximately 39.2%46.2% limited partner interest in NEP OpCo and NEE Equity owned a noncontrolling 60.8%53.8% limited partner interest in NEP OpCo. See Note 13 - Common Unit Issuances. 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 December 31, 2019,2022, NEP OpCo consolidated 1221 VIEs related to certain subsidiaries which have sold differential membership interests (see Note 2 -– Noncontrolling Interests) in entities which own and operate 2037 wind electric generation facilities.facilities as well as eight solar projects, including related battery storage facilities, and one battery storage facility. These entities are considered VIEs because the holders of the differential membership interests do not have substantive rights over the significant activities of these entities. The assets, primarily property, plant and equipment -– net, and liabilities, primarily accounts payable and accrued expenses and asset retirement obligation, and non-current due to related party, of the VIEs, totaled approximately $4,814$12,127 million and $122$1,336 million, respectively, at December 31, 2019,2022, and $4,937$9,740 million and $132$1,310 million, respectively, at December 31, 2018.2021. In January 2023, NEP bought out differential membership investors with ownership interests in two wind projects for approximately $187 million impacting two differential membership VIEs.
At December 31, 2019,2022, NEP OpCo also consolidated 4six VIEs related to the sales of noncontrolling Class B interests in certain NEP subsidiaries. See Note 2 -– Noncontrolling Interests and Note 11 - Equity.13 – Class B Noncontrolling Interests. These entities are considered VIEs because the holders of the noncontrolling Class B interests do not have substantive rights over the significant activities of the entities. The assets, primarily property, plant and equipment -– net, and intangible assets -– PPAs and investments in equity method investees, and the liabilities, primarily accounts payable and accrued expenses, long-term debt, intangible liabilities – PPAs, noncurrent other long-term liabilities and asset retirement obligation, of the VIEs totaled approximately $7,900$16,448 million and $1,448$3,456 million, respectively, at December 31, 2019. The assets, primarily property, plant2022 and equipment - net, and the liabilities, primarily long-term debt and asset retirement obligation, of the VIEs totaled approximately $2,339$11,810 million and $89$2,480 million, respectively, at December 31, 2018.2021. Certain of these VIEs include 3six other VIEs related to NEP's ownership interests in Rosmar, Silver State, Meade, Pine Brooke Holdings, Star Moon Holdings and MeadeEmerald Breeze (see Note 3). In addition, certain of these VIEs contain entities which have sold differential membership interests and approximately $2,122$8,088 million and $2,183$4,749 million of assets and $53$1,198 million and $55$1,159 million of liabilities are also included in the disclosure of the VIEs related to differential membership interests at December 31, 20192022 and 2018,2021, respectively.
At December 31, 2022, NEP OpCo consolidated Sunlight Renewables Holdings which is a VIE (see Note 3). The assets, primarily property, plant and equipment – net, and the liabilities, primarily accounts payable and accrued expenses, asset retirement obligation and noncurrent other liabilities, of the VIE totaled approximately $443 million and $10 million at December 31, 2022, respectively. This VIE contains entities which have sold differential membership interests and approximately $344 million of assets and $10 million of liabilities is included in the disclosure of VIEs related to differential membership interests at December 31, 2022 above.
Certain subsidiaries of NEP OpCo have noncontrolling interests in entities accounted for under the equity method that are considered VIEs. See Note 9.
NEP has an indirect equity method investment in 3three NEER solar projects with a total generating capacity of 277 MW and battery storage capacity of 230 MW. 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 3three solar projects (non-economic ownership interests). NEER, as holder of the NEP OpCo 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 December 31, 20192022 and 2018,2021, NEP's equity method investment related to the non-economic ownership interests of approximately $11$98 million and $20$47 million, respectively, is reflected as noncurrent other non-current assets and, at December 31, 2019, $7 million is reflected as other non-current liabilities on NEP's consolidated balance sheets. All equity in earnings of the non-economic ownership interests is allocated to net income attributable to noncontrolling interests. 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.
11. Leases
NEP has operating and finance leases primarily related to land use agreements for certain of its renewable energy projects. At December 31, 2022 and 2021, NEP had recorded right-of-use (ROU) assets for operating leases of approximately $24 million and $44 million, respectively, and operating lease liabilities of $26 million and $45 million, respectively. At December 31, 2022
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
and 2021, NEP's ROU assets for finance leases totaled approximately $47 million and $48 million, respectively, and finance lease liabilities totaled $51 million and $49 million, respectively. NEP’s operating lease liabilities were calculated based on a weighted average discount rate of 4.04% and 4.01% based on the incremental borrowing rate at the lease commencement date and have a weighted-average remaining lease term of 25 years and 26 years, at December 31, 2022 and 2021, respectively. NEP's finance lease liabilities were calculated based on a weighted average discount rate of 3.55% and 3.55% with a weighted-average remaining lease term of 34 years and 35 years, at December 31, 2022 and 2021, respectively. Lease payments under the land use agreements, which convey exclusive use of the land during the arrangement, are either fixed based on the terms of the related lease agreement or variable primarily based on the amount of generation at the renewable energy project. NEP’s operating and finance leases with fixed payments have expiration dates ranging from 2028 to 2057. NEP recognized approximately $2 million, $3 million and $3 million in 2022, 2021 and 2020, respectively, of operating lease costs associated with its ROU assets and lease obligations which are included in O&M expenses in NEP’s consolidated statements of income (loss). In addition, approximately $8 million, $7 million and $6 million was recorded related to variable lease costs in 2022, 2021 and 2020, respectively. Other operating and finance lease-related amounts were not material to NEP’s consolidated statements of income (loss) or cash flows for the periods presented. At December 31, 2022, NEP's lease agreements call for fixed payments of approximately $3 million in 2023, $4 million annually over the next four years and $112 million thereafter. During 2022, NEP's ROU assets obtained in exchange for operating and finance lease obligations resulted in a decrease of approximately $11 million, primarily relating to lease remeasurements offset by operating leases acquired during 2022 (see Note 3). During 2021, NEP's ROU assets obtained in exchange for operating and finance lease obligations totaled approximately $51 million and primarily relate to finance leases acquired in the December 2021 acquisition from NEER (see Note 3).
NEP has operating leases and a sales-type lease relating to battery storage facilities that sell their electric output under power sales agreements to third parties which provide the customers the ability to dispatch the facilities. At both December 31, 2022 and 2021, the net investment in sales-type lease is approximately $16 million. At December 31, 2022, the power sales agreements have expiration dates from 2037 to 2041 and NEP expects to receive approximately $118 million of lease payments over the remaining term of the power sales agreement with no one year being material. Operating and sales-type lease-related amounts relating to battery storage facilities were not material to NEP's consolidated statements of income for the periods presented.
11. Capitalization
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
12. Debt
-
NEP’s long-term debt agreements require monthly, quarterly or semi-annual payments of interest. Principal payments on the senior secured limited-recourse debt is primarily due monthly or semi-annually. The carrying value of NEP’s long-term debt consists of the following:
|
| | | | | | | | | | | | | | | |
| | | December 31, |
| | | 2019 | | 2018 |
| Maturity Date | | Balance | | Weighted-Average Interest Rate | | Balance | | Weighted-Average Interest Rate |
| | | (millions) | | | | (millions) | | |
NEP: | | | | | | | | | |
Senior unsecured convertible notes - fixed(a) | 2020 | | $ | 300 |
| | 1.50 | % | | $ | 300 |
| | 1.50 | % |
NEP OpCo: | | | | | | | | | |
Senior unsecured notes - fixed(b) | 2024 - 2027 | | 2,300 |
| | 4.23 | % | | $ | 1,100 |
| | 4.38 | % |
Revolving credit facility - variable(a)(c) | 2024 | | 510 |
| | 3.35 | % | | — |
| |
|
|
Project level: | | | | | | | | | |
Senior secured limited-recourse debt - fixed | 2033 | | 25 |
| | 4.52 | % | | 985 |
| | 5.16 | % |
Senior secured limited-recourse debt - variable(c)(d) | 2026 - 2032 | | 859 |
| | 3.38 | % | | 269 |
| | 4.43 | % |
Bank loan(c) | 2023 | | 205 |
| | 3.46 | % | | 200 |
| | 4.76 | % |
Non-recourse notes payable - fixed |
| | — |
| |
|
| | 20 |
| | 6.30 | % |
Limited-recourse term loan - variable(c)(d) |
| | — |
| |
|
| | 604 |
| | 4.93 | % |
Unamortized debt issuance costs | | | (55 | ) | | | | (45 | ) | | |
Unamortized premium | | | — |
| | | | 2 |
| | |
Total long-term debt | | | 4,144 |
| | | | 3,435 |
| | |
Less current portion of long-term debt(e) | | | 12 |
| | | | 707 |
| | |
Long-term debt, excluding current portion | | | $ | 4,132 |
| | | | $ | 2,728 |
| | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| December 31, |
| 2022 | | 2021 |
| Maturity Date | | | | Balance | | Weighted-Average Interest Rate | | Balance | | Weighted-Average Interest Rate |
| | | | | (millions) | | | | (millions) | | |
NEP: | | | | | | | | | | | |
Senior unsecured convertible notes – fixed(a) | 2024 – 2026 | | | | $ | 1,600 | | | 0.78 | % | | $ | 1,100 | | | — | % |
NEP OpCo: | | | | | | | | | | | |
Senior unsecured notes – fixed(b) | 2024 – 2027 | | | | 1,800 | | | 4.22 | % | | 1,800 | | | 4.22 | % |
| | | | | | | | | | | |
Revolving credit facility – variable(a)(c) | 2027 | | | | — | | | — | % | | 554 | | | 1.61 | % |
Project level: | | | | | | | | | | | |
Senior secured limited-recourse debt – fixed | 2033 | | | | 20 | | | 4.52 | % | | 21 | | | 4.52 | % |
Senior secured limited-recourse debt – variable(c)(d) | 2026 – 2032 | | | | 1,529 | | | 5.83 | % | | 1,544 | | | 1.55 | % |
Bank loan(c)(d) | 2023 | | | | 200 | | | 6.13 | % | | 205 | | | 1.90 | % |
| | | | | | | | | | | |
Other long-term debt – variable(c)(d) | 2028 | | | | 141 | | | 6.73 | % | | 154 | | | 2.16 | % |
Other long-term debt – fixed(e) | 2026 – 2031(e) | | | | 49 | | | 0.13 | % | | — | | | |
Unamortized debt issuance costs and discount | | | | | (51) | | | | | (51) | | | |
| | | | | | | | | | | |
Total long-term debt | | | | | 5,288 | | | | | 5,327 | | | |
Less current portion of long-term debt | | | | | 38 | | | | | 33 | | | |
Long-term debt, excluding current portion | | | | | $ | 5,250 | | | | | $ | 5,294 | | | |
________________________
| |
(a) | See additional discussion of the convertible notes and the NEP OpCo credit facility below. |
| |
(b) | The NEP OpCo senior unsecured notes are absolutely and unconditionally guaranteed, on a senior unsecured basis, by NEP and a subsidiary of NEP OpCo. |
| |
(c) | Variable rate is based on an underlying index plus a margin. |
| |
(d) | Interest rate contracts, primarily swaps, have been entered into for a majority of these debt issuances. See Note 7. |
| |
(e) | At December 31, 2018, included approximately $641 million of principal with final maturity dates ranging from 2033 - 2038, net of the related unamortized debt issuance costs, which was reclassified to current debt as a result of events of default under the related financing agreements. See Note 15 - PG&E Bankruptcy. |
(a) See additional discussion of the convertible notes and the NEP OpCo credit facility below.
(b) The NEP OpCo senior unsecured notes are absolutely and unconditionally guaranteed, on a senior unsecured basis, by NEP and a subsidiary of NEP OpCo.
(c) Variable rate is based on an underlying index plus a margin.
(d) Interest rate contracts, primarily swaps, have been entered into for a majority of these debt issuances. See Note 5.
(e) See Note 14 – Related Party Long-term Debt.
Minimum annual maturities of long-term debt are approximately $312$38 million, $12$1,528 million, $14$680 million, $220$1,878 million and $1,776$607 million for 2020, 2021, 2022, 2023, 2024, 2025, 2026 and 2024,2027, respectively.
NEP OpCo and its direct subsidiary (loan parties) are parties to a variable rate, senior secured revolving credit facility (NEP OpCo credit facility). At December 31, 2019,2022, the NEP OpCo credit facility provided up to $1.25$2.5 billion of revolving credit loans and included borrowing capacity of up to $400 million for letters of credit and incremental commitments to increase the NEP OpCo credit facility to up to $2.0$3.25 billion in the aggregate, subject to certain conditions. Borrowings under the NEP OpCo credit facility can be used by the loan parties to fund working capital and expansion projects, to make acquisitions and for general business purposes. The NEP OpCo credit facility is subject to a facility fee ranging from 0.20% to 0.35% per annum depending on NEP OpCo's leverage ratio (as defined in the NEP OpCo credit facility). At December 31, 2019,2022, approximately $122$118 million of letters of credit were issued under the NEP OpCo credit facility primarily related to debt service reserves and as security for certain financing agreements of NEP OpCo's subsidiaries. In February 2020,2023, the loan parties extended the maturity date for substantially all of the NEP OpCo credit facility to 20252028 and NEP OpCo borrowed approximately $50 million under the NEP OpCo credit facility.
At December 31, 2019, the Meade purchaser and Pipeline Investment Holdings, LLC (Meade Holdings) are parties to a credit agreement (Meade credit agreement) which provides up to $915 million under three limited-recourse senior secured variable rate term loans maturing in 2026 to finance a portion of the Meade acquisition and the expansion (see Note 3). Approximately $816 million was borrowed simultaneously with the closing of the Meade acquisition and the remaining amount available under the credit agreement is expected to be borrowed regularly through the completion of the expansion. At December 31, 2019, approximately $90 million remains available under the Meade credit agreement.
In addition, at December 31, 2019,2022, South Texas Midstream Holdings, LLC (STX Holdings) is party to a credit agreement which provides up to $270 million under a revolving credit facility (STX Holdings revolving credit facility). Proceeds from any borrowings under the STX Holdings revolving credit facility are available exclusively to fund the cash portion of NEP's repurchase, if any, of the Class B noncontrolling interests related to STX Midstream (see discussion below)Note 13 – Class B Noncontrolling Interests), subject to certain limitations.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The long-term debt agreements listeddiscussed above contain default and related acceleration provisions relating to the failure to make required payments or to observe other covenants in the respective financing agreements and related documents including financial covenants primarily related to debt service coverage ratios, as well as a maximum leverage ratio and a minimum interest coverage ratio. Additionally, under the NEP OpCo credit facility, NEP OpCo and its direct subsidiary are required to
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
comply with certain financial covenants on a quarterly basis and NEP OpCo's ability to pay cash distributions is subject to certain other restrictions. All borrowings under the NEP OpCo credit facility and the NEP OpCo senior unsecured notes are guaranteed by NEP OpCo and NEP.
The NEP OpCo credit facility contains various covenants and restrictive provisions that limit NEP OpCo’s ability to, among other things:
•incur or guarantee additional debt;
•make distributions on or redeem or repurchase common units;
•make certain investments and acquisitions;
•incur certain liens or permit them to exist;
•enter into certain types of transactions with affiliates;
•merge or consolidate with another company; and
•transfer, sell or otherwise dispose of projects.
The long-term debt agreements listed above all contain provisions which, under certain conditions, restrict the payment of dividends and other distributions. At December 31, 2019,2022, NEP and its subsidiaries were in compliance with all financial debt covenants under their respective financing agreements except as discussed in Note 15 - PG&E Bankruptcy.agreements.
The $300During 2022, NEP issued $500 million principal amount of senior unsecured convertible notes (convertible(2022 convertible notes). The 2022 convertible notes are unsecured obligations of NEP and are absolutely and unconditionally guaranteed, on a senior unsecured basis, by NEP OpCo. A holder may convert all or a portion of its 2022 convertible notes intoin accordance with the related indenture. Upon conversion of the 2022 convertible notes, NEP will pay cash up to the aggregate principal amount of the notes to be converted and pay or deliver, as the case may be, cash, NEP common units or a combination of cash and cashcommon units, at NEP's election, in lieurespect of the remainder, if any, fractional common unit atof NEP's conversion obligation in excess of the conversion rate.aggregate principal amount of the notes being converted. At December 31, 2019,2022, the conversion rate, which is subject to certain adjustments, was 18.917010.5339 NEP common units per $1,000 principal amount of the 2022 convertible notes, which rate is equivalent to aan initial conversion price of approximately $52.8625$94.9316 per NEP common unit. The conversion rate is subject to adjustment in certain circumstances, as set forth in the related indenture. Upon the occurrence of a fundamental change (as defined in the related indenture), holders of the 2022 convertible notes may require NEP to repurchase all or a portion of their convertible notes for cash in an amount equal to the principal amount of the 2022 convertible notes to be repurchased, plus accrued and unpaid interest, if any. The 2022 convertible notes are not redeemable at NEP’s option prior to maturity.
In connection with the issuance of the 2022 convertible notes, NEP entered into a registration rights agreement pursuant to which, among other things, NEP has agreed to file a shelf registration statement with the Securities and Exchange Commission and use its commercially reasonable efforts to cause such registration statement to become effective on or prior to December 12, 2023, covering resales of NEP common units, if any, issuable upon a conversion of the 2022 convertible notes.
NEP entered capped call transaction (cappedtransactions (2022 capped call) in connection with the issuance of the 2022 convertible notes. Under the 2022 capped call, NEP purchased capped call options with aan initial strike price of $52.8625$94.9316 and aan initial cap price of $63.4350.$118.6650, subject to certain adjustments. The 2022 capped call was purchased for approximately $12$31 million, which was recorded as a reduction to common units equity on NEP's consolidated balance sheets. If, upon conversion of the 2022 convertible notes, the price per NEP common unit during the relevant settlementvaluation period is above the strike price, there would generally be a payment to NEP (if NEP elects to cash settle) or an offset of potential dilution to NEP's common units (if NEP elects to settle in NEP common units).
Equity - In November 2017,During 2021, NEP issued $500 million principal amount of senior unsecured convertible notes (2021 convertible notes). The 2021 convertible notes are unsecured obligations of NEP and sold 14,021,561 Seriesare absolutely and unconditionally guaranteed, on a senior unsecured basis, by NEP OpCo. A holder may convert all or a portion of its 2021 convertible preferrednotes in accordance with the related indenture. Upon conversion of the 2021 convertible notes, NEP will pay cash up to the aggregate principal amount of the notes to be converted and pay or deliver, as the case may be, cash, NEP common units representing limited partner interestsor a combination of cash and common units, at NEP's election, in respect of the remainder, if any, of NEP's conversion obligation in excess of the aggregate principal amount of the notes being converted. At December 31, 2022, the conversion rate, which is subject to certain adjustments, was 11.0492 NEP (preferred units) forcommon units per $1,000 of the 2021 convertible notes, which is equivalent to an aggregate purchaseinitial conversion price of approximately $550 million.$90.5043 per NEP contributedcommon unit. The conversion rate is subject to adjustment in certain circumstances, as set forth in the proceeds to NEP OpCo in exchange for an equivalent numberrelated indenture. Upon the occurrence of a new series of NEP OpCo preferred units with economically equivalent rights tofundamental change (as defined in the preferred units. In both July 2019 and November 2019, NEP converted approximately 4,673,852 Series A convertible preferred units into NEP common units on a 1-for-one basis.
The preferred units are a class of securities that rank senior to the common units representing limited partner interests in NEP. The preferred units will vote on an as-converted basis with the common units and have certain class voting rights with respect to amendments that adversely affect their distribution, liquidation or conversion rights, their ranking or certain other protections under the NEP partnership agreement.
Holdersrelated indenture), holders of the preferred units will receive cumulative quarterly distributions equal2021 convertible notes may require NEP to $0.4413 per unitrepurchase all or a portion of their convertible notes for quarters ending on or before November 15, 2020, which was prorated for the fourth quarter of 2017 and which may be paid, at NEP’s election, in cash in kind or a combination thereof. For quarters ending after November 15, 2020, holders will receive cumulative quarterly distributionsan amount equal to the greater of $0.4413 per unit and theprincipal amount that the preferred units would have received if they had converted into common units at the then-applicable conversion rate (defined below), and NEP may elect to pay up to 1/9th of the subsequent distribution period amounts in kind. The quarterly distribution amount and portion of the distribution that may2021 convertible notes to be paid in kind will be prorated for the fourth quarter of 2020. If NEP fails to pay a distribution during a subsequent distribution period, NEP would be unable to pay any distributions on or redeem or repurchase any junior securities, including the common units, prior to paying the unpaid cash component of the quarterly distribution, including any previouslyrepurchased, plus accrued and unpaid cash distributions. special interest, if any. The 2021 convertible notes are not redeemable at NEP’s option prior to maturity.
Each holderNEP entered capped call transactions (2021 capped call) in connection with the issuance of preferred units (togetherthe 2021 convertible notes. Under the 2021 capped call, NEP purchased capped call options with its affiliates) may elect to convert all or any portionan initial strike price of its preferred units into common units initially on a one-for-one basis, subject to customary adjustments$90.5043 and an adjustment for any distributions that have accrued but have not been paid when due (the conversion rate), at any time after June 20, 2019,initial cap price of $113.1300, subject to certain conditions. NEP may
adjustments. The 2021 capped call was purchased for approximately $31 million, which was recorded as a reduction to common units equity on NEP's consolidated balance sheets. If, upon conversion of the 2021
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
convertible notes, the price per NEP common unit during the relevant valuation period is above the strike price, there would generally be a payment to NEP (if NEP elects to cash settle) or an offset of potential dilution to NEP's common units up to the cap price (if NEP elects to settle in NEP common units).
elect
During 2020, approximately $300 million of senior unsecured convertible notes issued in 2017 (2017 convertible notes) were converted and NEP issued 5.7 million NEP common units and received $30 million in cash related to the unwinding of a capped call transaction that was entered into in connection with the issuance of the 2017 convertible notes. Also during 2020, NEP issued $600 million principal amount of senior unsecured convertible notes (2020 convertible notes). In connection with the issuance of the 2020 convertible notes, NEP recorded the value of the conversion option of approximately $64 million in common units equity (see Note 2 – Distinguishing Liabilities and Equity). The 2020 convertible notes are unsecured obligations of NEP and are absolutely and unconditionally guaranteed, on a senior unsecured basis, by NEP OpCo. A holder may convert all or a portion of its 2020 convertible notes in accordance with the preferred units intorelated indenture. Upon conversion of the 2020 convertible notes, NEP will pay cash up to the aggregate principal amount of the notes to be converted and pay or deliver, as the case may be, cash, NEP common units based on the conversion rate at any time after November 15, 2018 if certain conditions, including specific common unit priceor a combination of cash and trading volume conditions, are met and subject to certain maximum conversion amounts prior to November 2020 under the purchase agreement. In addition, certain change of control events, as specified in the NEP partnership agreement, will result in, or provide holders of the preferred units with the right to elect, conversion of preferred units to common units (or substantially equivalent securities of a surviving entity) or redemption of the preferred units, with such redemption to be paid in cash or common units, at NEP's discretion. Beginning January 1, 2021,election, in respect of the remainder, if any, of NEP's conversion obligation in excess of the aggregate principal amount of the notes being converted. At December 31, 2022, the conversion rate, which is subject to certain adjustments, was 13.2748 NEP will givecommon units per $1,000 of the purchasers certain rights2020 convertible notes, which rate is equivalent to a conversion price of approximately $75.3305 per NEP common unit. Upon the occurrence of a fundamental change (as defined in the related indenture), holders of the 2020 convertible notes may require NEP underto repurchase all or a portion of their convertible notes for cash in an amount equal to the principal amount of the 2020 convertible notes to be repurchased, plus accrued and unpaid special interest, if any. The 2020 convertible notes are not redeemable at NEP’s option prior to maturity.
NEP entered a capped call transaction (2020 capped call) in connection with the issuance of the 2020 convertible notes. Under the 2020 capped call, NEP purchased capped call options which at December 31, 2022 have a strike price of $75.3305 and a cap price of $119.2736, subject to certain circumstances,adjustments. The 2020 capped call was purchased for approximately $63 million, which was recorded as a reduction to initiate underwritten offerings for the common units that are issuableequity on NEP's consolidated balance sheets. If, upon conversion of the preferred units.2020 convertible notes, the price per NEP common unit during the relevant valuation period is above the strike price, there would generally be a payment to NEP (if NEP elects to cash settle) or an offset of potential dilution to NEP's common units (if NEP elects to settle in NEP common units).
13. Equity
Distributions – During 2019, 20182022, 2021 and 2017,2020, NEP distributed approximately $115$254 million, $94$198 million and $81$154 million, respectively, to its common unitholders. In addition, NEP paid approximately $35$70 million in distributions to its common unitholders and $2 million in distributions to its preferred unitholders in February 2020.2023.
During 2019 and 2018, subsidiaries of NEP sold Class B noncontrolling membership interests in NEP Renewables, NEP Renewables II, NEP Pipelines and STX Midstream as described below:
|
| | | | | | | |
| NEP Renewables | | NEP Renewables II | | NEP Pipelines | | STX Midstream |
Underlying projects/pipelines | Renewable energy projects with a combined generating capacity of approximately 1,388 MW | | Renewable energy projects with a combined net generating capacity of approximately 611 MW | | Equity method interest in a natural gas pipeline located in Pennsylvania | | Seven natural gas pipeline assets located in Texas |
Date of sale | December 21, 2018 | | June 11, 2019 | | November 13, 2019 | | December 4, 2019 |
Gross proceeds | $750 million | | $900 million | | $168 million | | $750 million |
Initial allocation of distributable cash to Class B investor | 15% | | 5% | | 1% | | 12.5% |
Period for initial allocation | 3 years | | 6 years | | 6 years | | 4 years |
Period for initial allocation if minimum buyouts have not occurred | n/a | | 4.5 years | | 5 years | | 3.5 years |
Allocation of distributable cash to Class B investor after initial allocation period | 80% | | 99% | | 99% | | 75%(a) |
Date buyout period begins | December 21, 2021 | | December 11, 2022 | | May 13, 2023 | | December 4, 2022 |
Buyout right timing | One time during year 4 | | Periodically, and for partial interests between years 3.5 and 6(b) | | Periodically, and for partial interests between years 3.5 and 6.5(b) | | Periodically, and for partial interests between years 3 and 7(b) |
Percentage of buyout price that can be paid in NEP non-voting common units at current market price(c) | 70% | | 70% | | 100% | | 70% |
Date registration rights begin | January 1, 2025 | | January 1, 2025 | | Date of first buyout notice | | January 1, 2023 |
________________
| |
(a) | Increases to 95% if NEP has not exercised its entire buyout right by December 4, 2025. |
| |
(b) | The buyout right is subject to certain limitations, including NEP being able to purchase a maximum of the Class B units at certain anniversaries specified in the agreement. |
| |
(c) | The NEP non-voting common units will have the right to receive pro rata quarterly cash distributions and rights to convert, subject to certain limitation, the NEP non-voting common units into NEP common units on a one-for-one basis. The specified percentage of the buyout price for the Class B noncontrolling interests in STX Midstream are payable in NEP common units. |
In 2015, NEP established an at-the-market equity issuance program (ATM program) pursuant to which NEP could issue, from time to time, up to $150 million of its common units, giving NEP the flexibility to issue new units when the price is acceptable. In July 2018, NEP implemented a $150 million ATM program which replaced its prior program. During the year ended December 31, 2018, NEP issued approximately 1.8 million common units under the ATM program for gross proceeds of approximately $86 million. During the years ended December 31, 2019 and 2017, NEP did 0t issue any common units under the ATM program. Fees related to the ATM program totaled approximately $1 million in 2018.
Earnings Per Unit -– Diluted earnings per unit are based on the weighted-average number of common units and potential common units outstanding during the period, including the dilutive effect of the convertible notes and preferred units. Theunits (see Preferred Units below). Following the adoption of a new accounting standard on January 1, 2021 (see Note 2 – Distinguishing Liabilities from Equity), the dilutive effect of the 2020 convertible notes, the 2021 convertible notes and the 2022 convertible notes is calculated using the if-converted method. During 2020, the dilutive effect of the preferred units iswas computed using the if-converted method and the dilutive effect of the 2020 convertible notes was computed using the treasury stock method.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The reconciliation of NEP's basic and diluted earnings (loss) per unit is as follows:
|
| | | | | | | | | | | | |
| | Years Ended December 31, |
| | 2019 | | 2018 | | 2017 |
| (millions, except per unit data) |
Numerator: | | | | | | |
Net income (loss) attributable to NEP – basic | | $ | (88 | ) | | $ | 167 |
| | $ | (64 | ) |
Adjustments for convertible notes and preferred units(a) | | — |
| | 50 |
| | — |
|
Net income (loss) attributable to NEP used to compute diluted earnings per unit | | $ | (88 | ) |
| $ | 217 |
| | $ | (64 | ) |
Denominator: | | | | | | |
Weighted-average number of common units outstanding – basic | | 58.8 |
| | 54.9 |
| | 54.2 |
|
Effect of dilutive convertible notes and preferred units(a) | | — |
|
| 19.7 |
| | — |
|
Weighted-average number of common units outstanding and assumed conversions | | 58.8 |
| | 74.6 |
| | 54.2 |
|
Earnings (loss) per unit attributable to NEP: | | | | | | |
Basic | | $ | (1.51 | ) | | $ | 3.05 |
| | $ | (1.18 | ) |
Assuming dilution | | $ | (1.51 | ) | | $ | 2.91 |
| | $ | (1.18 | ) |
| | | | | | | | | | | | | | | | | | | | |
| | Years Ended December 31, |
| | 2022 | | 2021 | | 2020 |
| (millions, except per unit amounts) |
Numerator: | | | | | | |
Net income (loss) attributable to NEP – basic | | $ | 477 | | | $ | 137 | | | $ | (55) | |
Adjustments for convertible notes and preferred units(a) | | — | | | — | | | — | |
Net income (loss) attributable to NEP used to compute diluted earnings per unit | | $ | 477 | | | $ | 137 | | | $ | (55) | |
Denominator: | | | | | | |
Weighted-average number of common units outstanding – basic | | 84.9 | | | 77.2 | | | 68.4 | |
Effect of dilutive convertible notes and preferred units(a) | | — | | | 0.2 | | | — | |
Weighted-average number of common units outstanding and assumed conversions | | 84.9 | | | 77.4 | | | 68.4 | |
Earnings (loss) per unit attributable to NEP: | | | | | | |
Basic | | $ | 5.62 | | | $ | 1.77 | | | $ | (0.81) | |
Assuming dilution | | $ | 5.62 | | | $ | 1.77 | | | $ | (0.81) | |
____________________
(a) Due to the net lossesloss incurred during the yearsyear ended December 31, 2019 and 2017,2020, the weighted-average number of common units issuable pursuant to the convertible notes and preferred units totaling approximately 17.07.5 million and 3.6 million, respectively, werewas not included in the calculation of diluted earnings per unit due to their antidilutive effect.
12.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
ATM Program – NEP has an at-the-market equity issuance program (ATM program), which was renewed in 2021, pursuant to which NEP may issue, from time to time, up to $300 million of its common units. During the years ended December 31, 2022 and 2021, NEP issued approximately 1.8 million common units and 0.7 million common units under the ATM program for gross proceeds of approximately $145 million and $50 million, respectively. During the year ended December 31, 2020, NEP did not issue any common units under the ATM program. Fees related to the ATM program totaled approximately $1 million and less than $1 million in 2022 and 2021, respectively.
Preferred Units – In 2017, NEP issued and sold Series A convertible preferred units representing limited partner interests in NEP. During the year ended December 31, 2020, NEP issued approximately 4.7 million NEP common units upon the conversion of the remaining convertible preferred units on a one-for-one basis.
Common Unit Issuances – In July 2022, NEP issued 0.8 million NEP common units upon NEE Equity's exchange of NEP OpCo common units on a one-for-one basis. In January 2023, NEE Equity delivered notice to NEP OpCo of its election to exchange 0.9 million NEP OpCo common units for NEP common units on a one-for-one basis. The exchange of common units, and related issuance of NEP common units, is expected to occur in the second quarter of 2023.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Class B Noncontrolling Interests – Subsidiaries of NEP sold Class B noncontrolling membership interests in NEP Renewables II, NEP Pipelines, STX Midstream, Genesis Holdings, NEP Renewables III and NEP Renewables IV as described below:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | NEP Renewables II | | NEP Pipelines | | STX Midstream | | Genesis Holdings | | NEP Renewables III | | NEP Renewables IV |
Underlying projects/pipelines | | | Renewable energy projects with a combined net generating capacity of approximately 1,192 MW(a) | | Equity method interest in a natural gas pipeline located in Pennsylvania | | Six natural gas pipeline assets located in Texas | | Renewable energy projects with a combined net generating capacity of approximately 1,124 MW | | Renewable energy projects with a combined net generating capacity of approximately 1,260 MW | | Renewable energy projects with a combined net generating capacity of approximately 1,992 MW(b) |
Date of sale | | | June 11, 2019 | | November 13, 2019 | | December 4, 2019 | | December 18, 2020 | | December 28, 2021 | | December 15, 2022 |
Gross proceeds | | | $900 million(a) | | $168 million | | $750 million(c) | | $1,243 million(d) | | $816 million(e) | | $710 million(f) |
Initial allocation of distributable cash to Class B investors | | | 5% | | 1% | | 12.5% | | 25%(d) | | 65%(e) | | 17%(f) |
Period for initial allocation | | | 6 years | | 6 years | | 4 years | | 10 years | | 10 years | | 10 years |
Period for initial allocation if minimum buyouts have not occurred | | | 4.5 years | | 5 years | | 3.5 years | | 6.75 years | | 6 years | | 6.5 years |
Allocation of distributable cash to Class B investors after initial allocation period | | | 99% | | 99% | | 75%(g) | | 80%(d) | | 99% | | 99% |
Date buyout period begins | | | December 11, 2022 | | May 13, 2023 | | December 4, 2022 | | December 18, 2025 | | December 28, 2026 | | December 15, 2027 |
Buyout right timing(h) | | | Periodically, and for partial interests between years 3.5 and 6 | | Periodically, and for partial interests between years 3.5 and 6.5 | | Periodically, and for partial interests between years 3 and 7 | | Periodically, and for partial interests between years 5 and 10 | | Periodically, and for partial interests between years 5 and 10 | | Periodically, and for partial interests between years 5 and 10 |
Percentage of buyout price that can be paid in NEP non-voting common units at current market price(i) | | | 70% | | 100% | | 70% | | 100% | | 100% | | 100% |
| | | | | | | | | | | | | |
____________________
(a)In January 2023, NEP sold its ownership interests in one wind project with a net generating capacity of approximately 62 MW to a third party and approximately $45 million of the cash proceeds from the sale were distributed to the third-party owner of Class B membership interests (see Note 2 – Disposal of Wind Project).
(b)Excludes net generating capacity of approximately 54 MW relating to a wind facility in New York which is expected to be transferred to NEP Renewables IV in the first quarter of 2023. See Note 3.
(c)In April 2022, NEP sold its ownership interests in one pipeline to a third party and approximately $70 million of the cash proceeds from the sale were distributed to the third-party owner of Class B membership interests (see Note 2 – Disposal of Pipeline).
(d)At December 31, 2020, NEP retained certain Class B membership interests in Genesis Holdings which were sold to the Class B investors for approximately $493 million at a final funding in June 2021. Prior to the final Class B funding, NEP received approximately 83% of Genesis Holdings’ cash distributions and the third-party investors received 17%. The allocation of distributable cash to Class B investors increases to 99% if NEP has not exercised certain buyout rights by September 18, 2027, but after December 18, 2030, the allocation of distributable cash to Class B investors decreases to 80%, subject to certain adjustments.
(e)At December 31, 2021, NEP retained certain Class B membership interests in NEP Renewables III which were sold to the Class B investors for approximately $408 million at a final funding in June 2022. Prior to the final Class B funding, NEP received approximately 67.5% of NEP Renewables III's cash distributions and the third-party investors received 32.5%.
(f)At December 31, 2022, NEP retained certain Class B membership interests in NEP Renewables IV which will be sold to the Class B investors for approximately $178 million at a final funding expected to occur by the end of the third quarter of 2023. Until the final Class B funding, NEP will receive approximately 86% of NEP Renewables IV's cash distributions and the third-party investors will receive 14%.
(g)Increases to 95% if NEP has not exercised its entire buyout right by December 4, 2025.
(h)The buyout right is subject to certain limitations and/or extensions in the respective agreements, including, but not limited to, NEP being able to purchase a maximum of the Class B units following anniversaries specified in certain of the agreements.
(i)NEP may elect to pay the buyout price in NEP non-voting common units or cash (or any combination thereof), subject to conditions and limitations set forth in the applicable agreements. Percentages shown represent the maximum percentages NEP expects it can pay in NEP non-voting common units without the acquiescence of the Class B investor, subject to applicable closing conditions. Holders of the NEP non-voting common units will have the right to receive pro rata quarterly cash distributions and the right to convert, subject to certain limitations, the NEP non-voting common units into NEP common units on a one-for-one basis. The specified percentage of the buyout price for the Class B noncontrolling interests in STX Midstream are payable in NEP common units.
In 2018, a subsidiary of NEP sold Class B membership interests in NEP Renewables, with underlying renewable energy projects with a combined generating capacity of approximately 1,388 MW, to a third-party investor. In November 2021, NEP paid aggregate consideration of approximately $885 million, consisting of 7,253,580 NEP common units and approximately $265 million in cash to the third-party investor after electing to exercise the buyout right and purchase all of the Class B membership interests in NEP Renewables.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Accumulated Other Comprehensive Income (Loss)–
| | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | Accumulated Other Comprehensive Income (Loss) |
| | | | | Other Comprehensive Income (Loss) Related to Equity Method Investee | | Total |
| | | | | | | (millions) |
Balances, December 31, 2019 | | | | | $ | (22) | | | $ | (22) | |
| | | | | | | |
| | | | | | | |
Other comprehensive income related to equity method investee | | | | | 2 | | | 2 | |
| | | | | | | |
Balances, December 31, 2020 | | | | | (20) | | | (20) | |
| | | | | | | |
| | | | | | | |
Other comprehensive income related to equity method investee | | | | | 2 | | | 2 | |
| | | | | | | |
Balances, December 31, 2021 | | | | | (18) | | | (18) | |
| | | | | | | |
| | | | | | | |
Other comprehensive income related to equity method investee | | | | | 2 | | | 2 | |
| | | | | | | |
| | | | | | | |
Balances, December 31, 2022 | | | | | $ | (16) | | | $ | (16) | |
AOCI attributable to noncontrolling interest, December 31, 2022 | | | | | $ | (9) | | | $ | (9) | |
AOCI attributable to NextEra Energy Partners, December 31, 2022 | | | | | $ | (7) | | | $ | (7) | |
|
| | | | | | | | | | | | | | | | | | | |
| Accumulated Other Comprehensive Income (Loss) |
| Net Unrealized Gains (Losses) on Cash Flow Hedges | | Net Unrealized Gains (Losses) on Foreign Currency Translation | | Other Comprehensive Income (Loss) Related to Equity Method Investee | | Total |
| (millions) |
Balances, December 31, 2016 | $ | (4 | ) | | $ | (105 | ) | | $ | (35 | ) | | $ | (144 | ) |
Other comprehensive income before reclassification | — | | | 7 | | | — | | | 7 | |
Amounts reclassified from AOCI to interest expense | 5 | | | — | | | — | | | 5 | |
Other comprehensive income related to equity method investee | — | | | — | | | 5 | | | 5 | |
Net other comprehensive income | 5 | | | 7 | | | 5 | | | 17 | |
Balances, December 31, 2017 | 1 | | | (98 | ) | | (30 | ) | | (127 | ) |
Other comprehensive income before reclassification | — | | | (6 | ) | | — | | | (6 | ) |
Amounts reclassified from AOCI to interest expense | 2 | | | — | | | — | | | 2 | |
Other comprehensive income related to equity method investee | — | | | — | | | 6 | | | 6 | |
Net other comprehensive income (loss) | 2 | | | (6 | ) | | 6 | | | 2 | |
Impact of disposal of Canadian Holdings | 3 | | | 104 | | | — | | | 107 | |
Balances, December 31, 2018 | 6 | | | — | | | (24 | ) | | (18 | ) |
Amounts reclassified from AOCI to interest expense | (6 | ) | | — | | | — | | | (6 | ) |
Other comprehensive income related to equity method investee | — | | | — | | | 2 | | | 2 | |
Net other comprehensive income (loss) | (6 | ) | | — | | | 2 | | | (4 | ) |
Balances, December 31, 2019 | $ | — | | | $ | — | | | $ | (22 | ) | | $ | (22 | ) |
AOCI attributable to noncontrolling interest | $ | — | | | $ | — | | | $ | (14 | ) | | $ | (14 | ) |
AOCI attributable to NextEra Energy Partners, December 31, 2019 | $ | — | | | $ | — | | | $ | (8 | ) | | $ | (8 | ) |
13.14. Related Party Transactions
Each project entered into O&M and administrative services agreements (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 in NEP's consolidated statements of income (loss). Additionally, acertain NEP subsidiary pays an affiliatesubsidiaries pay affiliates for transmission and retail power services which are reflected as operations and maintenance in NEP's consolidated statements of income (loss). 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.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Management Services Agreement (MSA) -– Under the MSA, an indirect wholly owned subsidiary of NEE provides operational, management and administrative services to NEP, including managing NEP’s day-to-day affairs and providing individuals to act as NEP’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 pays 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 is 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 also makes certain payments to NEE based on the achievement by NEP OpCo of certain target quarterly distribution levels to its unitholders. NEP’s O&M expenses for the years ended December 31, 2019,2022, 20182021 and 20172020 include approximately $93$163 million, $78$138 million and $67$112 million, respectively, related to the MSA.
Cash Sweep and Credit Support Agreement (CSCS agreement) -– NEP OpCo is a party to the CSCS agreement with NEER under which NEER and certain of its affiliates provide credit support in the form of letters of credit and guarantees to satisfy NEP’s subsidiaries’ contractual obligations. NEP OpCo pays NEER an annual credit support fee based on the level and cost of the credit support provided, payable in quarterly installments. NEP’s O&M expenses for the years ended December 31, 2019,2022, 20182021 and 20172020 include approximately $7 million, $6 million $4 million and $4$6 million, respectively, related to the CSCS agreement.
NEER and certain of its affiliates may withdraw funds (Project Sweeps) received byfrom NEP OpCo under the CSCS agreement or itsNEP OpCo's subsidiaries in connection with certain long-term debt agreements, and hold those funds in accounts belonging to NEER or its affiliates 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 affiliates 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 or its affiliates fail to return withdrawn funds when required by NEP'sNEP OpCo's subsidiaries’ financing agreements, the lenders will be entitled to draw on any credit support provided by NEER or its affiliates 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. At December 31, 20192022 and 20182021, the cash sweep amounts held in accounts belonging to NEER or its affiliates were approximately $12$298 million and $66$57 million, respectively, and are included in due from related parties on NEP’s 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. NextEra Energy Capital Holdings, Inc. (NEECH) or NEER has provided letters of credit or
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Concluded)
guarantees for certain of these performance obligations and payment of any obligations from the transactions contemplated by the PPAs. In addition, certain 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 surety 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. In addition, NEECH and NEER provided guarantees associated with obligations, primarily incurred and future construction payables, associated with the December 2022 acquisition from NEER discussed in Note 3. At December 31, 2019,2022, NEECH or NEER guaranteed or provided indemnifications, letters of credit or surety bonds totaling approximately $658 million related to these obligations. Agreements related to the sale of differential membership interests require NEER to guarantee payments due by the VIEs and the indemnifications to the VIEs' respective investors. At December 31, 2019, NEER guaranteed a total of approximately $11 million$4.6 billion related to these obligations.
Related Party Long-Term Debt –In connection with the December 2022 acquisition from NEER of Emerald Breeze (see Note 3), a subsidiary of NEP acquired a note payable from a subsidiary of NEER relating to restricted cash reserve funds put in place for certain operational costs at the project based on a requirement of the differential membership investor. At December 31, 2022, the note payable was approximately $48 million and is included in long-term debt on NEP's consolidated balance sheets. The note payable does not bear interest and does not have a maturity date.
Due to Related PartyParties - Non-current– Noncurrent amounts due to related partyparties on NEP's consolidated balance sheets primarily 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 noncurrent other non-current assets on NEP’s consolidated balance sheets.
Transportation and Fuel Management Agreements -– 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 years ended December 31, 2019, 20182022, 2021 and 2017,2020, NEP recognized approximately $7$9 million, $7$36 million and $9$15 million, respectively, in revenues related to the transportation and fuel management agreements. The increase in the recognized revenues in 2021 primarily relates to higher demand and the related impact on natural gas prices during extreme winter weather experienced primarily in Texas during February 2021.
Related Party Note Receivable -– As part of the 2016 acquisition from NEER of Seiling Wind Investments, LLC, a subsidiary of NEP acquired an approximately $25 million receivable from a subsidiary of NEER (Seiling related party note receivable) relating to operational performance issues at this facility.the related projects. The Seiling related party note receivable is intended to compensate NEP for the operational performance issues and is supported in full by compensation expected from an equipment vendor under an undertaking the vendor has with NEER. This receivable bears interest at 7.1% per annum, is payable by NEER in equal semi-annual installments and matures in December 2035. During each of the years ended December 31, 2019, 20182022, 2021 and 2017,2020, NEP received payments of approximately $2 million. The Seiling related party note receivable, interest and related payments are reflected in noncontrolling interests on NEP's consolidated financial statements.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
14. Leases
NEP has operating leases primarily related to land use agreements for certain of its renewable energy projects. At December 31, 2019 and 2018, NEP had recorded ROU assets of approximately $43 million and $24 million, respectively, and $41 million and $24 million of operating lease liabilities, respectively. NEP’s operating lease liabilities were calculated based on a weighted average discount rate of 4.52% and 4.46% based on the incremental borrowing rate at the lease commencement date and have a weighted-average remaining lease term of 25 years and 25 years, at December 31, 2019 and 2018, respectively. Lease payments under the land use agreements, which convey exclusive use of the land during the arrangement, are either fixed based on the terms of the related lease agreement or variable primarily based on the amount of generation at the renewable energy project. NEP’s operating leases with fixed payments have expiration dates ranging from 2022 to 2046. NEP recognized approximately $3 million, $2 million, and $2 million in 2019, 2018 and 2017, respectively, of operating lease costs associated with its ROU assets and which are included in O&M expenses in NEP’s consolidated statements of income (loss). In addition, approximately $7 million, $5 million and $5 million was recorded related to variable lease costs in 2019, 2018 and 2017, respectively. Short-term lease expense, which is included in O&M expenses, was not material to NEP’s consolidated statements of income (loss) for the periods presented. At December 31, 2019, NEP's lease agreements call for fixed payments of approximately $3 million annually over the next five years and $56 million thereafter.
15. Commitments and Contingencies
Development, Engineering and Construction Commitments - At December 31, 2019, indirect subsidiaries of NEP had several engineering, procurement and construction contracts and a funding commitment related to the repowering of certain wind facilities and expansion projects at certain pipelines. Those contracts have varying payment terms and some include performance obligations that allow the NEP subsidiaries to receive liquidated damages if the contractor does not perform. As of December 31, 2019, the NEP subsidiaries had purchased approximately $54 million under these contracts, of which $36 million was purchased from NEER. Such costs primarily have been capitalized in property, plant and equipment - net on the consolidated balance sheets. As of December 31, 2019, the NEP subsidiaries have remaining commitments under these contracts of approximately $278 million.
PG&E Bankruptcy - During 2019, approximately $1 million of net income attributable to NEP relates to PPAs that the Genesis, Desert Sunlight and Shafter solar projects have with PG&E. On January 29, 2019, PG&E filed a voluntary petition for reorganization under Chapter 11 of the U.S. Bankruptcy Code. While PG&E or other stakeholders in the bankruptcy proceeding could seek to reject some or all of the PPAs, PG&E's proposed plan of reorganization, which is the only plan of reorganization that is progressing through the PG&E bankruptcy proceeding as of February 18, 2020, specifies that PG&E would assume all of the PPAs. PG&E’s Chapter 11 filing, or related events, caused events of default under the financings for the Genesis and Shafter projects, which, among other things, blocked the distribution of cash generated by those projects.
At December 31, 2018, the debt outstanding under the Genesis and Shafter financings totaled approximately $682 million, of which $641 million with scheduled final maturity dates ranging from 2033 to 2038 was reclassified into current debt on NEP's consolidated balance sheets. An indirect subsidiary of NEP repaid or redeemed all of the outstanding principal under the Genesis financings during 2019. At December 31, 2019, the debt outstanding under the Shafter financing totaled approximately $25 million, substantially all of which was classified as long-term debt as a result of a default waiver obtained in April 2019 that extends to April 2021.
Based on the estimated future cash flows related to the Genesis, Shafter and Desert Sunlight solar projects, 0 impairment adjustment was recorded at December 31, 2019. NEP will continue to monitor its investments in these projects. At December 31, 2019, cumulative cash distributions of approximately $41 million from the Shafter and Desert Sunlight solar projects were not distributed as a result of the events of default under the financings that arose due to PG&E’s bankruptcy filing.
NEXTERA ENERGY PARTNERS, LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Concluded)
16. Quarterly Data (Unaudited)
Condensed consolidated quarterly financial information is as follows:
|
| | | | | | | | | | | | | | | |
| March 31(a) | | June 30(a) | | September 30(a) | | December 31(a) |
| (millions, except per unit amounts) |
2019 | | | | | | | |
Operating revenues | $ | 177 |
| | $ | 219 |
| | $ | 253 |
| | $ | 206 |
|
Operating income | $ | 34 |
| | $ | 67 |
| | $ | 88 |
| | $ | 43 |
|
Net income (loss) | $ | (121 | ) | | $ | (124 | ) | | $ | (243 | ) | | $ | 83 |
|
Net income (loss) attributable to NEP | $ | (22 | ) | | $ | (28 | ) | | $ | (72 | ) | | $ | 34 |
|
Earnings (loss) per unit - basic | $ | (0.38 | ) | | $ | (0.49 | ) | | $ | (1.21 | ) | | $ | 0.53 |
|
Earnings (loss) per unit - assuming dilution | $ | (0.38 | ) | | $ | (0.49 | ) | | $ | (1.21 | ) | | $ | 0.50 |
|
Distributions per unit | $ | 0.47 |
| | $ | 0.48 |
| | $ | 0.50 |
| | $ | 0.52 |
|
High-low common unit sales prices | $47.98 - $39.51 |
| | $50.50 - $43.68 |
| | $53.90 - $47.45 |
| | $53.63 - $49.89 |
|
| | | | | | | |
2018 | | | | | | | |
Operating revenues | $ | 212 |
| | $ | 225 |
| | $ | 178 |
| | $ | 155 |
|
Operating income(b) | $ | 92 |
| | $ | 261 |
| | $ | 59 |
| | $ | 31 |
|
Net income (loss)(b)(c) | $ | (19 | ) | | $ | 292 |
| | $ | 110 |
| | $ | (117 | ) |
Net income (loss) attributable to NEP(b)(c) | $ | 74 |
| | $ | 82 |
| | $ | 33 |
| | $ | (22 | ) |
Earnings (loss) per unit - basic | $ | 1.36 |
| | $ | 1.51 |
| | $ | 0.60 |
| | $ | (0.39 | ) |
Earnings (loss) per unit - assuming dilution | $ | 1.22 |
| | $ | 1.42 |
| | $ | 0.58 |
| | $ | (0.39 | ) |
Distributions per unit | $ | 0.41 |
| | $ | 0.42 |
| | $ | 0.44 |
| | $ | 0.45 |
|
High-low common unit sales prices | $45.38 - $36.84 |
| | $48.75 - $38.05 |
| | $50.66 - $44.04 |
| | $49.16 - $39.35 |
|
______________________
| |
(a) | In the opinion of management, all adjustments, which consist of normal recurring accruals necessary to present a fair statement of the amounts shown for such periods, have been made. Results of operations for an interim period generally will not give a true indication of results for the year. Variations in operations reported on a quarterly basis primarily reflect the seasonal nature of NEP's business. The sum of the quarterly amounts may not equal the total for the year due to rounding. |
| |
(b) | Second quarter of 2018 includes the gain on the sale of Canadian Holdings. See Note 2 - Disposal of Canadian Holdings. |
| |
(c) | First quarter of 2018 reflects a reduction of differential membership interests as a result of the change in federal income tax rates effective January 1, 2018, which is included in net loss attributable to noncontrolling interests. See Note 2 - Noncontrolling Interests. |
Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure
None
Item 9A. Controls and Procedures
Disclosure Controls and Procedures
As of December 31, 2019,2022, NEP had performed an evaluation, under the supervision and with the participation of its management, including its chief executive officer and chief financial officer, 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 concluded that NEP's disclosure controls and procedures were effective as of December 31, 2019.2022.
Internal Control Over Financial Reporting
(a) Management's Annual Report on Internal Control Over Financial Reporting
See Item 8. Financial Statements and Supplementary Data.
(b) Attestation Report of the Independent Registered Public Accounting Firm
See Item 8. Financial Statements and Supplementary Data.
(c) 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. However, 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.
Item 9B. Other Information
None
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections
Not applicable
PART III -– OTHER INFORMATION
Item 10. Directors, Executive Officers and Corporate Governance
The information required by this item will be included under the headings "Business of the Annual Meeting," "Information About NextEra Energy Partners and Management" and "Corporate Governance and Board Matters" in NEP's Proxy Statement which will be filed with the SEC in connection with the 20202023 Annual Meeting of Unitholders (NEP's Proxy Statement) and is incorporated herein by reference.
NEP has adopted the NextEra Energy Partners, LP Code of Ethics for Senior Executive and Financial Officers (the Senior Financial Executive Code), which is applicable to the chief executive officer, the chief financial officer, the chief accounting officer and other senior executive and financial officers. The Senior Financial Executive Code is available under Corporate Governance in the Investor Relations section of NEP’s internet website at www.nexteraenergypartners.com. Any amendments or waivers of the Senior Financial Executive Code which are required to be disclosed to unitholders under SEC rules will be disclosed on NEP’s website at the address listed above.
Item 11. Executive Compensation
The information required by this item will be included in NEP's Proxy Statement under the headings "Executive Compensation" and "Corporate Governance and Board Matters" and is incorporated herein by reference.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The information required by this item relating to security ownership of certain beneficial owners and management will be included in NEP's Proxy Statement under the heading "Information About NextEra Energy Partners and Management" and is incorporated herein by reference.
Securities Authorized for Issuance Under Equity Compensation Plans
The following table provides certain information as of December 31, 20192022 with respect to equity compensation under the NextEra Energy Partners, LP 2014 Long-Term Incentive Plan:
|
| | | | | | | | | | | | | | | | | | | | | |
Plan Category | | Number of securities to be issued upon exercise of outstanding options, warrants and rights | | | Weighted-average exercise price of outstanding options, warrants and rights | | Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in the first column) | |
Equity compensation plans approved by security holders | | — |
| | | N/A | | 1,138,5021,009,401 |
| |
Equity compensation plans not approved by security holders | | — |
| | | N/A | | — |
| |
Total | | — |
| | | N/A | | 1,138,5021,009,401 |
| |
Item 13. Certain Relationships and Related Transactions, and Director Independence
The information required by this item, to the extent applicable, will be included in NEP's Proxy Statement under the heading "Corporate Governance and Board Matters" and is incorporated herein by reference.
Item 14. Principal AccountingAccountant Fees and Services
The information required by this item will be included in NEP's Proxy Statement under the heading "Audit-Related Matters" and is incorporated herein by reference.
PART IV
Item 15. Exhibits and Financial Statement Schedules
| | | | | | | | | | | |
| | | Page(s) |
(a) | 1 | Financial Statements | Page(s) |
(a) | 1. | Financial Statements | |
| | Management's Report on Internal Control over Financial Reporting | |
| | Attestation Report of Independent Registered Public Accounting Firm | |
| | Report of Independent Registered Public Accounting Firm (PCAOB ID 34) | |
| | Consolidated Statements of Income (Loss) | |
| | Consolidated Statements of Comprehensive Income (Loss) | |
| | Consolidated Balance Sheets | |
| | Consolidated Statements of Cash Flows | |
| | Consolidated Statements of Changes in Equity | |
| | Notes to Consolidated Financial Statements | |
| | | |
| 2.2 | Financial Statement Schedules -– Schedules are omitted as not applicable or not required. | |
| | | |
| 3.3 | Exhibits (including those incorporated by reference) | |
|
| | | | | | | |
Exhibit Number | | Description |
2.1* | | Amended and Restated Purchase and Sale Agreement, dated as of February 22, 2016, by and between NEP US SellCo, LLC and NextEra Energy Partners Acquisitions, LLC, as amended by First Global Amendment to Amended and Restated Purchase and Sale Agreement, dated as of September 8, 2016, by and between NEP US SellCo, LLC, NextEra Energy Partners Acquisitions, LLC and ESI Energy, LLC (filed as Exhibit 2.1 to Form 10-Q for the quarter ended September 30, 2017, File No. 1-36518) |
2.2* | | |
| | |
2.2* | | Membership Interest Purchase Agreement, dated as of November 2, 2020, among Genesis Solar Holdings, LLC, NextEra Energy Partners, LP, Genesis Solar Funding, LLC, and the Class B purchasers party thereto (filed as Exhibit 2.1 to Form 8-K dated November 2, 2020, File 1-36518) |
2.2(a)* | | Amendment to Membership Interest Purchase Agreement, dated as of May 16, 2021, among Genesis Solar Holdings, LLC, NextEra Energy Partners, LP, Genesis Solar Funding, LLC and the Class B purchasers thereto (filed as Exhibit 2.1 to Form 8-K dated May 16, 2021, File No. 1-36518) |
2.3* | | Amendment to Amended and Restated Purchase and Sale Agreement (Desert Sunlight, Nokota,(2020 Projects Annex), dated as of November 2, 2020, by and Javelinaamong NEP US SellCo LLC, NextEra Energy Partners Acquisitions, LLC and ESI Energy, LLC (filed as Exhibit 2.3 to Form 8-K dated November 2, 2020, File 1-36518) |
2.4* | | |
2.5* | | Amendment to Amended and Restated Purchase and Sale Agreement (2021-B Projects Annex), dated as of October 25, 2017,21, 2021, by and among NEP US SellCo LLC and NEP US SellCo II LLC, NextEra Energy Partners Acquisitions, LLC and ESI Energy, LLC (filed as Exhibit 2.2 to Form 10-Q for the quarter ended September 30, 2017,2021, File No. 1-36518) |
2.3*2.6* | | Membership Interest Purchase and Sale Agreement, by and between NextEra Energy Operating Partners, LP and Canada Pension Plan Investment Board dated as of March 30, 2018October 21, 2021, among NEP Renewables III Holdings, LLC, NextEra Energy Partners, LP, NEP Renewables III, LLC, and the Class B purchasers party thereto (filed as Exhibit 2.12.3 to Form 8-K dated March10-Q for the quarter ended September 30, 2018,2021, File No. 1-36518) |
2.4*2.7* | | Amendment to Amended and Restated Purchase and Sale Agreement (2018(2022-A Projects Annex), dated as of August 31, 2018,April 20, 2022, by and among NEP US SellCo LLC, NextEra Energy Partners Acquisitions, LLC and ESI Energy, LLC (filed as Exhibit 2.2 to Form 8-K dated August10-Q for the quarter ended March 31 2018,, 2022, File No. 1-36518) |
2.5*2.8* | | |
2.9* | | Membership Interest Purchase Agreement, dated as of August 31, 2018, betweenNovember 17, 2022, among NEP Renewables IV, LLC, NEP Renewables Holdings IV, LLC, NextEra Energy Partners, LP, NEP Renewables Holdings, LLC and the Class B purchasers party thereto (filed as Exhibit 2.3 to Form 8-K dated August 31, 2018,November 17, 2022, File No. 1-36518) |
2.6*3.1* | | |
2.7* | | Membership Interest Purchase Agreement, dated as of March 4, 2019, between NEP Renewables II, LLC, NextEra Energy Partners, LP, NEP Renewables Holdings II, LLC and the Class B Purchasers party thereto (filed as Exhibit 2.3 to Form 8-K dated March 4, 2019, File No. 1-36518) |
2.8* | | Purchase and Sale Agreement by and among EIF Meade Holdings, LLC, VED NPI II, LLC, VED NPI I, LLC, WGL Midstream MP, LLC and COG Holdings LLC, and Meade Pipeline Investment, LLC, dated as of September 29, 2019 (filed as Exhibit 2.1 to Form 8‑K dated September 29, 2019, File No. 1-36518) |
2.9* | | Membership Interest Purchase Agreement, dated as of September 29, 2019, by and among NextEra Energy Partners Pipelines, LLC, NextEra Energy Partners, LP, NextEra Energy Partners Pipelines Holdings, LLC and GEPIF III Meade Investco, L.P. (filed as Exhibit 2.2 to Form 8-K dated September 29, 2019, File No. 1-36518) |
3.1* | | |
3.2* | | |
3.3* | | |
3.4* | | |
4.1* | | |
4.2*4.1* | | |
4.3*4.2* | | |
|
4.2(a)* | | |
Exhibit
Number
| | Description |
4.3(a)* | | |
4.4*4.3* | | |
| | | | | | | | |
4.4(a)*Exhibit Number | | Description |
4.3(a)* | | |
4.5*4.4* | | |
4.6*4.5* | | |
4.7*4.6* | | |
4.84.7* | | |
4.8* | | |
4.9* | | |
4.10 | | |
10.1* | | SecondThird Amended and Restated Management Services Agreement, dated as of August 4, 2017,June 9, 2022, by and among NextEra Energy Partners, LP, NextEra Energy Operating Partners GP, LLC, NextEra Energy Operating Partners, LP and NextEra Energy Management Partners, LP (filed as Exhibit 10.210.1 to Form 8-K dated August 4, 2017,June 14, 2022, File No. 1-36518) |
10.2* | | |
10.3* | | |
10.4*10.3* | | 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 1, 2014 (filed as Exhibit 10.5 to Form 8‑K dated July 1, 2014, File No. 1-36518) |
10.4(a)10.3(a)* | | |
10.5*10.4* | | |
10.6*10.5* | | Second Amended and Restated Revolving Credit Agreement by and between NextEra Energy US Partners Holdings, LLC, NextEra Energy Operating Partners, LP and the lenders party thereto, dated as of October 24, 2017May 27, 2022 (filed as Exhibit 10.610.1 to Form 10-Q for the quarter ended September 30, 2017,8-K dated May 27, 2022, File No. 1-36518) |
10.6(a)*10.5(a) | |
|
10.6(b)10.6* | | |
10.6(c) | | |
10.7* | | |
10.8*10.7* | | NextEra Energy Partners, LP Guaranty dated as of July 1, 2014 in favor of Bank of America, N.A., as collateral agent under the Revolving Credit Agreement by and between NextEra Energy US Partners Holdings, LLC, NextEra Energy Operating Partners, LP, Bank of America, N.A., as administrative agent and collateral agent, and the lenders party thereto, dated as of July 1, 2014 (filed as Exhibit 10.1 to Form 10‑Q for the quarter ended March 31, 2015, File No. 1-36518) |
10.9*10.8* | | |
10.10*10.9* | | |
10.11*10.9(a)* | | |
10.10* | | Right of First Refusal Agreement, dated as of August 4, 2017, by and among NextEra Energy Partners, LP, NextEra Energy Operating Partners, LP, and NextEra Energy Resources, LLC (filed as Exhibit 10.3 to Form 8-K dated August 4, 2017, File No. 1-36518) |
10.12* | | |
10.12(a)* | | |
10.13*10.11* | | |
10.14*10.12* | | |
10.13* | | |
10.15* | | |
|
| | |
Exhibit
Number 10.14* | | Description |
10.16* | | |
10.17 | | |
10.18* | | |
10.19*10.15* | | Amended and Restated Limited Liability Company AgreementNextEra Energy Partners, LP Compensation Summary for Independent Non-Employee Director of NEP Renewables, LLC, dated December 21, 2018NextEra Energy Partners, LP, effective January 1, 2021 (filed as Exhibit 10.210.17 to Form 8-K dated10-K for the year ended December 20, 2018,31, 2020, File No. 1-36518) |
10.20*10.16* | | |
10.17 | | |
| | |
10.18* | | |
10.21*10.19* | | Contribution Agreement among South Texas Midstream, LLC, NextEra Energy Partners, LP, South Texas Midstream Holdings, LLC, and EIG NET Holdings III, LLC, dated November 1, 2019 (filed as Exhibit 10.1 to Form 8-K dated November 1, 2019, File No. 1-36518) |
| | | | | | | | |
10.22*Exhibit Number | | Description |
10.20* | | |
10.23*10.21* | | |
2110.22* | | |
10.22(a)* | | |
10.23* | | |
10.24* | | |
21 | | |
23 | | |
31(a) | | |
31(b) | | |
32 | | |
101.INS | | XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document |
101.SCH | | Inline XBRL Schema Document |
101.PRE | | Inline XBRL Presentation Linkbase Document |
101.CAL | | Inline XBRL Calculation Linkbase Document |
101.LAB | | Inline XBRL Label Linkbase Document |
101.DEF | | Inline XBRL Definition Linkbase Document |
104 | | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) |
__________________________
| |
* | Incorporated herein by reference. |
* 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.
Item 16. Form 10-K Summary
Not applicable.
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: February 18, 2020
| | | | | |
NEXTERA ENERGY PARTNERS, LP |
(Registrant) |
|
|
|
NEXTERA ENERGY PARTNERS, LP |
(Registrant)JOHN W. KETCHUM |
|
|
|
|
JAMES L. ROBO |
James L. Robo
John W. Ketchum Chairman of the Board, Chief Executive Officer and Director
(Principal Executive Officer)
|
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities with NextEra Energy Partners, LP and on the date indicated.
Signature and Title as ofFebruary 18, 202022, 2023:
| | | | | | | | |
| | |
REBECCA J. KUJAWA | | |
TERRELL KIRK CREWS II | | JAMES M. MAY |
Rebecca J. Kujawa
Terrell Kirk Crews II Chief Financial Officer and Director (Principal Financial Officer)
| | James M. May Controller and Chief Accounting Officer (Principal Accounting Officer) |
| | | | | | | | |
| | |
| | |
| | |
SUSAN DAVENPORT AUSTIN | | PETER H. KIND |
Susan Davenport Austin Director | | Peter H. Kind Director |
| | | | | | | | |
| | |
| | |
| | |
ROBERT J. BYRNE | | JOHN W. KETCHUMREBECCA J. KUJAWA |
Robert J. Byrne Director | | John W. KetchumRebecca J. Kujawa
Director
|
| | |
| | |
| | |
MARK E. HICKSON | | |
Mark E. Hickson Director | | |