Publicly traded partnerships (PTPs), often called master limited partnerships (MLPs), occupy a unique position in the U.S. tax code that offers significant advantages but also introduces substantial complexity for investors. Unlike corporations that face double taxation—once at the entity level and again when dividends are distributed to shareholders—PTPs structured to meet specific requirements under Internal Revenue Code Section 7704 avoid entity-level taxation and pass income, deductions, and credits directly to their partners. This pass-through treatment, combined with the liquidity of publicly traded securities, makes PTPs an attractive investment vehicle, particularly in the energy infrastructure and natural resources sectors where they are predominantly concentrated.
The taxation of PTPs hinges on a critical threshold: partnerships must derive at least 90% of their gross income from “qualifying income” sources to retain pass-through tax treatment. Those failing this test are taxed as corporations, subjecting investors to the very double taxation PTPs were designed to avoid. This requirement, established by the Revenue Act of 1987, was Congress’s response to concerns that widespread use of publicly traded partnerships would erode the corporate tax base.
For investors who meet the qualifying income threshold, PTPs offer compelling tax advantages, including tax-deferred distributions through return of capital, depreciation and depletion benefits that shelter current income, and potential access to the Section 199A qualified business income deduction that can reduce effective tax rates by up to 20%. However, these benefits come with significant trade-offs: complex annual tax reporting via Schedule K-1 forms that often arrive late in tax season, mandatory multi-state filing requirements even for small investments, intricate basis tracking obligations that span the entire investment period, and potential exposure to unrelated business taxable income for tax-exempt entities.
This comprehensive analysis examines the complete tax framework governing PTPs, from foundational statutory requirements to practical investor considerations. Understanding PTP taxation is essential not only for individual investors evaluating these high-yield securities but also for tax professionals navigating one of the most complex areas of partnership taxation.
Understanding Publicly Traded Partnerships: Definition and Structure
A publicly traded partnership is a partnership whose interests are either traded on an established securities market or are readily tradable on a secondary market (or its substantial equivalent). This definition encompasses two critical elements: the partnership must be organized as a partnership for federal tax purposes, and its ownership interests must have the liquidity characteristics of publicly traded securities.
The term “PTP” and “MLP” are often used interchangeably in practice, though technically MLPs represent a specific organizational form—a limited partnership that conducts operations through subsidiaries—while PTPs is the broader statutory category. Most PTPs are indeed organized as MLPs, featuring a two-tier ownership structure with general partners who manage operations and assume unlimited liability, and limited partners who provide capital but have no management role and limited liability.
The modern PTP structure emerged in 1981 when Apache Corporation formed the United States’ first MLP, Apache Petroleum Company. The concept proved so attractive that by the mid-1980s, PTPs proliferated across diverse industries including real estate, restaurants, hotels, and even professional sports teams—the Boston Celtics basketball franchise became an MLP. This rapid expansion triggered congressional concern about corporate tax base erosion, leading directly to the enactment of Section 7704 in 1987.
The Section 7704 Framework: The 90% Qualifying Income Test
Section 7704 of the Internal Revenue Code establishes the fundamental tax rule for PTPs: a publicly traded partnership is taxed as a corporation unless it meets the gross income requirements. Specifically, a PTP retains partnership tax treatment if 90% or more of its gross income for each taxable year consists of “qualifying income”.
This 90% threshold operates as a bright-line test that PTPs must satisfy annually. A partnership that meets the test in one year but fails in a subsequent year immediately loses partnership tax treatment and becomes taxable as a corporation. The partnership must meet the 90-percent test for its first taxable year after 1987 in which it is a PTP and every year thereafter.
The definition of “gross income” for purposes of this test varies depending on the partnership’s activities. For service-providing partnerships, gross income means gross revenue before costs. For partnerships that sell products, gross income is defined as sales less cost of goods sold—effectively gross margin. This distinction can significantly impact whether a partnership meets the 90% threshold.
Qualifying Income: Categories and Definitions
Section 7704(d)(1) defines qualifying income to include several categories of passive-type income as well as income from natural resources activities. The statute specifies qualifying income as:
Passive Investment Income. Interest, dividends, real property rents, and gains from the sale or disposition of real property (including property described in Section 1221(a)(1)) constitute qualifying income. This category encompasses traditional passive investment returns. However, income that would qualify under the regulated investment company provisions of Section 851(b)(2)(A) or the real estate investment trust provisions of Section 856(c)(2) also qualifies.
Natural Resources Income. The most significant qualifying income category for PTPs is “income and gains derived from the exploration, development, mining or production, processing, refining, transportation (including pipelines transporting gas, oil, or products thereof), or the marketing of any mineral or natural resource (including fertilizer, geothermal energy, and timber)”. This broad definition encompasses the full value chain of natural resource activities and explains why PTPs are concentrated in the energy sector.
The Internal Revenue Service published final regulations in January 2017 that provide detailed guidance on what constitutes qualifying income from natural resources activities. These regulations clarify several important points. First, minerals and natural resources are defined by reference to Section 613, which governs percentage depletion. Excluded from the definition are soil, sod, dirt, turf, water, mosses, and minerals from seawater, air, or similar inexhaustible sources (although minerals other than sodium chloride extracted from brines pumped from saline perennial lakes within the United States are not considered from an inexhaustible source).
Second, the regulations recognize that certain “intrinsic activities” supporting natural resources operations can generate qualifying income even though they are not explicitly listed in Section 7704(d)(1)(E). To qualify as intrinsic, an activity must meet three requirements: it must be specialized (requiring personnel with training unique to the mineral or natural resource industry), essential (required to comply with law or physically complete the natural resources activity), and require significant services.
Third, the regulations address specific examples that have generated controversy. For instance, petroleum coke qualifies as a natural resource, but not if it is upgraded to calcined coke or anode-grade coke because it is then no longer considered a primary product. Transportation of liquefied petroleum gas to retail customers generates qualifying income. Sand qualifies as a depletable mineral, and its sale to oil companies for well fracking produces qualifying income—a determination with significant implications given the hydraulic fracturing boom.
Passive Mineral Interests. Income from passive mineral interests such as production royalties, minimum annual royalties, net profits interests, delay rentals, and lease-bonus payments constitutes qualifying income. This allows PTPs to hold royalty interests and working interests without jeopardizing their qualifying income status.
Partnership Interests. Significantly, dividends received from corporate subsidiaries can constitute qualifying income. This is particularly important because Congress was aware when enacting Section 7704 that partnerships might use corporate subsidiaries for “downstream” operations such as milling, processing, refining, or marketing activities that generate non-qualifying income. By allowing such income to be taxed at the corporate level and then distributed to the PTP as dividends, the statute prevents partnerships from circumventing the qualifying income test while still protecting the corporate tax base.
Historical Evolution and Legislative Changes
Congress enacted Section 7704 in 1987 due to concerns that the widespread use of PTPs would lead to extensive disincorporation of American businesses and consequent erosion of corporate tax revenues. The legislative history makes clear that while there were varying views on the degree to which PTPs should be restricted, there was considerable support for the idea that the natural resources industry, which had always operated through partnerships, should continue to receive pass-through tax treatment.
In 2008, Congress expanded the definition of qualifying income for the first time since Section 7704’s enactment, allowing MLPs to earn income from the storage and transportation of alternative fuels. This expansion reflected the same policy rationales that applied to traditional energy sources in 1987—the need to increase domestic energy production and achieve energy independence.
Tax Treatment for PTP Investors: Pass-Through Mechanics
When a PTP meets the 90% qualifying income test, it is treated as a partnership for federal income tax purposes. This means the partnership itself pays no federal income tax at the entity level. Instead, all items of income, gain, deduction, loss, and credit flow through to the partners, who report these items on their individual tax returns and pay tax at their personal rates.
Schedule K-1: The Central Reporting Document
Unlike stockholders in corporations who receive Form 1099-DIV reporting dividends, PTP investors receive Schedule K-1 (Form 1065), which details their allocable share of partnership tax items. The K-1 is a complex document that can span multiple pages when supporting schedules and footnotes are included.
Schedule K-1 contains three main parts. Part I provides information about the partnership itself, including whether it is a publicly traded partnership. Part II provides information about the partner, including the partner’s ownership percentage, capital account analysis, and share of partnership liabilities. Part III details the partner’s share of current year income, deductions, credits, and other items, with information organized across more than 20 boxes, many containing multiple code designations.
The timing of K-1 delivery creates practical challenges for investors. Partnerships must furnish K-1s to partners by the due date of Form 1065, which is March 15 for calendar-year partnerships (March 17, 2026 for calendar year 2025). This is later than the typical Form 1099 delivery deadline, and in practice many PTPs deliver K-1s even later, often not until mid-to-late March or even into April for complex partnerships. For taxpayers who wish to file their returns early or who are part of flowthrough entities that need K-1 information to prepare their own returns, this late delivery can be problematic.
The content reported on a PTP K-1 can be extraordinarily complex. A single PTP investment can result in reportable amounts across numerous boxes: ordinary business income or loss (Box 1), guaranteed payments (Box 4), interest income (Box 5), dividend income (Box 6), royalties (Box 7), net short-term capital gain or loss (Box 8), net long-term capital gain or loss (Box 9), Section 1231 gains and losses (Box 10), other income and deductions (Box 11), Section 179 deduction (Box 12), other deductions (Box 13), self-employment earnings (Box 14), credits (Box 15), alternative minimum tax items (Box 17), tax-exempt income (Box 18), distributions (Box 19), and other information including Section 199A qualified business income data, UBTI, and foreign taxes (Box 20).
Each of these items must be reported in the correct location on the partner’s Form 1040. Box 1 ordinary income typically flows to Schedule E, Part II. Capital gains and losses flow to Schedule D and Form 8949. Section 1231 gains and losses are reported on Form 4797. AMT items require Form 6251. Section 199A information is used to calculate the qualified business income deduction on Form 8995 or 8995-A. This complexity multiplies when an investor holds multiple PTPs, as each generates its own K-1 with potentially different combinations of tax items.
Return of Capital: The Tax Deferral Mechanism
One of the most attractive features of PTP investments is that a significant portion of distributions is often treated as a return of capital (ROC) rather than taxable income in the year received. This occurs because PTPs, particularly those in capital-intensive industries like energy infrastructure, claim substantial depreciation and depletion deductions that exceed their taxable income allocations to partners.
The mechanics work as follows. Assume a PTP distributes $1,000 to an investor during the year but allocates only $300 of taxable income to that investor on the K-1. The $300 is taxable in the current year. The remaining $700 is classified as a return of capital. This $700 is not taxed immediately. Instead, it reduces the partner’s tax basis in the partnership interest.
Return of capital treatment creates tax deferral, not tax elimination. When the partner eventually sells the PTP units, the reduced basis results in a larger capital gain (or smaller capital loss). In effect, the “tax-free” distributions received over the years are recaptured as capital gain on sale. For an investor in a high ordinary income tax bracket, this can still be beneficial if the gain is taxed at the preferential long-term capital gains rate rather than ordinary income rates.
However, if distributions reduce basis to zero, any additional distributions are immediately taxable as capital gain under Section 731. This can create an unexpected current tax liability for investors who assume all distributions are tax-deferred.
The tax reporting of distributions can be confusing. Box 19 of the K-1 reports cash distributions, but this is an informational item, not a directly taxable amount. The taxable income is reported in Boxes 1 through 18, and the difference between total distributions and total taxable income represents the return of capital amount that reduces basis.
Basis Tracking: A Multi-Dimensional Requirement
Partners in PTPs must maintain three separate basis calculations: tax basis (also called outside basis), at-risk basis, and alternative minimum tax (AMT) basis. Each serves a different purpose in limiting loss deductions and calculating gain on sale.
Tax Basis (Outside Basis). Tax basis begins with the partner’s initial investment—the amount paid to acquire the units, including any acquisition costs. This basis is then adjusted annually for the partner’s share of partnership items. Basis increases for the partner’s share of partnership income (including tax-exempt income) and the partner’s share of increases in partnership liabilities. Basis decreases for distributions received, the partner’s share of partnership losses and nondeductible expenses, and the partner’s share of decreases in partnership liabilities.
The basis adjustments for partnership liabilities are unique to partnership taxation and can be particularly complex. A partner’s share of partnership liabilities is treated as a deemed contribution that increases basis, while a decrease in the share of liabilities is treated as a deemed distribution that reduces basis. For PTPs, liability allocations are reported in Box K of Schedule K-1 Part II and must be factored into basis calculations.
Distributions of cash or property that exceed a partner’s basis trigger immediate gain recognition under Section 731. This “excess distribution” is taxed as capital gain in the year received. Similarly, if a partner is allocated losses that exceed basis, those excess losses are suspended and carried forward until the partner has sufficient basis to absorb them or until the partnership interest is sold.
At-Risk Basis. Even if a partner has sufficient tax basis to claim a loss, Section 465 imposes an additional limitation: losses are deductible only to the extent the partner is “at risk” in the activity. Generally, a partner is at risk for cash and the adjusted basis of property contributed to the partnership, plus the partner’s share of partnership liabilities for which the partner is personally liable. For most limited partners in PTPs, the at-risk amount equals the tax basis because limited partners typically have no personal liability for partnership debts beyond their investment. However, if a partnership has significant nonrecourse financing or if a limited partner’s basis includes items for which the partner is not at risk, the at-risk limitation can become binding.
AMT Basis. For purposes of the alternative minimum tax, partners must maintain a separate basis calculation. AMT basis is adjusted for AMT income and deduction items rather than regular tax items. This separate calculation is necessary because many PTPs generate AMT preference items and adjustments, such as accelerated depreciation differences, percentage depletion in excess of cost basis, and intangible drilling costs. Box 17 of the K-1 reports AMT items, and partners must use this information to calculate AMT basis separately from regular tax basis.
Maintaining these three basis calculations across multiple years and potentially multiple PTP investments requires meticulous record-keeping. Partners must retain all K-1s received from the date of initial investment through the date of final disposition, as each year’s adjustments build upon prior years. Many PTPs provide basis tracking worksheets or online tools to assist investors, but the ultimate responsibility for accurate basis calculation rests with the partner.
Passive Activity Loss Rules: The PTP Silo
Section 469 imposes passive activity loss (PAL) limitations that restrict the deduction of losses from passive activities against active income or portfolio income. For most taxpayers, investments in limited partnerships are passive activities because the limited partner does not materially participate in the partnership’s business.
PTPs are subject to a special PAL rule that is more restrictive than the general passive loss limitations. Under Section 469(k), passive income, gains, losses, deductions, and credits from each PTP must be tracked separately and may not be aggregated with passive items from other PTPs or from non-PTP passive activities. In other words, each PTP operates in its own “silo.”
This means that if an investor owns units in PTP #1 that generates $5,000 of passive income and PTP #2 that generates a $3,000 passive loss, the investor cannot use the PTP #2 loss to offset the PTP #1 income in the current year. The $5,000 from PTP #1 is fully taxable. The $3,000 loss from PTP #2 is suspended and carried forward. It can only be used in future years against passive income from that same PTP #2, or when the investor completely disposes of the PTP #2 interest in a fully taxable transaction.
The practical implication is that investors can accumulate multiple “buckets” of suspended PTP losses, each tied to a specific partnership and each unusable until that particular partnership generates income or is sold. This is a frequent surprise for investors who assume they can net passive losses across all their investments.
Form 8582, which is used to calculate allowable passive losses, specifically excludes PTP items. Instead, investors must maintain a separate pro forma Form 8582 or worksheet for each PTP to track suspended losses. When a PTP is completely disposed of in a taxable transaction, all previously suspended passive losses from that PTP become deductible in the year of disposition.
If a PTP generates overall net income for a tax year, that income is treated as non-passive income on Schedule E. If it generates an overall net loss (after considering any suspended losses from prior years), the allowable portion of that loss is treated as a passive loss.
Sale of PTP Units: Section 751 Ordinary Income Recapture
The sale of a partnership interest is one of the most complex areas of partnership taxation, and PTPs are no exception. While a partner might expect that selling units held long-term would generate only long-term capital gain, Section 751(a) can recharacterize a portion of the gain as ordinary income.
Section 751 Property and the “Hot Asset” Rule
Section 751(a) provides that when a partner sells or exchanges a partnership interest, the partner must recognize ordinary income (or loss) to the extent the selling price is attributable to the partner’s share of “Section 751 property” held by the partnership. Section 751 property includes two categories: unrealized receivables and inventory items.
For purposes of this rule, “unrealized receivables” has a broader meaning than accounts receivable. It includes not only receivables from services or goods that have not yet been recognized as income, but also potential gain from the sale of property that would be characterized as ordinary income under the depreciation recapture rules of Sections 1245 and 1250, as well as recapture under Section 1254 for oil and gas properties.
This is particularly significant for PTPs in capital-intensive industries. Energy infrastructure partnerships typically own substantial amounts of depreciable property—pipelines, storage facilities, processing plants, and transportation equipment. Over the years, these assets generate depreciation deductions that flow through to partners and reduce their taxable income. When a partner sells PTP units, a portion of the gain attributable to this depreciation must be recaptured as ordinary income.
The calculation is complex. In general, if the partnership were to sell all of its assets in a hypothetical sale at fair market value immediately before the partner’s disposition, the partner’s share of ordinary income that would be allocated from that hypothetical sale represents the Section 751 ordinary income that must be recognized on the sale of the partnership interest. This amount is then characterized as ordinary income, while the remaining gain (if any) is capital gain.
The Mechanics of Reporting PTP Sales
When a PTP unitholder sells units, the reporting involves multiple tax forms and careful coordination of basis adjustments. The broker who executes the sale will issue Form 1099-B reporting the gross proceeds and, in many cases, a cost basis. However, the broker’s cost basis is almost always incorrect for PTP units because it does not reflect the years of K-1 basis adjustments.
The PTP partnership typically provides a “Sales Schedule” or “Sales Disclosure Statement” with the final K-1 for the year of sale. This schedule shows the selling partner’s adjusted tax basis (incorporating all prior years’ adjustments), the Section 751 ordinary income amount, and sometimes a breakdown of short-term and long-term capital gain components.
The reporting typically follows this structure. First, the Section 751 ordinary income is reported on Form 4797, Part II, as ordinary income from the sale of the partnership interest. Second, the sale is reported on Form 8949 and Schedule D, using the corrected adjusted basis from the partnership’s sales schedule. Critically, to avoid double taxation of the Section 751 ordinary income portion, that amount must be added back to basis for purposes of calculating the capital gain or loss.
For example, assume an investor sells PTP units for $50,000. The original cost was $30,000, but after years of return of capital distributions and income allocations, the adjusted basis is $25,000. The partnership’s sales schedule indicates Section 751 ordinary income of $8,000. The reporting would be:
- Form 4797, Part II: $8,000 ordinary income
- Form 8949/Schedule D: Sales price $50,000 minus adjusted basis of $33,000 ($25,000 original adjusted basis plus $8,000 Section 751 amount to avoid double counting) equals $17,000 capital gain
The total gain recognized is $25,000 ($50,000 sales price minus $25,000 adjusted basis), consisting of $8,000 ordinary income and $17,000 capital gain.
This reporting structure can produce unexpected results. In some cases, particularly where the PTP has claimed substantial depreciation, the Section 751 ordinary income can exceed the overall gain, resulting in ordinary income plus a capital loss. For taxpayers who cannot fully utilize capital losses due to the $3,000 annual limitation, this recharacterization can be particularly painful.
Disclosure Requirements
Regulations Section 1.751-1(a)(3) requires a disclosure statement to be attached to both the partnership’s tax return and each selling partner’s tax return in the year of sale. Most PTPs provide recommended disclosure language in footnotes to the K-1. However, many tax preparation software packages do not automatically generate this disclosure, so preparers must manually attach the statement. Failure to include the required disclosure can trigger IRS inquiries or adjustments.
State Tax Complications: Multi-State Filing Requirements
One of the most underappreciated complexities of PTP investments is the potential for multi-state tax filing obligations. Because PTPs are pass-through entities, partners are subject to tax on their share of partnership income in each state where the partnership conducts business, not merely in the partner’s state of residence.
Many PTPs, particularly those in the energy sector, operate across multiple states through an extensive network of pipelines, storage facilities, and processing plants. A single PTP investment can trigger filing requirements in five, ten, or even twenty or more states. Each state has its own rules for determining when a nonresident must file a return, with thresholds ranging from as low as $1 of state-source income to several hundred or even thousand dollars.
The K-1 from a PTP typically includes a state allocation schedule, either as a separate attachment or in footnotes, showing the partner’s share of income, deductions, and credits allocated to each state. Some PTPs provide this information in a clear, organized format; others bury it in dense footnotes that require careful parsing.
For each state in which the partner has allocable income above that state’s filing threshold, a nonresident tax return must be filed. This can result in substantial additional tax preparation fees, as each state return requires separate preparation and may involve unique state tax rules, modifications, and credits. Many tax preparation firms charge per-state fees for PTP investors, with costs that can easily exceed several hundred dollars for investors with multiple PTPs operating in numerous states.
Withholding and Composite Returns
Many states have enacted partnership withholding requirements for nonresident partners. Under these regimes, the partnership must withhold tax on the nonresident partner’s share of state-source income and remit it to the state. Common withholding rates include California (7%), New York (10.9%), and Illinois (4.95%), though rates vary widely.
If the partnership withholds, the amount withheld is reported on the K-1 and the partner can claim a credit for the withholding on the state tax return. However, partners must file the state return to claim the credit; simply allowing the partnership to withhold without filing leaves money on the table if the withholding exceeds the actual tax liability.
Some states allow or require partnerships to file composite or group returns on behalf of nonresident partners. Under a composite return, the partnership files a single return reporting the income of all participating nonresident partners and pays tax on their behalf at a specified rate. Partners who participate in the composite return generally do not need to file individual nonresident returns in that state, simplifying compliance. However, composite returns are usually filed at the highest marginal rate and do not allow for partner-specific deductions or credits, so they may result in higher tax than individual filing.
Pass-Through Entity Tax (PTET) Elections
In response to the $10,000 federal cap on state and local tax (SALT) deductions imposed by the Tax Cuts and Jobs Act of 2017, many states have enacted pass-through entity tax regimes. Under these provisions, partnerships can elect to pay state income tax at the entity level. Because the entity-level tax is deductible as a business expense rather than an itemized deduction, it bypasses the federal SALT cap limitation.
The One Big Beautiful Bill Act (OBBBA) enacted in July 2025 made modifications to the interaction between state PTET elections and federal taxation, though the overall availability of PTET workarounds remains intact. PTPs and their partners must carefully coordinate PTET elections across multiple states to optimize the overall tax outcome.
Special Considerations for Tax-Exempt and Retirement Accounts
While PTPs offer compelling returns and tax benefits for taxable investors, holding PTP units in tax-advantaged accounts such as IRAs, 401(k)s, and accounts of tax-exempt organizations creates unique complications due to unrelated business taxable income (UBTI).
Unrelated Business Taxable Income (UBTI)
Tax-exempt organizations and retirement accounts are generally exempt from taxation on investment income. However, income from an active trade or business that is unrelated to the exempt purpose of the organization—unrelated business taxable income—remains taxable even for exempt entities.
When a tax-exempt entity or retirement account invests in a partnership that conducts an active trade or business, the entity “looks through” to the partnership’s activities. If the partnership is engaged in an unrelated trade or business, the exempt entity’s allocable share of income from that business is UBTI.
Most PTPs are engaged in active business operations—transporting oil and gas, operating pipelines, providing midstream services. These are trades or businesses, not passive investments. Therefore, the income allocated to a tax-exempt or retirement account investor typically constitutes UBTI.
Additionally, even if the income would otherwise be exempt (such as dividend or interest income), it can become UBTI if it is “debt-financed”. Section 514 provides that if a tax-exempt organization acquires property with borrowed funds, a portion of the income from that property proportionate to the debt financing is treated as UBTI. Many PTPs employ significant leverage, meaning their income may be partially debt-financed, resulting in UBTI even from otherwise passive sources.
The threshold for UBTI filing and taxation is $1,000. If a tax-exempt entity or retirement account has gross UBTI of $1,000 or more from all sources during a tax year, it must file Form 990-T and pay tax on the net UBTI at applicable rates. For IRAs and other retirement accounts, the tax is paid from the account assets, reducing the value available for retirement.
For IRAs, the custodian is responsible for filing Form 990-T if UBTI exceeds $1,000, though in practice many custodians fail to monitor this requirement or notify account holders. Account holders who discover UBTI after the fact may face late filing penalties in addition to the UBTI tax itself.
PTPs are required to report UBTI information to partners in Box 20, Code V of Schedule K-1. However, the reporting can be incomplete or unclear, and some PTPs do not adequately disclose UBTI amounts. Partners must carefully review K-1 supporting statements and contact the partnership’s investor relations department if UBTI information is not provided.
Given these complications, many financial advisors recommend that tax-exempt entities and retirement accounts avoid PTP investments altogether, or limit them to amounts that will not generate material UBTI. For taxable accounts, PTPs remain attractive, but the UBTI issue is a significant deterrent for tax-advantaged accounts.
Section 199A Qualified Business Income Deduction
The Tax Cuts and Jobs Act of 2017 introduced Section 199A, which allows non-corporate taxpayers to deduct up to 20% of qualified business income (QBI) from qualified trades or businesses, plus 20% of qualified REIT dividends and qualified publicly traded partnership income. This deduction, extended permanently (subject to future legislation) by the One Big Beautiful Bill Act of 2025, can provide significant tax savings for PTP investors.
Qualified Publicly Traded Partnership Income
For PTPs, the Section 199A deduction is calculated separately from the QBI component applicable to other businesses. Specifically, the statute provides for a deduction equal to 20% of the combined amount of qualified REIT dividends plus qualified publicly traded partnership income. This PTP component is not subject to the wage and qualified property limitations that apply to QBI from other trades or businesses.
“Qualified publicly traded partnership income” means, with respect to any qualified trade or business of the taxpayer, the sum of the partner’s allocable share of each qualified item of income, gain, deduction, and loss from the PTP, and any gain recognized on disposition of the PTP interest to the extent attributable to the qualified trade or business. However, if the PTP is engaged in a specified service trade or business (SSTB), limitations apply.
PTPs must report Section 199A information to partners, typically in Box 20 of Schedule K-1 with various codes designating the amounts and types of income. The K-1 instructions and supplemental statements should specify the Section 199A qualified items, any W-2 wages allocated to the partner (relevant if the PTP has qualifying business income subject to limitations), and unadjusted basis immediately after acquisition (UBIA) of qualified property.
Interaction with Passive Loss Rules and Other Limitations
The Section 199A deduction is calculated after applying the passive loss limitations. This means that if PTP income is offset by suspended passive losses from that same PTP, the net income eligible for the Section 199A deduction is reduced. Similarly, negative qualified income or loss from a PTP carries over to offset qualified income from PTPs in future years, but does not offset QBI from other trades or businesses.
For taxpayers with taxable income above the Section 199A threshold amounts ($394,600 for married filing jointly in 2025, $197,300 for other filers, with these thresholds increased and indexed under the OBBBA for 2026 and beyond), limitations and phase-outs apply. If the PTP is engaged in a specified service trade or business, income from the PTP may be partially or entirely excluded from the definition of qualified PTP income depending on the taxpayer’s income level.
The One Big Beautiful Bill Act made several modifications to Section 199A effective beginning in 2026. The income phase-out range for SSTB limitations was broadened from $100,000 to $150,000 for married couples filing jointly. A new minimum deduction of $400 (indexed for inflation) was added for taxpayers with at least $1,000 of QBI from actively running a trade or business. While these changes primarily affect non-PTP businesses, they interact with the overall Section 199A calculation when taxpayers have both PTP income and other business income.
Alternative Minimum Tax (AMT) Considerations
Individual investors in PTPs may be subject to the alternative minimum tax, a parallel tax system designed to ensure that taxpayers with substantial economic income pay at least a minimum amount of tax. PTPs can generate AMT preference items and adjustments that increase a partner’s exposure to AMT.
The AMT calculation starts with regular taxable income and makes a series of adjustments. Common PTP-related AMT items include accelerated depreciation adjustments (the difference between regular tax depreciation and AMT depreciation), percentage depletion in excess of the property’s adjusted basis, intangible drilling and development costs, and certain tax-exempt interest from private activity bonds.
For 2025, the AMT exemption amounts are $88,100 for married filing jointly and $66,075 for single filers, with these amounts indexed for inflation. The exemption phases out at higher income levels. The AMT rate is 26% on the first $220,700 of alternative minimum taxable income (AMTI) and 28% on AMTI above that threshold.
PTPs report AMT items in Box 17 of Schedule K-1, using various codes to designate different types of adjustments and preferences. Partners must transfer these amounts to Form 6251 to calculate AMT liability. If AMT exceeds regular tax, the partner pays the AMT amount.
Importantly, if a partner pays AMT in one year, that AMT payment can generate a minimum tax credit that can be used to offset regular tax in future years when regular tax exceeds AMT. This credit effectively allows the recovery of AMT paid to the extent it represents a timing difference rather than a permanent exclusion. The credit is tracked on Form 8801 and can be carried forward indefinitely until used.
Partners holding PTP units must also maintain a separate AMT basis as discussed earlier, because AMT income and deductions may differ from regular tax items, leading to different basis adjustments.
Comparing PTP Taxation to C Corporation Taxation
The fundamental difference between PTP taxation and C corporation taxation lies in the number of layers of tax imposed. C corporations are subject to double taxation: the corporation pays tax at the entity level on its taxable income (currently at a flat 21% rate), and shareholders pay tax again when they receive dividends or sell their shares at a gain. This double taxation can result in effective tax rates exceeding the top individual income tax bracket when both layers are combined.
PTPs structured to meet the Section 7704 requirements avoid entity-level tax entirely. The partnership’s income, deductions, and credits flow through to partners who pay tax only once, at their individual rates. For high-income investors in the top 37% federal bracket (plus 3.8% net investment income tax), the combined rate can approach 40.8% on ordinary income. However, if distributions are partly return of capital and the eventual sale generates long-term capital gain taxed at 20%, the effective rate can be significantly lower.
The following table illustrates a simplified comparison:
| Feature | C Corporation | PTP (Qualifying) |
|---|---|---|
| Entity-level tax | Yes (21%) | No |
| Shareholder/partner level tax | Yes (up to 23.8% on qualified dividends) | Yes (up to 40.8% on ordinary income, 23.8% on LTCG) |
| Overall effective rate on distributed earnings | Approximately 39.8% | Varies; often lower due to ROC and capital gains treatment |
| Tax reporting | Form 1099-DIV (simple) | Schedule K-1 (complex) |
| State tax complexity | Generally limited to state of residence | Multi-state filing often required |
| Deductibility of entity debts | Interest deductible by corporation | Interest flows through to partners |
| Basis adjustments | No annual basis adjustment | Annual basis adjustments required |
The avoidance of double taxation gives PTPs a significant structural advantage for distributing cash to investors. However, this advantage comes with the trade-off of substantially greater tax compliance complexity, as the preceding sections have detailed.
Common Examples of Publicly Traded Partnerships
PTPs are concentrated in the energy infrastructure and natural resources sectors, though some operate in real estate and other qualifying industries. Notable examples include:
Enterprise Products Partners L.P. (EPD). With a market capitalization exceeding $57 billion, Enterprise Products Partners is one of the largest PTPs. Headquartered in Houston, Texas, Enterprise provides midstream energy services including natural gas processing, NGL pipelines, crude oil pipelines, petrochemical services, and storage facilities. Enterprise is frequently cited as a best-in-class MLP with strong management, diversified operations, and a long history of stable distributions. Investors in EPD receive Schedule K-1 forms that typically report ordinary business income, capital gains, Section 199A information, and multi-state allocations.
Magellan Midstream Partners LP (MMP). Based in Tulsa, Oklahoma, Magellan Midstream operates refined products pipelines and storage facilities, transporting gasoline, diesel, and other fuels to customers across the United States. The partnership has been recognized for consistent performance and disciplined capital allocation. In 2023, Magellan was acquired by ONEOK, though it continues to serve as an example of a traditional midstream MLP structure.
MPLX LP (MPLX). MPLX is the MLP subsidiary of Marathon Petroleum Corporation, operating gathering, processing, and transportation assets for natural gas, NGLs, and crude oil. It is often highlighted as offering a balance between high yield (similar to other MLPs) and strong management backing from its parent company.
Energy Transfer LP (ET). Energy Transfer operates one of the largest and most diversified portfolios of energy assets in North America, including approximately 120,000 miles of pipelines and related infrastructure. The partnership has experienced periods of volatility, including significant unit price declines during the 2016 oil price crash and the 2020 pandemic, but has since recovered and is frequently recommended for patient, long-term income investors.
These examples share common characteristics: they generate qualifying income primarily from the transportation, storage, and processing of oil, natural gas, and related products; they distribute substantial cash to unitholders quarterly; they issue complex K-1 forms reflecting operations across multiple states; and they offer yields significantly higher than typical dividend-paying stocks, often in the range of 6% to 8% or higher.
Practical Investor Considerations and Common Mistakes
Investing in PTPs requires careful consideration of both the financial benefits and the tax complexities. Common mistakes and important considerations include:
Underestimating Tax Complexity and Compliance Costs
Many investors are attracted to PTPs by their high yields but fail to appreciate the tax reporting complexity. A small investment in a single PTP can generate multi-state filing requirements and substantially increase tax preparation fees. Investors should factor these costs into their return calculations. For investors with modest PTP holdings, the additional tax preparation fees can consume a meaningful portion of the incremental yield advantage.
Failure to Track Basis Accurately
The most common and consequential mistake PTP investors make is failing to maintain accurate basis records. Each year’s K-1 contains information that adjusts basis, and these adjustments accumulate over the entire holding period. When an investor sells PTP units after holding them for ten or fifteen years but has not maintained basis records, reconstructing the adjusted basis requires obtaining and analyzing all K-1s from the entire holding period—a time-consuming and sometimes impossible task if K-1s have been lost.
Some brokerage firms attempt to track partnership basis, but their records are frequently incomplete or incorrect because they lack access to all the information needed to make proper adjustments. Investors who rely solely on broker basis reporting risk overpaying tax on sale (if the broker understates basis) or triggering IRS scrutiny and potential penalties (if the broker overstates basis).
Best practice is to maintain a spreadsheet or use tax software to track basis annually, incorporating all adjustments from each K-1 as it is received. Many PTPs also provide basis tracking tools on their investor relations websites.
Ignoring Section 751 Ordinary Income Recapture
Investors who have held PTP units for many years and assume the entire gain on sale will be long-term capital gain are often shocked to discover that a substantial portion—sometimes the majority—of the gain is recharacterized as ordinary income under Section 751. This is particularly painful for investors in high tax brackets, as ordinary income is taxed at rates up to 40.8% (37% top rate plus 3.8% net investment income tax) compared to 23.8% for long-term capital gains.
The Section 751 recapture cannot be avoided, but it can be anticipated. Before selling, investors should request a basis projection from the PTP’s investor relations department or tax package support team. Most PTPs can provide an estimate of the Section 751 ordinary income that would result from a sale, allowing the investor to plan for the tax liability.
Holding PTPs in IRAs and Other Tax-Advantaged Accounts
As discussed, PTPs generate UBTI that can subject retirement accounts to taxation. The $1,000 UBTI threshold seems high, but for actively traded PTPs or those with substantial income allocations, it can be exceeded even with a modest position. If the IRA custodian fails to file Form 990-T, the account holder may face penalties in addition to the tax.
Financial advisors almost universally recommend keeping PTPs in taxable accounts and reserving tax-advantaged accounts for investments that do not generate UBTI. The tax-deferred compounding advantage of a retirement account is largely negated if the account is subject to UBTI tax, and the additional complexity is rarely worth the marginal benefit.
Overlooking State Tax Consequences
Investors often focus on federal tax implications and overlook state tax consequences. A retiree living in Florida (which has no state income tax) who invests in a PTP operating in California, New York, and Texas may discover they must file nonresident returns in all three states, potentially owing significant state tax. For some investors, particularly those in low-tax or no-tax states, the state tax liability from PTP investments can exceed the federal tax benefit.
Before purchasing PTP units, investors should review the partnership’s state allocation schedule (often available on the investor relations website or in prior year K-1 packages) to understand where the partnership operates and whether the investment will trigger multi-state filing requirements.
Inadequate Planning for Estimated Tax Payments
Unlike dividends from corporations, which are subject to withholding or can be easily anticipated for estimated tax purposes, PTP income allocations can be volatile and unpredictable. There is no withholding on PTP income allocations, so investors must make quarterly estimated tax payments to avoid underpayment penalties.
Adding to the complexity, the K-1 for a given year is not available until the following year, often well after the fourth quarter estimated payment is due. Investors must estimate their PTP allocations based on prior year data or interim information, and then true up when the K-1 arrives. This requires proactive planning and coordination with a tax professional.
Misjudging the “High Yield” as Current Cash Flow
A PTP with an 8% distribution yield appears to provide 8% current cash income, but the economic reality is different. If 60% of the distribution is return of capital, only 40%—or 3.2 percentage points of the 8% yield—represents current taxable income. The remaining 4.8 percentage points is not tax-free income; it is a return of the investor’s own capital that will be taxed later when the units are sold.
Investors who need current cash flow for living expenses may find PTP distributions attractive, but they should understand that they are partially liquidating their investment through return of capital. Investors focused on total return should consider whether the after-tax compounding is superior to alternative investments with simpler tax treatment.
Estate Planning: Step-Up in Basis at Death
One significant tax advantage of holding PTPs until death is the step-up in basis under Section 1014. When a partner dies, the deceased partner’s interest in the PTP generally receives a step-up in basis to the fair market value as of the date of death. This step-up can eliminate all the built-in gain that would have been subject to tax had the units been sold during life, including the Section 751 ordinary income recapture.
For example, an investor who purchased PTP units for $50,000, accumulated $30,000 of return of capital distributions (reducing basis to $20,000), and held the units until death when they are worth $100,000, bequeaths units with a stepped-up basis of $100,000 to heirs. The $80,000 of appreciation ($100,000 value minus $20,000 adjusted basis) is permanently exempt from income tax. If the heirs sell the units shortly after inheriting them, they recognize little or no gain.
This step-up benefit can be even more valuable for PTPs than for regular stocks due to the Section 751 recapture issue. Not only is capital gain eliminated, but the ordinary income recapture that would have applied on a lifetime sale is also eliminated. This makes PTP units particularly attractive for older investors who intend to hold the units for life and bequeath them to heirs.
However, complexities can arise. If the partnership has a negative capital account or holds negative basis assets, the step-up may be limited. Additionally, if the partnership has made a Section 754 election, the mechanics of the basis adjustment can become more complex, requiring coordination among tax, legal, and valuation professionals. Partnerships and heirs should ensure that proper valuations are obtained and that all required elections and filings are timely made.
The step-up in basis has been a periodic target for legislative reform, with proposals to eliminate it for high-net-worth estates, replace it with carryover basis, or trigger capital gains recognition at death. While no such changes have been enacted as of 2026, the increased IRS scrutiny around basis calculations and estate valuations means that taxpayers should be prepared for greater examination of basis step-up claims.
Frequently Asked Questions (FAQs)
1. What is the main tax advantage of investing in a publicly traded partnership compared to a regular corporation?
The primary tax advantage is the avoidance of double taxation. PTPs that meet the Section 7704 qualifying income test are not taxed at the entity level; all income flows through to partners who pay tax only once at their individual rates. In contrast, C corporations pay tax on their income at the entity level, and shareholders pay tax again on dividends or capital gains. This single-layer taxation can result in a lower overall effective tax rate for PTP investors, particularly when distributions include return of capital and eventual gains are taxed at long-term capital gains rates.
2. What is “qualifying income” and why is it important?
Qualifying income is income from specific sources that allows a publicly traded partnership to retain pass-through tax treatment rather than being taxed as a corporation. Section 7704(c) requires that 90% or more of a PTP’s gross income must be qualifying income. Qualifying income includes interest, dividends, real property rents, gains from the sale of real property, and income from exploration, development, production, processing, refining, transportation, or marketing of minerals and natural resources. If a PTP fails the 90% test in any year, it loses partnership status and becomes taxable as a corporation, triggering double taxation.
3. What is a Schedule K-1 and when will I receive it?
Schedule K-1 (Form 1065) is the tax document a partnership provides to each partner showing their share of partnership income, deductions, credits, and other tax items for the year. Unlike a Form 1099-DIV from a corporation, which simply reports dividends, a K-1 can contain dozens of different items across more than 20 boxes, each requiring different treatment on the partner’s tax return. Partnerships must provide K-1s by March 15 following the tax year (or March 17, 2026 for calendar year 2025), though many PTPs deliver them later, sometimes not until late March or April. This late delivery can complicate tax return filing for investors who want to file early.
4. Why do I owe tax if I didn’t sell my PTP units?
PTPs are pass-through entities, meaning the partnership’s taxable income flows through to partners regardless of whether cash is distributed. You are taxed on your allocable share of the partnership’s income as reported on Schedule K-1, not on the distributions you receive. This is fundamentally different from stock ownership, where you are taxed only on dividends received and gains realized on sale. It is possible to have taxable income from a PTP even if you received no distributions, or conversely to receive distributions that exceed your taxable income (return of capital).
5. What is “return of capital” and is it really tax-free?
Return of capital (ROC) is the portion of a PTP distribution that exceeds your allocable share of taxable income for the year. It is not immediately taxable but reduces your tax basis in the PTP units. When you eventually sell the units, your gain is larger (or loss smaller) due to the reduced basis, so the ROC is effectively taxed at that time. If distributions reduce your basis to zero, any additional distributions are immediately taxable as capital gain. Return of capital is tax-deferred, not tax-free—it simply shifts the tax liability from the distribution date to the sale date.
6. How do I calculate my tax basis in PTP units?
Tax basis starts with the amount you paid for the units, including any acquisition costs. Each year, basis increases by your share of partnership income (including tax-exempt income) and your share of increases in partnership liabilities, and decreases by distributions received, your share of losses and nondeductible expenses, and your share of decreases in partnership liabilities. You must track these adjustments annually using the information from each year’s Schedule K-1. Additionally, you must maintain separate at-risk basis and AMT basis calculations. Most investors maintain a spreadsheet tracking basis or use tax software that automatically calculates basis adjustments.
7. Can I use losses from one PTP to offset income from another PTP?
No. PTPs are subject to special passive loss rules that require each PTP to be treated separately. Losses from PTP #1 can only offset income from that same PTP #1, not income from PTP #2 or from other passive activities. This is sometimes called the “PTP silo rule.” Suspended losses from a PTP can be used only when that same PTP generates income in future years or when you completely dispose of your interest in that PTP in a taxable transaction. You may accumulate multiple buckets of suspended PTP losses, each tied to a specific partnership.
8. What is Section 751 ordinary income recapture and how does it affect my sale?
Section 751(a) requires that when you sell PTP units, a portion of your gain equal to your share of the partnership’s “unrealized receivables and inventory items” must be characterized as ordinary income rather than capital gain. For PTPs with significant depreciable property, this includes depreciation recapture under Sections 1245, 1250, and 1254. The PTP provides a sales schedule with your final K-1 showing the Section 751 ordinary income amount. This amount is reported as ordinary income on Form 4797, and the remaining gain is capital gain. In some cases, Section 751 recapture can exceed the total gain, resulting in ordinary income plus a capital loss.
9. Do I have to file tax returns in multiple states if I own PTP units?
Potentially yes. Because PTPs are pass-through entities, you may owe tax in each state where the partnership conducts business, and you may be required to file nonresident tax returns in those states. The K-1 or supporting schedules will show your allocable income by state. Each state has different thresholds for when a nonresident must file, ranging from as low as $1 of state-source income to several hundred or thousand dollars. A single PTP investment can trigger filing requirements in multiple states, adding significant tax preparation complexity and cost. Review the PTP’s state allocation schedule before investing to understand potential multi-state obligations.
10. Can I hold PTP units in my IRA or 401(k)?
You can, but it is generally not recommended. PTPs often generate unrelated business taxable income (UBTI), which is taxable even when earned by a tax-exempt retirement account. If your retirement account has $1,000 or more of gross UBTI in a year, it must file Form 990-T and pay income tax on the UBTI. The tax is paid from the account’s assets, reducing your retirement savings. Additionally, the IRA custodian must track and file the Form 990-T, creating administrative complexity. Most financial advisors recommend holding PTPs only in taxable accounts to avoid these complications.
11. What is the Section 199A deduction and how does it apply to PTP income?
Section 199A allows non-corporate taxpayers to deduct up to 20% of qualified business income, including 20% of qualified publicly traded partnership income. For PTPs, this deduction is generally not subject to the wage and qualified property limitations that apply to other QBI, though limitations apply if the PTP is engaged in a specified service trade or business and the taxpayer’s income exceeds threshold amounts. The PTP reports Section 199A information on Schedule K-1, typically in Box 20. This deduction can significantly reduce the effective tax rate on PTP income. For example, if you are allocated $10,000 of PTP income and qualify for the full Section 199A deduction, you can deduct $2,000 (20% of $10,000), reducing your taxable income to $8,000.
12. Will my PTP investment affect my alternative minimum tax (AMT)?
It may. PTPs can generate AMT preference items and adjustments, such as accelerated depreciation differences, excess percentage depletion, and intangible drilling costs. These items are reported in Box 17 of the K-1 and must be included on Form 6251 to calculate AMT liability. If your tentative minimum tax (calculated on Form 6251) exceeds your regular tax, you must pay AMT. However, AMT paid in one year can generate a minimum tax credit that can offset regular tax in future years, effectively allowing recovery of AMT attributable to timing differences. You must also maintain a separate AMT basis in your PTP units, adjusted for AMT income and deduction items.
13. What happens to the tax basis of my PTP units when I die?
PTP units held at death generally receive a step-up in basis to fair market value as of the date of death under Section 1014. This eliminates the built-in gain, including any Section 751 ordinary income recapture that would have applied on a lifetime sale. Heirs who inherit PTP units with a stepped-up basis can sell them shortly after death with little or no taxable gain. This makes PTPs attractive estate planning assets for older investors who intend to hold them for life and bequeath them to heirs. However, complexities can arise with negative capital accounts or Section 754 elections, requiring professional guidance.
14. How do I report the sale of PTP units on my tax return?
Reporting a PTP sale requires multiple tax forms and careful coordination. First, report the Section 751 ordinary income (shown on the PTP’s sales schedule) on Form 4797, Part II. Second, report the sale on Form 8949 and Schedule D using the corrected adjusted basis from the sales schedule (which includes all prior years’ basis adjustments), not the basis shown on Form 1099-B from your broker. Add the Section 751 amount to basis when calculating capital gain to avoid double taxation of that portion. Third, attach the required Section 751 disclosure statement to your return. Many tax software programs do not automatically generate the correct reporting, so professional assistance is often advisable.
15. Are there any situations where a PTP would be taxed as a corporation?
Yes. If a PTP fails to meet the 90% qualifying income test in any year, it is taxed as a corporation for that year and all subsequent years unless it restructures to regain partnership status. Additionally, a partnership can elect to be taxed as a corporation even if it meets the qualifying income test, though this would be rare. When a PTP is taxed as a corporation, it pays entity-level tax on its income, and distributions to partners are treated as taxable dividends, resulting in double taxation. Investors should monitor whether their PTP continues to meet the qualifying income test; most established PTPs disclose their qualifying income percentage in quarterly earnings materials or investor presentations.
16. What are the biggest mistakes investors make with PTP investments?
The most common mistakes include: (1) failing to maintain accurate basis records over the entire holding period, making it difficult or impossible to correctly calculate gain or loss on sale; (2) underestimating the tax preparation complexity and costs, particularly multi-state filing requirements; (3) holding PTPs in IRAs or other tax-advantaged accounts and triggering UBTI; (4) not planning for Section 751 ordinary income recapture on sale, resulting in unexpected tax at ordinary rates instead of capital gains rates; (5) failing to make adequate estimated tax payments and incurring underpayment penalties; and (6) ignoring state tax consequences, particularly for investors in low-tax or no-tax states who may owe significant tax to other states where the PTP operates.
17. Should I invest in PTPs given all the tax complexity?
The decision depends on your specific situation. PTPs can be excellent investments for taxable accounts of investors who have the resources to handle the tax complexity, work with competent tax professionals, maintain meticulous records, and are comfortable with multi-state filing obligations. The combination of high yields, tax-deferred distributions through return of capital, and potential Section 199A deductions can produce attractive after-tax returns. However, for investors who cannot tolerate tax complexity, have modest portfolio sizes where the incremental tax costs would consume much of the yield advantage, or want to hold investments in retirement accounts, alternatives such as C corporations with qualified dividends or REIT ETFs may be more appropriate. Consider consulting with both an investment advisor and a tax professional before adding PTPs to your portfolio.
Related reading
- Does a Partnership Actually Issue a K-1? – Avoid this Mistake + FAQs
- Are Publicly Traded Partnerships Passive Income? (w/Examples) + FAQs
- Are Publicly Traded Partnerships Taxed as Corporations? (w/Examples) + FAQs
- Can a Partnership Be Publicly Traded? (w/Examples) + FAQs
- Do Publicly Traded Partnerships Qualify for QBI? (w/Examples) + FAQs
- Are General Partnerships Double-Taxed? (w/Examples) + FAQs
- How to Structure a Limited Partnership (w/Examples) + FAQs