10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

☒  ANNUAL REPORT PURSUANT TO SECTION 13 or 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2021

OR 

☐ TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                      to                    

Commission File Number 001-33503

BLUEKNIGHT ENERGY PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation or organization)	20-8536826 (IRS Employer Identification No.)
6060 American Plaza, Suite 600 Tulsa, Oklahoma 74135 (Address of principal executive offices, zip code) Registrant’s telephone number, including area code: (918) 237-4000

(Former name, former address and former fiscal year, if changed since last report)

Securities Registered Pursuant to Section 12(b) of the Act: 

Title of each class	Trading Symbols	Name of each exchange on which registered
Common Units representing limited partner interests	BKEP	Nasdaq Global Market
Series A Preferred Units representing limited partner interests	BKEPP	Nasdaq Global Market

Securities Registered Pursuant to Section 12(g) of the Act:

None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.  Yes ☐               No ☒

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  Yes ☐           No ☒

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).  Yes   ☒    No   ☐

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ☒

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ☐	Accelerated filer ☒
Non-accelerated filer ☐	Smaller reporting company ☒
	Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒

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

As of June 30, 2021, the aggregate market value of the registrant’s common units held by non-affiliates of the registrant was approximately $144.5 million, based on $3.78 per common unit, the closing price of the common units as reported on the Nasdaq Global Market on that date.

As of March 1, 2022, there were 34,406,683 Series A Preferred Units and 41,856,847 common units outstanding.

Table of Contents
		Page
PART I.		1
Item 1.	Business.	1
Item 1A.	Risk Factors.	6
Item 1B.	Unresolved Staff Comments.	21
Item 2.	Properties.	21
Item 3.	Legal Proceedings.	22
Item 4.	Mine Safety Disclosures.	22
PART II.		22
Item 5.	Market for Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities.	22
Item 6.	Reserved.	23
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations.	24
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk.	32
Item 8.	Financial Statements and Supplementary Data.	32
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.	32
Item 9A.	Controls and Procedures.	32
PART III.		33
Item 10.	Directors, Executive Officers and Corporate Governance.	33
Item 11.	Executive Compensation.	37
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters.	40
Item 13.	Certain Relationships and Related Transactions, and Director Independence.	41
Item 14.	Principal Accountant Fees and Services.	42
PART IV.		43
Item 15.	Exhibits, Financial Statement Schedules.	43
Item 16.	Form 10-K Summary.	45

i

DEFINITIONS

We use the following terms in this report:

Finished asphalt products: As used herein, the term refers to: (i) liquid asphalt cement sold directly to end users, and to (ii) asphalt emulsions, asphalt cutbacks, polymer modified asphalt cement, and related asphalt products processed using liquid asphalt cement. The term is also used to refer to various residual fuel oil products directly sold to end users.

Liquid asphalt: A dark brown-to-black cementitious material that is primarily produced by petroleum distillation. When crude oil is separated in distillation towers at a refinery, the heaviest hydrocarbons with the highest boiling points settle at the bottom. These tar-like fractions, called residuum, require relatively little additional processing to become products such as liquid asphalt cement or residual fuel oil. Liquid asphalt cement is primarily used in the road construction and maintenance industry. Residual fuel oil is primarily used as a burner fuel in numerous industrial and commercial business applications. As used herein, the term refers to both liquid asphalt cement and residual fuel oils.

 Preferred Units: Series A Preferred Units representing limited partnership interests in our partnership.

Terminalling: The receipt of products for storage into storage tanks and other appurtenant equipment where the products may be commingled with other products of similar quality or where the products may be manufactured and changed; the storage of the products; and the delivery of the products as directed by a distributor into a truck or other transportation vessels.

Throughput: The volume of product transported or passing through a plant, terminal or other facility.

ii

PART I.

As used in this annual report, unless we indicate otherwise: (1) “Blueknight,” “our,” “we,” “us” and similar terms refer to Blueknight Energy Partners, L.P., together with its subsidiaries, (2) our “General Partner” refers to Blueknight Energy Partners G.P., L.L.C., and (3) “Ergon” refers to Ergon, Inc., its affiliates and subsidiaries (other than our General Partner and us).

Forward-Looking Statements

This report contains “forward-looking statements” within the meaning of the federal securities laws. Statements included in this annual report that are not historical facts (including any statements regarding plans and objectives of management for future operations or economic performance, or assumptions or forecasts related thereto) are forward-looking statements. These statements can be identified by the use of forward-looking terminology including “may,” “will,” “should,” “believe,” “expect,” “intend,” “anticipate,” “estimate,” “continue,” or other similar words. These statements discuss future expectations, contain projections of results of operations or of financial condition, or state other “forward-looking” information. We and our representatives may from time to time make other oral or written statements that are also forward-looking statements.

Such forward-looking statements are subject to various risks and uncertainties that could cause actual results to differ materially from those anticipated as of the date of this report. Although we believe that the expectations or assumptions reflected in these forward-looking statements are based on reasonable assumptions, no assurance can be given that these expectations will prove to be correct. Important factors that could cause our actual results to differ materially from the expectations reflected in these forward-looking statements include, among other things, those set forth in “Item 1A-Risk Factors,” included in this annual report, and those set forth from time to time in our filings with the Securities and Exchange Commission (“SEC”), which are available through the Investors - SEC Filings page at www.bkep.com and through the SEC’s Electronic Data Gathering and Retrieval System (“EDGAR”) at www.sec.gov.

All forward-looking statements included in this report are based on information available to us on the date of this report. We undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. All subsequent written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the cautionary statements contained throughout this report.

Item 1. Business.

Overview

Blueknight is a publicly traded master limited partnership with operations in 26 states. We have the largest independent asphalt facility footprint in the nation, and through that we provide integrated terminalling services for companies engaged in the production, distribution, and handling of liquid asphalt that are providing the basic materials for the infrastructure and construction needed to maintain and expand the U.S. economy. We manage our operations through a single segment, asphalt terminalling services.

We previously provided integrated terminalling, gathering, and transportation services for companies engaged in the production, distribution, and marketing of crude oil in three different operating segments: (i) crude oil terminalling services, (ii) crude oil pipeline services, and (iii) crude oil trucking services. On December 21, 2020, we announced we had entered into multiple definitive agreements to sell these segments, and these segments are presented as discontinued operations. The transaction related to the crude oil pipeline services segment closed on February 1, 2021, and the transactions relating to the crude oil trucking services segment closed on December 15, 2020, and February 2, 2021. The transaction related to the crude oil terminalling services segment closed on March 1, 2021.

Our Operations

We were formed as a Delaware limited partnership in 2007. Our operating assets are owned by, and our operations are conducted through, our subsidiaries. Our General Partner has sole responsibility for conducting our business and for managing our operations. Ergon owns 100% of the outstanding membership interest of Blueknight GP Holding, L.L.C., which owns 100% of the membership interest of our General Partner.

Our General Partner has no business or operations other than managing our business. In addition, outside of its investment in us, our General Partner owns no assets or property. Our partnership agreement imposes no additional material liabilities upon our General Partner or obligations to contribute to us other than those liabilities and obligations imposed on general partners under the Delaware Revised Uniform Limited Partnership Act.

1

The following diagram depicts our organizational structure, including our relationship with our affiliates and subsidiaries, as of March 1, 2022:

Our Strengths and Strategies

Business strategy. Our strategy is to be a downstream terminalling solutions provider focused on infrastructure and transportation end-markets. During the first quarter of 2021, we completed the transformational divestitures of our three crude oil business segments. Through these divestitures, we have improved our balance sheet and achieved financial flexibility to pursue accretive growth investments. We have refocused expansion activities on core competencies and inherent competitive advantages in specialty terminalling markets. We plan to redeploy capital and maximize risk-adjusted returns in both organic and non-organic growth projects.

Strategically placed assets. We own 54 asphalt terminalling facilities in 26 states, consisting of approximately 9.0 million barrels of liquid asphalt storage, which we believe are well positioned to provide services in the market areas they serve throughout the continental United States. In addition, we have a focus on leveraging this existing site footprint to increase utilization for other complementary specialty products.

Growth opportunities. We evaluate growth opportunities from multiple angles, including growth through third-party acquisitions and optimizing our existing asset base.

Experienced management team. Our General Partner has an experienced and knowledgeable management team with extensive experience as a service provider in the product handling and construction materials industries. We expect to directly benefit from this management team’s strengths, including significant relationships throughout these industries with customers of our terminalling services.

2

Our relationship with Ergon. Ergon owns our General Partner and therefore controls our operations. Ergon is a privately held company formed in 1954 and is based in Jackson, Mississippi, with over 3,000 employees globally. Ergon and its subsidiaries are engaged in a wide range of operations that are categorized into six primary business segments: Refining & Marketing, Specialty Chemicals, Asphalt & Emulsions, Midstream & Logistics, Oil & Gas, and Construction & Real Estate. This relationship may provide us with additional capital sources for future growth as well as increased opportunities to provide terminalling services. While this relationship may benefit us, it may also be a source of potential conflicts. Ergon is not restricted from competing with us and may acquire, construct or dispose of additional assets in the future without any obligation to offer us the opportunity to purchase or construct those assets.

Asphalt Industry Overview

Liquid asphalt is one of the oldest engineering materials. Liquid asphalt’s adhesive and waterproofing properties have been used for building structures, waterproofing ships, and numerous other applications.

Production of liquid asphalt begins with the refining of crude oil. When crude oil is separated in distillation towers at a refinery, the heaviest hydrocarbons with the highest boiling points settle at the bottom. These tar-like fractions, called residuum, require relatively little additional processing to become products such as liquid asphalt. Liquid asphalt production typically represents only a small portion of the total product production in the crude oil refining process. The liquid asphalt produced by petroleum distillation can be sold by the refinery either directly into the wholesale or retail liquid asphalt markets.

In its normal state, liquid asphalt cement is too viscous to be used at ambient temperatures. For paving and roofing applications, asphalt cement is heated for handling and transporting to markets. Asphalt cement is generally used as straight-run asphalt cement (asphalt straight from refineries), polymer modified asphalt (PMA) or emulsified in a water base with emulsifying chemicals by a colloid mill (asphalt emulsions) and handled and transported at lower temperatures.

Hot mix asphalt is produced by mixing asphalt cement and heated with aggregate (stone, sand and/or gravel). The hot mix asphalt is loaded into trucks for transport to the paving site, where it is placed on the road surface by paving machines and compacted by rollers. Hot mix asphalt is used for roofing applications, new construction, reconstruction, and for thin maintenance overlay on existing roads.

Polymer modified asphalt is produced by mixing asphalt cement and heated with various qualities of polymers and chemicals to produce a higher quality of finished material that provides greater durability and elasticity for various markets. Polymer modified asphalt can also be included in asphalt emulsions. The polymer modified asphalt is loaded into trucks for transport to the paving site, or the hot mix facility, where it is then placed on the road surface by paving machines and compacted by rollers. Polymer modified asphalt is used for roofing applications, new construction, reconstruction, and for thin maintenance overlay on existing roads. 

Asphalt emulsions are used for a variety of applications, including spraying as a tack coat between an old pavement and a new hot mix asphalt overlay, cold mix pothole patching material, and preventive maintenance surface applications such as chip seals. Asphalt emulsions are also used for fog seal, slurry seal, scrub seal, sand seal and microsurfacing maintenance treatments, warm mix emulsion/aggregate mixtures, base stabilization, and in-place recycling.

The asphalt industry in the United States is characterized by a high degree of seasonality. Much of this seasonality is due to the impact that weather conditions have on road construction schedules, particularly in cold weather states. Refineries produce liquid asphalt year-round, but the peak asphalt demand season is during the warm weather months when most of the road construction activity in the United States takes place. Liquid asphalt marketers and finished asphalt product producers with access to storage capacity possess the inherent advantage of being able to purchase supply from refineries on a year-round basis and then sell finished asphalt products in the peak summer demand season.

Asphalt Terminalling Services

We provide asphalt terminalling services to marketers and distributors of liquid asphalt and asphalt-related products. We do not take title to the product. With approximately 9.0 million barrels of liquid asphalt cement storage capacity, we are able to provide our customers the ability to effectively manage their liquid asphalt inventories while allowing significant flexibility in their processing and marketing activities. As of March 1, 2022, we have 54 terminals located in 26 states and, as such, are well-positioned to provide asphalt terminalling services in the market areas we serve throughout the continental United States. 

We serve the asphalt industry by providing our customers access to their market areas through a combination of leasing our liquid asphalt facilities and providing terminalling services at certain facilities. We generate revenues by charging a fee for the lease of a facility or for services provided as asphalt products are terminalled at our facilities.

As of March 1, 2022, we have leases and terminalling agreements relating to all of our asphalt facilities, including 28 under contract with Ergon. Our agreements have, based on a weighted average of remaining fixed revenue, approximately 5.3 years remaining under their terms. Based on tank capacity, approximately 13% of capacity, all with third parties, expire in late 2022 if not renewed with the current customer or a new customer, and the remaining capacity expires at varying times thereafter, through 2035. We may not be able to extend, renegotiate or replace these contracts when they expire, and the terms of any renegotiated contracts may not be as favorable as the contracts they replace.

3

At facilities where we have terminalling agreements, we receive, store and/or process our customers’ asphalt products until those products are ready to be delivered to our customers or other third parties. Our asphalt assets include the logistics assets, such as docks and rail spurs and the piping and pumping equipment necessary to facilitate the unloading of liquid asphalt into our terminalling and storage facilities, as well as the processing and manufacturing equipment required for the processing of asphalt emulsions, polymer modified asphalt cement, and other related finished asphalt products. After initial unloading, the liquid asphalt is moved via heat-traced pipe into storage tanks. Those tanks are insulated and contain heating elements that allow the liquid asphalt to be stored in a heated state. The liquid asphalt can then be directly sold by our customers to end users or used as a raw material for the processing of asphalt emulsions, polymer modified asphalt cement, and related finished asphalt products that we process in accordance with the formulations and specifications provided by our customers. Depending on the product, the processing of asphalt entails combining asphalt cement and various other products such as emulsifying chemicals and polymers to achieve the desired specification and application requirements.

At leased facilities, our customers conduct the operations at the asphalt facility, including the storage and processing of asphalt products, and we collect a monthly rental fee relating to the lease of such facility. Generally, under the terms of those leases, (i) title to the asphalt, raw materials or finished asphalt products received, unloaded, stored, or otherwise handled at such asphalt facility is in the name of the lessee; (ii) the lessee is responsible for complying with environmental, health, safety, transportation and security laws; (iii) the lessee is required to obtain and maintain necessary permits, licenses, plans, approvals, or other such authorizations and is required to provide insurance for such asphalt facility; and (iv) most routine maintenance and repairs of such asphalt facility are the responsibility of the lessee.

We do not take title to or have marketing responsibility for the liquid asphalt product at terminals we operate. As a result, our asphalt operations have minimal direct exposure to changes in commodity prices, but the volumes of liquid asphalt we terminal are indirectly affected by commodity prices. 

The following table provides an overview of our asphalt facilities as of March 1, 2022:

		Total Tankage
Location	Number of Facilities	(in thousands of bbls)(1)
Alabama	1	205
Arizona	1	66
Arkansas	1	21
California	1	66
Colorado	5	736
Georgia	2	192
Idaho	1	285
Illinois	2	232
Indiana	1	156
Kansas	5	662
Missouri	3	662
Mississippi	1	202
Montana	1	123
Nebraska	1	292
New Jersey	1	459
Nevada	1	280
North Carolina	1	243
Ohio	1	38
Oklahoma	7	1,420
Pennsylvania	1	59
Tennessee	4	770
Texas	4	248
Utah	2	300
Virginia	2	635
Washington	3	468
Wyoming	1	220
Total	54	9,040

(1) Total tankage refers to the approximate total capacity of all tanks.

4

Our asphalt assets range in age from one year to over 50 years, and we expect that our storage tanks and related assets will have an average remaining life in excess of 20 years.

Significant Customers. For the year ended December 31, 2021, Ergon accounted for at least 40% but not more than 45% of our total asphalt terminalling services revenue. Two third-party customers each accounted for at least 10% but not more than 15% of asphalt terminalling services revenue in 2021. The loss of any of those customers could have a material adverse effect on our business, cash flows and results of operations. No other customer accounted for more than 10% of our revenue during 2021. As of March 1, 2022, we have terminalling agreements or operating leases with Ergon for 28 of our asphalt facilities. For more information regarding the Ergon agreements, please see Note 12 to our consolidated financial statements.

Competition

We compete with regional and local terminalling companies of widely varying sizes, financial resources, and experience. Participants range in size from major companies to small family-owned businesses. We are subject to competition from other terminalling operations that may be able to supply our customers with the same or comparable services on a more competitive basis. Our ability to compete could be harmed by factors we cannot control, including the perception that another company can provide better service or a decision by our competitors to acquire or construct asphalt terminalling assets and provide terminalling services in geographic areas, or to customers, served by our assets and services. Competition we are subject to is mitigated by our long-term contracts, the fact that we do not market products, and high barriers to entry from new construction. If we are unable to compete effectively with services offered by other asphalt terminalling companies, our financial results and ability to make distributions to our unitholders may be adversely affected. Additionally, we also compete with regional and local companies for asset acquisitions and expansion opportunities. Some of these competitors are substantially larger than us and have greater financial resources and lower costs of capital than we do.

Environmental, Health and Safety Risk

Federal, state and local laws and regulations related to zoning, land use, air emissions (including greenhouse gases), water discharges, waste management and disposal, noise, odor and dust control, and other environmental, health and safety and security matters govern our operations. Some of our operations require permits or other government-issued authorizations, which may impose additional operating standards, and are subject to modification renewal and revocation. We commit resources to achieve and maintain compliance with all applicable laws and regulations, however the risk of liabilities, particularly environmental liabilities, is inherent in the operation of our businesses. These potential liabilities could result in material costs, including for fines or personal injury or damages claims, which could have an adverse impact on our operations and profitability.

Future events, including changes in existing laws or regulations or enforcement policies, or further investigation or evaluation of the potential health hazards of the products handled or business activities may result in additional or unanticipated compliance and other costs. We could be required to invest in preventive or remedial action, like control equipment, which could be substantial, or which could result in restrictions on our operations or delays in obtaining required permits or other approvals.

Our operations are subject to manufacturing, operating, and handling risks associated with the products we produce and the products we use in our operations, including the related storage of finished products, hazardous substances, and wastes. We are exposed to potential hazards including storage tank leaks, explosions, discharges or releases of hazardous substances, health hazard exposure, documentation and reporting failures and the operation of mobile equipment and manufacturing machinery. These risks can subject us to potential liabilities relating to personal injury or death, or property damage, and may result in civil or criminal penalties, which could have an adverse impact on our productivity or profitability. We may be called upon to investigate and remediate environmental contamination relating to our prior or current operations, as well as operations we have acquired from others, or we may be named as a defendant in litigation brought by governmental agencies or private parties.

5

Operational Hazards and Insurance

Terminals and similar facilities may experience damage as a result of an accident or natural disaster. These hazards can cause personal injury and loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage, and suspension of operations. We maintain insurance of various types and varying levels of coverage which we consider adequate under the circumstances to cover our operations and properties, including coverage for pollution-related events. However, such insurance does not cover every potential risk associated with operating terminals and other facilities. In 2020, we experienced increased costs as insurers are increasing premiums to ameliorate recent losses. Through the utilization of deductibles and retentions, where appropriate and efficient, we self-insure the “working layer” of loss activity to create a more efficient and cost-effective program. The working layer consists of high-frequency/low-severity losses that are best retained and managed in-house. We continue to monitor our retentions as they relate to the overall cost and scope of our insurance program.

Employees

As of December 31, 2021, we had approximately 130 full-time employees. None of these employees are represented by labor unions or covered by any collective bargaining agreement. 

Financial Information about Segments

We operate our asphalt terminalling facilities under a single operating segment.

 Available Information

We provide public access to our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to these reports filed with the SEC under the Securities and Exchange Act of 1934. These documents may be accessed free of charge on our website, www.bkep.com, as soon as is reasonably practicable after their filing with the SEC. Information contained on our website is not incorporated by reference in this report or any of our other filings. The SEC also maintains a website which contains reports, proxy and information statements and other information regarding issuers that file electronically with the SEC. The SEC’s website is www.sec.gov.

Item 1A. Risk Factors.

Limited partner interests are inherently different from the capital stock of a corporation, although many of the business risks to which we are subject are similar to those that would be faced by a corporation engaged in a similar business. You should carefully consider the following risk factors together with all of the other information included in this report. If any of the following risks were actually to occur, our business, financial condition, results of operations and cash flows could be materially adversely affected. In that case, we might not be able to pay distributions on our units, the trading price of our units could decline and our unitholders could lose all or part of their investment.

Risks Related to our Business

We may not have sufficient cash from operations following the establishment of cash reserves and payment of fees and expenses, including cost reimbursements to our General Partner, to enable us to make cash distributions to holders of our units at our current distribution rate.

In order to make cash distributions on our Preferred Units at the preference distribution rate of $0.17875 per unit per quarter, or $0.715 per unit per year, and on our common units at the current quarterly distribution of $0.0425 per unit per quarter, or $0.17 per unit per year, we will require available cash of approximately $8.1 million per quarter, or $32.4 million per year. We may not have sufficient available cash from operating surplus each quarter to enable us to make cash distributions on our Preferred Units at the preference rate or on our common units at the current quarterly distribution rate. The amount of cash we can distribute on our units principally depends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things, the risks described herein.

In addition, the actual amount of cash we will have available for distribution will depend on other factors, including:

• the level of capital expenditures we make;

• the cost of acquisitions;

• our debt service requirements and other liabilities;

• fluctuations in our working capital needs;

• our ability to borrow funds and access capital markets;

• restrictions contained in our credit facility or other debt agreements; and

• the amount of cash reserves established by our General Partner.

6

We depend on certain key customers for a portion of our revenues and are exposed to credit risks of these customers. The loss of or material nonpayment or nonperformance by any of these key customers could adversely affect our financial condition, results of operations and cash flows.

We rely on certain key customers for a portion of our revenues. For example, Ergon Asphalt and Emulsion, Inc., a wholly-owned subsidiary of Ergon, Inc., represented at least 40% but not more than 45% of our total revenue in 2021. Ergon is a private company and we have limited information regarding its financial condition. Ergon comprised 11% of total accounts receivable at December 31, 2021.

In addition to Ergon, we have two other key customers that each accounted for at least 10% but not more than 15% of total revenue in 2021. Four third-party customers each accounted for between 10% and 25% of accounts receivable at December 31, 2021.

We may be unable to negotiate extensions or replacements of contracts with key customers on favorable terms. In addition, some of these key customers may experience financial problems which could have a significant effect on their creditworthiness. Severe financial problems encountered by our customers could limit our ability to collect amounts owed to us or to enforce performance of obligations under contractual arrangements. Additionally, many of our customers finance their activities through cash flows from operations, the incurrence of debt or the issuance of equity. The reduction of cash flows resulting from a reduction in borrowing bases under credit facilities, the lack of availability of debt or equity financing, or any combination of such factors may result in a significant reduction of our customers’ liquidity and limit their ability to make payments or perform on their obligations to us. Furthermore, some of our customers may be highly leveraged and subject to their own operating and regulatory risks, which increases the risk that they may default on their obligations to us. The loss of all or even a portion of the contracted fees of these key customers, as a result of competition, creditworthiness or otherwise, could have a material adverse effect on our business, cash flows, ability to make distributions to our unitholders, unit price, results of operations and ability to conduct our business.

The amount of cash we have available for distribution to holders of our units depends primarily on our cash flows and not solely on earnings reflected in our financial statements. Consequently, even if we are profitable and are otherwise able to pay distributions, we may not be able to make cash distributions to holders of our units.

Our unitholders should be aware that the amount of cash we have available for distribution depends primarily upon our cash flows and not solely on earnings reflected in our financial statements, which will be affected by non-cash items. As a result, we may make cash distributions, if permitted by our credit agreement, during periods when we record losses for financial accounting purposes and may not make cash distributions during periods when we record net earnings for financial accounting purposes.

Our debt levels under our credit agreement may limit our ability to make distributions and our flexibility in obtaining additional financing and in pursuing other business opportunities.

As of December 31, 2021, we had $98.0 million in outstanding indebtedness, excluding approximately $0.6 million in outstanding letters of credit, under our $300.0 million credit agreement. Our level of debt under the credit agreement could have important consequences for us, including the following:

• Our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired or such financing may not be available on favorable terms.

• We will need a substantial portion of our cash flows to make principal and interest payments on our debt, reducing the funds that would otherwise be available for operations, future business opportunities and distributions to unitholders.

• We could be more vulnerable to competitive pressures or a downturn in our business or the economy generally.

• Our flexibility in responding to changing business and economic conditions may be limited. 

Our ability to service our debt will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors. Our ability to service debt under our credit agreement also will depend on market interest rates, since the interest rates applicable to our borrowings will fluctuate with the eurodollar rate or the prime rate. If our operating results are not sufficient to service our current or future indebtedness, we may be forced to take actions such as reducing distributions, reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets, restructuring or refinancing our debt, or seeking additional equity capital. We may not be able to effect any of these actions on satisfactory terms, or at all.

7

Restrictions in our credit agreement could materially adversely affect our business, financial condition, results of operations, ability to make cash distributions to unitholders and value of our units.

We are dependent upon the earnings and cash flows generated by our operations to meet our debt service obligations and to make cash distributions to our unitholders. The operating and financial restrictions and covenants in our credit agreement and any future financing agreements could restrict our ability to finance future operations or capital needs or to expand or pursue our business activities, which may, in turn, limit our ability to make cash distributions to our unitholders. For example, our credit agreement restricts our ability to, among other things:

• incur or guarantee certain additional debt;

• make certain cash distributions on or redeem or repurchase certain units;

• make certain investments and acquisitions;

• make certain capital expenditures;

• incur certain liens or permit them to exist;

• enter into certain types of transactions with affiliates;

• merge or consolidate with another company or otherwise engage in a change of control transaction; and

• transfer, sell or otherwise dispose of certain assets.

Our credit agreement also contains covenants requiring us to maintain certain financial ratios and meet certain financial tests. Our ability to meet those financial ratios and financial tests can be affected by events beyond our control, and we cannot guarantee that we will meet those ratios and tests.

The provisions of our credit agreement may affect our ability to obtain future financing and pursue attractive business opportunities, as well as affect our flexibility in planning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of our credit agreement could result in a default or an event of default that could enable our lenders to declare the outstanding principal of that debt, together with accrued and unpaid interest, to be immediately due and payable. If we were unable to repay the accelerated amounts, the lenders under our credit agreement could proceed against the collateral granted to them to secure such debt. If the payment of our debt is accelerated, our assets may be insufficient to repay such debt in full, and our unitholders could experience a partial or total loss of their investment. The credit agreement also has cross default provisions that apply to any other indebtedness we may have, and the indentures have cross default provisions that apply to certain other indebtedness.

We may not be able to raise sufficient capital to grow our business.

As of March 1, 2022, we have aggregate unused credit availability under our credit agreement of approximately $189.4 million, plus cash on hand of approximately $1.1 million. Our ability to borrow funds under our credit facility may be limited by the financial covenants in our credit agreement. Our ability to access the public capital markets on terms acceptable to us or at all may be limited due to, among other things, general economic conditions, rising interest rates, capital market volatility, the uncertainty of our future cash flows, adverse business developments and other contingencies. In addition, we may have difficulty obtaining a credit rating or any credit rating that we do obtain may be lower than it otherwise would be due to these uncertainties. The lack of a credit rating or a low credit rating may also adversely impact our ability to access capital markets on terms acceptable to us or at all, and may increase significantly the costs of financing our growth potential. The credit agreement includes procedures for additional financial institutions to become revolving lenders, or for any existing lender to increase its revolving commitment thereunder, subject to an aggregate maximum of $450.0 million for all revolving loan commitments under the credit agreement.

If we fail to raise additional capital or an event of default occurs under our credit agreement, we may be forced to sell assets or take other action that could have a material adverse effect on our business, unit price and results of operations. In addition, if we are unable to access the capital markets for acquisitions or expansion projects on terms acceptable to us or at all, or if the financing cost related to any such acquisitions or expansion projects increases, it may have a material adverse effect on our business, cash flows, ability to make distributions to our unitholders, unit price, results of operations and ability to conduct our business.

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If we borrow funds to make any permitted quarterly distributions, our ability to pursue acquisitions and other business opportunities may be limited and our operations may be materially and adversely affected.

Available cash for the purpose of making distributions to unitholders includes working capital borrowings. If we borrow funds to pay one or more quarterly distributions, such amounts will incur interest and must be repaid in accordance with the terms of our credit agreement. In addition, any amounts borrowed for permitted distributions to our unitholders will reduce the funds available to us for other purposes under our credit agreement, including amounts available for use in connection with acquisitions and other business opportunities. If we are unable to pursue our growth strategy due to our limited ability to borrow funds, our operations may be materially and adversely affected.

Our revenues from third-party customers are generated under contracts that must be renegotiated periodically and that allow the customer to reduce or suspend performance in some circumstances, which could cause our revenues from those contracts to decline and reduce our ability to make distributions to our unitholders.

Some of our contract-based revenues from customers are generated under contracts with terms which allow the customer to reduce or suspend performance under the contract in specified circumstances, such as the occurrence of a catastrophic event to our or the customer’s operations. The occurrence of an event which results in a material reduction or suspension of our customer’s performance could have a material adverse effect on our financial condition, results of operations and cash flows.

Our contracts with some of our customers have remaining terms of one year or less. As these contracts expire, they must be extended and renegotiated or replaced. We may not be able to extend and renegotiate or replace these contracts when they expire, and the terms of any renegotiated contracts may not be as favorable as the contracts they replace. In particular, our ability to extend or replace contracts could be harmed by numerous competitive factors, such as those described above under “Item 1. Business - Competition.” If we cannot successfully renew significant contracts or must renew them on less favorable terms, or if we incur substantial costs in modifying our terminals, our revenues from these arrangements could decline, which could have a material adverse effect on our financial condition, results of operations and cash flows.

Certain of our asphalt terminalling services contracts have short remaining terms, and certain leases relating to our asphalt operations may be terminated upon short notice.

As of March 1, 2022, we had leases or terminalling agreements with customers for all of our 54 asphalt facilities. Approximately 13% of our tank capacity, all with third parties, will expire by the end of 2022 if not renewed with the current customer or a new customer. We may not be able to renew or extend our existing contracts or enter into new leases or terminalling agreements when such contracts expire on terms acceptable to us or at all. In addition, certain key customers account for a significant portion of our asphalt terminalling services revenues, the loss of which could result in a significant decrease in revenues from our asphalt operations. A significant decrease in the revenues we receive from our asphalt operations could result in violations of covenants under our credit agreement and could have a material adverse effect on our business, cash flows, ability to make distributions to our unitholders, unit price, results of operations, and ability to conduct our business.

In addition, certain of our asphalt facilities are located on land that we lease from third parties. Some of these leases may be terminated by the lessor with as short as thirty days’ notice. We also have not yet received consent from certain of the lessors to sublease such facilities, which may result in a default under such lease or invalidate the subleases. If such leases were terminated, it could have a material adverse effect on our ability to provide asphalt terminalling services, which could have a material adverse effect on our business, cash flows, ability to make distributions to our unitholders, unit price, results of operations, and ability to conduct our business. In addition, in certain instances we have not entered into new leases with a lessor, although we continue to operate under expired leases and make payments to the lessor and are in the process of negotiating new leases. If it were determined that we did not have rights under these expired leases, it could have a material adverse effect on our ability to conduct our asphalt operations and on our financial condition, results of operations and cash flows.

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We may not be fully insured against all risks incident to our business and could incur substantial liabilities as a result.

We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of changing market conditions, premiums and deductibles for certain of our insurance policies may increase substantially in the future. In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage. If we were to incur a significant liability for which we were not fully insured, it could have a material adverse effect on our business, cash flows, ability to make distributions to our unitholders, unit price, results of operations, and ability to conduct our business.

A significant decrease in demand for liquid asphalt products in the areas served by our operations could reduce our ability to make distributions to our unitholders.

A sustained decrease in demand for liquid asphalt products in the areas served by our terminalling facilities could significantly reduce our revenues and, therefore, reduce our ability to make or increase distributions to our unitholders. Factors that could lead to a decrease in market demand for liquid asphalt products include: lower demand by consumers for refined products, including asphalt products, as a result of (i) recession or other adverse economic conditions; (ii) higher prices caused by an increase in the market price of crude oil; or (iii) higher taxes or other governmental or regulatory actions that increase, directly or indirectly, the cost of gasoline or other refined products.

A material decrease in the production of liquid asphalt could materially reduce our ability to make distributions to our unitholders.

The throughput at our asphalt facilities depends on the availability of attractively priced liquid asphalt produced from the various liquid asphalt producing refineries. Liquid asphalt production may decline for a number of reasons, including refiners processing more light, sweet crude oil or refiners installing coker units which further refine heavy residual fuel oil bottoms such as liquid asphalt. If our customers are unable to replace volumes lost due to a temporary or permanent material decrease in production from the suppliers of liquid asphalt, our throughput could decline, reducing our revenue and cash flows and adversely affecting our financial condition and results of operations.

If we are unable to make acquisitions on economically acceptable terms, our future growth may be limited.

Our ability to grow in the future will depend, in part, on our ability to make acquisitions that result in an increase in the cash generated per unit from operations. If we are unable to make accretive acquisitions because we are (i) unable to acquire projects when they are available; (ii) unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts with them; (iii) unable to obtain financing for these acquisitions on economically acceptable terms; or (iv) outbid by competitors, then our future growth and ability to increase distributions may be limited. Furthermore, even if we do make acquisitions that we believe will be accretive, these acquisitions may nevertheless result in a decrease in the cash generated from operations per unit.

Any acquisition involves potential risks, including, among other things:

• inaccurate assumptions about volumes, revenues and costs, including synergies;

• an inability to integrate successfully the businesses we acquire;

• an inability to hire, train or retain qualified personnel to manage and operate our business and assets;

• the assumption of unknown liabilities;

• limitations on rights to indemnity from the seller;

• mistaken assumptions about the overall costs of equity or debt;

• the diversion of management’s and employees’ attention from other business concerns;

• unforeseen difficulties operating in new product areas or new geographic areas; and

• customer or key employee losses at the acquired businesses.

If we consummate any future acquisitions, our capitalization and results of operations may change significantly, and our unitholders likely will not have the opportunity to evaluate the economic, financial, and other relevant information that we will consider in determining the application of these funds and other resources.

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If we acquire assets that are distinct and separate from our existing terminalling operations, it could subject us to additional business and operating risks.

We may acquire assets that have operations in new and distinct lines of business from our liquid asphalt operations. Integration of a new business is a complex, costly and time-consuming process. Failure to timely and successfully integrate acquired entities’ lines of business with our existing operations may have a material adverse effect on our business, financial condition, results of operations and cash flows. The difficulties of integrating a new business with our existing operations include, among other things:

• operating distinct businesses which require different operating strategies and different managerial expertise;

• the necessity of coordinating organizations, systems and facilities in different locations;

• integrating personnel with diverse business backgrounds and organizational cultures; and

• consolidating corporate and administrative functions.

In addition, the diversion of our attention and any delays or difficulties encountered in connection with the integration of a new business, such as unanticipated liabilities or costs, could harm our existing business, results of operations, financial condition, and prospects. Furthermore, new lines of business may subject us to additional business and operating risks. These new business and operating risks could have a material adverse effect on our financial condition, results of operations and cash flows.

Expanding our business by constructing new assets subjects us to risks that projects may not be completed on schedule and that the costs associated with projects may exceed our expectations and budgets, which could cause our cash available for distribution to our unitholders to be less than anticipated.

The construction of additions or modifications to our existing assets and the construction of new assets involves numerous regulatory, environmental, political, legal, and operational uncertainties and requires the expenditure of significant amounts of capital. If we undertake these types of projects, they may not be completed on schedule or at all or within the budgeted cost. Moreover, we may construct facilities to capture anticipated future growth in demand in a market in which such growth does not materialize.

Our expansion projects may not immediately produce operating cash flows.

Expansion projects require significant capital investments over time, and we will incur financing costs during the planning and construction phases of these projects; however, the operating cash flows we expect these projects to generate will not materialize, if at all, until sometime after the projects are completed and placed into service. As a result, to the extent we finance our projects with borrowings, our leverage may increase during the period prior to the generation of those operating cash flows and, to the extent we finance our projects with equity, our cash available for distribution on a common unit basis may decrease during the period prior to the generation of those operating cash flows. If we experience unanticipated or extended delays in generating operating cash flows from construction projects, or if such operating cash flows do not materialize as expected, we may need to reduce or reprioritize our capital budget in order to meet our capital requirements, and our liquidity and capital position could be adversely affected.

Our business involves many hazards and operational risks, including adverse weather conditions, which could cause us to incur substantial liabilities.

Our operations are subject to the many hazards inherent in the terminalling of liquid asphalt cement, including:

• explosions, earthquakes, fires and accidents;

• extreme weather conditions, such as hurricanes, which are common in the Gulf Coast and East Coast regions, and tornadoes and flooding, which are common in the Midwest and other areas of the United States in which we operate;

• damage to our terminals and equipment;

• leaks or releases of liquid asphalt product into the environment; and

• acts of terrorism or vandalism.

If any of these events were to occur, we could suffer substantial losses because of personal injury or loss of life, severe damage to and destruction of property and equipment and pollution or other environmental damage resulting in curtailment or suspension of our related operations. In addition, mechanical malfunctions, faulty measurement or other errors may result in significant costs or lost revenues.

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We could be negatively impacted by the outbreak of coronavirus (COVID-19).

In light of the uncertain situation relating to the coronavirus (COVID-19), including resurgences and variants of the virus, this public health concern could pose a risk to our employees, our customers, our vendors and the communities in which we operate, which could negatively impact our business. While COVID-19 has not had a significant impact on our business thus far, the extent to which COVID-19 could impact our business will depend on future developments, which are uncertain and cannot be predicted at this time. We continue to monitor the situation, have actively implemented policies and practices to address the situation, and may adjust our current policies and practices as more information and guidance become available.

We do not own all of the land on which our facilities are located, which could disrupt our operations.

We do not own all of the land on which our asphalt facilities have been constructed, and we are therefore subject to the possibility of more onerous terms and/or increased costs to retain necessary land use if any material real property leases are invalid, lapse or terminate. We obtain the rights to construct and operate some of our asphalt facilities on land owned by third parties and governmental agencies for a specific period of time. Our loss of these rights through our inability to renew leases, could have a material adverse effect on our business, results of operations, financial condition, cash flows and ability to make cash distributions to our unitholders. In addition, we are in the process of obtaining consents from the lessors for certain leased property that was transferred to us as part of the acquisition of our asphalt assets. If any consent is denied, it could have a material adverse effect on our business, results of operations, financial condition, cash flows and our ability to make cash distributions to our unitholders.

Terrorist or cyber-attacks and threats, escalation of military activity in response to these attacks, or acts of war could have a material adverse effect on our business, financial condition or results of operations.

Terrorist attacks and threats, cyber-attacks, escalation of military activity, or acts of war may have significant effects on general economic conditions, fluctuations in consumer confidence and spending, and market liquidity, each of which could materially and adversely affect our business. Terrorist or cyber-attacks, rumors or threats of war, actual conflicts involving the United States or its allies, or military or trade disruptions may significantly affect our operations and those of our customers. Strategic targets, such as infrastructure-related and energy-related assets, may be at greater risk of future attacks than other targets in the United States. We do not maintain specialized insurance for possible exposures resulting from a cyber-attack on our assets that may shut down all or part of our business. Disruption or significant increases in commodity prices could result in government-imposed price controls. It is possible that any of these occurrences, or a combination of them, could have a material adverse effect on our business, financial condition, and results of operations.

The threat and impact of cyberattacks may adversely impact our operations and could result in information theft, data corruption, operational disruption, and/or financial loss.

We depend on digital technology, including information systems and related infrastructure as well as cloud applications and services, to store, transmit, process, and record sensitive information (including trade secrets, employee information and financial and operating data), communicate with our employees and business partners and for many other activities related to our business. Our business processes depend on the availability, capacity, reliability and security of our information technology infrastructure and our ability to expand and continually update this infrastructure in response to our changing needs and, therefore, it is critical to our business that our facilities and infrastructure remain secure. While we have implemented strategies to mitigate impacts from these types of events, we cannot guarantee that measures taken to defend against cybersecurity threats will be sufficient for this purpose. The ability of the information technology function to support our business in the event of a security breach or a disaster such as fire or flood and our ability to recover key systems and information from unexpected interruptions cannot be fully tested, and there is a risk that, if such an event occurs, we may not be able to address immediately the repercussions of the breach or disaster. In that event, key information and systems may be unavailable for a number of days or weeks, leading to our inability to conduct business or perform some business processes in a timely manner. Moreover, if any of these events were to materialize, they could lead to losses of sensitive information, critical infrastructure, personnel or capabilities essential to our operations and could have a material adverse effect on our reputation, financial condition or results of operations.

Our employees have been and will continue to be targeted by parties using fraudulent “spoof” and “phishing” emails to misappropriate information or to introduce viruses or other malware through “trojan horse” programs to our computers. These emails appear to be legitimate emails but direct recipients to fake websites operated by the sender of the email or request that the recipient send a password or other confidential information through email or download malware. “Spoof” and “phishing” activities are a serious risk that may damage our information technology infrastructure.

If we fail to maintain an effective system of internal controls, we may not be able to accurately report our financial results or prevent fraud. In addition, potential changes in accounting standards might cause us to revise our financial results and disclosure in the future.

Effective internal controls are necessary for us to provide timely and reliable financial reports and effectively prevent fraud. If we cannot provide timely and reliable financial reports or prevent fraud, our reputation and operating results would be harmed. We continue to enhance our internal controls and financial reporting capabilities. These enhancements require a significant commitment of resources, personnel and the development and maintenance of formalized internal reporting procedures to ensure the reliability of our financial reporting. Our efforts to update and maintain our internal controls may not be successful, and we may be unable to maintain adequate controls over our financial processes and reporting now or in the future, including future compliance with the obligations under Section 404 of the Sarbanes-Oxley Act of 2002. Any failure to maintain effective controls or difficulties encountered in the effective improvement of our internal controls could prevent us from timely and reliably reporting our financial results and may harm our operating results. Ineffective internal controls could also cause investors to lose confidence in our reported financial information. In addition, the Financial Accounting Standards Board or the SEC could enact new accounting standards that might affect how we are required to record revenues, expenses, assets and liabilities. Any significant change in accounting standards or disclosure requirements could have a material effect on our business, results of operations, financial condition and ability to comply with our debt obligations. 

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Risks Inherent in an Investment in Us

Ergon controls our General Partner, which has sole responsibility for conducting our business and managing our operations. Our General Partner has conflicts of interest with us and limited fiduciary duties, which may permit it to favor its own interests to the detriment of our unitholders.

Ergon owns and controls our General Partner. Some of our General Partner’s directors are directors and officers of Ergon. Therefore, conflicts of interest may arise between our General Partner, on the one hand, and us and our unitholders, on the other hand. In resolving those conflicts of interest, our General Partner may favor its own interests and the interests of its affiliates over the interests of our unitholders. Although the conflicts committee of the board of directors of our General Partner (the “Board”) may review such conflicts of interest, the Board is not required to submit such matters to the conflicts committee. These conflicts include, among others, the following situations:

• Neither our partnership agreement nor any other agreement requires our General Partner or Ergon to pursue a business strategy that favors us. Such persons may make decisions in their best interest, which may be contrary to our interests.

• Our General Partner is allowed to consider the interests of parties other than us and our unitholders, such as Ergon and its affiliates, in resolving conflicts of interest.

• If we do not have sufficient available cash from operating surplus, our General Partner could cause us to use cash from non-operating sources, such as asset sales, issuances of securities and borrowings, to pay distributions, which means that we could make distributions that deteriorate our capital base and that our General Partner could receive distributions on its incentive distribution rights to which it would not otherwise be entitled if we did not have sufficient available cash from operating surplus to make such distributions.

• Ergon is a holder of our Preferred Units and may favor its own interests in actions relating to such units, including causing us to make distributions on such units even if no distributions are made on the common units.

• Ergon may compete with us, including with respect to future acquisition opportunities.

• Ergon may favor its own interests in proposing the terms of any acquisitions we make directly from them, and such terms may not be as favorable as those we could receive from an unrelated third party.

• Our General Partner has limited liability and reduced fiduciary duties and our unitholders have restricted remedies available for actions that, without the limitations, might constitute breaches of fiduciary duty.

• Our General Partner determines the amount and timing of asset purchases and sales, borrowings, issuance of additional partnership securities and reserves, each of which can affect the amount of cash that is distributed to unitholders.

• Our General Partner determines the amount and timing of any capital expenditures and whether a capital expenditure is a maintenance capital expenditure, which reduces operating surplus, or an expansion capital expenditure, which does not reduce operating surplus. This determination can affect the amount of cash that is distributed to our unitholders.

• Our General Partner may decide to receive a quantity of our Class B units in exchange for resetting the target distribution levels related to its incentive distribution rights without the approval of the conflicts committee of our General Partner or our unitholders.

• Our General Partner determines which costs incurred by it and its affiliates are reimbursable by us.

• Our partnership agreement does not restrict our General Partner from causing us to pay it or its affiliates for any services rendered to us or entering into additional contractual arrangements with any of these entities on our behalf.

• Our General Partner intends to limit its liability regarding our contractual and other obligations and, in some circumstances, is entitled to be indemnified by us.

• Our General Partner may exercise its limited right to call and purchase common units if it and its affiliates own more than 80% of the common units.

• Our General Partner controls the enforcement of obligations owed to us by our General Partner and its affiliates.

• Our General Partner decides whether to retain separate counsel, accountants or others to perform services for us.

Our partnership agreement limits the fiduciary duties our General Partner owes to holders of our units and restricts the remedies available to holders of our units for actions taken by our General Partner that might otherwise constitute breaches of fiduciary duty.

Our partnership agreement contains provisions that reduce the fiduciary standards to which our General Partner would otherwise be held by state fiduciary duty laws. For example, our partnership agreement:

• permits our General Partner to make a number of decisions in its individual capacity, as opposed to in its capacity as our General Partner. This entitles our General Partner to consider only the interests and factors that it desires, and it has no duty or obligation to give any consideration to any interest of, or factors affecting, us, our affiliates or any limited partner. Examples include the exercise of its right to receive a quantity of our Class B units in exchange for resetting the target distribution levels related to its incentive distribution rights, the exercise of its limited call right, the exercise of its rights to transfer or vote the units it owns, the exercise of its registration rights and its determination whether or not to consent to any merger or consolidation of the partnership or amendment to the partnership agreement;

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• provides that our General Partner will not have any liability to us or our unitholders for decisions made in its capacity as a general partner so long as it acted in good faith, meaning it believed the decision was in the best interests of our partnership;

• generally provides that affiliated transactions and resolutions of conflicts of interest not approved by the conflicts committee of the Board acting in good faith and not involving a vote of unitholders must be on terms no less favorable to us than those generally being provided to or available from unrelated third parties or must be “fair and reasonable” to us, as determined by our General Partner in good faith. In determining whether a transaction or resolution is “fair and reasonable,” our General Partner may consider the totality of the relationships between the parties involved, including other transactions that may be particularly advantageous or beneficial to us;

• provides that our General Partner and its officers and directors will not be liable for monetary damages to us, our limited partners or assignees for any acts or omissions unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining that our General Partner or its officers and directors 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

• provides that in resolving conflicts of interest, it will be presumed that in making its decision, our General Partner acted in good faith, and in any proceeding brought by or on behalf of any limited partner or us, the person bringing or prosecuting such proceeding will have the burden of overcoming such presumption.

By purchasing a common unit, a common unitholder will become bound by the provisions in the partnership agreement, including the provisions discussed above.

Ergon may compete with us, which could adversely affect our existing business and limit our ability to acquire additional assets or businesses.

Neither our partnership agreement nor any other agreement with Ergon prohibits Ergon from owning assets or engaging in businesses that compete directly or indirectly with us. In addition, Ergon may acquire, construct or dispose of assets in the future, without any obligation to offer us the opportunity to purchase or construct any of those assets. Ergon is a privately held company engaged in a wide range of operations. Ergon has significantly greater resources and experience than we have, which may make it more difficult for us to compete with Ergon with respect to commercial activities as well as for acquisition candidates. As a result, competition from Ergon could adversely impact our results of operations and cash available for distribution.

Cost reimbursements due to our General Partner and its affiliates for services provided, which are determined by our General Partner, may be substantial and will reduce our cash available for distribution to our unitholders.

Pursuant to our partnership agreement, our General Partner is entitled to receive reimbursement for the payment of expenses related to our operations and for the provision of various general and administrative services for our benefit. Payments for these services may be substantial and reduce the amount of cash available for distribution to unitholders. In addition, under Delaware partnership law, our General Partner has unlimited liability for our obligations, such as our debts and environmental liabilities, except for our contractual obligations that are expressly made without recourse to our General Partner. To the extent our General Partner incurs obligations on our behalf, we are obligated under our partnership agreement to reimburse or indemnify our General Partner. If we are unable or unwilling to reimburse or indemnify our General Partner, our General Partner may take actions to cause us to make payments of these obligations and liabilities. Any such payments would reduce the amount of cash otherwise available for distribution to our unitholders.

Holders of our Preferred Units and common units have limited voting rights and are not entitled to elect our General Partner or its directors.

Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management’s decisions regarding our business. Unitholders did not elect our General Partner or the Board and have no right to elect our General Partner or the Board on an annual or other continuing basis. The Board is chosen by Ergon. Furthermore, if the unitholders are dissatisfied with the performance of our General Partner, they have little ability to remove our General Partner. Amendments to our partnership agreement may be proposed only by or with the consent of our General Partner. As a result of these limitations, the price at which the common units will trade could be diminished because of the absence or reduction of a takeover premium in the trading price.

Control of our General Partner may be transferred to a third party without unitholder consent.

Our General Partner may transfer its general partner interest to a third party in a merger or in a sale of all or substantially all of its assets without the consent of the unitholders. Furthermore, our partnership agreement does not restrict the ability of Ergon, the owner of our General Partner, from transferring all or a portion of its ownership interest in our General Partner to a third party. The new owner of our General Partner would then be in a position to replace the Board and officers of our General Partner with its own choices and thereby influence the decisions made by the Board and officers.

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We may issue additional units without approval of our unitholders, which would dilute our unitholders’ ownership interests.

Except in the case of the issuance of units that rank equal to or senior to the Preferred Units, our partnership agreement does not limit the number or price of additional limited partner interests we may issue at any time without the approval of our unitholders. In addition, because we are a limited partnership, we will not be subject to the shareholder approval requirements relating to the issuance of securities (other than in connection with the establishment or material amendment of a stock option or purchase plan or the making or material amendment of any other equity compensation arrangement) contained in Nasdaq Marketplace Rule 5635. The issuance by us of additional common units or other equity securities of equal or senior rank may have any or all of the following effects, among others:

• Our unitholders’ proportionate ownership interest in us will decrease.

• The amount of cash available for distribution on each unit may decrease.

• The ratio of taxable income to distributions may increase.

• The relative voting strength of each previously outstanding unit may be diminished.

• The market price of the common units may decline.

Our partnership agreement restricts the voting rights of unitholders, other than our General Partner and its affiliates, including Ergon, owning 20% or more of any class of our partnership securities.

Unitholders’ voting rights are further restricted by the partnership agreement, which provides that any units held by a person that owns 20% or more of any class of units then outstanding, other than our General Partner, its affiliates, their transferees and persons who acquired such units with the prior approval of the Board, cannot vote on any matter. Our partnership agreement also contains provisions limiting the ability of unitholders to call meetings or to acquire information about our operations, as well as other provisions.

Even if our public unitholders are dissatisfied with our General Partner, it will be difficult for them to remove our General Partner without its consent.

It will be difficult for our public unitholders to remove our General Partner without its consent because our General Partner and its affiliates own a substantial number of our units. The vote of the holders of at least 66 ²/3% of all outstanding units voting together as a single class is required to remove the General Partner. As of March 1, 2022, Ergon owned approximately 30.9% of our aggregate outstanding Preferred Units and common units.

Affiliates of our General Partner may sell units in the public markets, which sales could have an adverse impact on the trading price of the units.

As of March 1, 2022, the executive officers and directors of our General Partner beneficially own an aggregate of 619,810 common units and Ergon and its affiliates own 2,795,837 common units and 20,801,757 Preferred Units. The sale of these units in the public markets could have an adverse impact on the public trading price of the units or on any trading market that may develop.

Our General Partner has a limited call right that may require our unitholders to sell their units at an undesirable time or price.

If at any time our General Partner and its affiliates own more than 80% of any class of units then outstanding, our General Partner will have the right, but not the obligation, which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of such class of units held by unaffiliated persons at a price not less than the then-current market price. As a result, our unitholders may be required to sell their units at an undesirable time or price and may not receive any return on their investment. Our unitholders also may incur a tax liability upon a sale of their units. As of March 1, 2022, Ergon owned 60.5% of our outstanding Preferred Units.

Holders of our Preferred Units have a distribution preference and a liquidation preference, which may adversely impact the value of our common units.

The Preferred Units rank prior to our common units as to both distributions of available cash and distributions upon liquidation. Holders of our Preferred Units are entitled to preferred quarterly distributions of $0.17875 per unit per quarter (or $0.715 per unit on an annual basis). If we fail to pay in full any distribution on our Preferred Units, the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full. If we are liquidated, we may not have sufficient funds remaining after payment of amounts to our creditors and to holders of our Preferred Units to make any distribution to holders of our common units.

The conversion rate applicable to the Preferred Units will not be adjusted for all events that may be dilutive.

The number of our common units issuable upon conversion of the Preferred Units is subject to adjustment only for subdivisions, splits or certain combinations of our common units. The number of common units issuable upon conversion is not subject to adjustment for other events, such as employee option grants, offerings of our common units for cash or in connection with acquisitions or other transactions that may increase the number of outstanding common units and dilute the ownership of existing common unitholders. The terms of the Preferred Units do not restrict our ability to offer common units in the future or to engage in other transactions that could dilute our common units.

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We have rights to require our preferred unitholders to convert their Preferred Units into common units, and we may exercise this mandatory conversion right at an undesirable time.

We have the right in certain circumstances to force the conversion of all outstanding Preferred Units to common units. These circumstances include a situation in which if the holders of a certain number of Preferred Units elect to convert the Preferred Units that they hold to common units, we could then force all remaining outstanding Preferred Units to convert to common units. Ergon, the owner of our General Partner, owns enough Preferred Units such that if they were all converted to common units, we would be able to exercise this mandatory conversion right. In addition, we also have the right to force the conversion of the outstanding Preferred Units at any time if (i) the daily volume-weighted average trading price of our common units is greater than $8.45 for 20 out of the trailing 30 trading days ending two trading days before we furnish notice of conversion and (ii) the average trading volume of our common units has exceeded 20,000 common units for 20 out of the trailing 30 trading days ending two trading days before we furnish notice of conversion. In addition, the conversion provisions may be modified with the consent of a majority of the outstanding Preferred Units. As of March 1, 2022, Ergon owned 60.5% of our outstanding Preferred Units and has the ability to consent to amendments to such conversion provisions. As a result, our preferred unitholders may be required to convert their Preferred Units at an undesirable time and may not receive their expected return on investment.

Ergon, as the holder of a majority of the outstanding Preferred Units, has the ability to consent to the amendments to the provisions of the Preferred Units.

The Preferred Units have voting rights that are identical to the voting rights of common units and vote with the common units as a single class, so that each Preferred Unit is entitled to one vote for each common unit into which such Preferred Unit is convertible on each matter with respect to which each common unit is entitled to vote. In addition, the approval of a majority of the Preferred Units, voting separately as a class, is necessary on any matter that adversely affects any of the rights of the Preferred Units or amends or modifies the terms of the Preferred Units in any material respect or affects the holders of the Preferred Units disproportionately in relation to the holders of common units, including, without limitation, any action that would (i) reduce the distribution amount to the Preferred Units or change the time or form of payment of distributions, (ii) reduce the amount payable to the Preferred Units upon the liquidation of our partnership, (iii) modify the conditions relating to the conversion of the Preferred Units or (iv) issue any equity security that, with respect to distributions or rights upon liquidation, ranks equal to or senior to the Preferred Units or issue any additional Preferred Units. As of March 1, 2022, Ergon owned 60.5% of our outstanding Preferred Units and has the ability to consent to amendments to the terms of the Preferred Units without the consent of other unitholders.

Holders of the Preferred Units will not have rights to distributions as holders of common units until they acquire our common units.

Until our preferred unitholders acquire common units upon conversion of the Preferred Units, such preferred unitholders will have no rights with respect to distributions on our common units. Upon conversion, our preferred unitholders will be entitled to exercise the rights of a holder of our common units only as to matters for which the record date occurs after the date on which such Preferred Units were converted to our common units.

The Preferred Units are limited partner interests in our partnership and therefore are subordinate to any indebtedness.

The Preferred Units are limited partner interests in our partnership and do not constitute indebtedness. As such, the Preferred Units will rank junior to all indebtedness and other non-equity claims on our partnership with respect to assets available to satisfy claims on our partnership, including in a liquidation of our partnership. 

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Market interest rates may affect the value of our units.

One of the factors that will influence the price of our units will be the distribution yield on our units relative to market interest rates. An increase in market interest rates could cause the market price of the units to go down. The trading price of the units will also depend on many other factors, which may change from time to time, including:

• the market for similar securities;

• government action or regulation;

• general economic conditions or conditions in the financial markets; and

• our financial condition, performance and prospects.

Our unitholders’ liability may not be limited if a court finds that unitholder action constitutes control of our business.

A general partner of a partnership generally has unlimited liability for the obligations of the partnership, except for those contractual obligations of the partnership that are expressly made without recourse to the general partner. Our partnership is organized under Delaware law, and we conduct business in a number of other states. The limitations on the liability of holders of limited partner interests for the obligations of a limited partnership have not been clearly established in some of the other states in which we do business.

Our unitholders could be liable for our obligations as if they were a general partner if:

• a court or government agency determined that we were conducting business in a state but had not complied with that particular state’s partnership statute; or

• a unitholder’s right to act with other unitholders to remove or replace the general partner, to approve some amendments to our partnership agreement or to take other actions under our partnership agreement constitute “control” of our 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 Section 17-607 and 17-804 of the Delaware Revised Uniform Limited Partnership Act, we may not make a distribution to our unitholders if the distribution would cause our liabilities to exceed the fair value of our assets. Delaware law provides that for a period of three years from the date of the 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 distribution amount. Substituted limited partners are liable for the obligations of the assignor to make contributions to the partnership that are known to the substituted limited partner at the time it became a limited partner and for unknown obligations if the liabilities could be determined from the partnership agreement. Liabilities to partners on account of their partnership interests and liabilities that are non-recourse to the partnership are not counted for purposes of determining whether a distribution is permitted.

Tax Risks to Unitholders

Our tax treatment depends on our status as a partnership for federal income tax purposes, as well as us not being subject to a material amount of entity-level taxation by individual states. If the IRS were to treat us as a corporation, or if we were to otherwise become subject to a material amount of entity-level taxation (either for federal, state, or local tax purposes), then our cash available for distribution to our unitholders would be substantially reduced.

The anticipated after-tax economic benefit of an investment in our common units depends largely on us being treated as a partnership for federal income tax purposes. If less than 90% of the gross income of a publicly traded partnership, such as us, for any taxable year is “qualifying income” as defined under Section 7704(d) of the Internal Revenue Code, that partnership will be treated as a corporation for federal income tax purposes for that taxable year and all subsequent years. We have not requested and do not plan to request a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes.

If we were treated as a corporation for federal income tax purposes, then we would pay federal income tax on our taxable income at the corporate tax rate, which is currently a maximum of 21%, and would likely pay additional state income tax at varying rates. Distributions would generally be taxed again to unitholders as corporate distributions and none of our income, gains, losses, deductions or credits would flow through to our unitholders. Because a tax would be imposed upon us as a corporation, cash available for distribution to our unitholders would be substantially reduced. Therefore, treatment of us as a corporation would result in a material reduction in the anticipated cash flows and after-tax return to unitholders and thus would likely result in a substantial reduction in the value of our units.

In addition, changes in law may subject us to more entity-level taxation than the amount of entity-level taxation to which we are currently subject. Imposition of such a tax on us may reduce the cash available for distribution to our unitholders.

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Our partnership agreement provides that if a law is enacted or an existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal, state or local income tax purposes, the minimum quarterly distribution amount and the target distribution amounts will be adjusted to reflect the impact of that law on us. No such adjustments have been made to date, but there can be no assurance that no such adjustments will be made in the future.

The tax treatment of publicly traded partnerships or an investment in our units could be subject to potential legislative, judicial or administrative changes and differing interpretations, possibly on a retroactive basis.

The present federal income tax treatment of publicly traded partnerships, including us or an investment in our units, may be modified by administrative, legislative or judicial interpretation at any time. Any modification to the federal income tax laws and interpretations thereof may or may not be applied retroactively. Moreover, any such modification could make it more difficult or impossible for us to meet the exception which allows a publicly traded partnership that generates qualifying income to be treated as a partnership (rather than a corporation) for U.S. federal income tax purposes, could affect or cause us to change our business activities, and could affect the tax consequences of an investment in our units. From time to time, members of Congress have proposed and considered substantive changes to existing federal income tax laws that would affect the tax treatment of certain publicly traded partnerships. We are unable to predict whether any of these changes or other proposals will ultimately be enacted. Any such changes could materially and negatively impact the value of an investment in our units.

Our unitholders have been and will be required to pay taxes on their share of our taxable income even if they have not received or do not receive any cash distributions from us.

Because our unitholders are treated as partners to whom we allocate taxable income which could be different in amount than the cash we distribute, our unitholders will be required to pay any federal income taxes and, in some cases, state and local income taxes, on their share of our taxable income, even if our unitholders receive no cash distributions from us. A unitholder may not receive cash distributions from us equal to their share of our taxable income or even equal to the tax liability that results from that income. 

If the IRS contests any of the federal income tax positions we take, the market for our units may be adversely affected, and the costs of any such contest will reduce our cash available for distribution to our unitholders.

We have not requested a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes or any other matter affecting us. The IRS may adopt positions that differ from the conclusions of our counsel or from the positions we take. It may be necessary to resort to administrative or court proceedings to sustain some or all of our counsel’s conclusions or the positions we take. A court may not agree with some or all of our counsel’s conclusions or the positions we take. Any contest with the IRS may materially and adversely impact the market for our units and the price at which they trade. In addition, the costs of any contest with the IRS will be borne indirectly by our unitholders and our General Partner because the costs will reduce our cash available for distribution. 

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Unitholders may be subject to limitation on their ability to deduct interest expense incurred by us.

Our ability to deduct interest on indebtedness properly allocable to our trade or business is limited to an amount equal to the sum of our business interest income and a certain percentage of our adjusted taxable income for such taxable year. For purposes of this limitation, our adjusted taxable income is computed without regard to any business interest income or business interest expense, and in the case of taxable years beginning before January 1, 2022, any deduction allowable for depreciation, amortization or depletion to the extent such depreciation, amortization or depletion is not capitalized into the cost of goods sold with respect to inventory, among other items. If our business interest expense is limited under these rules, our unitholders will be limited in their ability to deduct their share of any business interest expense that has been allocated to them.

Tax gain or loss on the disposition of our units could be more or less than expected.

If our unitholders sell their units, they will recognize a gain or loss equal to the difference between the amount realized and their tax basis in those units. Because, in general, aggregate distributions to a unitholder that exceed the total net taxable income allocated to the unitholder decrease the unitholder’s tax basis in his or her units, any such prior excess distribution will, in effect, become taxable income to the unitholder if the units are sold by the unitholder at a price greater than their tax basis, even if the price the unitholder receives is less than the original cost. Furthermore, a substantial portion of the amount realized, whether or not representing gain, may be taxed as ordinary income to the selling unitholder due to potential recapture items, including depreciation recapture. In addition, because the amount realized includes a unitholder’s share of our non-recourse liabilities, a unitholder that sells common units may, under certain circumstances, incur a tax liability in excess of the amount of cash received from the sale.

If the IRS makes audit adjustments to our income tax returns for tax years beginning after 2017, it may collect any resulting taxes (including any applicable penalties and interest) directly from us, in which case our cash available for distribution to our unitholders might be substantially reduced.

If the IRS makes audit adjustments to income tax returns for tax years beginning after 2017, it may assess and collect taxes (including any applicable penalties and interest) directly from us in the year in which the audit is completed. If we are required to make payments of taxes, penalties and interest resulting from audit adjustments, our cash available for distribution to our unitholders might be substantially reduced. In addition, because payment would be due for the taxable year in which the audit is completed, unitholders during that taxable year would bear the expense of the adjustment even if they were not unitholders during the audited taxable year.

Tax-exempt entities and non-United States persons face unique tax issues from owning units that may result in adverse tax consequences to them.

Investment in our units by tax-exempt entities, such as individual retirement accounts (known as IRAs), pension plans and non-U.S. persons raises issues unique to them. For example, virtually all of our income allocated to organizations exempt from federal income tax, including individual retirement accounts and other retirement plans, will be unrelated business taxable income and will be taxable to them. Distributions to non-U.S. persons will be reduced by applicable withholding taxes, and non-U.S. persons will be required to file U.S. federal income tax returns and pay tax on their share of our taxable income. Moreover, withholding could be required in respect of a disposition of our units by a non-U.S. person. If a potential unitholder is a tax-exempt entity or a non-U.S. person, it should consult its tax advisors before investing in our units.

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We will treat each purchaser of our common units as having the same tax benefits without regard to the specific common units purchased. The IRS may challenge this treatment, which could adversely affect the value of the common units.

Because we cannot match transferors and transferees of common units and because of other reasons, we will adopt depreciation and/or amortization positions that may not conform with all aspects of existing Treasury regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to our unitholders. It also could affect the timing of these tax benefits or the amount of gain from their sale of common units and could have a negative impact on the value of our common units or result in audit adjustments to our unitholders’ tax returns.

Our unitholders likely will be subject to state and local taxes and return filing or withholding requirements in states in which they do not live as a result of investing in our units.

In addition to federal income taxes, our unitholders will likely be subject to other taxes, such as state and local income taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we conduct business or own property. Our unitholders may be required to file state and local income tax returns and pay state and local income taxes in certain of these various jurisdictions. Further, our unitholders may be subject to penalties for failure to comply with those requirements. We currently own property and conduct business in several states, most of which currently impose income taxes on corporations, and many of which impose income taxes on other entities and nonresident individuals. We may own property or conduct business in other states or foreign countries in the future. It is each unitholder’s responsibility to file all federal, state, local and foreign tax returns.

We hold certain assets located at certain of our liquid asphalt facilities in a subsidiary taxed as a corporation. Such subsidiary is subject to entity-level federal and state income taxes on its net taxable income and, if a material amount of entity-level taxes were incurred, then our cash available for distribution to our unitholders could be substantially reduced.

We hold certain of our liquid asphalt processing assets and related fee income through BKEP Asphalt, L.L.C., a subsidiary taxed as a corporation. Such subsidiary is required to pay federal income tax on its income at the corporate tax rate, which is currently a maximum of 21%, and will likely pay state (and possibly local) income tax at varying rates. We may elect to conduct additional operations in corporate form in the future. If a material amount of corporate-level taxes is incurred by such a subsidiary, then our cash available for distribution to our unitholders could be substantially reduced.

We prorate our items of income, gain, loss and deduction between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among our unitholders.

We prorate our items of income, gain, loss and deduction between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The use of this proration method may not be permitted under existing Treasury regulations. Under applicable regulatory guidance, a publicly traded partnership may use a similar monthly simplifying convention to allocate tax items among transferor and transferee unitholders, although such tax items must be prorated on a daily basis. However, this regulatory guidance does not specifically authorize the use of the proration method we have adopted. If the IRS were to successfully challenge our proration method, we may be required to change the allocation of items of income, gain, loss and deduction among our unitholders. 

A unitholder whose units are loaned to a “short seller” to effect a short sale of units may be considered as having disposed of those units. If so, such unitholder would no longer be treated for tax purposes as a partner with respect to those units during the period of the loan and may recognize gain or loss from the disposition.

Because a unitholder whose units are loaned to a “short seller” to effect a short sale of units may be considered as having disposed of the loaned units, such unitholder may no longer be treated for tax purposes as a partner with respect to those units during the period of the loan to the short seller and the unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan to the short seller, any of our income, gain, loss or deduction with respect to those units may not be reportable by the unitholder, and any cash distributions received by the unitholder as to those units could be fully taxable as ordinary income. Each unitholder desiring to assure their status as a partner and avoid the risk of gain recognition from a loan to a short seller is urged to consult a tax advisor to discuss whether it is advisable to modify any applicable brokerage account agreements to prohibit such unitholder's brokers from borrowing, or lending, their units.

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Unitholders converting Preferred Units into common units could under certain limited circumstances receive a gross income allocation that may materially increase the taxable income allocated to such unitholders.

Under our partnership agreement and in accordance with Treasury regulations, immediately after the conversion of a Preferred Unit, we will adjust the capital accounts of all of our partners to reflect any positive difference (“Unrealized Gain”) or negative difference (“Unrealized Loss”) between the fair market value and the carrying value of our assets at such time as if such Unrealized Gain or Unrealized Loss had been recognized on an actual sale of each such asset for an amount equal to its fair market value at the time of such conversion. Such Unrealized Gain or Unrealized Loss (or items thereof) will be allocated first to the converting preferred unitholder in respect to common units received upon the conversion until the capital account of each such common unit is equal to the per unit capital account for each existing common unit. This allocation of Unrealized Gain or Unrealized Loss will not be taxable to the converting preferred unitholder or to any other unitholders. If the Unrealized Gain or Unrealized Loss allocated as a result of the conversion of a Preferred Unit is not sufficient to cause the capital account of each common unit received upon such conversion to equal the per unit capital account for each existing common unit, then capital account balances will be reallocated among the unitholders as needed to produce this result. In the event that such a reallocation occurs, a converting preferred unitholder would be allocated taxable gross income in an amount equal to the amount of any such reallocation to it.

We may adopt certain valuation methodologies and monthly conventions for federal income tax purposes that may result in a shift of income, gain, loss or deduction between our General Partner and our common unitholders. The IRS may challenge this treatment, which could adversely affect the value of our outstanding units.

When we issue additional units or engage in certain other transactions, we will determine the fair market value of our assets and allocate any unrealized gain or loss attributable to our assets to the capital accounts of our common unitholders and our General Partner. Our methodology may be viewed as understating the value of our assets. In that case, there may be a shift of income, gain, loss or deduction between certain common unitholders and our General Partner, which may be unfavorable to such unitholders. Moreover, under our valuation methods, subsequent purchasers of units may have a greater portion of their Internal Revenue Code Section 743(b) adjustment allocated to our tangible assets and a lesser portion allocated to our intangible assets. The IRS may challenge our valuation methods, or our allocation of the Section 743(b) adjustment attributable to our tangible and intangible assets, and allocations of taxable income, gain, loss or deduction between our General Partner and certain of our common unitholders.

A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to our common unitholders. It also could affect the amount of taxable gain from our unitholders’ sale of units and could have a negative impact on the value of the units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions.

Compliance with and changes in tax law could adversely affect our performance.

We are subject to extensive tax laws and regulations, including federal and state income taxes and transactional taxes such as excise, sales/use, payroll, franchise and ad valorem taxes. New tax laws and regulations and changes in existing tax laws and regulations are continuously being enacted that could result in increased tax expenditures in the future. Many of these tax liabilities are subject to audits by the respective taxing authority. These audits may result in additional taxes as well as interest and penalties.

Item 1B. Unresolved Staff Comments.

None.

Item 2. Properties.

A description of our properties is contained in “Item 1-Business.”

Title to Properties

Our asphalt assets are on real property owned or leased by us. Some of the real property leases that were transferred to us as part of the acquisition of our asphalt assets required the consent of the counterparty to such lease. In certain instances, we have not entered into new leases with a lessor although we continue to use such leases and make payments to the lessor and are in the process of negotiating new leases.

Other than as described above, we believe that we have satisfactory title to or rights in all of our assets. Although title or rights to such properties is subject to encumbrances in certain cases, such as customary interests generally retained in connection with acquisition of real property, liens related to environmental liabilities associated with historical operations, liens for current taxes and other burdens and minor easements, restrictions and other encumbrances to which the underlying properties were subject at the time of acquisition by our predecessor or us, we believe that none of these burdens will materially interfere with their use in the operation of our business.

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Item 3. Legal Proceedings.

The information required by this item is included under the caption “Commitments and Contingencies” in Note 15 to our consolidated financial statements and is incorporated herein by reference thereto.

Item 4. Mine Safety Disclosures.

Not applicable.

PART II. OTHER INFORMATION

Item 5.  Market for Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities.

Our common units are traded on the Nasdaq Global Market under the symbol “BKEP” and our Preferred Units are traded on the Nasdaq Global Market under the symbol “BKEPP”.

On March 1, 2022, there were 41,856,847 common units outstanding, held by approximately 663 unitholders of record and 34,406,683 Preferred Units outstanding held by approximately 2 unitholders of record. The actual number of unitholders is greater than the number of holders of record as it does not include unitholders whose units are held in trust by other entities. Ergon holds 6.7% of the common units and 60.5% of the Preferred Units.

Distributions of Available Cash

Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash (as defined in our partnership agreement) to unitholders of record on the applicable record date.

Available cash, for any quarter, consists of all cash on hand at the end of that quarter:

• less the amount of cash reserves established by our General Partner to:

◦ provide for the proper conduct of our business;

◦ comply with applicable law, any of our debt instruments or other agreements; or

◦ provide funds for distributions to our unitholders for any one or more of the next four quarters;

• plus all additional cash and cash equivalents on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter. Working capital borrowings are generally borrowings that are made under a credit facility, commercial paper facility or similar financing arrangement, and in all cases are used solely for working capital purposes or to pay distributions to partners and with the intent of the borrower to repay such borrowings within 12 months.

Pursuant to our credit agreement, we are permitted to make quarterly distributions of available cash to unitholders so long as no default exists under the credit agreement on a pro forma basis after giving effect to such distribution.

Our partnership agreement requires that we make distributions of available cash from operating surplus for any quarter in the following manner:

• first, 98.4% to the holders of Preferred Units, pro rata, and 1.6% to our General Partner, until we distribute for each outstanding Preferred Unit an amount equal to the Series A quarterly distribution amount discussed below;

• second, 98.4% to the holders of Preferred Units, pro rata, and 1.6% to our General Partner, until we distribute for each outstanding Preferred Unit an amount equal to any arrearages in the payment of the Series A quarterly distribution amount for any prior quarters;

• third, 98.4% to all common unitholders and Class B unitholders (if any), pro rata, and 1.6% to our General Partner, until we distribute for each outstanding common and Class B unit an amount equal to the minimum quarterly distribution of $0.11 per unit for that quarter; and

• thereafter, in the manner described in “General Partner Interest and Incentive Distribution Rights” below.

The Preferred Units are convertible at the holders’ option into common units. Holders of the Preferred Units are entitled to quarterly distributions of $0.17875 per unit per quarter. If the Partnership fails to pay in full any distribution on the Preferred Units, the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full. The preceding discussion is based on the assumptions that our General Partner maintains its 1.6% general partner interest and that we do not issue additional classes of equity securities. 

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General Partner Interest and Incentive Distribution Rights

The following discussion assumes that our General Partner maintains its approximate 1.6% general partner’s interest and continues to own the incentive distribution rights.

Our partnership agreement provides that our General Partner will be entitled to approximately 1.6% of all distributions that we make prior to our liquidation. Our General Partner has the right, but not the obligation, to contribute a proportionate amount of capital to us to maintain its approximate 1.6% general partner interest if we issue additional units. Our General Partner’s approximate 1.6% interest, and the percentage of our cash distributions to which it is entitled, will be proportionately reduced if we issue additional units in the future (other than the issuance of partnership securities issued in connection with a reset of the incentive distribution target levels relating to our General Partner’s incentive distribution rights or the issuance of partnership securities upon conversion of outstanding partnership securities) and our General Partner does not contribute a proportionate amount of capital to us in order to maintain its then current general partner interest. Our General Partner will be entitled to make a capital contribution in order to maintain its then current general partner interest.

Incentive distribution rights represent the right to receive an increasing percentage (13.0%, 23.0% and 48.0%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels have been achieved. Our General Partner currently holds the incentive distribution rights but may transfer these rights separately from its general partner interest, subject to restrictions in the partnership agreement.

If for any quarter:

• we have distributed available cash from operating surplus to the holders of our Preferred Units in an amount equal to the Series A Quarterly Distribution Amount;

• we have distributed available cash from operating surplus to the holders of our Preferred Units in an amount necessary to eliminate any cumulative arrearages in the payment of the Series A Quarterly Distribution Amount; and

• we have distributed available cash from operating surplus to the common unitholders and Class B unitholders in an amount equal to the minimum quarterly distribution;

then our partnership agreement requires that we distribute any additional available cash from operating surplus for that quarter among the unitholders and our General Partner in the following manner:

• first, 98.4% to all unitholders holding common units or Class B units, pro rata, and 1.6% to our General Partner, until each unitholder receives a total of $0.1265 per unit for that quarter (the “first target distribution”);

• second, 85.4% to all unitholders holding common units or Class B units, pro rata, and 14.6% to our General Partner, until each unitholder receives a total of $0.1375 per unit for that quarter (the “second target distribution”);

• third, 75.4% to all unitholders holding common units or Class B units, pro rata, and 24.6% to our General Partner, until each unitholder receives a total of $0.1825 per unit for that quarter (the “third target distribution”); and

• thereafter, 50.4% to all unitholders holding common units or Class B units, pro rata, and 49.6% to our General Partner.

For equity compensation plan information, see “Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters-Securities Authorized for Issuance under Equity Compensation Plans.”

Unregistered Sales of Securities

None.

Item 6. Reserved.

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Overview

We are a publicly traded master limited partnership with operations in 26 states. We have the largest independent asphalt facility footprint in the nation, and through that we provide integrated terminalling services for companies engaged in the production and marketing of liquid asphalt. We manage our operations through a single operating segment, asphalt terminalling services.

We previously provided integrated terminalling, gathering, and transportation services for companies engaged in the production, distribution, and marketing of crude oil in three different operating segments: (i) crude oil terminalling services, (ii) crude oil pipeline services, and (iii) crude oil trucking services. On December 21, 2020, we announced we had entered into multiple definitive agreements to sell these segments. The transactions closed in February and March 2021, and these segments are presented as discontinued operations.

Our 54 asphalt facilities are well-positioned to provide asphalt terminalling services in the market areas they serve throughout the continental United States. With our approximately 9.0 million barrels of total liquid asphalt storage capacity, we are able to provide our customers the ability to effectively manage their liquid asphalt inventories while allowing significant flexibility in their processing and marketing activities. Our asphalt terminalling business delivers a stable cash flow profile underpinned by long-term take-or-pay contracts that generally have original terms of 5 to 10 years with options to extend the term. The stability comes from the contract structure that is comprised primarily of fixed fees and cost reimbursements, which make up approximately 95% of our revenues. The remaining revenue is variable, primarily consisting of volume-based throughput fees.

We have agreements for all our 54 asphalt terminalling facilities throughout the 26 states. We lease certain facilities for operation by our customers and at the remaining facilities we store, process, blend, and manufacture products, among other things, to meet our customers’ specifications. The agreements have, based on a weighted average by remaining fixed revenue, approximately 5.3 years remaining under their terms as of March 1, 2022. Approximately 13% of our tank capacity will expire at the end of 2022 if not renewed with the current customer or a new customer, and the remaining capacity expires at varying times thereafter, through 2035. Our varying contract expiration dates provide for staggered renewals, which provides additional stability to the cash flow. 

Potential Impact of Certain Factors on Future Revenues

Due to the high percentage of fixed and reimbursement revenue from our long-term contracts, our focus and our primary risk is renewing contracts at favorable terms. Our ability to renew agreements on favorable terms, or at all, could be impacted if our customers experience negative market conditions. These factors include infrastructure spending, the strength of state and local economies, and the level of allocations of tax funding to transportation spending from state or federal funds. Public transportation infrastructure projects historically have been a relatively stable portion of state and federal budgets and represent a significant share of the United States construction market. Federal funds are allocated on a state-by-state basis, and each state is required to match a portion of the federal funds that it receives. Currently, from a macroeconomic view, there are positive indicators for the infrastructure and construction sector, such as the federal infrastructure spending bill that was passed in November 2021, low interest rates, and a recovering economy. However, due to COVID-19, as discussed below, some uncertainty exists.

Due to the global pandemic related to COVID-19, the economy experienced a significant downturn during part of 2020. Despite this economic volatility, our cash flows remained stable and are expected to remain stable moving forward. While our customers may be impacted by the economic volatility, they are primarily high-quality counterparties, with over 50% of our revenues earned from those that are investment-grade quality, which minimizes our counterparty credit risk. We do not expect any supply chain disruptions from COVID-19 to affect our customers. While we are unaware of any potential negative impact of COVID-19 on our business at this time, we are continuing to monitor the situation and have prepared our employees to take precautions and planning for unexpected events, which may include disruptions to our workforce, customers, vendors, facilities and communities in which we operate.

Infrastructure spending is currently a focus at the federal, state, and local levels. The federal infrastructure spending bill (the Infrastructure Investment and Jobs Act) that was passed in November 2021, subject to final appropriations, provides long-term funding and support for road construction and repair. Increased funding potentially impacts us through favorable customer contract renewals, including facility expansion opportunities, as well as increased customer volumes through our terminals. Separate from these funds, COVID relief funds remain available and could have a positive impact on the allocation of state and local spending. Further, there has been an increase in state and local initiatives to support infrastructure funding, and a high percentage of those initiatives have been approved by voters. 

Another factor impacting us and our customers, from a short-term perspective, is weather patterns. Our customers’ volumes could be significantly impacted by prolonged rain or snow seasons or any severe weather that occurs. Damage to our terminal facilities from severe weather, such as flooding or hurricanes, could impact our operating results through additional costs and/or loss of revenue.

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Ergon Agreements

Twenty-eight of our asphalt facilities are contracted to Ergon under multiple agreements. Service revenues under these agreements are primarily based on contracted monthly fees under the applicable agreement at rates, which we believe are fair and reasonable to us and our unitholders and are comparable with the rates we charge third parties. Agreements for six of the facilities expire in late 2025, and agreements for the remaining 22 facilities expire on December 31, 2027. We may not be able to extend, renegotiate or replace these contracts when they expire, and the terms of any renegotiated contracts may not be as favorable as the contracts they replace. The Board’s conflicts committee reviewed and approved these agreements in accordance with our procedures for approval of related-party transactions and the provisions of the partnership agreement. For the years ended December 31, 2020 and 2021, we recognized revenues of $44.4 million and $49.6 million, respectively, for services provided to Ergon under these agreements.

Ergon Buyout Offer

On October 8, 2021, Ergon filed an amendment to its Schedule 13D with the SEC disclosing that Ergon made a non-binding proposal to the Board, pursuant to which Ergon would acquire all the outstanding common units and Preferred Units of the Partnership not already owned by Ergon and its affiliates in exchange for $3.32 per common unit and $8.46 per Preferred Unit. The transaction, as proposed, is subject to a number of contingencies, including the approval of the conflicts committee of the Board, the approval by the Partnership's unitholders and the satisfaction of any conditions to the consummation of a transaction set forth in any definitive agreement concerning the transaction. There can be no assurance that a definitive agreement will be executed or that any transaction will materialize.

Results of Operations

Non-GAAP Financial Measures

To supplement our financial information presented in accordance with GAAP, management uses additional measures that are known as “non-GAAP financial measures” in its evaluation of past performance and prospects for the future. The primary measure used by management is operating margin excluding depreciation and amortization.

Management believes that the presentation of this additional financial measure provides useful information to investors regarding our performance and results of operations because this measure, when used in conjunction with related GAAP financial measures, (i) provides additional information about our core operating performance and ability to generate and distribute cash flow; (ii) provides investors with the financial analytical framework upon which management bases financial, operational, compensation and planning decisions; and (iii) presents measurements that investors, rating agencies and debt holders have indicated are useful in assessing us and our results of operations. This additional financial measure is reconciled to the most directly comparable measures as reported in accordance with GAAP, and should be viewed in addition to, and not in lieu of, our consolidated financial statements and footnotes.

The table below summarizes our financial results for the years ended December 31, 2020 and 2021, and presents a reconciliation of our non-GAAP financial measure reconciled to the most directly comparable GAAP measure: 

Operating Results	Year ended December 31,						Favorable/(Unfavorable)
(dollars in thousands)	2020			2021			$			%
Fixed fee revenue	$	91,879		$	97,603		$	5,724			6	%
Variable cost recovery revenue		12,664			12,066			(598	)		(5	)%
Variable throughput and other revenue		5,702			5,748			46			1	%
Total revenue		110,245			115,417			5,172			5	%
Operating expenses, excluding depreciation and amortization		(49,396	)		(52,312	)		(2,916	)		(6	)%
Total operating margin		60,849			63,105			2,256			4	%
Depreciation and amortization		13,416			11,891			1,525			11	%
General and administrative expense		14,182			13,902			280			2	%
Loss on disposal of assets		67			195			(128	)		(191	)%
Operating income		33,184			37,117			3,933			12	%
Other income (expenses):
Other income		1,169			2,615			1,446			124	%
Interest expense		(5,665	)		(4,944	)		721			13	%
Provision for income taxes		7			(30	)		(37	)		(529	)%
Income from continuing operations		28,695			34,758			6,063			21	%
Gain (loss) from discontinued operations, net		(42,175	)		75,772			117,947			280	%
Net income (loss)	$	(13,480	)	$	110,530			124,010			920	%

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Revenues. Total revenues increased to $115.4 million for 2021 as compared to $110.2 million for 2020. Revenues consist primarily of fixed fees for items such as storage and minimum throughput requirements, with consideration of annual consumer price index (“CPI”) adjustments built into our agreements. In addition to CPI escalations, the increase in fixed fee revenue is primarily due to certain contracts that changed from a lease arrangement to an operating arrangement. Variable cost recovery revenue is driven by certain reimbursable operating expenses, such as utility costs, and therefore have no net impact on operating margin or net income. Variable throughput revenue is primarily driven by our customers’ excess volumes over annual minimum thresholds, which was comparable in 2021 to 2020. 

Operating expenses, excluding depreciation and amortization. Operating expense, excluding depreciation and amortization increased by 6%, or $2.9 million, for 2021 as compared to 2020. Significant factors contributing to this change include certain contracts that changed from a lease arrangement to an operating arrangement and higher utility costs from rising prices, which are recoverable costs from our customers.

Depreciation and amortization. Depreciation and amortization decreased to $11.9 million for 2021 as compared to $13.4 million for 2020. The decrease is primarily the result of certain assets reaching the end of their depreciable lives.

General and administrative expense. General and administrative expense decreased to $13.9 million for the year ended December 31, 2021, as compared to $14.2 million for 2020. The decrease from 2020 to 2021 is primarily due to separation costs incurred in the second quarter of 2020 related to the resignation of the former Chief Executive Officer of our general partner and lower compensation costs in 2021 due to reductions in corporate overhead, partially offset by severance paid in the first quarter of 2021 related to the crude oil business divestitures and $0.7 million in non-recurring legal and professional fees related to the Ergon buyout offer.

Other income. Other income for the years ended December 31, 2020 and 2021, primarily related to insurance claim recoveries related to damages incurred in 2019 and 2020 at certain asphalt facilities.

Income (loss) from discontinued operations. Income from discontinued operations represents the results of our former crude oil trucking, pipeline, and terminalling services segments that were sold in February and March of 2021. The year ended December 31, 2020, included $39.1 million of losses on disposal and classification as held for sale the crude oil trucking and pipeline services segments based on the net book value of the assets compared to expected net proceeds under the sale agreements. The year ended December 31, 2021, included a $73.5 million gain on the sale of the crude oil terminalling services segment.

Interest expense. Interest expense was $4.9 million for 2021 compared to $5.7 million for 2020. Interest expense represents interest on borrowings under our credit agreement, as well as amortization of debt issuance costs. The following table presents the significant components of interest expense (dollars in thousands):

	Year ended December 31,				Favorable/(Unfavorable)
	2020		2021		$			%
Credit agreement interest	$	4,611	$	3,350	$	1,261			27	%
Amortization of debt issuance costs		1,004		856		148			15	%
Write-off of debt issuance costs		-		730		(730	)		N/A
Other		50		8		42			84	%
Total interest expense	$	5,665	$	4,944	$	721			13	%

The decrease in credit agreement interest was primarily driven by lower floating eurodollar rates, lower average borrowings outstanding during the period, and favorable changes to the applicable margin based on an improved leverage ratio. 

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Income Taxes

As part of the process of preparing the consolidated financial statements, we are required to estimate the federal and state income taxes in each of the jurisdictions in which our subsidiary that is taxed as a corporation operates. This process involves estimating the actual current tax exposure together with assessing temporary differences resulting from differing treatment of items, such as depreciation, for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in our consolidated balance sheets. We must then assess, using all available positive and negative evidence, the likelihood that the deferred tax assets will be recovered from future taxable income. If we believe that recovery is not likely, we must establish a valuation allowance. To the extent we establish a valuation allowance or increase or decrease this allowance in a period, we must include an expense or reduction of expense within the tax provisions in the consolidated statements of operations.

Under ASC 740 – Accounting for Income Taxes, an enterprise must use judgment in considering the relative impact of negative and positive evidence. The weight given to the potential effect of negative and positive evidence should be commensurate with the extent to which it can be objectively verified. The more negative evidence that exists (a) the more positive evidence is necessary and (b) the more difficult it is to support a conclusion that a valuation allowance is not needed for some portion, or all of the deferred tax asset. Among the more significant types of evidence that we consider are:

• taxable income projections in future years;

• future revenue and operating cost projections that will produce more than enough taxable income to realize the deferred tax asset based on existing service rates and cost structures; and

• our earnings history exclusive of the loss that created the future deductible amount coupled with evidence indicating that the loss is an aberration rather than a continuing condition.

Based on the consideration of the above factors for our subsidiary that is taxed as a corporation for purposes of determining the likelihood of realizing the benefits of the deferred tax assets, we have provided a full valuation allowance against our deferred tax asset as of December 31, 2021.

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Liquidity and Capital Resources

Cash Flows and Capital Expenditures

The following table summarizes our sources and uses of cash, including discontinued operations, for the years ended December 31, 2020 and 2021:

	Year ended December 31,
	2020			2021
	(in thousands)
Net cash provided by operating activities	$	61,167		$	49,329
Net cash provided by (used in) investing activities		(22,657	)		147,879
Net cash used in financing activities		(38,263	)		(196,841	)

Operating Activities. Net cash provided by operating activities was $49.3 million for the year ended December 31, 2021, as compared to $61.2 million for the year ended December 31, 2020. The decrease in cash provided by operating activities is primarily the result of the crude oil business sales at the beginning of 2021 and changes in working capital.

Investing Activities. Net cash provided by investing activities was $147.9 million for the year ended December 31, 2021, compared to net cash used in investing activities of $22.7 million for the year ended December 31, 2020. The year ended December 31, 2021, included net proceeds, primarily from the sale of the crude oil businesses, of $155.2 million, which excludes $1.4 million of funds held in escrow for right of way renewals. Capital expenditures for the year ended December 31, 2021, inclusive of both continuing and discontinued operations, included net maintenance capital expenditures of $6.4 million and net expansion capital expenditures of $1.9 million. In addition, we received $1.1 million of insurance proceeds during the year ended December 31, 2021, from claims related to property damage. Capital expenditures for the year ended December 31, 2020, inclusive of both continuing and discontinued operations, included net maintenance capital expenditures of $7.8 million and net expansion capital expenditures of $6.2 million. The year ended December 31, 2020, also included a $12.2 million payment to Ergon related to our purchase of Ergon’s DEVCO entity associated with Cimarron Express.

Financing Activities. Net cash used in financing activities of $196.8 million for the year ended December 31, 2021, included net payments under our credit agreement of $157.5 million, distributions to unitholders of $32.1 million, and the repurchase of Preferred Units of $5.4 million. Net cash used in financing activities was $38.3 million for the year ended December 31, 2020, and primarily comprised of net payments under our credit agreement of $3.0 million and distributions to unitholders of $32.4 million.

Liquidity and Capital Resources

Cash flows from operations and borrowings under our credit agreement are our primary sources of liquidity. Our ability to borrow funds under our credit agreement may be limited by financial covenants. At December 31, 2021, we had a working capital deficit of $12.1 million. This is primarily a function of our approach to cash management. At December 31, 2021, we had approximately $98.0 million of revolver borrowings and approximately $0.6 million of letters of credit outstanding under the credit agreement, leaving us with $201.4 million of availability under our revolving loan facility, subject to covenant restrictions, which limited our availability to $155.4 million. At March 1, 2022, we had approximately $110.0 million of revolver borrowings and approximately $0.6 million of letters of credit outstanding under the credit agreement, leaving us with $189.4 million of availability under our revolving loan facility. The Partnership’s ability to borrow such funds may be limited by the financial covenants in the credit agreement.

The Partnership has certain financial covenants associated with its credit agreement which include a maximum permitted consolidated total leverage ratio. The consolidated total leverage ratio is assessed quarterly based on the trailing twelve months of EBITDA, as defined in the credit agreement. The maximum permitted consolidated total leverage ratio as of December 31, 2021, and for every quarter thereafter, is 4.75 to 1.00. The Partnership’s consolidated total leverage ratio was 1.84 to 1.00 as of December 31, 2021.

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Capital Requirements. Our capital requirements consist of the following:

• maintenance capital expenditures, which are capital expenditures made to maintain the existing integrity and operating capacity of our assets and related cash flows further extending the useful lives of the assets; and

• expansion capital expenditures, which are capital expenditures made to expand or to replace partially or fully depreciated assets or to expand the operating capacity or revenue of existing or new assets, whether through construction, acquisition or modification.

The following table breaks out capital expenditures from continuing operations for the years ended December 31, 2020 and 2021 (in thousands):

	Year ended December 31,
	2020			2021
Acquisitions(1)	$	12,221		$	-
Expansion capital expenditures	$	723		$	1,992
Reimbursable expenditures		(289	)		(54	)
Net expansion capital expenditures	$	434		$	1,938
Gross Maintenance capital expenditures	$	8,260		$	6,301
Reimbursable expenditures		(2,084	)		(19	)
Net maintenance capital expenditures	$	6,176		$	6,282

(1) Relates to the purchase of Ergon’s interest in the Cimarron Express project. See Note 12 to our consolidated financial statements for additional information.

We currently expect our 2022 expansion capital expenditures to be approximately $15.0 million and our maintenance capital expenditures to be between $5.5 million and $6.5 million, each net of reimbursable expenditures. Our expansion capital expenditures will consist of organic growth projects and acquisitions, which includes expanding one of our current terminals and an acquisition that closed in January 2022 for an asphalt terminal and industrial park. Management is evaluating other expansion opportunities for 2022 and beyond that could increase this range of capital expenditures. These projects will have potential future expansion opportunities that are not currently part of our 2022 expansion capital forecast. Our sources of liquidity for expansion and maintenance capital expenditures in 2021 were a combination of cash flows from operations and borrowings under our credit agreement, and we expect to use the same sources in 2022.

Our Ability to Grow Depends on Our Ability to Access External Expansion Capital. Our partnership agreement requires that we distribute all of our available cash to our unitholders. Available cash is reduced by cash reserves established by our General Partner to provide for the proper conduct of our business (including for future capital expenditures) and to comply with the provisions of our credit agreement. We may not grow as quickly as businesses that reinvest their available cash to expand ongoing operations because we distribute all of our available cash.

Description of Credit Agreement. On May 26, 2021, we entered into an amended and restated credit agreement with a revolving loan facility of $300.0 million.

Our credit agreement is guaranteed by all of our existing subsidiaries. Obligations under our credit agreement are secured by first priority liens on substantially all of our assets and those of the guarantors.

Our credit agreement includes procedures for adding financial institutions as revolving lenders or for increasing the revolving commitment of any currently committed revolving lender, subject to the consent of the new or increasing lenders and an aggregate maximum of $450.0 million for all revolving loan commitments under our credit agreement.

The credit agreement will mature on May 26, 2025, and all amounts outstanding under our credit agreement shall become due and payable on such date. The credit agreement requires mandatory prepayments of amounts outstanding thereunder with the net proceeds from certain asset sales, property or casualty insurance claims and condemnation proceedings, unless we reinvest such proceeds in accordance with the credit agreement, but these mandatory prepayments will not require any reduction of the lenders’ commitments under the credit agreement.

Borrowings under our credit agreement bear interest, at our option, at either the reserve-adjusted eurodollar rate (as defined in the credit agreement) plus an applicable margin which ranges from 2.0% to 3.25% or the alternate base rate (the highest of the agent bank’s prime rate, the federal funds effective rate plus 0.5%, and the 30-day eurodollar rate plus 1.0%) plus an applicable margin which ranges from 1.0% to 2.25%. 

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We pay a per annum fee on all letters of credit issued under the credit agreement, which fee equals the applicable margin for loans accruing interest based on the eurodollar rate, and we pay a commitment fee ranging from 0.375% to 0.5% on the unused commitments under the credit agreement. The applicable margins for the interest rate, the letters of credit fee and the commitment fee vary quarterly based on our consolidated total leverage ratio (as defined in the credit agreement, being generally computed as the ratio of consolidated total debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges).

The credit agreement includes financial covenants which are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter.

Prior to the date on which we issue qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million, the maximum permitted consolidated total leverage ratio is 4.75 to 1.00 for the fiscal quarter ending December 31, 2021, and each fiscal quarter thereafter; provided that the maximum permitted consolidated total leverage ratio will be 5.25 to 1.00 for certain quarters based on the occurrence of a specified acquisition (as defined in the credit agreement, but generally being an acquisition for which the aggregate consideration is $15.0 million or more).

From and after the date on which we issue qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million, the maximum permitted consolidated total leverage ratio is 5.00 to 1.00; provided that from and after the fiscal quarter ending immediately preceding the fiscal quarter in which a specified acquisition occurs to and including the last day of the second full fiscal quarter following the fiscal quarter in which such acquisition occurred, the maximum permitted consolidated total leverage ratio is 5.50 to 1.00.

The maximum permitted consolidated senior secured leverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated total secured debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) is 3.50 to 1.00, but this covenant is only tested from and after the date on which we issue qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million.

The minimum permitted consolidated interest coverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges to consolidated interest expense) is 2.50 to 1.00.

In addition, the credit agreement contains various covenants that, among other restrictions, limit our ability to:

• create, issue, incur or assume indebtedness;

• create, incur or assume liens;

• engage in mergers or acquisitions;

• sell, transfer, assign or convey assets;

• repurchase the Partnership’s equity, make distributions to unitholders and make certain other restricted payments;

• make investments;

• modify the terms of certain indebtedness, or prepay certain indebtedness;

• engage in transactions with affiliates;

• enter into certain hedging contracts;

• enter into certain burdensome agreements;

• change the nature of the Partnership’s business; and

• make certain amendments to the Fourth Amended and Restated Agreement of Limited Partnership of the Partnership (the “Partnership’s partnership agreement”).

At December 31, 2021, our consolidated total leverage ratio was 1.84 to 1.00 and our consolidated interest coverage ratio was 15.79 to 1.00. We were in compliance with all covenants of our credit agreement as of December 31, 2021. Based on current operating plans and forecasts, the Partnership expects to remain in compliance with all covenants of the credit agreement for at least the next year.

The credit agreement permits us to make quarterly distributions of available cash (as defined in the partnership agreement) to unitholders so long as, on a pro forma basis after giving effect to such distributions, we are in compliance with its financial covenants under the credit agreement and no default or event of default exists under the credit agreement. Additionally, the credit agreement permits us to repurchase up to an aggregate of $40.0 million of its units (including Preferred Units), up to $10.0 million for each calendar year, so long as, on a pro forma basis after giving effect to such repurchases, the total leverage ratio is less than 4.00 to 1.00, no default or event of default exists under the credit agreement, and availability under the revolving credit facility is at least 20% of the total commitments thereunder.

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In addition to other customary events of default, the credit agreement includes an event of default if:

(i) our General Partner ceases to own 100% of our general partner interest or ceases to control us;

(ii) Ergon ceases to own and control 50.0% or more of the membership interests of our General Partner; or

(iii) during any period of 12 consecutive months, a majority of the members of the Board of our General Partner ceases to be composed of individuals:

(A) who were members of the Board on the first day of such period;

(B) whose election or nomination to the Board was approved by individuals referred to in clause (A) above constituting at the time of such election or nomination at least a majority of the Board; or

(C) whose election or nomination to the Board was approved by individuals referred to in clauses (A) and (B) above constituting at the time of such election or nomination at least a majority of the Board, provided that any changes to the composition of individuals serving as members of the Board approved by Ergon will not cause an event of default.

If an event of default relating to bankruptcy or other insolvency events occurs with respect to our General Partner or us, all indebtedness under our credit agreement will immediately become due and payable. If any other event of default exists under our credit agreement, the lenders may accelerate the maturity of the obligations outstanding under our credit agreement and exercise other rights and remedies. In addition, if any event of default exists under our credit agreement, the lenders may commence foreclosure or other actions against the collateral.

If any default occurs under our credit agreement, or if we are unable to make any of the representations and warranties in our credit agreement, we will be unable to borrow funds or have letters of credit issued under our credit agreement.

Critical Accounting Policies and Estimates

Our discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements. We prepared these consolidated financial statements in conformity with accounting principles generally accepted in the United States of America. As such, we are required to make certain estimates, judgments and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the periods presented. We based our estimates on historical experience, available information and various other assumptions we believe to be reasonable under the circumstances. On an ongoing basis, we evaluate our estimates; however, actual results may differ from these estimates under different assumptions or conditions. The accounting policies that we believe require our most difficult, subjective or complex judgments and are the most critical to our reporting of results of operations and financial position are as follows:

Use of Estimates. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts and disclosure of contingencies. Management makes significant estimates including: (1) estimated cash flows and fair values inherent in impairment tests; (2) the estimated fair value of financial instruments; and (3) liability and contingency accruals. Although management believes these estimates are reasonable, actual results could differ from these estimates.

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Impairment of Long-Lived Assets. Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written down to estimated fair value. Assets are tested for impairment when events or circumstances indicate that their carrying values may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount the carrying value exceeds the fair value of the asset is recognized. Fair value is generally determined from estimated discounted future net cash flows.

Goodwill. Goodwill represents the excess of the cost of acquisitions over the amounts assigned to assets acquired and liabilities assumed. Goodwill is not amortized but is tested annually for impairment and when events and circumstances warrant an interim evaluation. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired. Entities may elect to utilize a qualitative assessment to evaluate whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. Should the quantitative assessment be required, the valuation would generally be based on the estimated discounted future net cash flows of the reporting unit, utilizing discount rates and other factors in determining the fair value of the reporting unit. Management utilized the qualitative assessment in 2020 and 2021 and no impairment expense was recorded in either period.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

As a smaller reporting company, we are not required to provide the information required by Item 7A.

Item 8. Financial Statements and Supplementary Data.

Our consolidated financial statements, together with the reports of our independent registered public accounting firm, are set forth on pages F-1 through F-24 of this report and are incorporated herein by reference.

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.

None.

Item 9A. Controls and Procedures.

Evaluation of disclosure controls and procedures. Our General Partner’s management, including the Chief Executive Officer and Chief Financial Officer, the principal executive officer and principal financial officer, respectively, of our General Partner, evaluated as of the end of the period covered by this report, the effectiveness of our disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer of our General Partner concluded that our disclosure controls and procedures were effective as of December 31, 2021.

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Management’s Report on Internal Control Over Financial Reporting. Our General Partner’s management is responsible for establishing and maintaining adequate internal control over financial reporting. Our General Partner’s management, including the Chief Executive Officer and Chief Financial Officer of our General Partner, conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on its evaluation under the framework in Internal Control - Integrated Framework, our management concluded that our internal control over financial reporting was effective as of December 31, 2021. Our internal control over financial reporting as of December 31, 2021, has been audited by Ernst & Young LLP, our independent registered public accounting firm, as stated in their report appearing on page F-2.

Changes in internal control over financial reporting. There were no changes to our internal control over financial reporting that occurred during the three months ended December 31, 2021, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART III.

Item 10. Directors, Executive Officers and Corporate Governance.

Our General Partner manages our operations and activities. Our General Partner is not elected by our unitholders and will not be subject to re-election on a regular basis in the future. The directors of our General Partner oversee our operations. Unitholders are not entitled to elect the directors of our General Partner or directly or indirectly participate in our management or operations. Our General Partner owes a limited fiduciary duty to our unitholders. Our General Partner will be liable, as general partner, for all of our debts (to the extent not paid from our assets), except for indebtedness or other obligations that are made specifically nonrecourse to it. Our General Partner, therefore, may cause us to incur indebtedness or other obligations that are nonrecourse to it. Borrowings under our existing credit facility are nonrecourse to our General Partner.

Directors and Executive Officers

The Board currently consists of W. R. “Lee” Adams (affiliated with Ergon), Edward D. Brooks (affiliated with Ergon), Joel D. Pastorek (affiliated with Ergon), Robert H. Lampton (affiliated with Ergon), William W. Lampton (affiliated with Ergon), Duke R. Ligon (an independent director), Steven M. Bradshaw (an independent director) and John A. Shapiro (an independent director). Mr. Ligon serves as the Chairman of the Board, the chairman of the audit committee and a member of the compensation committee and the conflicts committee of the Board. Mr. Bradshaw serves as the chairman of the conflicts committee and a member of the compensation committee and the audit committee of the Board. Mr. Shapiro serves as the chairman of the compensation committee and a member of the conflicts committee and the audit committee of the Board.

The following table shows information regarding the current directors and executive officers of our General Partner as of March 1, 2022:

Name	Age		Position with Blueknight Energy Partners G.P., L.L.C.
D. Andrew Woodward		39	Chief Executive Officer
Matthew R. Lewis		35	Chief Financial Officer
Joel W. Kanvik		52	Chief Legal Officer and Secretary
Michael McLanahan		39	Chief Accounting Officer
Jeffery A. Speer		55	Chief Operating Officer
Duke R. Ligon		80	Director, chairman of the Board and audit committee
Steven M. Bradshaw		73	Director, chairman of the conflicts committee
John A. Shapiro		70	Director, chairman of the compensation committee
W.R. “Lee” Adams		53	Director
Edward D. Brooks		39	Director
Joel D. Pastorek		39	Director
Robert H. Lampton		61	Director
William W. Lampton		66	Director

Our directors hold office until the earlier of their death, resignation, removal or disqualification or until their successors have been elected and qualified. Officers serve at the discretion of the Board. Robert H. Lampton and William W. Lampton are brothers. There are no other family relationships between officers and directors.

D. Andrew Woodward became the Chief Executive Officer of our General Partner in June 2020, after serving as the Chief Financial Officer of our General Partner since April 2019. Mr. Woodward has substantial financial experience across investment banking, corporate development, and corporate finance within the energy and midstream industry. Mr. Woodward previously served as Vice President, Finance and Treasurer of Andeavor Logistics (NYSE: ANDX), where he was appointed by its board of directors to be the principal financial officer. Prior to this appointment, he led investor relations for ANDX and started his career with Andeavor, now Marathon Petroleum, in corporate development leading valuation, structuring and economic analysis on corporate and asset transactions. Before joining Andeavor, Mr. Woodward served as Vice President at RBC Capital Markets within its energy investment banking group where he advised on numerous large scale mergers and acquisitions and capital markets transactions. Mr. Woodward received his Bachelor of Arts in economics and philosophy from Colorado College and his Master of Business Administration from the University of Texas at Austin. 

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Matthew R. Lewis became the Chief Financial Officer of our General Partner in September 2020. Mr. Lewis has substantial financial experience having previously served in a number of corporate and operational finance roles in addition to middle market leveraged finance activities. Mr. Lewis previously served as Chief Financial Officer at Streamline Innovations, Inc., a privately held company providing specialty solutions for water and gas treating processes within energy and industrial markets. Prior to that, Mr. Lewis was the Director of Business Planning & Analysis at Andeavor Logistics (NYSE: ANDX), where he served on the extended leadership team. Previously, Mr. Lewis served in multiple roles at Mid-Con Energy Partners, LP (NASDAQ: MCEP), prior to being appointed Vice President & Chief Financial Officer in 2016. Mr. Lewis received his Bachelor of Business Administration in Finance from Texas Tech University and his Master of Business of Administration from Southern Methodist University.

Jeffery A. Speer has served as Chief Operating Officer of our General Partner since July 2013. Mr. Speer served as Senior Vice President-Operations of our General Partner from February 2010 to July 2013. Previously, Mr. Speer served as the Vice President of Operations of our asphalt and emulsion subsidiary since June 2009. Prior to joining our team, Mr. Speer served as Vice President of Operations for Koch Industries, Inc. and had operational responsibility for Koch’s crude oil, pipeline and trucking divisions in Oklahoma, Texas and Canada, as well as Koch’s agricultural and asphalt businesses. Mr. Speer has more than 30 years of experience in the energy industry and received his Bachelor of Science in mechanical engineering from Kansas State University.

Joel W. Kanvik has served as Chief Legal Officer of our General Partner since November 2016 and as Secretary since September 2018. Mr. Kanvik previously served as the Director of U.S. Law and Assistant Secretary for Enbridge Energy Company, Inc., which he joined in January 2001. He provided legal and business counsel to a family of corporations/limited partnerships, including the development and execution for large-scale construction/acquisition projects, mergers and acquisitions, contracts and licenses, intellectual property, litigation management and corporate governance. Mr. Kanvik received his Bachelor of Arts in political science from Northwestern University and his Juris Doctor from the University of Wisconsin. 

Michael McLanahan has served as the Chief Accounting Officer of our General Partner since April 2019. Mr. McLanahan previously served the Partnership in various accounting roles, including the Corporate Controller, and prior to joining the Partnership, he served as an audit manager for the public accounting firm of Ernst & Young LLP. Mr. McLanahan received his Bachelor of Arts in accounting from Ouachita Baptist University and is a certified public accountant in the state of Oklahoma.

Duke R. Ligon has served as a director of our General Partner since October 2008. He is an attorney and the current owner and manager of Mekusukey Oil Company, LLC. He served as Senior Vice President and General Counsel of Devon Energy Corporation from January 1997 until he retired in February 2007. From February 2007 to February 2010, Mr. Ligon served in the capacity of Strategic Advisor to Love’s Travel Stops & Country Stores, Inc., based in Oklahoma City, Oklahoma, and previously acted as Executive Director of the Love’s Entrepreneurship Center at Oklahoma City University. He is also a member of the board of directors of Heritage Trust Company, Security State Bank (in which he has a 14% beneficial ownership), Cavaloz Holdings, Inc. and Pardus Oil and Gas. He was formerly on the board of directors of PostRock Energy Corporation, System One, Orion California LP, Emerald Oil, Inc., SteelPath MLP, TransMontaigne Partners L.P., Pre-Paid Legal Services, Inc., Panhandle Oil and Gas Inc., Vantage Drilling Company and TEPPCO Partners, L.P. Mr. Ligon received his undergraduate degree in chemistry from Westminster College and his law degree from the University of Texas School of Law. Mr. Ligon was selected to serve as a director on the Board due to his extensive business and leadership experience derived from his background as a director of various companies in the energy industry, as well as his financial and legal expertise.

Steven M. Bradshaw has served as a director of our General Partner since November 2009. He has over 40 years of experience in the global logistics and transportation industry and currently serves as the Managing Director at Global Logistics Solutions. From 2005 to 2009, Mr. Bradshaw served as Vice President-Administration of Premium Drilling, Inc., an offshore drilling contractor that provides jack-up drilling services to the international oil and gas industry. Previously, he served as Executive Vice President of Skaugen PetroTrans, Inc. from 2001 to 2003. He also served for 16 years in various operating and marketing capacities at Kirby Corporation, including as President-Refined Products Division from 1992 to 1996. Mr. Bradshaw also served as an officer in the United States Navy. He received his Master of Business Administration from Harvard University and a bachelor’s degree in mathematics from the University of Missouri. Mr. Bradshaw was selected to serve as a director on the Board due to his business judgment and extensive industry knowledge and experience.

John A. Shapiro has served as a director of our General Partner since November 2009. Mr. Shapiro also serves on the board of directors of Citymeals-on-Wheels, as a senior advisor to Mountain Capital Partners, a Houston-based private equity firm focused on upstream E&P investments, and as a director of Sprague Resources GP LLC since June 2021. Mr. Shapiro retired as an officer at Morgan Stanley & Co., where he had served for more than 24 years in various capacities, most recently as Global Head of Commodities. While an officer at Morgan Stanley, Mr. Shapiro participated in the successful acquisitions of TransMontaigne Inc. and Heidmar Inc. and served as a member of the board of directors of both companies. Prior to joining Morgan Stanley & Co., Mr. Shapiro worked for Conoco, Inc. and New England Merchants National Bank. Mr. Shapiro has been a lecturer at Princeton University, Harvard University School of Government, HEC Business School (Paris, France) and Oxford University Energy Program (Oxford, UK). In addition, Mr. Shapiro has served on the board of directors of Blue Wolf Mongolia Holdings. He received his Master of Business Administration from Harvard University and his bachelor’s degree in economics from Princeton University. Mr. Shapiro was selected to serve as a director on the Board due to his financial expertise and extensive industry experience developed through his work at Morgan Stanley & Co., and by serving as a director of other energy companies.

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W.R. “Lee” Adams has served as a director of our General Partner since February 2018. Mr. Adams joined Ergon, Inc. as the Vice President of Internal Audit in 2011 and currently serves as Senior Vice President - Finance. He also serves as Chairman of Ergon’s Senior Management Team. He is a certified public accountant in the state of Mississippi and previously worked at Arthur Anderson and Haddox Reid Burkes & Calhoun, PLLC, where he specialized in assurance and advisory services in the areas of oil and gas, manufacturing, investments and employee benefit plans. Mr. Adams received his Bachelor of Accountancy from Mississippi State University, and holds the designations of Chartered Global Management Accountant, Certified Fraud Examiner and Certified Internal Auditor. Mr. Adams currently serves as a member of the board of directors and executive committee of Hartfield Academy. He has previously served as Chairman/President of the Petroleum Accounting Society of Mississippi and of the Mississippi Society of Certified Public Accountants, a 2,600-member trade association for CPAs practicing in the state of Mississippi. Mr. Adams was selected to serve as a director on the Board due to his affiliation with Ergon and his financial and business expertise.

Edward D. Brooks has served as a director of our General Partner since October 2016. Mr. Brooks has been the Senior Vice President of Business Development for Ergon Asphalt & Emulsions, Inc. since 2019. Mr. Brooks joined Ergon in 2007 to serve as the Manager of Business Development. Prior to joining Ergon, Mr. Brooks worked with Haddox Reid Burkes & Calhoun, PLLC as a manager in the assurance services division. Mr. Brooks received his Bachelor of Science in Business Administration in accounting and his Master of Business Administration from Mississippi College and is a certified public accountant in the state of Mississippi. He also holds a Chartered Global Management Accountant designation. Mr. Brooks was selected to serve as a director on the Board due to his affiliation with Ergon and his financial and business expertise.

Joel D. Pastorek has served as a director of our General Partner since August 2018. Mr. Pastorek serves as the Executive Vice President - Midstream & Logistics and as President of Ergon Terminaling, Inc. He also serves as the Vice Chairman of the Ergon Senior Management Team. Mr. Pastorek joined Ergon in 2005. Prior to taking the role of Executive Vice President, Mr. Pastorek held various positions within Ergon including Senior Project Manager, Manager of Corporate Maintenance, General Manager - Ergon Terminaling, Inc., Vice President - Ergon Terminaling, Inc., and President - Ergon Terminaling, Inc. Mr. Pastorek received his Bachelor of Science in mechanical engineering from Mississippi State University and is a licensed professional engineer in the state of Mississippi. Mr. Pastorek was selected to serve as a director on the Board due to his affiliation with Ergon and his financial and business expertise.

Robert H. Lampton has served as a director of our General Partner since October 2016. Mr. Lampton has been with Ergon since 1983, and currently is a member of Ergon's board of directors. He previously served as President of the Supply and Distribution Division, Ergon Terminaling, Inc., Ergon Trucking, Inc., Ergon Marine and Industrial Supply and Ergon Properties, Inc. He was a board member for Mississippi Valley Title Company from 2005 to 2015. Mr. Lampton received his degree in business administration with a minor in business psychology from The University of Mississippi. Mr. Lampton was selected to serve as a director on the Board due to his affiliation with Ergon and his financial and business expertise.

William W. Lampton has served as a director of our General Partner since October 2016. Mr. Lampton has been with Ergon since 1979, and currently is a member of Ergon’s board of directors. He previously served as President of Ergon’s Asphalt Groups and as Chairman of the board of directors of Ergon Asphalt & Emulsions, Inc. Mr. Lampton currently is a board member of Mississippi Economic Council, Boy Scouts of America, Andrew Jackson Council, Greater Jackson Chamber Partnership (of which he is a past chairman), and Mississippi Baptist Health Foundation. He is a member of the Dean’s Advisory Council of Mississippi State University’s Bagley College of Engineering and served as co-chair of the Mississippi Works initiative under Governor Phil Bryant. Mr. Lampton was selected to serve as a director on the Board due to his affiliation with Ergon and his financial and business expertise.

Independence of Directors

Our General Partner currently has eight directors, three of whom (Messrs. Bradshaw, Ligon and Shapiro) are “independent” as defined under the independence standards established by Nasdaq. Nasdaq’s independence definition includes a series of objective tests, including that the director is not an employee of the company and has not engaged in various types of business dealings with the company. In addition, the Board has made a subjective determination as to each independent director that no relationships exist which, in the opinion of the Board, would interfere with the exercise of independent judgment in carrying out the responsibilities of a director. In making these determinations, the directors reviewed and discussed information provided by the directors and us with regard to each director’s business and personal activities as they may relate to us and our management. Nasdaq does not require a listed limited partnership like us to have a majority of independent directors on the Board or to establish a nominating committee.

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In addition, the members of the audit committee also each qualify as “independent” under special standards established by the SEC for members of audit committees, and the audit committee includes at least one member who is determined by the Board to meet the qualifications of an “audit committee financial expert” in accordance with SEC rules, including that the person meets the relevant definition of an “independent” director. John A. Shapiro is the independent director who has been determined to be an audit committee financial expert. Unitholders should understand that this designation is a disclosure requirement of the SEC related to experience and understanding with respect to certain accounting and auditing matters. The designation does not impose any duties, obligations or liability that are greater than generally imposed on a member of the audit committee and the Board, and the designation of a director as an audit committee financial expert pursuant to this SEC requirement does not affect the duties, obligations or liability of any other member of the audit committee or the Board.

Board Leadership Structure and Risk Oversight

The Chief Executive Officer and chairman of the Board positions of our General Partner are held by separate individuals in recognition of the differences between the two roles. We have taken this position to achieve an appropriate balance with regard to our strategic direction, oversight of management, unitholder interests and director independence. Our General Partner’s Chief Executive Officer is responsible for setting our strategic direction and overseeing our day-to-day performance. Our General Partner’s chairman of the Board is an independent director who provides guidance to the Chief Executive Officer and sets the agenda for and presides over Board meetings.

Our Board is engaged in the oversight of risk through regular updates from our management team regarding those risks confronting us, the actions and strategies necessary to mitigate those risks and the status and effectiveness of those actions and strategies. These regular updates are provided at meetings of the Board and the audit committee as well as other meetings with the chairman of the Board, the Chief Executive Officer and other members of our General Partner’s management team.

Board Committees

We have standing conflicts, audit and compensation committees of the Board. Each member of the audit, compensation and conflicts committees is an independent director in accordance with Nasdaq and applicable securities laws. Each of the audit, compensation and conflicts committees has a written charter approved by the Board. The written charter for each of these committees is available on our website at www.bkep.com under the “Investors - Corporate Governance” section. We will also provide a copy of any of our committee charters to any of our unitholders without charge upon written request to the attention of Investor Relations at 6060 American Plaza, Suite 600, Tulsa, Oklahoma 74135. The current members of the audit, compensation and conflicts committees of the Board and a brief description of the functions performed by each committee are set forth below.

Conflicts Committee. The members of the conflicts committee are Messrs. Bradshaw (chairman), Ligon and Shapiro. The primary responsibility of the conflicts committee is to review matters that the directors believe may involve conflicts of interest. The conflicts committee determines if the resolution of the conflict of interest is fair and reasonable to us. The conflicts committee may retain independent legal and financial advisors to assist in its evaluation of a transaction. The members of the conflicts committee may not be officers or employees of our General Partner or directors, officers or employees of its affiliates and must meet the independence standards to serve on an audit committee of a board of directors established by any national securities exchange upon which our common units are traded and the SEC. Any matters approved by the conflicts committee will be conclusively deemed to be fair and reasonable to us, approved by all of our partners and not a breach by our General Partner of any duties it may owe us or our unitholders.

Audit Committee. The members of the audit committee are Messrs. Bradshaw, Ligon (chairman) and Shapiro. The primary responsibilities of the audit committee are to assist the Board in its general oversight of our financial reporting, internal controls and audit functions, and it is directly responsible for the appointment, retention, compensation and oversight of the work of our independent auditors. For information regarding our audit committee financial expert, see “Independence of Directors” above.

Compensation Committee. The members of the compensation committee are Messrs. Bradshaw, Ligon and Shapiro (chairman). The primary responsibility of the compensation committee is to oversee compensation decisions for the outside directors of our General Partner and executive officers of our General Partner, as well as administer the General Partner’s Long-Term Incentive Plan.

Code of Ethics and Business Conduct

Our General Partner has adopted a Code of Business Conduct and Ethics applicable to all of our General Partner’s employees, including all officers, and including our General Partner’s independent directors, who are not employees of our General Partner, with regard to their activities relating to us. The Code of Business Conduct and Ethics incorporates guidelines designed to deter wrongdoing and to promote honest and ethical conduct and compliance with applicable laws and regulations. It also incorporates our expectations of our General Partner’s employees that enable us to provide accurate and timely disclosure in our filings with the Securities and Exchange Commission and other public communications. The Code of Business Conduct and Ethics is publicly available under the “Investors - Corporate Governance” section of our website at www.bkep.com. The information contained on, or connected to, our website is not incorporated by reference into this annual report on Form 10-K and should not be considered part of this or any other report that we file with, or furnish to, the SEC. We will also provide a copy of the Code of Business Conduct and Ethics to any of our unitholders without charge upon written request to the attention of Investor Relations at 6060 American Plaza, Suite 600, Tulsa, Oklahoma 74135. If any substantive amendments are made to the Code of Business Conduct and Ethics, or if we or our General Partner grant any waiver, including any implicit waiver, from a provision of the code to any of our General Partner’s executive officers and directors, we will disclose the nature of such amendment or waiver on that website or in a current report on Form 8-K.

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Reimbursement of Expenses of our General Partner

Pursuant to our partnership agreement, our General Partner and its affiliates are entitled to receive reimbursement for the payment of expenses related to our operations and for the provision of various general and administrative services for our benefit.

Item 11. Executive Compensation

Throughout this section, each person who served as the Principal Executive Officer (“PEO”) during 2021 and the two most highly compensated executive officers other than the PEO serving at December 31, 2021, are referred to as the Named Executive Officers (“NEOs”). Our NEOs for 2021 were:

• D. Andrew Woodward, Chief Executive Officer;

• Jeffery A. Speer, Chief Operating Officer; and

• Joel Kanvik, Chief Legal Officer.

As is the case with many publicly traded partnerships, we do not and have not historically directly employed any persons responsible for managing or operating us or for providing services relating to day-to-day business affairs. Our General Partner manages our operations and activities, and its Board and officers make decisions on our behalf. The compensation for the NEOs for services rendered to us is determined by the compensation committee of our General Partner.

Employment Agreements. Messrs. Woodward and Kanvik have entered into new employment agreements with BKEP Management, Inc., a subsidiary of our General Partner. Mr. Speer is not party to an employment agreement. The employment agreements have an effective date of May 14, 2021, and include an initial term of three years with automatic renewals for subsequent one-year periods unless either party gives 90 days advance notice of termination. Pursuant to the employment agreements, Messrs. Woodward’s and Kanvik’s annual base salaries were set at $412,000 and $294,000, respectively. Under the agreements, each executive is also eligible to participate in all benefit programs maintained by us or our General Partner, as applicable, including annual bonus and long-term incentive programs. The employment agreements also contain customary confidentiality, intellectual property, customer non-solicitation and employee non-solicitation covenants. Mr. Woodward’s employment agreement also confirmed that, subject to his continued employment through December 31, 2021, he would receive the $200,000 remaining installment of his make-whole payment that was provided pursuant to his original offer of employment to replace certain lost compensation opportunities with his prior employer. 

In the event of the executive's termination without Cause or resignation for Good Reason, each as defined in the applicable agreement, the employment agreements provide for a lump sum severance payment equal to 12 months of base salary and subsidized COBRA continuation coverage under our General Partner’s welfare benefit programs for a period of up to 12 months following termination (as long as the executive is eligible and not covered by other employer plans). Upon such a termination, the executive would also receive accelerated vesting of unvested “phantom” units awarded under our long-term incentive program. In the event of non-renewal of the employment agreement by us, the applicable executive would be entitled to a lump sum payment equal to 6 months of base salary and subsidized COBRA continuation coverage under our General Partner’s welfare benefit programs for up to 6 months. All such separation payments and benefits are conditioned upon the executive’s execution of a release of claims. In the event of the executive’s death or Total Disability (as defined in the applicable agreement), the executive (or his dependents) will receive subsidized COBRA continuation coverage for up to 12 months.

Long-Term Incentive Plan. Our General Partner has adopted the amended and restated Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan (the “LTIP”), which was most recently approved by our unitholders on November 23, 2020. The discussion of the LTIP contained herein does not purport to be complete and is qualified in its entirety by reference to the LTIP. Among other award types, the compensation committee may make grants of restricted units and phantom units under the LTIP to eligible individuals containing such terms, consistent with the LTIP, as the compensation committee may determine, including the period over which restricted units and phantom units granted will vest. The compensation committee may, at its discretion, base vesting on the grantee’s completion of a period of service or upon the achievement of specified performance goals or other criteria.

Restricted units have been granted to the independent directors of our General Partner. A restricted unit is a common unit that is subject to forfeiture. Upon vesting, the forfeiture restrictions lapse, and the recipient holds a common unit that is not subject to forfeiture.

Phantom units have been granted to employees, including executive officers. A phantom unit is a notional unit that entitles the grantee to receive a common unit upon the vesting of the phantom unit or, at the discretion of the compensation committee, cash equal to the fair market value of a common unit. The phantom units contain distribution equivalent rights, which are rights to receive all or a portion of the distributions otherwise payable on units during a specified time.

On March 10, 2021, the compensation committee of our General Partner approved grants of phantom units under the LTIP to each of the NEOs, as set forth in the “Outstanding Equity Awards at Fiscal Year-End 2021” table below. These phantom units will vest in full on January 1, 2024, generally subject to the officer’s continued employment through such date.

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Employee Unit Purchase Plan. The Partnership’s unitholders have also approved the Blueknight Energy Partners, L.P. Employee Unit Purchase Plan (the “EUPP”). The EUPP provides employees of the General Partner and its affiliates who perform services for the Partnership the opportunity to acquire or increase their ownership of common units. A maximum of 1,000,000 common units may be delivered under the EUPP, subject to adjustment for a recapitalization, split, reorganization or similar event pursuant to the terms of the EUPP. Certain of the Partnership’s executive officers participated in this plan in 2020 and 2021. As of December 31, 2021, 608,775 common units have been delivered under the EUPP.

Summary Compensation Table

The following table summarizes the compensation of our NEOs for the years ended 2021 and 2020. 

						Stock		All Other
		Salary		Bonus		Awards		Compensation		Total
Name and Position	Year	($)		($)(1)		($)(2)		($)(3)		($)
D. Andrew Woodward,	2021		409,000		654,000		353,479		86,366		1,502,845
Chief Executive Officer	2020		378,602		500,000		72,102		54,878		1,005,582
Jeffery A. Speer,	2021		306,500		190,000		265,108		62,244		823,852
Chief Operating Officer	2020		294,000		220,000		66,733		52,040		632,773
Joel Kanvik,	2021		291,750		180,750		194,413		42,696		709,609
Chief Legal Officer	2020		283,000		180,000		43,180		35,163		541,343

(1)	Included in Mr. Woodward's bonus for 2020 and 2021 are annual installments on his new hire make-whole payments of $200,000 each.
(2)	Dollar amounts represent the grant date fair value of awards granted in each year with respect to phantom unit grants under the LTIP.
(3)	We provide distribution equivalent rights (“DERs”) under the LTIP, supplementary insurance for out-of-pocket medical expenses, and discretionary matching and profit sharing contributions to our 401(k) plan to our NEOs. In addition, executive compensation includes the taxable value related to purchases under the EUPP, computed as the difference between the fair market value and executive purchase price of units. In 2021, compensation related to these items was as follows:

	DERs		401(k) Plan Contributions		Supplementary Insurance Premiums		Taxable Value of EUPP Purchases		Taxable Value of Group Term Life Insurance Premiums		Total
D. Andrew Woodward	$	35,857	$	14,500	$	12,840	$	22,683	$	486	$	86,366
Jeffery A. Speer	$	33,662	$	14,500	$	12,840	$	-	$	1,242	$	62,244
Joel Kanvik	$	22,454	$	14,500	$	4,500	$	-	$	1,242	$	42,696

Outstanding Equity Awards at Fiscal Year-End 2021

The following table provides information concerning all outstanding equity awards held by each NEO as of December 31, 2021. All such awards were made under the LTIP. 

	Stock Awards
Name	Number of Units That Have Not Vested (#)				Market Value of Units That Have Not Vested ($)(1)
D. Andrew Woodward		130,435	(2	)		430,436
		80,113	(3	)		264,373
		46,168	(4	)		152,354
Jeffery A. Speer		97,826	(2	)		322,826
		74,148	(3	)		244,688
		62,867	(4	)		207,461
Joel Kanvik		71,739	(2	)		236,739
		47,978	(3	)		158,327
		38,558	(4	)		127,241

(1)	Market value of awards is calculated as the product of the closing market price of $3.30 of the Partnership’s common units at December 31, 2021, and the number of phantom units outstanding at December 31, 2021.
(2)	Represents phantom units granted in 2021 under our General Partner’s LTIP. These phantom units will vest on January 1, 2024. All of the distribution equivalent rights associated with these phantom units are currently payable.
(3)	Represents phantom units granted in 2020 under our General Partner’s LTIP. These phantom units will vest on January 1, 2023. All of the distribution equivalent rights associated with these phantom units are currently payable.
(4)	Represents phantom units granted in 2019 under our General Partner’s LTIP. Mr. Woodward’s units will vest on June 1, 2022 per the terms of his original offer letter. Messrs. Speers’s and Kanvik’s units vested on January 1, 2022.

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Director Compensation for Fiscal Year 2021

The following table summarizes the compensation of our directors for the year ended 2021. 

	Fees Earned or Paid in Cash		Stock Awards(2)		Total
Name	($)		($)		($)
Duke R. Ligon		129,000		55,041		184,041
Steven M. Bradshaw		129,000		45,032		174,032
John A. Shapiro		129,000		45,032		174,032
Edward D. Brooks(1)		—		—		—
Joel D. Pastorek(1)		—		—		—
W.R. “Lee” Adams(1)		—		—		—
Robert H. Lampton(1)		—		—		—
William W. Lampton(1)		—		—		—

(1)

Affiliated with Ergon.

(2)

These amounts represent the grant date fair value of restricted and unrestricted units awarded under the LTIP. The grant date fair value of these awards is computed in accordance with ASC 718 - Compensation—Stock Compensation. As of December 31, 2021, our directors held the following outstanding restricted units: Duke R. Ligon - 10,082; Steven M. Bradshaw - 10,082; and John A. Shapiro - 10,082. None of our directors affiliated with Ergon held any restricted units.

Directors who are not officers or employees of any controlling entity or their affiliates receive compensation for attending meetings of the Board and committees thereof. Such directors received the following in 2021, which, other than meeting fees and reimbursement of expenses, are retainers and fees for the following year:

(i)	$75,000 annual retainer fee paid in cash;
(ii)	$5,000 for each Board committee on which such director serves (except that the chairperson of each committee will receive $10,000 per year for serving as chairperson of such committee), paid in unrestricted common units based on the grant date fair value;
(iii)	$10,000 per year if Chairman of the Board, paid in unrestricted common units based on the grant date fair value;
(iv)	$2,000 per diem for each Board or committee meeting attended, paid in cash;
(vi)	$25,000 of restricted units based on the grant date fair value, vesting in one-third increments over a three-year period;
(vii)	reimbursement for out-of-pocket expenses associated with attending Board or committee meetings; and
(viii)	director and officer liability insurance coverage.

In addition, each director is fully indemnified by us for actions associated with being a director to the fullest extent permitted under Delaware law.

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Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters.

Security Ownership of Certain Beneficial Owners and Management

The following table sets forth the beneficial ownership of our units as of March 1, 2022, held by:

• each person or group of persons who beneficially own 5% or more of the then outstanding common units or Preferred Units;

• all of the directors of our General Partner;

• each NEO of our General Partner; and

• all current directors and executive officers of our General Partner as a group.

Except as indicated by footnote, the persons named in the table below have sole voting and investment power with respect to all units shown as beneficially owned by them, subject to community property laws where applicable. Percentage of total common and Preferred Units beneficially owned is based on 41,856,847 common units and 34,406,683 Preferred Units outstanding as of March 1, 2022.

Name of Beneficial Owner(1)	Common Units Beneficially Owned		Percentage of Common Units Beneficially Owned			Preferred Units Beneficially Owned		Percentage of Preferred Units Beneficially Owned			Percentage of Total Common and Preferred Units Beneficially Owned
Ergon Asphalt & Emulsions, Inc.(2)	2,745,837		6.6		%	20,801,757		60.5		%	30.9		%
D. Andrew Woodward(3)		105,318		*			—		—			*
Jeffery A. Speer(3)		148,911		*			—		—			*
Joel W. Kanvik(3)		55,922		*			—		—			*
Duke R. Ligon(4)		94,420		*			—		—			*
Steven M. Bradshaw(4)		73,517		*			—		—			*
John A. Shapiro(4)		67,927		*			—		—			*
W.R. “Lee” Adams(2)(5)		50,000		*			—		—			*
Edward D. Brooks(2)(5)		—		*			—		—			*
Joel D. Pastorek(2)(5)		—		*			—		—			*
Robert H. Lampton(2)(5)		—		*			—		—			*
William W. Lampton(2)(5)		—		*			—		—			*
DG Capital Management, Inc.(6)	3,837,981		9.2		%	—		—			5.0		%
Zazove Associates, Inc.(7)		3,317,982		7.9	%		—		—			4.4	%
Invesco Ltd.(8)		2,126,752		5.1	%		794,917		2.3	%		3.8	%
All current executive officers and directors as a group (13 persons)		619,810		1.5	%		—		—			0.8	%

*	Less than 1%.
(1)	Unless otherwise indicated, the address for all beneficial owners in this table is 6060 American Plaza, Suite 600, Tulsa, Oklahoma 74135.
(2)	Ergon Asphalt & Emulsions, Inc. owns Ergon Asphalt Holdings, LLC. The address for Ergon is 2829 Lakeland Drive, Suite 2000, Jackson, Mississippi 39215. Ergon Asphalt Holdings, LLC owns 100% of Blueknight GP Holding, LLC, which owns the membership interest in our General Partner.
(3)	Does not include unvested phantom units granted under the Long-Term Incentive Plan, none of which will vest within 60 days of the date hereof.
(4)	Does not include unvested restricted units granted under the Long-Term Incentive Plan, none of which will vest within 60 days of the date hereof.
(5)	Messrs. Adams, Brooks, Pastorek, R. Lampton and W. Lampton are affiliated with Ergon.
(6)	Based on a Schedule 13D/A filed December 21, 2021, by DG Capital Management, LLC with the SEC. The filing was made jointly with Dov Gertzulin, and reports that they have shared voting power with respect to the common units. Their address as reported in such Schedule 13G/A is 460 Park Avenue, 22nd Floor, New York, New York 10022.
(7)	Based on a Schedule 13G filed January 7, 2022, by Zazove Associates, Inc. with the SEC. Their address as reported in such Schedule 13G is 1001 Tahoe Blvd., Incline Village, NV 89451.
(8)	Based on a Schedule 13F filed February 14, 2022, by Invesco Ltd. with the SEC. Their address as reported in such Schedule 13F is 1555 Peachtree Street NE, Suite 1800, Atlanta, GA 30309.

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Securities Authorized for Issuance under Equity Compensation Plans (as of December 31, 2021)

Equity Compensation Plan Information(1)
	(a) Number of securities to be issued upon exercise of outstanding options, warrants and rights		(b) Weighted-average exercise price of outstanding options, warrants and rights		(c) Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a))
Equity compensation plans approved by security holders		1,555,290	$	—		4,364,412
Equity compensation plans not approved by security holders		N/A		N/A		N/A
Total		1,555,290	$	—		4,364,412

(1) Our General Partner has adopted and maintains the LTIP and EUPP for employees, consultants and directors of our General Partner and its affiliates who perform services for us. An aggregate of 1,525,044 phantom units that have been granted under the LTIP to our executive officers and other employees remain outstanding and have not yet vested. Excluding phantom unit grants, the responses are as follows: (a) 30,246, (b) $0 and (c) 5,889,456. No value is shown in column (b) of the table because the phantom units and restricted units do not have an exercise price. For more information about the LTIP, please see “Item 11-Executive Compensation-Compensation Discussion and Analysis-Long-Term Incentive Plan.” For more information about the EUPP, please see “Item 11-Executive Compensation-Compensation Discussion and Analysis-Employee Unit Purchase Plan.”

Item 13. Certain Relationships and Related Transactions, and Director Independence.

Distributions and Payments to Our General Partner and Its Affiliates

Our General Partner is owned by Ergon, which also owns 20,801,757 of the 34,406,683 outstanding Preferred Units and 2,795,837 of the 41,856,847 outstanding common units, representing an aggregate 30.9% limited partner interest in us as of March 1, 2022. In addition, our General Partner owns a 1.6% general partner interest in us and the incentive distribution rights. For a description of the distributions and payments our General Partner is entitled to receive, see “Item 5-Market for Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities-General Partner Interest and Incentive Distribution Rights.”

Agreements with Related Parties and Affiliates

For information regarding material agreements with related parties and affiliates, see Note 12 to our consolidated financial statements.

Indemnification of Directors and Officers

Under our partnership agreement, in most circumstances, we will indemnify the following persons, to the fullest extent permitted by law, from and against all losses, claims, damages or similar events:

• our General Partner;

• any departing general partner;

• any person who is or was an affiliate of a general partner or any departing general partner;

• any person who is or was a director, officer, member, partner, fiduciary or trustee of any entity set forth in the preceding three bullet points;

• any person who is or was serving as director, officer, member, partner, fiduciary or trustee of another person at the request of our General Partner or any departing general partner; and

• any person designated by our General Partner.

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Any indemnification under these provisions will only be out of our assets. Unless it otherwise agrees, our General Partner will not be liable for, or have any obligation to contribute or lend funds or assets to us to enable us to effectuate, indemnification. We may purchase insurance against liabilities asserted against us and expenses incurred by persons for our activities, regardless of whether we would have the power to indemnify the person against liabilities under our partnership agreement.

We and our General Partner have also entered into separate indemnification agreements with each of the directors and officers of our General Partner. The terms of the indemnification agreements are consistent with the terms of the indemnification provided by our partnership agreement and our General Partner’s limited liability company agreement. The indemnification agreements also provide that we and our General Partner must advance payment of certain expenses to such indemnified directors and officers, including fees of counsel, subject to receipt of an undertaking from the indemnitee to return such advance if it is ultimately determined that the indemnitee is not entitled to indemnification.

Approval and Review of Related-Party Transactions

If we contemplate entering into a transaction, other than a routine or ordinary course of business transaction, in which a related person will have a direct or indirect material interest, the proposed transaction is submitted for consideration to the Board of our General Partner or to our management, as appropriate. If the Board is involved in the approval process, it determines whether to refer the matter to the conflicts committee of the Board, as constituted under our limited partnership agreement. If a matter is referred to the conflicts committee, it obtains information regarding the proposed transaction from management and determines whether to engage independent legal counsel or an independent financial advisor to advise the members of the committee regarding the transaction. If the conflicts committee retains such counsel or financial advisor, it considers such advice and, in the case of a financial advisor, such advisor’s opinion as to whether the transaction is fair and reasonable to us and to our unitholders.

Director Independence

Please see “Item 10-Directors, Executive Officers and Corporate Governance” of this report for a discussion of director independence matters.

Item 14. Principal Accountant Fees and Services.

PricewaterhouseCoopers LLP was engaged as our principal accountant through the first quarter of 2020. We engaged Ernst & Young as our principal accountant in June 2020. The following table summarizes fees earned by PricewaterhouseCoopers LLP and Ernst & Young for independent auditing, tax and related services for each of the last two fiscal years during the period in which they were engaged as principal accountant:

	Year ended December 31,
	2020		2021
Audit fees(1)	$	480,510	$	640,276
Tax fees(2)		164,526		-

(1)

Audit fees represent amounts earned for each of the years presented for professional services rendered in connection with (a) the audit of our annual financial statements and internal controls over financial reporting, (b) the review of our quarterly financial statements and (c) those services normally provided in connection with statutory and regulatory filings or engagements, including comfort letters, consents and other services related to SEC matters.

(2)

Tax fees represent amounts earned for each of the years presented for professional services rendered in connection with tax compliance, tax advice and tax planning. This category primarily includes services relating to the preparation of unitholder annual K-1 statements by PricewaterhouseCoopers LLP. Ernst & Young does not provide us tax services.

All audit and non-audit services provided by PricewaterhouseCoopers LLP and Ernst & Young were/are subject to pre-approval by our audit committee to ensure that the provisions of such services do not impair the auditor’s independence. Under our pre-approval policy, the audit committee is informed of each engagement of the independent auditor to provide services under the policy. The audit committee of our General Partner has approved the use of Ernst & Young as our independent principal accountant.

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PART IV. FINANCIAL INFORMATION

Item 15. Exhibits, Financial Statement Schedules.

(a) Financial Statements and Schedules

(1) See the Index to Financial Statements on page F-1.

(2) All schedules have been omitted because they are either not applicable, not required or the information called for therein appears in the consolidated financial statements or notes thereto

(3) Exhibits

INDEX TO EXHIBITS 

Exhibit Number	Description
3.1	Amended and Restated Certificate of the Partnership, dated November 19, 2009, but effective as of December 1, 2009 (filed as Exhibit 3.1 to the Partnership’s Current Report on Form 8-K, filed on November 25, 2009, and incorporated herein by reference).
3.2	First Amendment to the Certificate of the Partnership, dated July 18, 2019, (filed as Exhibit 3.2 to the Partnership’s Current Report on Form 8-K, filed on July 22, 2019, and incorporated herein by reference.
3.3	Fourth Amended and Restated Agreement of Limited Partnership of the Partnership, dated September 14, 2011 (filed as Exhibit 3.1 to the Partnership’s Current Report on Form 8-K, filed on September 14, 2011, and incorporated herein by reference).
3.4	Amended and Restated Certificate of Formation of the General Partner, dated November 20, 2009, but effective as of December 1, 2009 (filed as Exhibit 3.2 to the Partnership’s Current Report on Form 8-K, filed on November 25, 2009, and incorporated herein by reference).
3.5	First Amendment to the Certificate of Formation of the General Partner, dated July 18, 2019 (filed as Exhibit 3.1 to the Partnership’s Current Report on Form 8-K, filed on July 22, 2019, and incorporated herein by reference.
3.6	Second Amended and Restated Limited Liability Company Agreement of the General Partner, dated December 1, 2009 (filed as Exhibit 3.2 to the Partnership’s Current Report on Form 8-K, filed on December 7, 2009, and incorporated herein by reference).
4.1	Specimen Unit Certificate (included in Exhibit 3.2).
4.2	Registration Rights Agreement, dated as of October 25, 2010, by and among Blueknight Energy Partners, L.P., Blueknight Energy Holding, Inc. and CB-Blueknight, LLC (filed as Exhibit 4.1 to the Partnership’s Current Report on Form 8-K, filed on October 25, 2010, and incorporated herein by reference).
4.3	Specimen Series A Preferred Unit Certificate (filed as Exhibit 4.3 to the Partnership’s Current Report on Form 8-K, filed on September 27, 2011, and incorporated herein by reference).
4.4	Amended and Restated Registration Rights Agreement, dated December 1, 2017, by and among Blueknight Energy Partners, L.P., Ergon Asphalt & Emulsions, Inc., Ergon Terminaling, Inc. and Ergon Asphalt Holdings, LLC (filed as Exhibit 4.1 to the Partnership’s Current Report on Form 8-K, filed on December 1, 2017, and incorporated herein by reference).
4.5	Description of Blueknight Energy Partners, L.P. securities registered under Section 12 of the Exchange Act (filed as Exhibit 4.5 to the Partnership’s Annual Report on Form 10-K, filed on March 26, 2020, and incorporated herein by reference.
10.1†	Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan (incorporated by reference to Annex A to the Partnership’s Definitive Proxy Statement on Schedule 14-A filed on October 9, 2020).
10.2†	Form of Phantom Unit Agreement (filed as Exhibit 10.9 to the Partnership’s Annual Report on Form 10-K, filed on March 8, 2018, and incorporated herein by reference).
10.3†	Form of Director Restricted Common Unit Agreement (filed as Exhibit 10.11 to the Partnership’s Annual Report on Form 10-K, filed on March 8, 2018, and incorporated herein by reference).

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10.4†	Employment Agreement, dated May 14, 2021, between D. Andrew Woodward and BKEP Management, Inc. (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed on May 19, 2021, and incorporated herein by reference).
10.5†	Offer of Employment Letter, dated March 29, 2019, between D. Andrew Woodard and BKEP Management, Inc (filed as Exhibit 10.8 to the Partnership’s Annual Report on Form 10-K, filed on March 26, 2020, and incorporated herein by reference).
10.6†	Employment Agreement, dated May 14, 2021, between Matthew Lewis and BKEP Management, Inc. (filed as Exhibit 10.2 to the Partnership’s Current Report on Form 8-K, filed on May 19, 2021, and incorporated herein by reference).
10.7†	Employment Agreement, dated May 14, 2021, between D. Joel W. Kanvik and BKEP Management, Inc. (filed as Exhibit 10.3 to the Partnership’s Current Report on Form 8-K, filed on May 19, 2021, and incorporated herein by reference).
10.8†	Form of Indemnification Agreement (filed as Exhibit 10.7 to the Partnership’s Registration Statement on Form S-1 (Reg. No. 333-141196), filed on May 25, 2007, and incorporated herein by reference).
10.9	Mutual Easement Agreement, dated as of April 7, 2009 to be effective as of 11:59 PM CDT March 31, 2009, among SemCrude, L.P., SemGroup Energy Partners, L.L.C., and SemGroup Crude Storage, L.L.C. (filed as Exhibit 10.12 to the Partnership’s Current Report on Form 8-K, filed on April 10, 2009, and incorporated herein by reference).
10.10	Pipeline Easement Agreement, dated as of April 7, 2009 to be effective as of 11:59 PM CDT March 31, 2009, by and among White Cliffs Pipeline, L.L.C., SemGroup Energy Partners, L.L.C., and SemGroup Crude Storage, L.L.C. (filed as Exhibit 10.13 to the Partnership’s Current Report on Form 8-K, filed on April 10, 2009, and incorporated herein by reference).
10.11†	Blueknight Energy Partners, L.P. Employee Unit Purchase Plan, dated to be effective as of June 23, 2014 (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed on June 27, 2014, and incorporated herein by reference).
10.12	Third Amended and Restated Credit Agreement, dated as of May 26, 2021, by and among Blueknight Energy Partners, L.P., Truist Bank, as Administrative Agent, and the several lenders from time to time party thereto (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed May 27, 2021, and incorporated herein by reference).
10.13#	Storage, Throughput and Handling Agreement, dated October 5, 2016, by and among BKEP Materials, L.L.C., BKEP Terminalling, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed on October 5, 2016, and incorporated herein by reference).
10.14#	First Amendment to the Storage, Throughput and Handling Agreement, dated July 12, 2018, by and between BKEP Materials, L.L.C., BKEP Terminalling, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed July 13, 2018, and incorporated herein by reference).
10.15	Second Amendment to the Storage, Throughput and Handling Agreement, dated January 8, 2020, by and between BKEP Materials, L.L.C., BKEP Terminalling, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.3 to the Partnership’s Current Report on Form 8-K, filed January 13, 2020, and incorporated herein by reference).
10.16	Amendment to the Storage, Throughput and Handling Agreement, effective January 1, 2019, by and between BKEP Materials, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.18 to the Partnership’s Annual Report on Form 10-K, filed on March 12, 2019, and incorporated herein by reference.
10.17#	Amended and Restated Omnibus Agreement, dated July 12, 2018, by and between Ergon Asphalt & Emulsions, Inc., Blueknight Energy Partners G.P., L.L.C., Blueknight Energy Partners, L.P., Blueknight Terminalling, L.L.C., BKEP Materials, L.L.C. and BKEP Asphalt, L.L.C. (filed as Exhibit 10.2 to the Partnership’s Current Report on Form 8-K, filed July 13, 2018, and incorporated herein by reference).
10.18	Agreement, dated May 9, 2018, by and between Ergon Terminaling, Inc. and Blueknight Energy Partners, L.P. (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed May 18, 2018, and incorporated herein by reference).
10.19	Membership Interest Purchase Agreement, dated January 2, 2020, by and between Blueknight Energy Partners, L.P. and Ergon, Inc. (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed January 6, 2020, and incorporated herein by reference).
10.20	Domestic Crude Oil and Condensate Agreement, dated March 28, 2018, by and between Ergon Oil Purchasing, Inc. and BKEP Supply and Marketing, LLC (filed as Exhibit 10.3 to the Partnership’s Quarterly Report on Form 10-Q, filed August 2, 2018, and incorporated herein by reference).

44

10.21	Partial Lease Termination No. 5 to Master Facilities Lease Agreement, dated March 7, 2018, by and between BKEP Materials, L.L.C, BKEP Asphalt, L.L.C and Ergon Asphalt & Emulsions, Inc (filed as Exhibit 10.26 to the Partnership’s Annual Report on Form 10-K, filed March 8, 2018, and incorporated herein by reference).
10.22	Fifth Amendment to Master Facilities Lease Agreement, dated March 7, 2018, by and between BKEP Materials, L.L.C, BKEP Asphalt, L.L.C and Ergon Asphalt & Emulsions, Inc (filed as Exhibit 10.27 to the Partnership’s Annual Report on Form 10-K, filed March 8, 2018, and incorporated herein by reference).
10.23	Lessee Operated Facilities Lease Agreement, dated January 1, 2019, by and between BKEP Materials, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.28 to the Partnership’s Annual Report on Form 10-K, filed on March 12, 2019, and incorporated herein by reference.
10.24	Amendment to Lessee Operated Facilities Lease Agreement, dated January 8, 2020, by and between BKEP Materials, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed January 13, 2020, and incorporated herein by reference).
10.25	Owner Operated Storage, Throughput and Handling Agreement, dated January 1, 2019, by and between BKEP Materials, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. filed as Exhibit 10.29 to the Partnership’s Annual Report on Form 10-K, filed on March 12, 2019, and incorporated herein by reference.
10.26	Amendment to Owner Operated Storage, Throughput and Handling Agreement, dated January 8, 2020, by and between BKEP Materials, L.L.C., BKEP Asphalt, L.L.C., and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.2 to the Partnership’s Current Report on Form 8-K, filed January 13, 2020, and incorporated herein by reference).
10.27	Master Storage, Throughput and Handling Agreement, dated effective August 1, 2020, by and between BKEP Materials, L.L.C., BKEP Terminalling, L.L.C., BKEP Asphalt, L.L.C. and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.1 to the Partnership's Current Report on Form 8-K, filed on August 5, 2020, and incorporated herein by reference).
10.28	Operating and Maintenance Agreement, dated effective August 1, 2020, by and between BKEP Materials, L.L.C., BKEP Terminalling, L.L.C., BKEP Asphalt, L.L.C. and Ergon Asphalt & Emulsions, Inc. (filed as Exhibit 10.2 to the Partnership's Current Report on Form 8-K, filed on August 5, 2020, and incorporated herein by reference).
21.1*	List of Subsidiaries of Blueknight Energy Partners, L.P.
23.1*	Consent of Ernst & Young LLP.
31.1*	Certifications of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	Certifications of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1*	Certification of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C., Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. Pursuant to SEC Release 34-47551, this Exhibit is furnished to the SEC and shall not be deemed to be “filed.”
101.INS**	Inline 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 Taxonomy Extension Schema Document.
101.CAL**	Inline XBRL Taxonomy Calculation Linkbase Document.
101.DEF**	Inline XBRL Taxonomy Extension Definitions Document.
101.LAB**	Inline XBRL Taxonomy Label Linkbase Document.
101.PRE**	Inline XBRL Taxonomy Presentation Linkbase Document.
104**	Cover Page Interactive Data File (embedded within the Inline XBRL document and contained in Exhibit 101).

 _________

* Filed herewith.

** Furnished herewith

# Certain portions of this exhibit are subject to a request for confidential treatment by the Securities and Exchange Commission. The omitted portions have been separately filed with the Securities and Exchange Commission.

†	As required by Item 15(a)(3) of Form 10-K, this exhibit is identified as a compensatory plan or arrangement.
&	Certain schedules and exhibits to this agreement have been omitted in accordance with Item 601(a)(5) of Regulation S-K. A copy of any omitted schedule and/or exhibit will be furnished supplementally to the SEC upon its request.

Item 16. Form 10-K Summary.

None.

45

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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. 

	BLUEKNIGHT ENERGY PARTNERS, L.P.
	By:	Blueknight Energy Partners G.P., L.L.C.
		Its General Partner
March 9, 2022	By:	/s/ Matthew R. Lewis
		Matthew R. Lewis
		Chief Financial Officer
March 9, 2022	By:	/s/ Michael McLanahan
		Michael McLanahan
		Chief Accounting 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 indicated on March 9, 2022.

Signature	Title
/s/ D. Andrew Woodward	Chief Executive Officer (Principal Executive Officer)
D. Andrew Woodward
/s/ Matthew R. Lewis	Chief Financial Officer (Principal Financial Officer)
Matthew R. Lewis
/s/ Michael McLanahan	Chief Accounting Officer (Principal Accounting Officer)
Michael McLanahan
/s/ Duke R. Ligon	Director
Duke R. Ligon
/s/ Steven M. Bradshaw	Director
Steven M. Bradshaw
/s/ John A. Shapiro	Director
John A. Shapiro
/s/ W.R. “Lee” Adams	Director
W.R. “Lee” Adams
/s/ Edward D. Brooks	Director
Edward D. Brooks
/s/ Joel D. Pastorek	Director
Joel D. Pastorek
/s/ Robert H. Lampton	Director
Robert H. Lampton
/s/ William W. Lampton	Director
William W. Lampton

46

INDEX TO BLUEKNIGHT ENERGY PARTNERS, L.P. CONSOLIDATED FINANCIAL STATEMENTS

Reports of Independent Registered Public Accounting Firm (PCAOB ID: Ernst & Young LLP (42))	F-1
Consolidated Balance Sheets as of December 31, 2020 and 2021	F-3
Consolidated Statements of Operations for the Years Ended December 31, 2020 and 2021	F-4
Consolidated Statements of Changes in Partners’ Capital (Deficit) for the Years Ended December 31, 2020 and 2021	F-5
Consolidated Statements of Cash Flows for the Years Ended December 31, 2020 and 2021	F-6
Notes to the Consolidated Financial Statements	F-7
1. Organization and Nature of Business	F-7
2. Basis of Presentation	F-7
3. Summary of Significant Accounting Policies	F-7
4. Revenue	F-9
5. Discontinued Operations	F-11
6. Property, Plant, and Equipment	F-13
7. Intangible Assets	F-13
8. Debt	F-14
9. Net Income Per Limited Partner Unit	F-16
10. Partners’ Capital (Deficit) and Distributions	F-17
11. Major Customers and Concentration of Credit Risk	F-18
12. Related-party Transactions	F-18
13. Long-Term Incentive Plan	F-20
14. Employee Benefit Plan	F-21
15. Commitments and Contingencies	F-21
16. Environmental Remediation	F-22
17. Fair Value Measurements	F-22
18. Leases	F-23
19. Income Taxes	F-24

Report of Independent Registered Public Accounting Firm

To the Board of Directors of Blueknight Energy Partners G.P., L.L.C. as the general partner of Blueknight Energy Partners, L.P. and unitholders of Blueknight Energy Partners, L.P.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Blueknight Energy Partners, L.P. (the Partnership) as of December 31, 2021 and 2020, the related consolidated statements of operations, partners’ capital (deficit) and cash flows for each of the two years in the period ended December 31, 2021, and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Partnership at December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the two years in the period ended December 31, 2021, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Partnership's internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework), and our report dated March 9, 2022 expressed an unqualified opinion thereon.

Basis for Opinion

These financial statements are the responsibility of the Partnership's management. Our responsibility is to express an opinion on the Partnership’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 the Partnership 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 audit 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 Matters

Critical audit matters are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. We determined that there are no critical audit matters.

/s/ Ernst & Young LLP

We have served as the Partnership’s auditor since 2020.

Tulsa, Oklahoma

March 9, 2022

F-1

Report of Independent Registered Public Accounting Firm

To the Board of Directors of Blueknight Energy Partners G.P., L.L.C. as the general partner of Blueknight Energy Partners, L.P. and unitholders of Blueknight Energy Partners, L.P.

Opinion on Internal Control Over Financial Reporting

We have audited Blueknight Energy Partners, L.P.’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, Blueknight Energy Partners, L.P. (the Partnership) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Partnership as of December 31, 2021 and 2020, the related consolidated statements of operations, partners’ capital (deficit) and cash flows for each of the two years in the period ended December 31, 2021, and the related notes and our report dated March 9, 2022 expressed an unqualified opinion thereon.

Basis for Opinion

The Partnership’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 the Partnership’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 the Partnership 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

An entity’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. An entity’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 entity; (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 entity are being made only in accordance with authorizations of management and directors of the entity; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the entity’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.

/s/ Ernst & Young LLP

Tulsa, Oklahoma

March 9, 2022

F-2

BLUEKNIGHT ENERGY PARTNERS, L.P.

CONSOLIDATED BALANCE SHEETS

(in thousands, except per unit data)

	As of December 31,
	2020			2021
ASSETS
Current assets:
Cash and cash equivalents	$	805		$	1,172
Accounts receivable, net		3,297			2,989
Receivables from related parties, net		507			369
Other current assets		2,355			3,112
Current assets of discontinued operations		96,945			2
Total current assets		103,909			7,644
Property, plant and equipment, net of accumulated depreciation of $197,561 and $204,101 at December 31, 2020 and 2021, respectively		104,709			106,389
Goodwill		6,728			6,728
Debt issuance costs, net		1,340			2,854
Operating lease assets		8,548			7,855
Intangible assets, net		7,531			5,088
Other noncurrent assets		252			340
Total assets	$	233,017		$	136,898
LIABILITIES AND PARTNERS’ CAPITAL (DEFICIT)
Current liabilities:
Accounts payable	$	1,635			2,105
Accounts payable to related parties		31			1,047
Accrued interest payable		274			250
Accrued property taxes payable		1,757			1,660
Unearned revenue		1,789			1,932
Unearned revenue with related parties		4,603			4,875
Accrued payroll		4,977			4,782
Current operating lease liability		1,684			1,418
Other current liabilities		1,349			1,711
Current liabilities of discontinued operations		17,248			240
Total current liabilities		35,347			20,020
Long-term unearned revenue with related parties		4,153			4,390
Other long-term liabilities		168			228
Noncurrent operating lease liability		6,980			6,703
Long-term debt		252,592			98,000
Commitments and contingencies (Note 15)
Partners’ capital (deficit):
Common unitholders (41,214,856 and 41,550,681 units issued and outstanding at December 31, 2020 and 2021, respectively)		312,591			390,310
Preferred unitholders (35,125,202 and 34,406,683 units issued and outstanding at December 31, 2020 and 2021, respectively)		253,923			248,729
General partner interest (1.6% interest with 1,225,409 general partner units outstanding at both dates)		(632,737	)		(631,482	)
Total partners’ capital (deficit)		(66,223	)		7,557
Total liabilities and partners’ capital (deficit)	$	233,017		$	136,898

The accompanying notes are an integral part of these consolidated financial statements.

F-3

BLUEKNIGHT ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per unit data)

	Year ended December 31,
	2020			2021
Service revenue:
Third-party revenue	$	29,171		$	30,715
Related-party revenue		18,028			20,195
Lease revenue:
Third-party revenue		36,630			35,065
Related-party revenue		26,416			29,442
Total revenue		110,245			115,417
Costs and expenses:
Operating expense		62,812			64,203
General and administrative expense		14,182			13,902
Total costs and expenses		76,994			78,105
Loss on disposal of assets		(67	)		(195	)
Operating income		33,184			37,117
Other income (expenses):
Other income		1,169			2,615
Interest expense		(5,665	)		(4,944	)
Income before income taxes		28,688			34,788
Provision for income taxes		(7	)		30
Income from continuing operations		28,695			34,758
Gain (loss) from discontinued operations, net		(42,175	)		75,772
Net income (loss)	$	(13,480	)	$	110,530
Allocation of net income (loss) for calculation of earnings per unit:
General partner interest in net income (loss)	$	(213	)	$	1,751
Preferred interest in net income	$	25,115		$	24,824
Net income (loss) available to limited partners	$	(38,382	)	$	83,955
Basic and diluted net income (loss) from discontinued operations per common unit	$	(0.98	)	$	1.74
Basic and diluted net income from continuing operations per common unit	$	0.07		$	0.22
Basic and diluted net income (loss) per common unit	$	(0.91	)	$	1.96
Weighted average common units outstanding - basic and diluted		41,104		$	41,484

The accompanying notes are an integral part of these consolidated financial statements.

F-4

BLUEKNIGHT ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS’ CAPITAL (DEFICIT)

(in thousands)

	Common			Preferred			General Partner			Total Partners’
	Unitholders			Unitholders			Interest			Capital (Deficit)
Balance, December 31, 2019	$	356,777		$	253,923		$	(632,023	)	$	(21,323	)
Net income (loss)		(38,382	)		25,115			(213	)		(13,480	)
Equity-based incentive compensation		804			-			12			816
Distributions		(6,778	)		(25,115	)		(513	)		(32,406	)
Proceeds from sale of 158,326 common units pursuant to the Employee Unit Purchase Plan		170			-			-			170
Balance, December 31, 2020	$	312,591		$	253,923		$	(632,737	)	$	(66,223	)
Net income		83,827			24,953			1,750			110,530
Equity-based incentive compensation		604			-			14			618
Repurchase of Preferred Units		-			(5,407	)		-			(5,407	)
Distributions		(6,866	)		(24,740	)		(509	)		(32,115	)
Proceeds from sale of 77,654 common units pursuant to the Employee Unit Purchase Plan		154			-			-			154
Balance, December 31, 2021	$	390,310		$	248,729		$	(631,482	)	$	7,557

The accompanying notes are an integral part of these consolidated financial statements.

F-5

BLUEKNIGHT ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

	Year ended December 31,
	2020			2021
Cash flows from operating activities:
Net income (loss)	$	(13,480	)	$	110,530
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization		23,068			11,949
Amortization and write-off of debt issuance costs		1,004			1,586
Loss on disposal/classification of held for sale for discontinued operations		39,096			-
Tangible asset impairment charge		6,416			156
Gain on sale of assets		(1,123	)		(75,001	)
Gain from insurance settlement related to investing activities		-			(1,059	)
Equity-based incentive compensation		816			618
Changes in assets and liabilities:
Decrease in accounts receivable		6,461			14,265
Decrease in receivables from related parties		603			138
Decrease in other current assets		4,094			2,318
Decrease in other non-current assets		2,324			1,417
Decrease in accounts payable		(557	)		(311	)
Increase (decrease) in payables to related parties		(1,792	)		1
Decrease in accrued crude oil purchases		(2,838	)		(3,868	)
Decrease in accrued crude oil purchases to related parties		(2,965	)		(8,842	)
Increase (decrease) in accrued interest payable		(19	)		305
Decrease in accrued property taxes		(671	)		(612	)
Decrease in unearned revenue		(1,618	)		(471	)
Increase (decrease) in unearned revenue from related parties		2,954			(423	)
Increase (decrease) in accrued payroll		1,617			(1,649	)
Decrease in other accrued liabilities		(2,223	)		(1,718	)
Net cash provided by operating activities		61,167			49,329
Cash flows from investing activities:
Acquisition of DEVCO from Ergon (Note 12)		(12,221	)		-
Capital expenditures		(16,332	)		(8,429	)
Proceeds from sale of assets		5,896			155,249
Proceeds from insurance settlement related to investing activities		-			1,059
Net cash provided by (used in) investing activities		(22,657	)		147,879
Cash flows from financing activities:
Payments on other financing activities		(3,027	)		(1,384	)
Debt issuance costs		-			(575	)
Borrowings under credit agreement		228,000			98,486
Payments under credit agreement		(231,000	)		(256,000	)
Repurchase of Preferred Units		-			(5,407	)
Proceeds from equity issuance		170			154
Distributions		(32,406	)		(32,115	)
Net cash used in financing activities		(38,263	)		(196,841	)
Net increase in cash and cash equivalents		247			367
Cash and cash equivalents at beginning of period		558			805
Cash and cash equivalents at end of period	$	805		$	1,172
Supplemental disclosure of non-cash financing and investing cash flow information:
Non-cash changes in property, plant and equipment	$	(259	)		2,765
Increase in accrued liabilities related to insurance premium financing agreement	$	2,324			1,208
Cash paid for interest, net of amounts capitalized	$	10,009		$	4,098
Cash paid for income taxes	$	30		$	37

The accompanying notes are an integral part of these consolidated financial statements. 

F-6

BLUEKNIGHT ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION AND NATURE OF BUSINESS

Blueknight Energy Partners, L.P. and subsidiaries (collectively, the “Partnership”) is a publicly traded master limited partnership with operations in 26 states. The Partnership provides integrated terminalling services for companies engaged in the production, distribution and marketing of liquid asphalt. The Partnership manages its operations through one operating segment, asphalt terminalling services. The Partnership’s common units and Preferred Units, which represent limited partnership interests in the Partnership, are listed on the Nasdaq Global Market under the symbols “BKEP” and “BKEPP,” respectively. The Partnership was formed in February 2007 as a Delaware master limited partnership.

The Partnership previously provided integrated terminalling, gathering, and transportation services for companies engaged in the production, distribution, and marketing of crude oil in three different operating segments: (i) crude oil terminalling services, (ii) crude oil pipeline services, and (iii) crude oil trucking services. On December 21, 2020, the Partnership announced it had entered into multiple definitive agreements to see these segments. The transaction related to the crude oil pipeline services segment closed on February 1, 2021, the final transaction related to crude oil trucking services closed on February 2, 2021, and the transaction related to crude oil terminalling services closed on March 1, 2021. These segments are presented as discontinued operations for all periods presented. Unless otherwise noted, information in these notes to the consolidated financial statements relates to continuing operations. As the Partnership is only operating through one operating segment, a segment footnote is no longer required.

2. BASIS OF PRESENTATION

The accompanying consolidated financial statements and related notes present and discuss the Partnership’s consolidated financial position as of December 31, 2020 and 2021, and the consolidated results of the Partnership’s operations, cash flows and changes in partners’ capital (deficit) for the years ended December 31, 2020 and 2021. The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). All significant intercompany accounts and transactions have been eliminated in the preparation of the accompanying consolidated financial statements.

3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

USE OF ESTIMATES - The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts and disclosure of contingencies. Management makes significant estimates including: (1) estimated cash flows and fair values inherent in impairment tests; (2) the estimated fair value of financial instruments; and (3) liability and contingency accruals. Although management believes these estimates are reasonable, actual results could differ from these estimates.

CASH AND CASH EQUIVALENTS - Cash and cash equivalents include cash and all investments with original maturities of three months or less which are readily convertible into known amounts of cash.

ACCOUNTS RECEIVABLE - The Partnership reviews all outstanding accounts receivable balances on a monthly basis and records a reserve for amounts that the Partnership expects will not be fully recovered. Although the Partnership considers its allowance for doubtful trade accounts receivable to be adequate, there is no assurance that actual amounts will not vary significantly from estimated amounts. The Partnership had no amounts that qualified for a reserve at both December 31, 2020 and 2021.

PROPERTY, PLANT AND EQUIPMENT - Property, plant and equipment are recorded at cost. Expenditures for maintenance and repairs that do not add capacity or extend the useful life of an asset are expensed as incurred. The carrying values of the assets are based on estimates, assumptions and judgments relative to useful lives and salvage values. As assets are disposed of, the cost and related accumulated depreciation are removed from the accounts, and any resulting gain or loss is included in operating income in the consolidated statements of operations.

Depreciation is calculated using the straight-line method based on estimated useful lives of the assets. These estimates are based on various factors, including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets. Uncertainties that impact these estimates include changes in laws and regulations relating to restoration and abandonment requirements, economic conditions and supply and demand in the area. When assets are put into service, management makes estimates with respect to useful lives and salvage values that it believes are reasonable. However, subsequent events could cause management to change its estimates, thus impacting the future calculation of depreciation.

The Partnership has contractual obligations to perform dismantlement and removal activities in the event that some of its liquid asphalt terminalling assets are abandoned (see Note 15). Such obligations are recognized in the period in which sufficient information becomes available for it to reasonably determine the settlement dates.

F- 7

 

IMPAIRMENT OF LONG-LIVED ASSETS AND OTHER INTANGIBLE ASSETS - Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written down to estimated fair value. A long-lived asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset is recognized. Fair value is generally determined from estimated discounted future net cash flows.

Acquired customer contracts are capitalized and amortized over useful lives ranging from approximately 5 to 10 years using the straight-line method of amortization. An impairment loss is recognized for definite-lived intangibles if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. 

The Partnership had no asset impairment charges for the years ended December 31, 2020 and 2021.

DEBT ISSUANCE COSTS - Costs incurred in connection with the issuance of long-term debt related to the Partnership’s credit agreement are capitalized and amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization.

GOODWILL - Goodwill represents the excess of the cost of acquisitions over the amounts assigned to assets acquired and liabilities assumed. Goodwill is not amortized but is tested annually in December for impairment or when events and circumstances warrant an interim evaluation. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. The Partnership currently has one reporting unit, asphalt terminalling services. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired. Entities may elect to utilize a qualitative assessment to evaluate whether it is more likely than not that the fair value of the reporting unit is less than its carrying amount. Should the quantitative assessment be required, the Partnership’s valuation would generally be based on the estimated discounted future net cash flows of the reporting unit, utilizing discount rates and other factors in determining the fair value of the reporting unit. The Partnership utilized the qualitative assessment in 2020 and 2021, and no impairment expense was recorded in either period.

ENVIRONMENTAL MATTERS - Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines, penalties and other sources are charged to expense when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. The Partnership had no loss contingencies related to environmental matters as of December 31, 2020 and 2021.

REVENUE RECOGNITION - The Partnership recognizes service revenue in accordance with ASC 606 and lease revenue in accordance with ASC 842. See Note 4 for detailed discussion regarding the Partnership’s revenue recognition policies.

INCOME AND OTHER TAXES - For federal and most state income tax purposes, the majority of income, gains, losses, deductions and tax credits generated by the Partnership flow through to the unitholders of the Partnership and are subject to income tax at the individual partner level. The Partnership is subject to the Texas state franchise (margin) tax, and the earnings associated with the Partnership’s taxable subsidiary are subject to federal and state income taxes. The Partnership's estimated liability related to these taxes is immaterial for both the years ended December 31, 2020 and 2021, and is reflected on the Partnership’s consolidated statements of operations as “Provision for income taxes.” See Note 19 for a discussion of certain risks related to the Partnership’s ability to be treated as a partnership for federal income tax purposes.

STOCK-BASED COMPENSATION - The Partnership’s general partner adopted the Blueknight Energy Partners G.P. L.L.C. Long-Term Incentive Plan (the “LTIP”), under which 8.1 million units are reserved for issuance, subject to adjustment for certain events. The compensation committee of the Board administers the LTIP. Although other types of awards are contemplated under the LTIP, awards issued to date include “phantom” units, which convey the right to receive common units upon vesting, and “restricted” units, which are grants of common units restricted until the time of vesting. The phantom unit awards also include distribution equivalent rights (“DERs”). A DER entitles the grantee to a cash payment equal to the cash distribution paid on an outstanding common unit prior to the vesting date of the underlying award. Cash distributions paid on DERs are accounted for as partnership distributions. Recipients of restricted units are entitled to receive cash distributions paid on common units during the vesting period.

The Partnership classifies unit award grants as either equity or liability awards. All award grants made under the LTIP from its inception through December 31, 2021, have been classified as equity awards. Fair value for award grants classified as equity is determined on the grant date of the award and this value is recognized as compensation expense ratably over the requisite service period of unit award grants, which generally is the vesting period. Fair value for equity awards is calculated as the closing price of the Partnership’s common units representing limited partner interests in the Partnership (“common units”) on the grant date and is reduced by the present value of estimated cash distributions to be paid on common units during the vesting period to the extent a unit award does not include DERs. Compensation expense related to unit-based payments is included in operating and general and administrative expenses on the Partnership’s consolidated statements of operations.

FAIR VALUE OF FINANCIAL INSTRUMENTS - The Partnership measures all financial instruments, including derivatives embedded in other contracts, at fair value and recognizes them in the consolidated balance sheets as an asset or a liability, depending on its rights and obligations under the applicable contract. The changes in the fair value of financial instruments are recognized currently in earnings in the consolidated statements of operations.

F- 8

 

LEASES - A lease is a contract, or part of a contract, that conveys the right to control the use of identified property, plant, or equipment (an identified asset) for a period of time in exchange for consideration. At the inception of a contract, and upon certain modifications, the Partnership determines whether the contract is or contains a lease. In evaluating whether a contract conveys a right to control the use of an asset, considerations include whether the contract conveys the right to substantially all of the economic benefits from use of the identified asset for a period of time and the right to direct the use of the identified asset. The determination of whether an arrangement represents a lease involves judgment in certain instances.

The Partnership is both a lessee and a lessor. For lessee contracts, the length of lease agreements varies from less than one year to approximately twenty-five years. The Partnership has elected to not record lease assets and liabilities for leases with a lease term at commencement of 12 months or less; such leases are expensed as paid. If a lease contains an option to extend the lease term and there is reasonable certainty the option will be exercised, the option is considered in the lease term at inception. The Partnership has elected to not separate non-lease components (e.g., common area maintenance) from lease components on real estate leases, accordingly the recognized lease asset and lease liability incorporate in their measurement payments for non-lease components. Certain leases include variable lease payments as the amounts are subject to change over the lease term. When the interest rate implicit in the leases is unable to be determined, the incremental borrowing rate related to the Partnership's revolving credit facility is used to capitalize the right-of-use asset and lease liability. See Note 4 for the Partnership’s policies on agreements in which it is the lessor.

4. REVENUE

There are two types of asphalt terminalling contracts: (i) operating lease contracts, under which customers operate the facilities, and (ii) storage, throughput and handling contracts, under which the Partnership operates the facilities. The operating lease contracts are accounted for in accordance with ASC 842 - Leases. The storage, throughput and handling contracts contain both lease revenue and non-lease service revenue. In accordance with ASC 842 and 606, fixed consideration is allocated to the lease and service components based on their relative stand-alone selling price. The stand-alone selling price of the lease component is calculated using the average internal rate of return under the operating lease agreements. The stand-alone selling price of the service component is calculated by applying an appropriate margin to the expected costs to operate the facility. The service component contains a single performance obligation that consists of a stand-ready obligation to perform activities as directed by the customer, and revenue is recognized on a straight-line basis over time as the customer receives and consumes benefits. The lease component is recognized on a straight-line basis over the term of the initial lease. Fixed consideration, consisting of the monthly storage and handling fees, is billed a month prior to the performance of services and is due by the first day of the month of service. Payments received in advance of the month of service are recorded as unearned revenue until the service is performed, and the service component is treated as a contract liability.

Asphalt storage, throughput and handling contracts also contain variable consideration in the form of reimbursements of utility, fuel and power expenses and throughput fees. Utility, fuel and power reimbursements are allocated entirely to the service component of the contracts. Utility, fuel and power reimbursements relate directly to the distinct monthly service that makes up the overall performance obligation and revenue is recognized in the period in which the service takes place. Variable consideration related to reimbursements of utility, fuel and power expenses is billed in the month subsequent to the period of service, and payment is due within 30 days of billing. Throughput fees are allocated to both the lease and service component of the contracts using the allocation percentages from contract inception. In accordance with ASC 842, the lease component of variable throughput fees is recognized in the period when the changes in facts and circumstances on which the variable payment is based occur. Additionally, under ASC 842, when variable consideration contains both a lease and non-lease service component, the service component cannot be recognized until the period in which the changes in facts and circumstances on which the variable payment is based occur. At that time, it can be recognized in accordance with ASC 606. The service component of variable throughput fees is treated as a change in estimate in the period changes in facts and circumstances on which the variable payment is based occur and is then recognized on a straight-line basis over time as the customer receives and consumes benefits. Payment on variable throughput consideration is due within 30 days of billing.

The following table includes revenue associated with contractual commitments in place related to future performance obligations as of the end of the reporting period, which are expected to be recognized in revenue in the specified periods (in thousands):

	Revenue from
	Contracts with		Revenue from
	Customers(1)		Leases		Total
2022	$	39,697	$	59,647	$	99,344
2023		31,934		47,952		79,886
2024		31,204		47,164		78,368
2025		28,996		41,095		70,091
2026		19,948		24,759		44,707
Thereafter		18,834		22,352		41,186
Total revenue related to future performance obligations	$	170,613	$	242,969	$	413,582

(1) Excluded from the table is revenue that is either constrained or related to performance obligations that are wholly unsatisfied as of December 31, 2021.

F- 9

 

Disaggregation of Revenue

Disaggregation of revenue from contracts with customers by revenue type is presented as follows (in thousands):

	Year ended December 31, 2020
	Revenue from contracts with customers				Lease revenue
	Third-party revenue		Related-party revenue		Third-party revenue		Related-party revenue			Total
Fixed storage and throughput revenue	$	20,303	$	14,531	$	-	$	-	$	34,834
Fixed lease revenue		-		-		32,207		24,547		56,754
Variable cost recovery revenue		6,620		3,076		2,205		763		12,664
Variable throughput and other revenue		2,248		421		2,218		1,106		5,993
Total	$	29,171	$	18,028	$	36,630	$	26,416	$	110,245

	Year ended December 31, 2021
	Revenue from contracts with customers				Lease revenue
	Third-party revenue		Related-party revenue		Third-party revenue		Related-party revenue			Total
Fixed storage and throughput revenue	$	20,315	$	18,883	$	-	$	-	$	39,198
Fixed lease revenue		-		-		31,263		27,142		58,405
Variable cost recovery revenue		8,616		680		1,816		954		12,066
Variable throughput and other revenue		1,784		632		1,986		1,346		5,748
Total	$	30,715	$	20,195	$	35,065	$	29,442	$	115,417

Contract Balances

The timing of revenue recognition, billings and cash collections result in billed accounts receivable and unearned revenue (contract liabilities) on the consolidated balance sheets as noted in the contract discussions above. Accounts receivable are reflected in the line items “Accounts receivable” and “Receivables from related parties” on the consolidated balance sheets. Unearned revenue is included in the line items “Unearned revenue,” “Unearned revenue with related parties,” “Long-term unearned revenue with related parties” and “Other long-term liabilities” on the consolidated balance sheets.

Billed accounts receivable from contracts with customers were $2.1 million and $2.2 million at  December 31, 2020 and 2021, respectively.

The Partnership records unearned revenues when cash payments are received in advance of performance. Unearned revenue related to contracts with customers was $3.2 million and $3.4 million at December 31, 2020 and 2021, respectively. For the year ended December 31, 2021, the Partnership recognized $2.3 million of revenues that were previously included in the unearned revenue balance for services provided during the period.

Practical Expedients and Exemptions

The Partnership does not disclose the value of unsatisfied performance obligations for contracts with an original expected length of one year or less.

F- 10

 

5. DISCONTINUED OPERATIONS

On December 21, 2020, the Partnership announced executed agreements to sell its crude oil trucking services, crude oil pipeline services, and crude oil terminalling services segments. These segments are reported as discontinued operations in the results of operations and financial position for all periods presented. The crude oil trucking services agreement closed in two phases, one on December 15, 2020, and one on February 2, 2021. The crude oil pipeline services agreement closed on February 1, 2021. Loss recognized on the disposal and classification of held for sale of these assets is reflected in the Statement of Operations for Discontinued Operations for the year ended December 31, 2020 below. The transaction related to the crude oil terminalling services segment closed on March 1, 2021. The Partnership has allocated interest on debt that was required to be repaid as a result of the sales of the crude oil pipeline and terminalling services segment for the years ended December 31, 2020 and 2021.

As part of the crude oil pipeline sale, $1.4 million of the gross sale proceeds are currently being held in escrow, subject to post-closing settlement terms and conditions. The Partnership expects to receive the majority of this in increments over the two years following the date of sale.

Exit and disposal costs related to these sales, in the form of employee severance payments, totaled $1.9 million. The Partnership provided limited transition services to both of the buyers of the crude oil pipeline and terminalling services segments, with the final transition services being completed during the third quarter of 2021. The contracts were designed to recover the costs of providing services, so there is minimal income statement impact for these services.

During the year ended December 31, 2020, prior to entering into the executed agreements, the Partnership recorded a $1.3 million impairment on the crude oil trucking segment based on the expected future cash flows and market interest of the segment compared to the carrying value of its assets. In addition, an impairment of $4.9 million was recognized in the first quarter of 2020 to write-down the value of the Partnership's crude oil linefill based on the market price of crude oil as of March 31, 2020. 
 

Assets and Liabilities of Discontinued Operations (in thousands)	As of December 31, 2020
	Crude Oil Trucking Services		Crude Oil Pipeline Services		Crude Oil Terminalling Services		Total
ASSETS
Accounts receivable, net	$	81	$	13,711	$	167	$	13,959
Plant, property, and equipment		442		23,541		52,854		76,837
Other assets		331		547		5,271		6,149
Total assets of discontinued operations	$	854	$	37,799	$	58,292	$	96,945
LIABILITIES
Current liabilities	$	1,017	$	14,921	$	1,310	$	17,248
Total liabilities of discontinued operations	$	1,017	$	14,921	$	1,310	$	17,248

Assets and Liabilities of Discontinued Operations (in thousands)	As of December 31, 2021
	Crude Oil Trucking Services		Crude Oil Pipeline Services		Crude Oil Terminalling Services		Total
ASSETS
Other Assets	$	-	$	1	$	1	$	2
Total assets of discontinued operations	$	-	$	1	$	1	$	2
LIABILITIES
Current liabilities	$	12	$	218	$	10	$	240
Total liabilities of discontinued operations	$	12	$	218	$	10	$	240

F- 11

 

Statement of Operations for Discontinued Operations (in thousands)
	Year ended December 31, 2020
	Crude Oil Trucking Services			Crude Oil Pipeline Services			Crude Oil Terminalling Services			Total
Revenue:
Third-party service revenue	$	5,293		$	1,689		$	16,856		$	23,838
Intercompany service revenue		5,587			-			-			5,587
Third-party product sales revenue		-			157,544			-			157,544
Costs and expenses:
Operating expense		12,386			13,427			8,561			34,374
Intercompany operating expense		-			5,587			-			5,587
Cost of product sales		-			52,624			-			52,624
Cost of product sales from related party		-			86,247			-			86,247
General and administrative expense		284			385			-			669
Asset impairment expense		1,330			2,821			2,266			6,417
Gain on sale of assets		(11	)		(445	)		(734	)		(1,190	)
Interest expense		11			960			4,348			5,319
Loss on disposal/classification as held for sale(1)		1,847			37,249			-			39,096
Income (loss) before income taxes		(4,967	)		(39,622	)		2,415			(42,174	)
Provision for income taxes		3			(2	)		-			1
Net income (loss) from discontinued operations	$	(4,970	)	$	(39,620	)	$	2,415		$	(42,175	)

(1) Included in the crude oil trucking services segment is a loss on disposal recorded during December 2020 for the first phase closing of $1.1 million, and a loss on the classification on assets held for sale as of December 31, 2020, for the second phase closing on February 2, 2021, of $0.7 million.

Statement of Operations for Discontinued Operations (in thousands)	Year ended December 31, 2021
	Crude Oil Trucking Services			Crude Oil Pipeline Services			Crude Oil Terminalling Services			Total
Revenue:
Third-party service revenue	$	9		$	535		$	5,097		$	5,641
Intercompany service revenue		409			-			-			409
Third-party product sales revenue		-			15,591			-			15,591
Costs and expenses:
Operating expense		1,416			1,564			2,189			5,169
Intercompany operating expense		-			409			-			409
Cost of product sales		-			4,994			-			4,994
Cost of product sales from related party		-			9,461			-			9,461
General and administrative expense		61			112			-			173
Tangible asset impairment expense		92			40			23			155
(Gain) loss on disposal of assets		23			(1,720	)		(73,499	)		(75,196	)
Interest expense		-			72			635			707
Income (loss) before income taxes		(1,174	)		1,194			75,749			75,769
Provision for income taxes		(3	)		-			-			(3	)
Net income (loss) from discontinued operations	$	(1,171	)	$	1,194		$	75,749		$	75,772

Select Cash Flow Information (in thousands)
	Crude Oil Trucking Services		Crude Oil Pipeline Services		Crude Oil Terminalling Services		Total
	Year ended December 31, 2020
Depreciation and amortization	$	719	$	4,550	$	4,383	$	9,652
Capital expenditures	$	2,074	$	4,555	$	720	$	7,349
	Year ended December 31, 2021
Amortization	$	3	$	14	$	41	$	58
Capital expenditures	$	-	$	30	$	106	$	136

F- 12

 

6. PROPERTY, PLANT AND EQUIPMENT

	Estimated
	Useful Lives		As of December 31,
	(Years)		2020			2021
			(dollars in thousands)
Land		N/A	$	21,826		$	21,826
Land improvements		10-20		5,024			5,125
Storage and terminal facilities		10-35		249,977			257,433
Office property and equipment and other		3-30		23,278			21,751
Construction-in-progress		N/A		2,165			4,355
Property, plant and equipment, gross				302,270			310,490
Accumulated depreciation				(197,561	)		(204,101	)
Property, plant and equipment, net			$	104,709		$	106,389

Property, plant and equipment under operating leases at December 31, 2021, in which the Partnership is the lessor, had a cost basis of $305.4 million and accumulated depreciation of $199.3 million.

Depreciation expense for the years ended  December 31, 2020 and 2021, was $11.0 million and $9.4 million, respectively.

7. INTANGIBLE ASSETS, NET

Intangible assets, net of accumulated amortization, consist of the following: 

	As of December 31,
	2020			2021
	(in thousands)
Customer contracts	$	16,022		$	16,022
Accumulated amortization of intangible assets		(8,491	)		(10,934	)
Intangible assets, net	$	7,531		$	5,088

Amortization expense related to intangibles for each of the years ended December 31, 2020 and 2021, was $2.4 million. The estimated aggregate future amortization expense on amortizable intangible assets currently owned by the Partnership is as follows (in thousands):

For year ending:
December 31, 2022	$	4,033
December 31, 2023		387
December 31, 2024		387
December 31, 2025		281
December 31, 2026		-
Thereafter		-
Total estimated aggregate amortization expense	$	5,088

Customer contracts include $7.6 million and $8.4 million related to the acquisition of asphalt facilities in March 2018 and February 2016, respectively. The customer contracts are being amortized over a range of 5 to 10 years. 

F- 13

 

8. DEBT

On May 26, 2021, the Partnership entered into an amended and restated credit agreement with a revolving loan facility from $300.0 million. As of  March 1, 2022, approximately $110.0 million of revolver borrowings and $0.6 million of letters of credit were outstanding under the credit agreement, leaving the Partnership with available capacity of approximately $189.4 million for additional revolver borrowings and letters of credit under the credit agreement, although the Partnership’s ability to borrow such funds may be limited by the financial covenants in the credit agreement. The proceeds of loans made under the credit agreement may be used for working capital and other general corporate purposes of the Partnership.

The credit agreement is guaranteed by all of the Partnership’s existing subsidiaries. Obligations under the credit agreement are secured by first priority liens on substantially all of the Partnership’s assets and those of the guarantors.

The credit agreement includes procedures for additional financial institutions to become revolving lenders, or for any existing lender to increase its revolving commitment thereunder, subject to an aggregate maximum of $450.0 million for all revolving loan commitments under the credit agreement.

The credit agreement will mature on May 26, 2025, and all amounts outstanding under the credit agreement will become due and payable on such date. The credit agreement requires mandatory prepayments of amounts outstanding thereunder with the net proceeds from certain asset sales, property or casualty insurance claims and condemnation proceedings, unless the Partnership reinvests such proceeds in accordance with the credit agreement, but these mandatory prepayments will not require any reduction of the lenders’ commitments under the credit agreement.

Borrowings under the credit agreement bear interest, at the Partnership’s option, at either the reserve-adjusted eurodollar rate (as defined in the credit agreement) (“eurodollar rate”) plus an applicable margin which ranges from 2.0% to 3.25% or the alternate base rate (the highest of the agent bank’s prime rate, the federal funds effective rate plus 0.5% and the 30-day eurodollar rate plus 1.0%) plus an applicable margin which ranges from 1.0% to 2.25%. The Partnership pays a per annum fee on all letters of credit issued under the credit agreement, which fee equals the applicable margin for loans accruing interest based on the eurodollar rate, and the Partnership pays a commitment fee ranging from 0.375% to 0.5% on the unused commitments under the credit agreement. The applicable margins for the Partnership’s interest rate, the letters of credit fee and the commitment fee vary quarterly based on the Partnership’s consolidated total leverage ratio (as defined in the credit agreement, being generally computed as the ratio of consolidated total debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges).

The credit agreement includes financial covenants which are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter.

Prior to the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million, the maximum permitted consolidated total leverage ratio is 4.75 to 1.00; provided that the maximum permitted consolidated total leverage ratio may be increased to 5.25 to 1.00 for certain quarters, based on the occurrence of a specified acquisition (as defined in the credit agreement, but generally being an acquisition for which the aggregate consideration is $15.0 million or more).

From and after the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million, the maximum permitted consolidated total leverage ratio is 5.00 to 1.00; provided that from and after the fiscal quarter ending immediately preceding the fiscal quarter in which a specified acquisition occurs, to and including the last day of the second full fiscal quarter following the fiscal quarter in which such acquisition occurred, the maximum permitted consolidated total leverage ratio is 5.50 to 1.00.

The maximum permitted consolidated senior secured leverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated total secured debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) is 3.50 to 1.00, but this covenant is only tested from and after the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million.

The minimum permitted consolidated interest coverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges to consolidated interest expense) is 2.50 to 1.00.

F- 14

 

In addition, the credit agreement contains various covenants that, among other restrictions, limit the Partnership’s ability to:

• create, issue, incur or assume indebtedness;

• create, incur or assume liens;

• consummate mergers or acquisitions;

• sell, transfer, assign or convey assets;

• repurchase the Partnership’s equity, make distributions to unitholders and make certain other restricted payments;

• make investments;

• modify the terms of certain indebtedness, or prepay certain indebtedness;

• engage in transactions with affiliates;

• enter into certain hedging contracts;

• enter into certain burdensome agreements;

• change the nature of the Partnership’s business; and

• make certain amendments to the Partnership’s partnership agreement.

At December 31, 2021, the Partnership’s consolidated total leverage ratio was 1.84 to 1.00 and the consolidated interest coverage ratio was 15.79 to 1.00. The Partnership was in compliance with all covenants of its credit agreement as of December 31, 2021. The Partnership was in compliance with all covenants of its credit agreement as of December 31, 2021. Based on current operating plans and forecasts, the Partnership expects to remain in compliance with all covenants of the credit agreement for at least the next year.

The credit agreement permits the Partnership to make quarterly distributions of available cash (as defined in the Partnership’s partnership agreement) to unitholders so long as, on a pro forma basis after giving effect to such distributions, the Partnership is in compliance with its financial covenants under the credit agreement and no default or event of default exists under the credit agreement. Additionally, the credit agreement permits the Partnership to repurchase up to an aggregate of $40.0 million of its units (including Preferred Units), up to $10.0 million for each calendar year, so long as, on a pro forma basis after giving effect to such repurchases, the Partnership’s total leverage ratio is less than 4.00 to 1.00, no default or event of default exists under the credit agreement, and availability under the revolving credit facility is at least 20% of the total commitments thereunder.

In addition to other customary events of default, the credit agreement includes an event of default if:

(i) the general partner ceases to own 100% of the Partnership’s general partner interest or ceases to control the Partnership;

(ii) Ergon ceases to own and control 50.0% or more of the membership interests of the general partner; or

(iii) during any period of 12 consecutive months, a majority of the members of the Board of the general partner ceases to be composed of individuals:

(A) who were members of the Board on the first day of such period;

(B) whose election or nomination to the Board was approved by individuals referred to in clause (A) above constituting at the time of such election or nomination at least a majority of the Board; or

(C) whose election or nomination to the Board was approved by individuals referred to in clauses (A) and (B) above constituting at the time of such election or nomination at least a majority of the Board, provided that any changes to the composition of individuals serving as members of the Board approved by Ergon will not cause an event of default.

F- 15

 

If an event of default relating to bankruptcy or other insolvency events occurs with respect to the general partner or the Partnership, all indebtedness under the credit agreement will immediately become due and payable. If any other event of default exists under the credit agreement, the lenders may accelerate the maturity of the obligations outstanding under the credit agreement and exercise other rights and remedies. In addition, if any event of default exists under the credit agreement, the lenders may commence foreclosure or other actions against the collateral.

If any default occurs under the credit agreement, or if the Partnership is unable to make any of the representations and warranties in the credit agreement, the Partnership will be unable to borrow funds or have letters of credit issued under the credit agreement. 

On May 26, 2021, as part of the credit agreement refinancing, there was a non-cash increase in credit borrowings of $2.9 million and a non-cash increase in debt issuance costs of $2.5 million.

The following table sets forth financial information pertaining to the credit agreement (dollars in thousands):

	Year Ended December 31,
	2020			2021
Debt issuance costs capitalized	$	-		$	3,100
Write-off of debt issuance costs due to amendments	$	-		$	147
Write-off of debt issuance costs due to new credit facility	$	-		$	583
Interest expense related to amortization of debt issuance costs	$	1,004		$	856
Credit facility interest expense(1)	$	4,611		$	3,350
Weighted average interest rate under credit facility(1)		3.97	%		3.70	%

(1) Excludes interest expense related to amortization and write-off of debt issuance costs for the year ending December 31, 2021.

9. NET INCOME PER LIMITED PARTNER UNIT

For purposes of calculating earnings per unit, Preferred Units, general partner units, and common units are first allocated net income to the extent they receive a distribution. Next, the excess of distributions over earnings or excess of earnings over distributions for each period are allocated to the Partnership’s general partner based on the general partner’s ownership interest at the time. For the year ended December 31, 2021, the Preferred Units were also allocated income for the excess consideration paid over carrying value for the repurchase of Preferred Units. The remainder is allocated to common units. The following sets forth the computation of basic and diluted net income per common unit (in thousands, except per unit data):

	Year ended December 31,
	2020			2021
Net income (loss)	$	(13,480	)	$	110,530
General partner interest in net income (loss)		(213	)		1,751
Preferred interest in net income		25,115			24,824
Net income (loss) available to limited partners	$	(38,382	)	$	83,955
Basic and diluted weighted average number of units:
Common units		41,104			41,484
Restricted and phantom units		1,285			1,453
Total units		42,389			42,937
Basic and diluted net income (loss) from discontinued operations per common unit	$	(0.98	)	$	1.74
Basic and diluted net income from continuing operations per common unit	$	0.07		$	0.22
Basic and diluted net income (loss) per common unit	$	(0.91	)	$	1.96

F- 16

 

10. PARTNERS’ CAPITAL (DEFICIT) AND DISTRIBUTIONS

In accordance with the terms of its partnership agreement, each quarter the Partnership distributes all of its available cash (as defined in the partnership agreement) to its unitholders. Generally, distributions are allocated as follows:

• first, 98.4% to the preferred unitholders and 1.6% to its general partner until the Partnership distributes for each Preferred Unit an amount equal to the Preferred Units quarterly distribution amount discussed below;

• second, 98.4% to the preferred unitholders and 1.6% to its general partner until the Partnership distributes for each Preferred Unit an amount equal to any Preferred Units cumulative distribution arrearage; and

• thereafter, 98.4% to the common unitholders and 1.6% to its general partner until the common unitholders receive the minimum quarterly distribution of $0.11 per unit.

The Preferred Units are convertible at the holders’ option into common units. Holders of the Preferred Units are entitled to quarterly distributions of $0.17875 per unit per quarter. If the Partnership fails to pay in full any distribution on the Preferred Units, the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full.

The general partner receives incentive distribution rights. Incentive distribution rights represent the right to receive an increasing percentage (13.0%, 23.0% and 48.0%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels have been achieved. The general partner currently holds the incentive distribution rights, but may transfer these rights separately from its general partner interest, subject to restrictions in the partnership agreement. If for any quarter:

• the Partnership has distributed available cash from operating surplus to the holders of our Preferred Units in an amount equal to the Preferred Units quarterly distribution amount;

• the Partnership has distributed available cash from operating surplus to the holders of our Preferred Units in an amount necessary to eliminate any cumulative arrearages in the payment of the Preferred Units quarterly distribution amount; and

• the Partnership has distributed available cash from operating surplus to the common unitholders and Class B unitholders in an amount equal to the minimum quarterly distribution;

then the partnership agreement requires that the Partnership distribute any additional available cash from operating surplus for that quarter among the unitholders and the general partner in the following manner:

• first, 98.4% to all unitholders holding common units or Class B units, pro rata, and 1.6% to the general partner, until each unitholder receives a total of $0.1265 per unit for that quarter (the “first target distribution”);

• second, 85.4% to all unitholders holding common units or Class B units, pro rata, and 14.6% to the general partner, until each unitholder receives a total of $0.1375 per unit for that quarter (the “second target distribution”);

• third, 75.4% to all unitholders holding common units or Class B units, pro rata, and 24.6% to the general partner, until each unitholder receives a total of $0.1825 per unit for that quarter (the “third target distribution”); and

• thereafter, 50.4% to all unitholders holding common units or Class B units, pro rata, and 49.6% to the general partner.

Distributions are also paid to the holders of restricted units and phantom units as disclosed in Note 13.

The Partnership paid the following distributions on the Preferred Units during the years ended  December 31, 2020 and 2021 (in thousands):

Year				Paid to Preferred		Partner
Paid	Periods Covered	Total		Unitholders		Paid to General
2020	Quarters ending December 31, 2019, March 31, 2020, June 30, 2020 and September 30, 2020	$	25,519	$	25,115	$	404
2021	Quarters ending December 31, 2020, March 31, 2021, June 30, 2021 and September 30, 2021	$	25,138	$	24,740	$	398

In addition, on January 25, 2022, the Board approved a cash distribution of $0.17875 per outstanding Preferred Unit for the quarter ending December 31, 2021. The Partnership paid this distribution on the Preferred Units on February 14, 2022, to unitholders of record as of February 7, 2022. The total distribution was approximately $6.2 million, with approximately $6.2 million and $0.1 million paid to the Partnership’s preferred unitholders and general partner, respectively.

F- 17

 

The Partnership paid the following distributions on the common units during the years ended  December 31, 2020 and 2021 (in thousands):

Year				Paid to Common		Paid to General		Paid to Phantom and Restricted Unitholders Under
Paid	Periods Covered	Total		Unitholders		Partner		the LTIP
2020	Quarters ending December 31, 2019, March 31, 2020, June 30, 2020 and September 30, 2020	$	6,887	$	6,576	$	109	$	202
2021	Quarters ending December 31, 2020, March 31, 2021, June 30, 2021 and September 30, 2021	$	6,977	$	6,637	$	111	$	229

In addition, on January 25, 2022, the Board approved a cash distribution of $0.0425 per outstanding common unit for the quarter ending December 31, 2021. The distribution was paid on February 14, 2022, to unitholders of record as of February 7, 2022. The total distribution was approximately $1.9 million, with approximately $1.8 million paid to the Partnership’s common unitholders and less than $0.1 million paid to the both the Partnership’s general partner and holders of phantom and restricted units pursuant to awards granted under the LTIP.

11. MAJOR CUSTOMERS AND CONCENTRATION OF CREDIT RISK

Significant customers are defined as those who represent 10% or more of our total consolidated revenues during the year.

For the year ended December 31, 2021, Ergon accounted for approximately 43% of the Partnership’s total revenues. In addition, two third-party customers accounted for 14% and 13% of the Partnership’s total revenues.

For the year ended December 31, 2020, Ergon accounted for approximately 40% of the Partnership’s total revenues. In addition, two third-party customers accounted for 12% and 15% of the Partnership’s total revenues.

12. RELATED-PARTY TRANSACTIONS

The Partnership leases facilities to Ergon and provides liquid asphalt terminalling services to Ergon. For the years ended December 31, 2020 and 2021, the Partnership recognized revenues of $44.4 million and $49.6 million, respectively, for services provided to Ergon. See additional discussion below regarding material asphalt operating lease contracts and storage, throughput and handling contracts. As of December 31, 2020 and 2021, the Partnership had receivables from Ergon of $0.5 million and $0.4 million, respectively. 

As of December 31, 2020 and 2021, the Partnership has unearned revenues from Ergon of $8.8 million and $9.3 million, respectively, which primarily relates to cash received in December for the following  January lease and storage fees, and capital project reimbursements and deductibles that are being recognized straight-line over the term of the existing revenue contracts. 

Effective April 1, 2018, the Partnership entered into an agreement with Ergon under which the Partnership purchases crude oil in connection with its crude oil marketing operations. For the years ended December 31, 2020 and 2021, the Partnership made purchases of crude oil under this agreement totaling $92.1 million and $9.5 million, respectively. This agreement terminated upon the closing of the sale of the crude oil pipeline services business on February 1, 2021.

As of December 31, 2019, the Partnership had a contingent liability to Ergon of $12.2 million related to the Cimarron Express project, a previously disclosed joint venture between Kingfisher Midstream and Ergon's development company (“DEVCO”) that was cancelled in December 2018. The contingent liability reflected Ergon's investment in the joint venture and accrued interest, for which the Partnership, in accordance with the membership interest purchase agreement with Ergon, was meant to bear the risk of loss related to DEVCO’s portion of the project. The Partnership paid this liability in full on January 3, 2020, and it is reflected as an acquisition of the DEVCO on the consolidated statement of cash flows for the year ended December 31, 2020.

Ergon 2020 Master Storage, Throughput and Handling Agreement

In August 2020, the Partnership and Ergon entered into the “2020 Master Storage, Throughput and Handling Agreement”, effective August 1, 2020, which replaced the three agreements noted below and all related amendments. Pursuant to this agreement, the Partnership provides Ergon with storage and terminalling services at 22 facilities through December 31, 2027. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the years ended December 31, 2020 and 2021, the Partnership generated revenues under this agreement of $16.8 million and $39.5 million, respectively.

F- 18

 

Ergon Operating and Maintenance Agreement

In August 2020, the Partnership and Ergon also entered into the Operating and Maintenance Agreement, effective August 1, 2020, pursuant to which Ergon will provide certain operations and maintenance services to the 22 facilities also under the 2020 Master Storage, Throughput and Handling Agreement through  December 31, 2025, with automatic one-year renewals unless either party cancels. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the years ended December 31, 2020 and 2021, the Partnership recognized expense under this agreement of $7.7 million and $18.6 million, respectively.

Ergon Lessee Operated Facility Lease Agreement and Previous Agreements

In March 2019, the Partnership and Ergon entered into a facilities lease agreement (the “Ergon Lessee Operated Facility Lease Agreement”) covering 12 facilities. The facilities covered by this agreement were previously accounted for under two separate agreements. This agreement was effective January 1, 2019, and on August 1, 2020, was replaced with the Ergon 2020 Master Storage, Throughput and Handling Agreement discussed above. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the year ended December 31, 2020, the Partnership generated revenues under this agreement of $4.4 million.

Ergon 2016 Storage and Handling Agreement

In October 2016, the Partnership and Ergon entered into a storage, throughput and handling agreement (the “Ergon 2016 Storage and Handling Agreement”) pursuant to which the Partnership provides Ergon storage and terminalling services at nine asphalt facilities. In July 2018, the Partnership sold one of the facilities to Ergon and the agreement was amended accordingly. The term of the Ergon 2016 Storage, Throughput and Handling Agreement commenced on October 5, 2016, and in August 2020, was replaced with the Ergon 2020 Master Storage, Throughput and Handling Agreement discussed above. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the year ended  December 31, 2020, the Partnership generated revenue under this agreement of $12.0 million.

Ergon Fontana and Las Vegas Storage Throughput and Handling Agreement

In October 2016, the Partnership and Ergon entered into a storage, throughput and handling agreement (the “Ergon Fontana and Las Vegas Storage Throughput and Handling Agreement”) pursuant to which the Partnership provides Ergon storage and terminalling services at two asphalt facilities. The original Ergon Fontana and Las Vegas Master Facilities Lease Agreement commenced on May 18, 2009, and was a part of previous agreement that expired in 2018. A new agreement was executed in March 2019 with an effective date of January 1, 2019, and, on  August 1, 2020, was replaced with the Ergon 2020 Master Storage, Throughput and Handling Agreement discussed above. The Board’s conflicts committee reviewed and approved these agreements in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the year ended December 31, 2020, the Partnership generated revenues under this agreement of $3.5 million.

F- 19

 

13. LONG-TERM INCENTIVE PLAN

In July 2007, the general partner adopted the LTIP, which is administered by the compensation committee of the Board. The Partnership’s unitholders have approved 8.1 million common units to be reserved for issuance under the incentive plan, subject to adjustment for certain events. Although other types of awards are contemplated under the LTIP, currently outstanding awards include “phantom” units, which convey the right to receive common units upon vesting, and “restricted” units, which are grants of common units restricted until the time of vesting. The phantom unit awards also include DERs.

Subject to applicable earning criteria, a DER entitles the grantee to a cash payment equal to the cash distribution paid on an outstanding common unit prior to the vesting date of the underlying award. Recipients of restricted and phantom units are entitled to receive cash distributions paid on common units during the vesting period which are reflected initially as a reduction of partners’ capital. Distributions paid on units that ultimately do not vest are reclassified as compensation expense. Awards granted to date are equity awards and, accordingly, the fair value of the awards as of the grant date is expensed over the vesting period. 

Each year, restricted common units are granted to the independent directors. The directors may receive units that do have vesting requirements and units that do not have vesting requirements. In December 2021, the directors received 21,228 units with a grant date fair value of $3.26 per unit and a total grant date fair value of $0.1 million, that do not have a vesting requirement. In December 2019, 2020, and 2021, the directors also received units that vest in one-third increments over three years. The following table includes information on outstanding grants made to the directors under the LTIP subject to vesting requirements:

			Weighted Average		Grant Date Total Fair
	Number of		Grant Date Fair		Value
Grant Date	Units		Value		(in thousands)
December 2019		7,500	$	1.07	$	8
December 2020		7,500	$	2.06	$	15
December 2021		22,743	$	3.26	$	74

The Partnership also grants phantom units to employees. These grants are equity awards under ASC 718 – Stock Compensation and, accordingly, the fair value of the awards as of the grant date is expensed over the vesting period. The following table includes information on the outstanding grants:

			Weighted Average		Grant Date Total Fair
	Number of		Grant Date Fair		Value
Grant Date	Units		Value		(in thousands)
March 2019		524,997	$	1.14	$	598
June 2019		46,168	$	1.08	$	50
March 2020		600,396	$	0.90	$	540
October 2020		16,339	$	1.53	$	25
March 2021		530,435	$	2.71	$	1,437

F- 20

 

Compensation expense for the equity awards is calculated as the number of unit awards less forfeitures, multiplied by the grant date fair value of those awards. The Partnership estimates forfeiture rates based on historical forfeitures under the LTIP. The unrecognized estimated compensation cost relating to outstanding phantom and restricted units at  December 31, 2021 was $1.1 million, which will be recognized over the remaining vesting period. On January 1, 2022, 426,297 units of the March 2019 grant vested. 

The Partnership’s equity-based incentive compensation expense for each of the years ended  December 31, 2020 and 2021, was $0.8 million.

Activity pertaining to phantom common units and restricted common unit awards granted under the LTIP is as follows:

	Number of		Grant Date Fair
	Units		Value
Nonvested, December 31, 2020		1,350,366	$	1.81
Granted		574,406		2.75
Vested		369,482		4.00
Forfeited		-		-
Nonvested, December 31, 2021		1,555,290	$	1.66

14. EMPLOYEE BENEFIT PLAN

Under the Partnership’s 401(k) Plan, which was instituted in 2009, employees who meet specified service requirements may contribute a percentage of their total compensation, up to a specified maximum, to the 401(k) Plan. The Partnership  may match each employee’s contribution, up to a specified maximum, in full or on a partial basis. The Partnership recognized expense of $0.6 million and $0.5 million for the years ended December 31, 2020 and 2021, respectively, for discretionary contributions under the 401(k) Plan.

The Partnership may also make annual lump-sum contributions to the 401(k) Plan irrespective of the employee’s contribution match. The Partnership may make a discretionary annual contribution in the form of profit sharing calculated as a percentage of an employee’s eligible compensation. This contribution is retirement income under the qualified 401(k) Plan. Annual profit sharing contributions to the 401(k) Plan are submitted to the Board for approval. The Partnership recognized expense of $0.6 million and $0.5 million for the years ended December 31, 2020 and 2021, respectively, for discretionary profit sharing contributions under the 401(k) Plan.

Under the Partnership’s Employee Unit Purchase Plan (the “EUPP”), which was instituted in January 2015, employees have the opportunity to acquire or increase their ownership of common units representing limited partner interests in the Partnership. Eligible employees who enroll in the EUPP may elect to have a designated whole percentage, up to a specified maximum, of their eligible compensation for each pay period withheld for the purchase of common units at a discount to the then current market value. A maximum of 1,000,000 common units may be delivered under the EUPP, subject to adjustment for a recapitalization, split, reorganization, or similar event pursuant to the terms of the EUPP. Expense for the EUPP was immaterial for both 2020 and 2021.

15. COMMITMENTS AND CONTINGENCIES

The Partnership is from time to time subject to various legal actions and claims incidental to its business. Management believes that these legal proceedings will not have a material adverse effect on the financial position, results of operations or cash flows of the Partnership. Once management determines that information pertaining to a legal proceeding indicates that it is probable that a liability has been incurred and the amount of such liability can be reasonably estimated, an accrual is established equal to its estimate of the likely exposure.

The Partnership has contractual obligations to perform dismantlement and removal activities in the event that some of its liquid asphalt terminalling assets are abandoned. These obligations include varying levels of activity, including completely removing the assets and returning the land to its original state. The Partnership has determined that the settlement dates related to the retirement obligations are indeterminate. The assets with indeterminate settlement dates have been in existence for many years and with regular maintenance will continue to be in service for many years to come. Also, it is not possible to predict when demands for the Partnership’s terminalling services will cease, and the Partnership does not believe that such demand will cease in the foreseeable future. Accordingly, the Partnership believes the date when these assets will be abandoned is indeterminate. With no reasonably determinable abandonment date, the Partnership cannot reasonably estimate the fair value of the associated asset retirement obligations. Management believes that if the Partnership’s asset retirement obligations were settled in the foreseeable future, the potential cash flows that would be required to settle the obligations based on current costs are not material. The Partnership will record asset retirement obligations for these assets in the period in which sufficient information becomes available for it to reasonably determine the settlement dates.

F- 21

 

16. ENVIRONMENTAL REMEDIATION

The Partnership maintains insurance of various types with varying levels of coverage that it considers adequate under the circumstances to cover its operations and properties. The insurance policies are subject to deductibles and retention levels that the Partnership considers reasonable and not excessive. Consistent with insurance coverage generally available in the industry, in certain circumstances the Partnership’s insurance policies provide limited coverage for losses or liabilities relating to gradual pollution, with broader coverage for sudden and accidental occurrences. Although the Partnership maintains a program designed to prevent and, as applicable, to detect and address such releases promptly, damages and liabilities incurred due to environmental releases from its assets may substantially affect its business.

At December 31, 2020 and 2021, the Partnership was aware of existing conditions that may cause it to incur expenditures in the future for the remediation of existing environmental matters. The Partnership had no environmental remediation loss contingencies as of December 31, 2020 and 2021. Changes in the Partnership’s estimates and assumptions may occur as a result of the passage of time and the occurrence of future events.

17. FAIR VALUE MEASUREMENTS

The Partnership uses valuation techniques, such as the market approach (comparable market prices), the income approach (present value of future income or cash flow) and the cost approach (cost to replace the service capacity of an asset or replacement cost) to value these assets and liabilities as appropriate. The Partnership uses an exit price when determining the fair value. The exit price represents amounts that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants.

The Partnership utilizes a three-tier fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:

Level 1 Observable inputs such as quoted prices (unadjusted) in active markets for identical assets or liabilities.

Level 2 Inputs other than quoted prices that are observable for these assets or liabilities, either directly or indirectly. These include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active.

Level 3 Unobservable inputs in which there is little market data, which requires the reporting entity to develop its own assumptions.

This hierarchy requires the use of observable market data, when available, to minimize the use of unobservable inputs when determining fair value. In periods in which they occur, the Partnership recognizes transfers into and out of Level 3 as of the end of the reporting period. Transfers out of Level 3 represent existing assets and liabilities that were classified previously as Level 3 for which the observable inputs became a more significant portion of the fair value estimates. Determining the appropriate classification of the Partnership’s fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data.

Fair Value of Other Financial Instruments

The following disclosure of the estimated fair value of financial instruments is made in accordance with accounting guidance for financial instruments. The Partnership has determined the estimated fair values by using available market information and valuation methodologies. Considerable judgment is required in interpreting market data to develop the estimates of fair value. The use of different market assumptions or valuation methodologies may have a material effect on the estimated fair value amounts.

At December 31, 2021, the carrying values on the consolidated balance sheets for cash and cash equivalents (classified as Level 1), accounts receivable and accounts payable approximate their fair value because of their short-term nature.

Based on the borrowing rates currently available to the Partnership for credit agreement debt with similar terms and maturities and consideration of the Partnership’s non-performance risk, long-term debt associated with the Partnership’s credit agreement at December 31, 2021, approximates its fair value. The fair value of the Partnership’s long-term debt was calculated using observable inputs (eurodollar rate for the risk-free component) and unobservable company-specific credit spread information. As such, the Partnership considers this debt to be Level 3.

F- 22

 

18. LEASES

The Partnership leases certain office space and land under operating leases. Leases with an initial term of 12 months or less are not recorded on the balance sheet; lease expense for these leases is recognized as paid over the lease term. For real property leases, the Partnership has elected the practical expedient to not separate non-lease components (e.g., common-area maintenance costs) from lease components and to instead account for each component as a single lease component. For leases that do not contain an implicit interest rate, the Partnership uses its most recent incremental borrowing rate.

Some real property leases contain options to renew, with renewal terms that can extend indefinitely. The exercise of such lease renewal options is at the Partnership’s sole discretion. The Partnership determines the lease term at the lease commencement date as the non-cancellable period of the lease, including options to extend or terminate the lease when such an option is reasonably certain to be exercised. The Partnership uses various data to analyze these options, including historical trends, current expectations and useful lives of assets related to the lease. Operating lease assets and liabilities are stated in separate line items on the consolidated balance sheets.

Future commitments, including options to extend lease terms that are reasonably certain of being exercised, related to leases at  December 31, 2021, are summarized below (in thousands):

	Operating Leases
Twelve months ending December 31, 2022	$	1,708
Twelve months ending December 31, 2023		1,615
Twelve months ending December 31, 2024		989
Twelve months ending December 31, 2025		887
Twelve months ending December 31, 2026		869
Thereafter		4,716
Total		10,784
Less: Interest		2,663
Present value of lease liabilities	$	8,121

The following table summarizes the Partnership’s total lease cost by type as well as cash flow information (in thousands):

		Year ended December 31, 2021
	Classification	2020		2021
Total Lease Cost by Type:
Operating lease cost(1)	Operating Expense	$	1,953	$	1,920
Short-term lease cost	Operating Expense		172		122
Net lease cost		$	2,125	$	2,042
Supplemental cash flow disclosures:
Cash paid for amounts included in the measurement of lease liabilities:
Payments on operating leases		$	1,400	$	1,895
Leased assets obtained in exchange for new operating lease liabilities		$	119	$	884

(1) Includes variable lease costs, which are immaterial.

	As of
	December 31,
	2021
Lease Term and Discount Rate
Weighted-average remaining operating lease term (years)		10.0
Weighted-average discount rate		5.5	%

F- 23

 

19. INCOME TAXES

The anticipated after-tax economic benefit of an investment in the Partnership’s common units depends largely on the Partnership being treated as a partnership for federal income tax purposes. If less than 90% of the gross income of a publicly traded partnership, such as the Partnership, for any taxable year is “qualifying income” from sources such as the transportation, marketing (other than to end users), or processing of crude oil, natural gas or products thereof, interest, dividends, or similar sources, that partnership will be taxable as a corporation under Section 7704 of the Internal Revenue Code for federal income tax purposes for that taxable year and all subsequent years.

If the Partnership were treated as a corporation for federal income tax purposes, then it would pay federal income tax on its income at the applicable corporate tax rate in addition to state income tax at varying rates. Distributions would generally be taxed again to unitholders as corporate distributions and none of the Partnership’s income, gains, losses, deductions, or credits would flow through to its unitholders. Because a tax would be imposed upon the Partnership as an entity, cash available for distribution to its unitholders would be substantially reduced. Treatment of the Partnership as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to unitholders and thus would likely result in a substantial reduction in the value of the Partnership’s common units.

The Partnership has entered into storage or lease contracts with third-party customers with respect to substantially all of its asphalt facilities. At the time of entering into such agreements, it was unclear under current tax law as to whether the rental income from the leases, and the fees attributable to certain of the processing services the Partnership provides under certain of the storage contracts, constitute “qualifying income.” In the second quarter of 2009, the Partnership submitted a request for a ruling from the IRS that rental income from the leases constitutes “qualifying income.” In October 2009, the Partnership received a favorable ruling from the IRS. As part of this ruling, however, the Partnership agreed to transfer, and has transferred, certain of its asphalt processing assets and related fee income to a subsidiary taxed as a corporation. This transfer occurred in the first quarter of 2010. Such subsidiary is required to pay federal income tax on its income at the applicable corporate tax rate and will likely pay state (and possibly local) income tax at varying rates. Distributions from this subsidiary will generally be taxed again to unitholders as corporate distributions and none of the income, gains, losses, deductions or credits of this subsidiary will flow through to the Partnership’s unitholders.

F-24

EX-21.1

Exhibit 21.1

List of Subsidiaries

of

Blueknight Energy Partners, L.P.

Name of Subsidiary	State of Organization
BKEP Finance Corporation	Delaware
BKEP Operating, L.L.C.	Delaware
BKEP Management, Inc.	Delaware
BKEP Crude, L.L.C.	Delaware
BKEP Sub, L.L.C.	Delaware
Ergon Oklahoma Pipeline, LLC	Delaware
Blueknight Motor Carrier LLC	Delaware
BKEP Trucking, L.L.C.	Delaware
BKEP Supply and Marketing LLC	Delaware
BKEP Terminal Services LLC	Texas
BKEP Materials, L.L.C.	Texas
BKEP Asphalt, L.L.C.	Texas
Knight Warrior LLC	Texas
BKEP Terminal Holding, L.L.C.	Texas
BKEP Terminalling, L.L.C.	Texas

EX-23.1

Exhibit 23.1

Consent of Independent Registered Public Accounting Firm

We consent to the incorporation by reference in the following Registration Statements:      

1. Form S-8 No. 333-253890 pertaining to the Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan

2. Form S-8 No. 333-202538 pertaining to the Blueknight Energy Partners, L.P. Employee Unit Purchase Plan

3. Form S-8 No. 333-202537 pertaining to the Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan

4. Form S-8 No. 333-177005 pertaining to the Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan

5. Form S-8 No. 333-144737 pertaining to the SemGroup Energy Partners G.P., L.L.C. Long-Term Incentive Plan

of our reports dated March 9, 2022, with respect to the consolidated financial statements of Blueknight Energy Partners, L.P. and the effectiveness of internal control over financial reporting of Blueknight Energy Partners, L.P. included in this Annual Report (Form 10-K) for the year ended December 31, 2021.

/s/ Ernst & Young LLP

Tulsa, Oklahoma

March 9, 2022

EX-31.1

Exhibit 31.1

CERTIFICATION

PURSUANT TO AND IN CONNECTION WITH THE REPORTS

TO BE FILED UNDER SECTION 13 AND 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, D. Andrew Woodward, certify that:

1. I have reviewed this annual report on Form 10-K of Blueknight Energy Partners, L.P.;

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

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

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

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

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

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

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

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

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

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

Date:	March 9, 2022
/s/ D. Andrew Woodward
D. Andrew Woodward
Chief Executive Officer
Blueknight Energy Partners, G.P., L.L.C.,
general partner of Blueknight Energy Partners, L.P.

EX-31.2

Exhibit 31.2

CERTIFICATION

PURSUANT TO AND IN CONNECTION WITH THE REPORTS

TO BE FILED UNDER SECTION 13 AND 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Matthew R. Lewis, certify that:

1. I have reviewed this annual report on Form 10-K of Blueknight Energy Partners, L.P.;

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

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

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

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

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

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

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

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

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

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

Date:	March 9, 2022
/s/ Matthew R. Lewis
Matthew R. Lewis
Chief Financial Officer
Blueknight Energy Partners, G.P., L.L.C.,
general partner of Blueknight Energy Partners, L.P.

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002 (18 U.S.C. SECTION 1350)*

In connection with the Annual Report of Blueknight Energy Partners, L.P., a Delaware limited partnership (the “Partnership”), on Form 10-K for the year ended December 31, 2021 as filed with the Securities and Exchange Commission (the “Report”), each of the undersigned, D. Andrew Woodward, Chief Executive Officer of Blueknight Energy Partners G.P., L.L.C., and Matthew R. Lewis, Chief Financial Officer of Blueknight Energy Partners G.P., L.L.C., certifies, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350), that to his knowledge:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

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

/s/ D. Andrew Woodward

D. Andrew Woodward

Chief Executive Officer

Blueknight Energy Partners G.P., L.L.C.,

general partner of Blueknight Energy Partners, L.P.

March 9, 2022

/s/ Matthew R. Lewis

Matthew R. Lewis

Chief Financial Officer

Blueknight Energy Partners G.P., L.L.C.,

general partner of Blueknight Energy Partners, L.P.

March 9, 2022

* A signed original of this written statement required by Section 906 has been provided to the Partnership and will be retained by the Partnership and furnished to the Securities and Exchange Commission or its staff upon request. The foregoing certification is being furnished to the Securities and Exchange Commission as an exhibit to the Report.

XML

Document And Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2021	Mar. 01, 2022	Jun. 30, 2021
Document Information [Line Items]
Entity Central Index Key	0001392091
Entity Registrant Name	Blueknight Energy Partners, L.P.
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2021
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	001-33503
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	20-8536826
Entity Address, Address Line One	6060 American Plaza, Suite 600
Entity Address, City or Town	Tulsa
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	74135
City Area Code	918
Local Phone Number	237-4000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 144,500,000
Auditor Name	Ernst & Young LLP
Auditor Location	Tulsa, Oklahoma
Auditor Firm ID	42
ICFR Auditor Attestation Flag	true
Common Unit [Member]
Document Information [Line Items]
Title of 12(b) Security	Common Units representing limited partner interests
Trading Symbol	BKEP
Security Exchange Name	NASDAQ
Entity Common Stock, Shares Outstanding		41,856,847
Series A Preferred Unit [Member]
Document Information [Line Items]
Title of 12(b) Security	Series A Preferred Units representing limited partner interests
Trading Symbol	BKEPP
Security Exchange Name	NASDAQ
Entity Common Stock, Shares Outstanding		34,406,683

XML

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 1,172	$ 805
Accounts receivable, net	2,989	3,297
Receivables from related parties, net	369	507
Other current assets	3,112	2,355
Current assets of discontinued operations	2	96,945
Total current assets	7,644	103,909
Property, plant and equipment, net of accumulated depreciation of $197,561 and $204,101 at December 31, 2020 and 2021, respectively	106,389	104,709
Goodwill	6,728	6,728
Debt issuance costs, net	2,854	1,340
Operating lease assets	7,855	8,548
Intangible assets, net	5,088	7,531
Other noncurrent assets	340	252
Total assets	136,898	233,017
Current liabilities:
Accounts payable	2,105	1,635
Accounts payable to related parties	1,047	31
Accrued interest payable	250	274
Accrued property taxes payable	1,660	1,757
Accrued payroll	4,782	4,977
Current operating lease liability	1,418	1,684
Other current liabilities	1,711	1,349
Current liabilities of discontinued operations	240	17,248
Total current liabilities	20,020	35,347
Other long-term liabilities	228	168
Noncurrent operating lease liability	6,703	6,980
Long-term debt	98,000	252,592
Commitments and contingencies (Note 15)
Partners’ capital (deficit):
Common unitholders (41,214,856 and 41,550,681 units issued and outstanding at December 31, 2020 and 2021, respectively)	390,310	312,591
Preferred unitholders (35,125,202 and 34,406,683 units issued and outstanding at December 31, 2020 and 2021, respectively)	248,729	253,923
General partner interest (1.6% interest with 1,225,409 general partner units outstanding at both dates)	(631,482)	(632,737)
Total partners’ capital (deficit)	7,557	(66,223)
Total liabilities and partners’ capital (deficit)	136,898	233,017
Third Party [Member]
Current liabilities:
Unearned revenue	1,932	1,789
Related Party [Member]
Current liabilities:
Unearned revenue	4,875	4,603
Long-term unearned revenue with related parties	$ 4,390	$ 4,153

XML

Consolidated Balance Sheets (Parentheticals) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Accumulated depreciation	$ 204,101	$ 197,561
Common units, issued (in shares)	41,550,681	41,214,856
Common units, outstanding (in shares)	41,550,681	41,214,856
Preferred units, issued (in shares)	34,406,683	35,125,202
Preferred units, outstanding (in shares)	34,406,683	35,125,202
General partner units, interest	1.60%	1.60%
General partner units, outstanding (in shares)	1,225,409	1,225,409

XML

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Total revenue	$ 115,417	$ 110,245
Costs and expenses:
Operating expense	64,203	62,812
General and administrative expense	13,902	14,182
Total costs and expenses	78,105	76,994
Loss on disposal of assets	(195)	(67)
Operating income	37,117	33,184
Other income (expenses):
Other income	2,615	1,169
Interest expense	(4,944)	(5,665)
Income before income taxes	34,788	28,688
Provision for income taxes	30	(7)
Income from continuing operations	34,758	28,695
Gain (loss) from discontinued operations, net	75,772	(42,175)
Net income (loss)	110,530	(13,480)
Allocation of net income (loss) for calculation of earnings per unit:
General partner interest in net income (loss)	1,751	(213)
Preferred interest in net income	24,824	25,115
Net income (loss) available to limited partners	$ 83,955	$ (38,382)
Basic and diluted net income (loss) from discontinued operations per common unit (in dollars per share)	$ 1.74	$ (0.98)
Basic and diluted net income from continuing operations per common unit (in dollars per share)	0.22	0.07
Basic and diluted net income (loss) per common unit (in dollars per share)	$ 1.96	$ (0.91)
Weighted average common units outstanding - basic and diluted (in shares)	41,484	41,104
Third Party [Member]
Revenue	$ 30,715	$ 29,171
Operating Lease, Lease Income, Total	35,065	36,630
Related Party [Member]
Revenue	20,195	18,028
Operating Lease, Lease Income, Total	29,442	26,416
Service [Member] | Third Party [Member]
Revenue	30,715	29,171
Service [Member] | Related Party [Member]
Revenue	$ 20,195	$ 18,028

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Consolidated Statements of Changes in Partners' Capital (Deficit) - USD ($) $ in Thousands	Total	Limited Partner [Member]	Preferred Partner [Member]	General Partner [Member]
Balance at Dec. 31, 2019	$ (21,323)	$ 356,777	$ 253,923	$ (632,023)
Net income (loss)	(13,480)	(38,382)	25,115	(213)
Equity-based incentive compensation	816	804	0	12
Distributions	(32,406)	(6,778)	(25,115)	(513)
Proceeds from sale of common units pursuant to the Employee Unit Purchase Plan	170	170	0	0
Balance at Dec. 31, 2020	(66,223)	312,591	253,923	(632,737)
Net income (loss)	110,530	83,827	24,953	1,750
Equity-based incentive compensation	618	604	0	14
Distributions	(32,115)	(6,866)	(24,740)	(509)
Proceeds from sale of common units pursuant to the Employee Unit Purchase Plan	154	154	0	0
Repurchase of Preferred Units	(5,407)	0	(5,407)	0
Balance at Dec. 31, 2021	$ 7,557	$ 390,310	$ 248,729	$ (631,482)

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Consolidated Statements of Changes in Partners' Capital (Deficit) (Parentheticals) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Limited Partner [Member]
Common units issued pursuant to the Employee Unit Purchase Plan (in shares)	77,654	158,326

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Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Cash flows from operating activities:
Net income (loss)	$ 110,530	$ (13,480)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	11,949	23,068
Amortization and write-off of debt issuance costs	1,586	1,004
Loss on disposal/classification of held for sale for discontinued operations	0	39,096
Tangible asset impairment charge	156	6,416
Gain on sale of assets	(75,001)	(1,123)
Gain from insurance settlement related to investing activities	(1,059)	0
Equity-based incentive compensation	618	816
Changes in assets and liabilities:
Decrease in accounts receivable	14,265	6,461
Decrease in receivables from related parties	138	603
Decrease in other current assets	2,318	4,094
Decrease in other non-current assets	1,417	2,324
Decrease in accounts payable	(311)	(557)
Increase (decrease) in payables to related parties	1	(1,792)
Increase (decrease) in accrued interest payable	305	(19)
Decrease in accrued property taxes	(612)	(671)
Decrease in unearned revenue	(471)	(1,618)
Increase (decrease) in accrued payroll	(1,649)	1,617
Decrease in other accrued liabilities	(1,718)	(2,223)
Net cash provided by operating activities	49,329	61,167
Cash flows from investing activities:
Acquisition of DEVCO from Ergon (Note 12)	0	(12,221)
Capital expenditures	(8,429)	(16,332)
Proceeds from sale of assets	155,249	5,896
Proceeds from insurance settlement related to investing activities	1,059	0
Net cash provided by (used in) investing activities	147,879	(22,657)
Cash flows from financing activities:
Payments on other financing activities	(1,384)	(3,027)
Debt issuance costs	(575)	0
Borrowings under credit agreement	98,486	228,000
Payments under credit agreement	(256,000)	(231,000)
Repurchase of Preferred Units	(5,407)	0
Proceeds from equity issuance	154	170
Distributions	(32,115)	(32,406)
Net cash used in financing activities	(196,841)	(38,263)
Net increase in cash and cash equivalents	367	247
Cash and cash equivalents at beginning of period	805	558
Cash and cash equivalents at end of period	1,172	805
Supplemental disclosure of non-cash financing and investing cash flow information:
Non-cash changes in property, plant and equipment	2,765	(259)
Increase in accrued liabilities related to insurance premium financing agreement	1,208	2,324
Cash paid for interest, net of amounts capitalized	4,098	10,009
Cash paid for income taxes	37	30
Third Party [Member]
Changes in assets and liabilities:
Increase (decrease) in accrued crude oil purchases	(3,868)	(2,838)
Related Party [Member]
Changes in assets and liabilities:
Increase (decrease) in accrued crude oil purchases	(8,842)	(2,965)
Decrease in unearned revenue	$ (423)	$ 2,954

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Note 1 - Organization and Nature of Business	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Business Description and Basis of Presentation [Text Block]	1. ORGANIZATION AND NATURE OF BUSINESS Blueknight Energy Partners, L.P. and subsidiaries (collectively, the “Partnership”) is a publicly traded master limited partnership with operations in 26 states. The Partnership provides integrated terminalling services for companies engaged in the production, distribution and marketing of liquid asphalt. The Partnership manages its operations through one operating segment, asphalt terminalling services. The Partnership’s common units and Preferred Units, which represent limited partnership interests in the Partnership, are listed on the Nasdaq Global Market under the symbols “BKEP” and “BKEPP,” respectively. The Partnership was formed in February 2007 as a Delaware master limited partnership. The Partnership previously provided integrated terminalling, gathering, and transportation services for companies engaged in the production, distribution, and marketing of crude oil in three different operating segments: (i) crude oil terminalling services, (ii) crude oil pipeline services, and (iii) crude oil trucking services. On December 21, 2020, the Partnership announced it had entered into multiple definitive agreements to see these segments. The transaction related to the crude oil pipeline services segment closed on February 1, 2021, the final transaction related to crude oil trucking services closed on February 2, 2021, and the transaction related to crude oil terminalling services closed on March 1, 2021. These segments are presented as discontinued operations for all periods presented. Unless otherwise noted, information in these notes to the consolidated financial statements relates to continuing operations. As the Partnership is only operating through one operating segment, a segment footnote is no longer required.

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Note 2 - Basis of Presentation	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Basis of Accounting [Text Block]	2. BASIS OF PRESENTATION The accompanying consolidated financial statements and related notes present and discuss the Partnership’s consolidated financial position as of December 31, 2020 and 2021, and the consolidated results of the Partnership’s operations, cash flows and changes in partners’ capital (deficit) for the years ended December 31, 2020 and 2021. The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). All significant intercompany accounts and transactions have been eliminated in the preparation of the accompanying consolidated financial statements.

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Note 3 - Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Significant Accounting Policies [Text Block]	3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES USE OF ESTIMATES - The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts and disclosure of contingencies. Management makes significant estimates including: (1) estimated cash flows and fair values inherent in impairment tests; (2) the estimated fair value of financial instruments; and (3) liability and contingency accruals. Although management believes these estimates are reasonable, actual results could differ from these estimates. CASH AND CASH EQUIVALENTS - Cash and cash equivalents include cash and all investments with original maturities of three months or less which are readily convertible into known amounts of cash. ACCOUNTS RECEIVABLE - The Partnership reviews all outstanding accounts receivable balances on a monthly basis and records a reserve for amounts that the Partnership expects will not be fully recovered. Although the Partnership considers its allowance for doubtful trade accounts receivable to be adequate, there is no assurance that actual amounts will not vary significantly from estimated amounts. The Partnership had no amounts that qualified for a reserve at both December 31, 2020 and 2021. PROPERTY, PLANT AND EQUIPMENT - Property, plant and equipment are recorded at cost. Expenditures for maintenance and repairs that do not add capacity or extend the useful life of an asset are expensed as incurred. The carrying values of the assets are based on estimates, assumptions and judgments relative to useful lives and salvage values. As assets are disposed of, the cost and related accumulated depreciation are removed from the accounts, and any resulting gain or loss is included in operating income in the consolidated statements of operations. Depreciation is calculated using the straight-line method based on estimated useful lives of the assets. These estimates are based on various factors, including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets. Uncertainties that impact these estimates include changes in laws and regulations relating to restoration and abandonment requirements, economic conditions and supply and demand in the area. When assets are put into service, management makes estimates with respect to useful lives and salvage values that it believes are reasonable. However, subsequent events could cause management to change its estimates, thus impacting the future calculation of depreciation. The Partnership has contractual obligations to perform dismantlement and removal activities in the event that some of its liquid asphalt terminalling assets are abandoned (see Note 15). Such obligations are recognized in the period in which sufficient information becomes available for it to reasonably determine the settlement dates. IMPAIRMENT OF LONG-LIVED ASSETS AND OTHER INTANGIBLE ASSETS - Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written down to estimated fair value. A long-lived asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset is recognized. Fair value is generally determined from estimated discounted future net cash flows. Acquired customer contracts are capitalized and amortized over useful lives ranging from approximately 5 to 10 years using the straight-line method of amortization. An impairment loss is recognized for definite-lived intangibles if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value.  The Partnership had no asset impairment charges for the years ended December 31, 2020 and 2021. DEBT ISSUANCE COSTS - Costs incurred in connection with the issuance of long-term debt related to the Partnership’s credit agreement are capitalized and amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization. GOODWILL - Goodwill represents the excess of the cost of acquisitions over the amounts assigned to assets acquired and liabilities assumed. Goodwill is not amortized but is tested annually in December for impairment or when events and circumstances warrant an interim evaluation. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. The Partnership currently has one reporting unit, asphalt terminalling services. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired. Entities may elect to utilize a qualitative assessment to evaluate whether it is more likely than not that the fair value of the reporting unit is less than its carrying amount. Should the quantitative assessment be required, the Partnership’s valuation would generally be based on the estimated discounted future net cash flows of the reporting unit, utilizing discount rates and other factors in determining the fair value of the reporting unit. The Partnership utilized the qualitative assessment in 2020 and 2021, and no impairment expense was recorded in either period. ENVIRONMENTAL MATTERS - Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines, penalties and other sources are charged to expense when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. The Partnership had no loss contingencies related to environmental matters as of December 31, 2020 and 2021. REVENUE RECOGNITION - The Partnership recognizes service revenue in accordance with ASC 606 and lease revenue in accordance with ASC 842. See Note 4 for detailed discussion regarding the Partnership’s revenue recognition policies. INCOME AND OTHER TAXES - For federal and most state income tax purposes, the majority of income, gains, losses, deductions and tax credits generated by the Partnership flow through to the unitholders of the Partnership and are subject to income tax at the individual partner level. The Partnership is subject to the Texas state franchise (margin) tax, and the earnings associated with the Partnership’s taxable subsidiary are subject to federal and state income taxes. The Partnership's estimated liability related to these taxes is immaterial for both the years ended December 31, 2020 and 2021, and is reflected on the Partnership’s consolidated statements of operations as “Provision for income taxes.” See Note 19 for a discussion of certain risks related to the Partnership’s ability to be treated as a partnership for federal income tax purposes. STOCK-BASED COMPENSATION - The Partnership’s general partner adopted the Blueknight Energy Partners G.P. L.L.C. Long-Term Incentive Plan (the “LTIP”), under which 8.1 million units are reserved for issuance, subject to adjustment for certain events. The compensation committee of the Board administers the LTIP. Although other types of awards are contemplated under the LTIP, awards issued to date include “phantom” units, which convey the right to receive common units upon vesting, and “restricted” units, which are grants of common units restricted until the time of vesting. The phantom unit awards also include distribution equivalent rights (“DERs”). A DER entitles the grantee to a cash payment equal to the cash distribution paid on an outstanding common unit prior to the vesting date of the underlying award. Cash distributions paid on DERs are accounted for as partnership distributions. Recipients of restricted units are entitled to receive cash distributions paid on common units during the vesting period. The Partnership classifies unit award grants as either equity or liability awards. All award grants made under the LTIP from its inception through December 31, 2021, have been classified as equity awards. Fair value for award grants classified as equity is determined on the grant date of the award and this value is recognized as compensation expense ratably over the requisite service period of unit award grants, which generally is the vesting period. Fair value for equity awards is calculated as the closing price of the Partnership’s common units representing limited partner interests in the Partnership (“common units”) on the grant date and is reduced by the present value of estimated cash distributions to be paid on common units during the vesting period to the extent a unit award does not include DERs. Compensation expense related to unit-based payments is included in operating and general and administrative expenses on the Partnership’s consolidated statements of operations. FAIR VALUE OF FINANCIAL INSTRUMENTS - The Partnership measures all financial instruments, including derivatives embedded in other contracts, at fair value and recognizes them in the consolidated balance sheets as an asset or a liability, depending on its rights and obligations under the applicable contract. The changes in the fair value of financial instruments are recognized currently in earnings in the consolidated statements of operations. LEASES - A lease is a contract, or part of a contract, that conveys the right to control the use of identified property, plant, or equipment (an identified asset) for a period of time in exchange for consideration. At the inception of a contract, and upon certain modifications, the Partnership determines whether the contract is or contains a lease. In evaluating whether a contract conveys a right to control the use of an asset, considerations include whether the contract conveys the right to substantially all of the economic benefits from use of the identified asset for a period of time and the right to direct the use of the identified asset. The determination of whether an arrangement represents a lease involves judgment in certain instances. The Partnership is both a lessee and a lessor. For lessee contracts, the length of lease agreements varies from less than one year to approximately twenty-five years. The Partnership has elected to not record lease assets and liabilities for leases with a lease term at commencement of 12 months or less; such leases are expensed as paid. If a lease contains an option to extend the lease term and there is reasonable certainty the option will be exercised, the option is considered in the lease term at inception. The Partnership has elected to not separate non-lease components (e.g., common area maintenance) from lease components on real estate leases, accordingly the recognized lease asset and lease liability incorporate in their measurement payments for non-lease components. Certain leases include variable lease payments as the amounts are subject to change over the lease term. When the interest rate implicit in the leases is unable to be determined, the incremental borrowing rate related to the Partnership's revolving credit facility is used to capitalize the right-of-use asset and lease liability. See Note 4 for the Partnership’s policies on agreements in which it is the lessor.

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Note 4 - Revenue

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Revenue [Text Block]

4. REVENUE

There are two types of asphalt terminalling contracts: (i) operating lease contracts, under which customers operate the facilities, and (ii) storage, throughput and handling contracts, under which the Partnership operates the facilities. The operating lease contracts are accounted for in accordance with ASC 842 - Leases. The storage, throughput and handling contracts contain both lease revenue and non-lease service revenue. In accordance with ASC 842 and 606, fixed consideration is allocated to the lease and service components based on their relative stand-alone selling price. The stand-alone selling price of the lease component is calculated using the average internal rate of return under the operating lease agreements. The stand-alone selling price of the service component is calculated by applying an appropriate margin to the expected costs to operate the facility. The service component contains a single performance obligation that consists of a stand-ready obligation to perform activities as directed by the customer, and revenue is recognized on a straight-line basis over time as the customer receives and consumes benefits. The lease component is recognized on a straight-line basis over the term of the initial lease. Fixed consideration, consisting of the monthly storage and handling fees, is billed a month prior to the performance of services and is due by the first day of the month of service. Payments received in advance of the month of service are recorded as unearned revenue until the service is performed, and the service component is treated as a contract liability.

Asphalt storage, throughput and handling contracts also contain variable consideration in the form of reimbursements of utility, fuel and power expenses and throughput fees. Utility, fuel and power reimbursements are allocated entirely to the service component of the contracts. Utility, fuel and power reimbursements relate directly to the distinct monthly service that makes up the overall performance obligation and revenue is recognized in the period in which the service takes place. Variable consideration related to reimbursements of utility, fuel and power expenses is billed in the month subsequent to the period of service, and payment is due within 30 days of billing. Throughput fees are allocated to both the lease and service component of the contracts using the allocation percentages from contract inception. In accordance with ASC 842, the lease component of variable throughput fees is recognized in the period when the changes in facts and circumstances on which the variable payment is based occur. Additionally, under ASC 842, when variable consideration contains both a lease and non-lease service component, the service component cannot be recognized until the period in which the changes in facts and circumstances on which the variable payment is based occur. At that time, it can be recognized in accordance with ASC 606. The service component of variable throughput fees is treated as a change in estimate in the period changes in facts and circumstances on which the variable payment is based occur and is then recognized on a straight-line basis over time as the customer receives and consumes benefits. Payment on variable throughput consideration is due within 30 days of billing.

The following table includes revenue associated with contractual commitments in place related to future performance obligations as of the end of the reporting period, which are expected to be recognized in revenue in the specified periods (in thousands):

	Revenue from
	Contracts with		Revenue from
	Customers(1)		Leases		Total
2022	$	39,697	$	59,647	$	99,344
2023		31,934		47,952		79,886
2024		31,204		47,164		78,368
2025		28,996		41,095		70,091
2026		19,948		24,759		44,707
Thereafter		18,834		22,352		41,186
Total revenue related to future performance obligations	$	170,613	$	242,969	$	413,582

(1) Excluded from the table is revenue that is either constrained or related to performance obligations that are wholly unsatisfied as of December 31, 2021.

Disaggregation of Revenue

Disaggregation of revenue from contracts with customers by revenue type is presented as follows (in thousands):

	Year ended December 31, 2020
	Revenue from contracts with customers				Lease revenue
	Third-party revenue		Related-party revenue		Third-party revenue		Related-party revenue			Total
Fixed storage and throughput revenue	$	20,303	$	14,531	$	-	$	-	$	34,834
Fixed lease revenue		-		-		32,207		24,547		56,754
Variable cost recovery revenue		6,620		3,076		2,205		763		12,664
Variable throughput and other revenue		2,248		421		2,218		1,106		5,993
Total	$	29,171	$	18,028	$	36,630	$	26,416	$	110,245

	Year ended December 31, 2021
	Revenue from contracts with customers				Lease revenue
	Third-party revenue		Related-party revenue		Third-party revenue		Related-party revenue			Total
Fixed storage and throughput revenue	$	20,315	$	18,883	$	-	$	-	$	39,198
Fixed lease revenue		-		-		31,263		27,142		58,405
Variable cost recovery revenue		8,616		680		1,816		954		12,066
Variable throughput and other revenue		1,784		632		1,986		1,346		5,748
Total	$	30,715	$	20,195	$	35,065	$	29,442	$	115,417

Contract Balances

The timing of revenue recognition, billings and cash collections result in billed accounts receivable and unearned revenue (contract liabilities) on the consolidated balance sheets as noted in the contract discussions above. Accounts receivable are reflected in the line items “Accounts receivable” and “Receivables from related parties” on the consolidated balance sheets. Unearned revenue is included in the line items “Unearned revenue,” “Unearned revenue with related parties,” “Long-term unearned revenue with related parties” and “Other long-term liabilities” on the consolidated balance sheets.

Billed accounts receivable from contracts with customers were $2.1 million and $2.2 million at  December 31, 2020 and 2021, respectively.

The Partnership records unearned revenues when cash payments are received in advance of performance. Unearned revenue related to contracts with customers was $3.2 million and $3.4 million at December 31, 2020 and 2021, respectively. For the year ended December 31, 2021, the Partnership recognized $2.3 million of revenues that were previously included in the unearned revenue balance for services provided during the period.

Practical Expedients and Exemptions

The Partnership does not disclose the value of unsatisfied performance obligations for contracts with an original expected length of one year or less.

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Note 5 - Discontinued Operations

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]

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Note 6 - Property, Plant and Equipment

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Property, Plant and Equipment Disclosure [Text Block]

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Note 7 - Intangible Assets, Net

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Intangible Assets Disclosure [Text Block]

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Note 8 - Debt

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Debt Disclosure [Text Block]

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Note 9 - Net Income Per Limited Partner Unit

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Earnings Per Share [Text Block]

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Note 10 - Partners' Capital (Deficit) and Distributions

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Partners' Capital Notes Disclosure [Text Block]

10. PARTNERS’ CAPITAL (DEFICIT) AND DISTRIBUTIONS

In accordance with the terms of its partnership agreement, each quarter the Partnership distributes all of its available cash (as defined in the partnership agreement) to its unitholders. Generally, distributions are allocated as follows:

• first, 98.4% to the preferred unitholders and 1.6% to its general partner until the Partnership distributes for each Preferred Unit an amount equal to the Preferred Units quarterly distribution amount discussed below;

• second, 98.4% to the preferred unitholders and 1.6% to its general partner until the Partnership distributes for each Preferred Unit an amount equal to any Preferred Units cumulative distribution arrearage; and

• thereafter, 98.4% to the common unitholders and 1.6% to its general partner until the common unitholders receive the minimum quarterly distribution of $0.11 per unit.

The Preferred Units are convertible at the holders’ option into common units. Holders of the Preferred Units are entitled to quarterly distributions of $0.17875 per unit per quarter. If the Partnership fails to pay in full any distribution on the Preferred Units, the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full.

The general partner receives incentive distribution rights. Incentive distribution rights represent the right to receive an increasing percentage (13.0%, 23.0% and 48.0%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels have been achieved. The general partner currently holds the incentive distribution rights, but may transfer these rights separately from its general partner interest, subject to restrictions in the partnership agreement. If for any quarter:

• the Partnership has distributed available cash from operating surplus to the holders of our Preferred Units in an amount equal to the Preferred Units quarterly distribution amount;

• the Partnership has distributed available cash from operating surplus to the holders of our Preferred Units in an amount necessary to eliminate any cumulative arrearages in the payment of the Preferred Units quarterly distribution amount; and

• the Partnership has distributed available cash from operating surplus to the common unitholders and Class B unitholders in an amount equal to the minimum quarterly distribution;

then the partnership agreement requires that the Partnership distribute any additional available cash from operating surplus for that quarter among the unitholders and the general partner in the following manner:

• first, 98.4% to all unitholders holding common units or Class B units, pro rata, and 1.6% to the general partner, until each unitholder receives a total of $0.1265 per unit for that quarter (the “first target distribution”);

• second, 85.4% to all unitholders holding common units or Class B units, pro rata, and 14.6% to the general partner, until each unitholder receives a total of $0.1375 per unit for that quarter (the “second target distribution”);

• third, 75.4% to all unitholders holding common units or Class B units, pro rata, and 24.6% to the general partner, until each unitholder receives a total of $0.1825 per unit for that quarter (the “third target distribution”); and

• thereafter, 50.4% to all unitholders holding common units or Class B units, pro rata, and 49.6% to the general partner.

Distributions are also paid to the holders of restricted units and phantom units as disclosed in Note 13.

The Partnership paid the following distributions on the Preferred Units during the years ended  December 31, 2020 and 2021 (in thousands):

Year				Paid to Preferred		Partner
Paid	Periods Covered	Total		Unitholders		Paid to General
2020	Quarters ending December 31, 2019, March 31, 2020, June 30, 2020 and September 30, 2020	$	25,519	$	25,115	$	404
2021	Quarters ending December 31, 2020, March 31, 2021, June 30, 2021 and September 30, 2021	$	25,138	$	24,740	$	398

In addition, on January 25, 2022, the Board approved a cash distribution of $0.17875 per outstanding Preferred Unit for the quarter ending December 31, 2021. The Partnership paid this distribution on the Preferred Units on February 14, 2022, to unitholders of record as of February 7, 2022. The total distribution was approximately $6.2 million, with approximately $6.2 million and $0.1 million paid to the Partnership’s preferred unitholders and general partner, respectively.

The Partnership paid the following distributions on the common units during the years ended  December 31, 2020 and 2021 (in thousands):

Year				Paid to Common		Paid to General		Paid to Phantom and Restricted Unitholders Under
Paid	Periods Covered	Total		Unitholders		Partner		the LTIP
2020	Quarters ending December 31, 2019, March 31, 2020, June 30, 2020 and September 30, 2020	$	6,887	$	6,576	$	109	$	202
2021	Quarters ending December 31, 2020, March 31, 2021, June 30, 2021 and September 30, 2021	$	6,977	$	6,637	$	111	$	229

In addition, on January 25, 2022, the Board approved a cash distribution of $0.0425 per outstanding common unit for the quarter ending December 31, 2021. The distribution was paid on February 14, 2022, to unitholders of record as of February 7, 2022. The total distribution was approximately $1.9 million, with approximately $1.8 million paid to the Partnership’s common unitholders and less than $0.1 million paid to the both the Partnership’s general partner and holders of phantom and restricted units pursuant to awards granted under the LTIP.

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Note 11 - Major Customers and Concentration of Credit Risk	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Concentration Risk Disclosure [Text Block]	11. MAJOR CUSTOMERS AND CONCENTRATION OF CREDIT RISK Significant customers are defined as those who represent 10% or more of our total consolidated revenues during the year. For the year ended December 31, 2021, Ergon accounted for approximately 43% of the Partnership’s total revenues. In addition, two third-party customers accounted for 14% and 13% of the Partnership’s total revenues. For the year ended December 31, 2020, Ergon accounted for approximately 40% of the Partnership’s total revenues. In addition, two third-party customers accounted for 12% and 15% of the Partnership’s total revenues.

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Note 12 - Related-party Transactions	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Related Party Transactions Disclosure [Text Block]	12. RELATED-PARTY TRANSACTIONS The Partnership leases facilities to Ergon and provides liquid asphalt terminalling services to Ergon. For the years ended December 31, 2020 and 2021, the Partnership recognized revenues of $44.4 million and $49.6 million, respectively, for services provided to Ergon. See additional discussion below regarding material asphalt operating lease contracts and storage, throughput and handling contracts. As of December 31, 2020 and 2021, the Partnership had receivables from Ergon of $0.5 million and $0.4 million, respectively.  As of December 31, 2020 and 2021, the Partnership has unearned revenues from Ergon of $8.8 million and $9.3 million, respectively, which primarily relates to cash received in December for the following  January lease and storage fees, and capital project reimbursements and deductibles that are being recognized straight-line over the term of the existing revenue contracts.  Effective April 1, 2018, the Partnership entered into an agreement with Ergon under which the Partnership purchases crude oil in connection with its crude oil marketing operations. For the years ended December 31, 2020 and 2021, the Partnership made purchases of crude oil under this agreement totaling $92.1 million and $9.5 million, respectively. This agreement terminated upon the closing of the sale of the crude oil pipeline services business on February 1, 2021. As of December 31, 2019, the Partnership had a contingent liability to Ergon of $12.2 million related to the Cimarron Express project, a previously disclosed joint venture between Kingfisher Midstream and Ergon's development company (“DEVCO”) that was cancelled in December 2018. The contingent liability reflected Ergon's investment in the joint venture and accrued interest, for which the Partnership, in accordance with the membership interest purchase agreement with Ergon, was meant to bear the risk of loss related to DEVCO’s portion of the project. The Partnership paid this liability in full on January 3, 2020, and it is reflected as an acquisition of the DEVCO on the consolidated statement of cash flows for the year ended December 31, 2020. Ergon 2020 Master Storage, Throughput and Handling Agreement In August 2020, the Partnership and Ergon entered into the “2020 Master Storage, Throughput and Handling Agreement”, effective August 1, 2020, which replaced the three agreements noted below and all related amendments. Pursuant to this agreement, the Partnership provides Ergon with storage and terminalling services at 22 facilities through December 31, 2027. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the years ended December 31, 2020 and 2021, the Partnership generated revenues under this agreement of $16.8 million and $39.5 million, respectively. Ergon Operating and Maintenance Agreement In August 2020, the Partnership and Ergon also entered into the Operating and Maintenance Agreement, effective August 1, 2020, pursuant to which Ergon will provide certain operations and maintenance services to the 22 facilities also under the 2020 Master Storage, Throughput and Handling Agreement through  December 31, 2025, with automatic one-year renewals unless either party cancels. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the years ended December 31, 2020 and 2021, the Partnership recognized expense under this agreement of $7.7 million and $18.6 million, respectively. Ergon Lessee Operated Facility Lease Agreement and Previous Agreements In March 2019, the Partnership and Ergon entered into a facilities lease agreement (the “Ergon Lessee Operated Facility Lease Agreement”) covering 12 facilities. The facilities covered by this agreement were previously accounted for under two separate agreements. This agreement was effective January 1, 2019, and on August 1, 2020, was replaced with the Ergon 2020 Master Storage, Throughput and Handling Agreement discussed above. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the year ended December 31, 2020, the Partnership generated revenues under this agreement of $4.4 million. Ergon 2016 Storage and Handling Agreement In October 2016, the Partnership and Ergon entered into a storage, throughput and handling agreement (the “Ergon 2016 Storage and Handling Agreement”) pursuant to which the Partnership provides Ergon storage and terminalling services at nine asphalt facilities. In July 2018, the Partnership sold one of the facilities to Ergon and the agreement was amended accordingly. The term of the Ergon 2016 Storage, Throughput and Handling Agreement commenced on October 5, 2016, and in August 2020, was replaced with the Ergon 2020 Master Storage, Throughput and Handling Agreement discussed above. The Board’s conflicts committee reviewed and approved this agreement in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the year ended  December 31, 2020, the Partnership generated revenue under this agreement of $12.0 million. Ergon Fontana and Las Vegas Storage Throughput and Handling Agreement In October 2016, the Partnership and Ergon entered into a storage, throughput and handling agreement (the “Ergon Fontana and Las Vegas Storage Throughput and Handling Agreement”) pursuant to which the Partnership provides Ergon storage and terminalling services at two asphalt facilities. The original Ergon Fontana and Las Vegas Master Facilities Lease Agreement commenced on May 18, 2009, and was a part of previous agreement that expired in 2018. A new agreement was executed in March 2019 with an effective date of January 1, 2019, and, on  August 1, 2020, was replaced with the Ergon 2020 Master Storage, Throughput and Handling Agreement discussed above. The Board’s conflicts committee reviewed and approved these agreements in accordance with the Partnership’s procedures for approval of related-party transactions and the provisions of the partnership agreement. During the year ended December 31, 2020, the Partnership generated revenues under this agreement of $3.5 million.

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Note 13 - Long-term Incentive Plan

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Share-based Payment Arrangement [Text Block]

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Note 14 - Employee Benefit Plan	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Compensation and Employee Benefit Plans [Text Block]	14. EMPLOYEE BENEFIT PLAN Under the Partnership’s 401(k) Plan, which was instituted in 2009, employees who meet specified service requirements may contribute a percentage of their total compensation, up to a specified maximum, to the 401(k) Plan. The Partnership  may match each employee’s contribution, up to a specified maximum, in full or on a partial basis. The Partnership recognized expense of $0.6 million and $0.5 million for the years ended December 31, 2020 and 2021, respectively, for discretionary contributions under the 401(k) Plan. The Partnership may also make annual lump-sum contributions to the 401(k) Plan irrespective of the employee’s contribution match. The Partnership may make a discretionary annual contribution in the form of profit sharing calculated as a percentage of an employee’s eligible compensation. This contribution is retirement income under the qualified 401(k) Plan. Annual profit sharing contributions to the 401(k) Plan are submitted to the Board for approval. The Partnership recognized expense of $0.6 million and $0.5 million for the years ended December 31, 2020 and 2021, respectively, for discretionary profit sharing contributions under the 401(k) Plan. Under the Partnership’s Employee Unit Purchase Plan (the “EUPP”), which was instituted in January 2015, employees have the opportunity to acquire or increase their ownership of common units representing limited partner interests in the Partnership. Eligible employees who enroll in the EUPP may elect to have a designated whole percentage, up to a specified maximum, of their eligible compensation for each pay period withheld for the purchase of common units at a discount to the then current market value. A maximum of 1,000,000 common units may be delivered under the EUPP, subject to adjustment for a recapitalization, split, reorganization, or similar event pursuant to the terms of the EUPP. Expense for the EUPP was immaterial for both 2020 and 2021.

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Note 15 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Commitments and Contingencies Disclosure [Text Block]	15. COMMITMENTS AND CONTINGENCIES The Partnership is from time to time subject to various legal actions and claims incidental to its business. Management believes that these legal proceedings will not have a material adverse effect on the financial position, results of operations or cash flows of the Partnership. Once management determines that information pertaining to a legal proceeding indicates that it is probable that a liability has been incurred and the amount of such liability can be reasonably estimated, an accrual is established equal to its estimate of the likely exposure. The Partnership has contractual obligations to perform dismantlement and removal activities in the event that some of its liquid asphalt terminalling assets are abandoned. These obligations include varying levels of activity, including completely removing the assets and returning the land to its original state. The Partnership has determined that the settlement dates related to the retirement obligations are indeterminate. The assets with indeterminate settlement dates have been in existence for many years and with regular maintenance will continue to be in service for many years to come. Also, it is not possible to predict when demands for the Partnership’s terminalling services will cease, and the Partnership does not believe that such demand will cease in the foreseeable future. Accordingly, the Partnership believes the date when these assets will be abandoned is indeterminate. With no reasonably determinable abandonment date, the Partnership cannot reasonably estimate the fair value of the associated asset retirement obligations. Management believes that if the Partnership’s asset retirement obligations were settled in the foreseeable future, the potential cash flows that would be required to settle the obligations based on current costs are not material. The Partnership will record asset retirement obligations for these assets in the period in which sufficient information becomes available for it to reasonably determine the settlement dates.

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Note 16 - Environmental Remediation

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Environmental Loss Contingency Disclosure [Text Block]

16. ENVIRONMENTAL REMEDIATION

The Partnership maintains insurance of various types with varying levels of coverage that it considers adequate under the circumstances to cover its operations and properties. The insurance policies are subject to deductibles and retention levels that the Partnership considers reasonable and not excessive. Consistent with insurance coverage generally available in the industry, in certain circumstances the Partnership’s insurance policies provide limited coverage for losses or liabilities relating to gradual pollution, with broader coverage for sudden and accidental occurrences. Although the Partnership maintains a program designed to prevent and, as applicable, to detect and address such releases promptly, damages and liabilities incurred due to environmental releases from its assets may substantially affect its business.

At December 31, 2020 and 2021, the Partnership was aware of existing conditions that may cause it to incur expenditures in the future for the remediation of existing environmental matters. The Partnership had no environmental remediation loss contingencies as of December 31, 2020 and 2021. Changes in the Partnership’s estimates and assumptions may occur as a result of the passage of time and the occurrence of future events.

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Note 17 - Fair Value Measurements	12 Months Ended
	Dec. 31, 2021
Notes to Financial Statements
Fair Value Disclosures [Text Block]	17. FAIR VALUE MEASUREMENTS The Partnership uses valuation techniques, such as the market approach (comparable market prices), the income approach (present value of future income or cash flow) and the cost approach (cost to replace the service capacity of an asset or replacement cost) to value these assets and liabilities as appropriate. The Partnership uses an exit price when determining the fair value. The exit price represents amounts that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The Partnership utilizes a three-tier fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels: Level 1 Observable inputs such as quoted prices (unadjusted) in active markets for identical assets or liabilities. Level 2 Inputs other than quoted prices that are observable for these assets or liabilities, either directly or indirectly. These include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active. Level 3 Unobservable inputs in which there is little market data, which requires the reporting entity to develop its own assumptions. This hierarchy requires the use of observable market data, when available, to minimize the use of unobservable inputs when determining fair value. In periods in which they occur, the Partnership recognizes transfers into and out of Level 3 as of the end of the reporting period. Transfers out of Level 3 represent existing assets and liabilities that were classified previously as Level 3 for which the observable inputs became a more significant portion of the fair value estimates. Determining the appropriate classification of the Partnership’s fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. Fair Value of Other Financial Instruments The following disclosure of the estimated fair value of financial instruments is made in accordance with accounting guidance for financial instruments. The Partnership has determined the estimated fair values by using available market information and valuation methodologies. Considerable judgment is required in interpreting market data to develop the estimates of fair value. The use of different market assumptions or valuation methodologies may have a material effect on the estimated fair value amounts. At December 31, 2021, the carrying values on the consolidated balance sheets for cash and cash equivalents (classified as Level 1), accounts receivable and accounts payable approximate their fair value because of their short-term nature. Based on the borrowing rates currently available to the Partnership for credit agreement debt with similar terms and maturities and consideration of the Partnership’s non-performance risk, long-term debt associated with the Partnership’s credit agreement at December 31, 2021, approximates its fair value. The fair value of the Partnership’s long-term debt was calculated using observable inputs (eurodollar rate for the risk-free component) and unobservable company-specific credit spread information. As such, the Partnership considers this debt to be Level 3.

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Note 18 - Leases

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Lessee, Operating Leases [Text Block]

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Note 19 - Income Taxes

12 Months Ended

Dec. 31, 2021

Notes to Financial Statements

Income Tax Disclosure [Text Block]

19. INCOME TAXES

The anticipated after-tax economic benefit of an investment in the Partnership’s common units depends largely on the Partnership being treated as a partnership for federal income tax purposes. If less than 90% of the gross income of a publicly traded partnership, such as the Partnership, for any taxable year is “qualifying income” from sources such as the transportation, marketing (other than to end users), or processing of crude oil, natural gas or products thereof, interest, dividends, or similar sources, that partnership will be taxable as a corporation under Section 7704 of the Internal Revenue Code for federal income tax purposes for that taxable year and all subsequent years.

If the Partnership were treated as a corporation for federal income tax purposes, then it would pay federal income tax on its income at the applicable corporate tax rate in addition to state income tax at varying rates. Distributions would generally be taxed again to unitholders as corporate distributions and none of the Partnership’s income, gains, losses, deductions, or credits would flow through to its unitholders. Because a tax would be imposed upon the Partnership as an entity, cash available for distribution to its unitholders would be substantially reduced. Treatment of the Partnership as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to unitholders and thus would likely result in a substantial reduction in the value of the Partnership’s common units.

The Partnership has entered into storage or lease contracts with third-party customers with respect to substantially all of its asphalt facilities. At the time of entering into such agreements, it was unclear under current tax law as to whether the rental income from the leases, and the fees attributable to certain of the processing services the Partnership provides under certain of the storage contracts, constitute “qualifying income.” In the second quarter of 2009, the Partnership submitted a request for a ruling from the IRS that rental income from the leases constitutes “qualifying income.” In October 2009, the Partnership received a favorable ruling from the IRS. As part of this ruling, however, the Partnership agreed to transfer, and has transferred, certain of its asphalt processing assets and related fee income to a subsidiary taxed as a corporation. This transfer occurred in the first quarter of 2010. Such subsidiary is required to pay federal income tax on its income at the applicable corporate tax rate and will likely pay state (and possibly local) income tax at varying rates. Distributions from this subsidiary will generally be taxed again to unitholders as corporate distributions and none of the income, gains, losses, deductions or credits of this subsidiary will flow through to the Partnership’s unitholders.

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Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2021

Accounting Policies [Abstract]

Use of Estimates, Policy [Policy Text Block]

USE OF ESTIMATES - The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts and disclosure of contingencies. Management makes significant estimates including: (1) estimated cash flows and fair values inherent in impairment tests; (2) the estimated fair value of financial instruments; and (3) liability and contingency accruals. Although management believes these estimates are reasonable, actual results could differ from these estimates.

Cash and Cash Equivalents, Policy [Policy Text Block]

CASH AND CASH EQUIVALENTS - Cash and cash equivalents include cash and all investments with original maturities of three months or less which are readily convertible into known amounts of cash.

Accounts Receivable [Policy Text Block]

ACCOUNTS RECEIVABLE - The Partnership reviews all outstanding accounts receivable balances on a monthly basis and records a reserve for amounts that the Partnership expects will not be fully recovered. Although the Partnership considers its allowance for doubtful trade accounts receivable to be adequate, there is no assurance that actual amounts will not vary significantly from estimated amounts. The Partnership had no amounts that qualified for a reserve at both December 31, 2020 and 2021.

Property, Plant and Equipment, Policy [Policy Text Block]

PROPERTY, PLANT AND EQUIPMENT - Property, plant and equipment are recorded at cost. Expenditures for maintenance and repairs that do not add capacity or extend the useful life of an asset are expensed as incurred. The carrying values of the assets are based on estimates, assumptions and judgments relative to useful lives and salvage values. As assets are disposed of, the cost and related accumulated depreciation are removed from the accounts, and any resulting gain or loss is included in operating income in the consolidated statements of operations.

Depreciation is calculated using the straight-line method based on estimated useful lives of the assets. These estimates are based on various factors, including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets. Uncertainties that impact these estimates include changes in laws and regulations relating to restoration and abandonment requirements, economic conditions and supply and demand in the area. When assets are put into service, management makes estimates with respect to useful lives and salvage values that it believes are reasonable. However, subsequent events could cause management to change its estimates, thus impacting the future calculation of depreciation.

The Partnership has contractual obligations to perform dismantlement and removal activities in the event that some of its liquid asphalt terminalling assets are abandoned (see Note 15). Such obligations are recognized in the period in which sufficient information becomes available for it to reasonably determine the settlement dates.

Impairment or Disposal of Long-Lived Assets, Including Intangible Assets, Policy [Policy Text Block]

IMPAIRMENT OF LONG-LIVED ASSETS AND OTHER INTANGIBLE ASSETS - Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written down to estimated fair value. A long-lived asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset is recognized. Fair value is generally determined from estimated discounted future net cash flows.

Acquired customer contracts are capitalized and amortized over useful lives ranging from approximately 5 to 10 years using the straight-line method of amortization. An impairment loss is recognized for definite-lived intangibles if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. 

The Partnership had no asset impairment charges for the years ended December 31, 2020 and 2021.

Debt, Policy [Policy Text Block]

DEBT ISSUANCE COSTS - Costs incurred in connection with the issuance of long-term debt related to the Partnership’s credit agreement are capitalized and amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization.

Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]

GOODWILL - Goodwill represents the excess of the cost of acquisitions over the amounts assigned to assets acquired and liabilities assumed. Goodwill is not amortized but is tested annually in December for impairment or when events and circumstances warrant an interim evaluation. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. The Partnership currently has one reporting unit, asphalt terminalling services. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired. Entities may elect to utilize a qualitative assessment to evaluate whether it is more likely than not that the fair value of the reporting unit is less than its carrying amount. Should the quantitative assessment be required, the Partnership’s valuation would generally be based on the estimated discounted future net cash flows of the reporting unit, utilizing discount rates and other factors in determining the fair value of the reporting unit. The Partnership utilized the qualitative assessment in 2020 and 2021, and no impairment expense was recorded in either period.

Environmental Costs, Policy [Policy Text Block]

ENVIRONMENTAL MATTERS - Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines, penalties and other sources are charged to expense when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. The Partnership had no loss contingencies related to environmental matters as of December 31, 2020 and 2021.

Revenue [Policy Text Block]

REVENUE RECOGNITION - The Partnership recognizes service revenue in accordance with ASC 606 and lease revenue in accordance with ASC 842. See Note 4 for detailed discussion regarding the Partnership’s revenue recognition policies.

Income Tax, Policy [Policy Text Block]

INCOME AND OTHER TAXES - For federal and most state income tax purposes, the majority of income, gains, losses, deductions and tax credits generated by the Partnership flow through to the unitholders of the Partnership and are subject to income tax at the individual partner level. The Partnership is subject to the Texas state franchise (margin) tax, and the earnings associated with the Partnership’s taxable subsidiary are subject to federal and state income taxes. The Partnership's estimated liability related to these taxes is immaterial for both the years ended December 31, 2020 and 2021, and is reflected on the Partnership’s consolidated statements of operations as “Provision for income taxes.” See Note 19 for a discussion of certain risks related to the Partnership’s ability to be treated as a partnership for federal income tax purposes.

Share-based Payment Arrangement [Policy Text Block]

STOCK-BASED COMPENSATION - The Partnership’s general partner adopted the Blueknight Energy Partners G.P. L.L.C. Long-Term Incentive Plan (the “LTIP”), under which 8.1 million units are reserved for issuance, subject to adjustment for certain events. The compensation committee of the Board administers the LTIP. Although other types of awards are contemplated under the LTIP, awards issued to date include “phantom” units, which convey the right to receive common units upon vesting, and “restricted” units, which are grants of common units restricted until the time of vesting. The phantom unit awards also include distribution equivalent rights (“DERs”). A DER entitles the grantee to a cash payment equal to the cash distribution paid on an outstanding common unit prior to the vesting date of the underlying award. Cash distributions paid on DERs are accounted for as partnership distributions. Recipients of restricted units are entitled to receive cash distributions paid on common units during the vesting period.

The Partnership classifies unit award grants as either equity or liability awards. All award grants made under the LTIP from its inception through December 31, 2021, have been classified as equity awards. Fair value for award grants classified as equity is determined on the grant date of the award and this value is recognized as compensation expense ratably over the requisite service period of unit award grants, which generally is the vesting period. Fair value for equity awards is calculated as the closing price of the Partnership’s common units representing limited partner interests in the Partnership (“common units”) on the grant date and is reduced by the present value of estimated cash distributions to be paid on common units during the vesting period to the extent a unit award does not include DERs. Compensation expense related to unit-based payments is included in operating and general and administrative expenses on the Partnership’s consolidated statements of operations.

Fair Value of Financial Instruments, Policy [Policy Text Block]

FAIR VALUE OF FINANCIAL INSTRUMENTS - The Partnership measures all financial instruments, including derivatives embedded in other contracts, at fair value and recognizes them in the consolidated balance sheets as an asset or a liability, depending on its rights and obligations under the applicable contract. The changes in the fair value of financial instruments are recognized currently in earnings in the consolidated statements of operations.

Leases [Policy Text Block]

LEASES - A lease is a contract, or part of a contract, that conveys the right to control the use of identified property, plant, or equipment (an identified asset) for a period of time in exchange for consideration. At the inception of a contract, and upon certain modifications, the Partnership determines whether the contract is or contains a lease. In evaluating whether a contract conveys a right to control the use of an asset, considerations include whether the contract conveys the right to substantially all of the economic benefits from use of the identified asset for a period of time and the right to direct the use of the identified asset. The determination of whether an arrangement represents a lease involves judgment in certain instances.

The Partnership is both a lessee and a lessor. For lessee contracts, the length of lease agreements varies from less than one year to approximately twenty-five years. The Partnership has elected to not record lease assets and liabilities for leases with a lease term at commencement of 12 months or less; such leases are expensed as paid. If a lease contains an option to extend the lease term and there is reasonable certainty the option will be exercised, the option is considered in the lease term at inception. The Partnership has elected to not separate non-lease components (e.g., common area maintenance) from lease components on real estate leases, accordingly the recognized lease asset and lease liability incorporate in their measurement payments for non-lease components. Certain leases include variable lease payments as the amounts are subject to change over the lease term. When the interest rate implicit in the leases is unable to be determined, the incremental borrowing rate related to the Partnership's revolving credit facility is used to capitalize the right-of-use asset and lease liability. See Note 4 for the Partnership’s policies on agreements in which it is the lessor.

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Note 4 - Revenue (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]

	Revenue from
	Contracts with		Revenue from
	Customers(1)		Leases		Total
2022	$	39,697	$	59,647	$	99,344
2023		31,934		47,952		79,886
2024		31,204		47,164		78,368
2025		28,996		41,095		70,091
2026		19,948		24,759		44,707
Thereafter		18,834		22,352		41,186
Total revenue related to future performance obligations	$	170,613	$	242,969	$	413,582

Disaggregation of Revenue [Table Text Block]

	Year ended December 31, 2020
	Revenue from contracts with customers				Lease revenue
	Third-party revenue		Related-party revenue		Third-party revenue		Related-party revenue			Total
Fixed storage and throughput revenue	$	20,303	$	14,531	$	-	$	-	$	34,834
Fixed lease revenue		-		-		32,207		24,547		56,754
Variable cost recovery revenue		6,620		3,076		2,205		763		12,664
Variable throughput and other revenue		2,248		421		2,218		1,106		5,993
Total	$	29,171	$	18,028	$	36,630	$	26,416	$	110,245

	Year ended December 31, 2021
	Revenue from contracts with customers				Lease revenue
	Third-party revenue		Related-party revenue		Third-party revenue		Related-party revenue			Total
Fixed storage and throughput revenue	$	20,315	$	18,883	$	-	$	-	$	39,198
Fixed lease revenue		-		-		31,263		27,142		58,405
Variable cost recovery revenue		8,616		680		1,816		954		12,066
Variable throughput and other revenue		1,784		632		1,986		1,346		5,748
Total	$	30,715	$	20,195	$	35,065	$	29,442	$	115,417

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Note 5 - Discontinued Operations (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Disposal Groups, Including Discontinued Operations [Table Text Block]

Assets and Liabilities of Discontinued Operations (in thousands)	As of December 31, 2020
	Crude Oil Trucking Services		Crude Oil Pipeline Services		Crude Oil Terminalling Services		Total
ASSETS
Accounts receivable, net	$	81	$	13,711	$	167	$	13,959
Plant, property, and equipment		442		23,541		52,854		76,837
Other assets		331		547		5,271		6,149
Total assets of discontinued operations	$	854	$	37,799	$	58,292	$	96,945
LIABILITIES
Current liabilities	$	1,017	$	14,921	$	1,310	$	17,248
Total liabilities of discontinued operations	$	1,017	$	14,921	$	1,310	$	17,248

Assets and Liabilities of Discontinued Operations (in thousands)	As of December 31, 2021
	Crude Oil Trucking Services		Crude Oil Pipeline Services		Crude Oil Terminalling Services		Total
ASSETS
Other Assets	$	-	$	1	$	1	$	2
Total assets of discontinued operations	$	-	$	1	$	1	$	2
LIABILITIES
Current liabilities	$	12	$	218	$	10	$	240
Total liabilities of discontinued operations	$	12	$	218	$	10	$	240

Statement of Operations for Discontinued Operations (in thousands)
	Year ended December 31, 2020
	Crude Oil Trucking Services			Crude Oil Pipeline Services			Crude Oil Terminalling Services			Total
Revenue:
Third-party service revenue	$	5,293		$	1,689		$	16,856		$	23,838
Intercompany service revenue		5,587			-			-			5,587
Third-party product sales revenue		-			157,544			-			157,544
Costs and expenses:
Operating expense		12,386			13,427			8,561			34,374
Intercompany operating expense		-			5,587			-			5,587
Cost of product sales		-			52,624			-			52,624
Cost of product sales from related party		-			86,247			-			86,247
General and administrative expense		284			385			-			669
Asset impairment expense		1,330			2,821			2,266			6,417
Gain on sale of assets		(11	)		(445	)		(734	)		(1,190	)
Interest expense		11			960			4,348			5,319
Loss on disposal/classification as held for sale(1)		1,847			37,249			-			39,096
Income (loss) before income taxes		(4,967	)		(39,622	)		2,415			(42,174	)
Provision for income taxes		3			(2	)		-			1
Net income (loss) from discontinued operations	$	(4,970	)	$	(39,620	)	$	2,415		$	(42,175	)

Statement of Operations for Discontinued Operations (in thousands)	Year ended December 31, 2021
	Crude Oil Trucking Services			Crude Oil Pipeline Services			Crude Oil Terminalling Services			Total
Revenue:
Third-party service revenue	$	9		$	535		$	5,097		$	5,641
Intercompany service revenue		409			-			-			409
Third-party product sales revenue		-			15,591			-			15,591
Costs and expenses:
Operating expense		1,416			1,564			2,189			5,169
Intercompany operating expense		-			409			-			409
Cost of product sales		-			4,994			-			4,994
Cost of product sales from related party		-			9,461			-			9,461
General and administrative expense		61			112			-			173
Tangible asset impairment expense		92			40			23			155
(Gain) loss on disposal of assets		23			(1,720	)		(73,499	)		(75,196	)
Interest expense		-			72			635			707
Income (loss) before income taxes		(1,174	)		1,194			75,749			75,769
Provision for income taxes		(3	)		-			-			(3	)
Net income (loss) from discontinued operations	$	(1,171	)	$	1,194		$	75,749		$	75,772

Select Cash Flow Information (in thousands)
	Crude Oil Trucking Services		Crude Oil Pipeline Services		Crude Oil Terminalling Services		Total
	Year ended December 31, 2020
Depreciation and amortization	$	719	$	4,550	$	4,383	$	9,652
Capital expenditures	$	2,074	$	4,555	$	720	$	7,349
	Year ended December 31, 2021
Amortization	$	3	$	14	$	41	$	58
Capital expenditures	$	-	$	30	$	106	$	136

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Note 6 - Property, Plant and Equipment (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Property, Plant and Equipment [Table Text Block]

	Estimated
	Useful Lives		As of December 31,
	(Years)		2020			2021
			(dollars in thousands)
Land		N/A	$	21,826		$	21,826
Land improvements		10-20		5,024			5,125
Storage and terminal facilities		10-35		249,977			257,433
Office property and equipment and other		3-30		23,278			21,751
Construction-in-progress		N/A		2,165			4,355
Property, plant and equipment, gross				302,270			310,490
Accumulated depreciation				(197,561	)		(204,101	)
Property, plant and equipment, net			$	104,709		$	106,389

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Note 7 - Intangible Assets, Net (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Schedule of Finite-Lived Intangible Assets [Table Text Block]

	As of December 31,
	2020			2021
	(in thousands)
Customer contracts	$	16,022		$	16,022
Accumulated amortization of intangible assets		(8,491	)		(10,934	)
Intangible assets, net	$	7,531		$	5,088

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]

For year ending:
December 31, 2022	$	4,033
December 31, 2023		387
December 31, 2024		387
December 31, 2025		281
December 31, 2026		-
Thereafter		-
Total estimated aggregate amortization expense	$	5,088

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Note 8 - Debt (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Schedule of Debt [Table Text Block]

	Year Ended December 31,
	2020			2021
Debt issuance costs capitalized	$	-		$	3,100
Write-off of debt issuance costs due to amendments	$	-		$	147
Write-off of debt issuance costs due to new credit facility	$	-		$	583
Interest expense related to amortization of debt issuance costs	$	1,004		$	856
Credit facility interest expense(1)	$	4,611		$	3,350
Weighted average interest rate under credit facility(1)		3.97	%		3.70	%

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Note 9 - Net Income Per Limited Partner Unit (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

	Year ended December 31,
	2020			2021
Net income (loss)	$	(13,480	)	$	110,530
General partner interest in net income (loss)		(213	)		1,751
Preferred interest in net income		25,115			24,824
Net income (loss) available to limited partners	$	(38,382	)	$	83,955
Basic and diluted weighted average number of units:
Common units		41,104			41,484
Restricted and phantom units		1,285			1,453
Total units		42,389			42,937
Basic and diluted net income (loss) from discontinued operations per common unit	$	(0.98	)	$	1.74
Basic and diluted net income from continuing operations per common unit	$	0.07		$	0.22
Basic and diluted net income (loss) per common unit	$	(0.91	)	$	1.96

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Note 10 - Partners' Capital (Deficit) and Distributions (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Distributions Made to Limited Partner, by Distribution [Table Text Block]

Year				Paid to Preferred		Partner
Paid	Periods Covered	Total		Unitholders		Paid to General
2020	Quarters ending December 31, 2019, March 31, 2020, June 30, 2020 and September 30, 2020	$	25,519	$	25,115	$	404
2021	Quarters ending December 31, 2020, March 31, 2021, June 30, 2021 and September 30, 2021	$	25,138	$	24,740	$	398

Year				Paid to Common		Paid to General		Paid to Phantom and Restricted Unitholders Under
Paid	Periods Covered	Total		Unitholders		Partner		the LTIP
2020	Quarters ending December 31, 2019, March 31, 2020, June 30, 2020 and September 30, 2020	$	6,887	$	6,576	$	109	$	202
2021	Quarters ending December 31, 2020, March 31, 2021, June 30, 2021 and September 30, 2021	$	6,977	$	6,637	$	111	$	229

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Note 13 - Long-term Incentive Plan (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Share-based Compensation Arrangements by Share-based Payment Award, Restricted Stock Units, Vested and Expected to Vest [Table Text Block]

			Weighted Average		Grant Date Total Fair
	Number of		Grant Date Fair		Value
Grant Date	Units		Value		(in thousands)
December 2019		7,500	$	1.07	$	8
December 2020		7,500	$	2.06	$	15
December 2021		22,743	$	3.26	$	74

Disclosure of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block]

			Weighted Average		Grant Date Total Fair
	Number of		Grant Date Fair		Value
Grant Date	Units		Value		(in thousands)
March 2019		524,997	$	1.14	$	598
June 2019		46,168	$	1.08	$	50
March 2020		600,396	$	0.90	$	540
October 2020		16,339	$	1.53	$	25
March 2021		530,435	$	2.71	$	1,437

Share-based Payment Arrangement, Activity [Table Text Block]

	Number of		Grant Date Fair
	Units		Value
Nonvested, December 31, 2020		1,350,366	$	1.81
Granted		574,406		2.75
Vested		369,482		4.00
Forfeited		-		-
Nonvested, December 31, 2021		1,555,290	$	1.66

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Note 18 - Leases (Tables)

12 Months Ended

Dec. 31, 2021

Notes Tables

Lessee, Operating Lease, Liability, Maturity [Table Text Block]

	Operating Leases
Twelve months ending December 31, 2022	$	1,708
Twelve months ending December 31, 2023		1,615
Twelve months ending December 31, 2024		989
Twelve months ending December 31, 2025		887
Twelve months ending December 31, 2026		869
Thereafter		4,716
Total		10,784
Less: Interest		2,663
Present value of lease liabilities	$	8,121

Lease, Cost [Table Text Block]

		Year ended December 31, 2021
	Classification	2020		2021
Total Lease Cost by Type:
Operating lease cost(1)	Operating Expense	$	1,953	$	1,920
Short-term lease cost	Operating Expense		172		122
Net lease cost		$	2,125	$	2,042
Supplemental cash flow disclosures:
Cash paid for amounts included in the measurement of lease liabilities:
Payments on operating leases		$	1,400	$	1,895
Leased assets obtained in exchange for new operating lease liabilities		$	119	$	884

	As of
	December 31,
	2021
Lease Term and Discount Rate
Weighted-average remaining operating lease term (years)		10.0
Weighted-average discount rate		5.5	%

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Note 1 - Organization and Nature of Business (Details Textual)	12 Months Ended
	Dec. 31, 2021
Number of States in which Entity Operates	26
Number of Operating Segments	1

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Note 3 - Summary of Significant Accounting Policies (Details Textual) $ in Thousands, shares in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) shares	Dec. 31, 2020 USD ($)
Accounts Receivable, Allowance for Credit Loss, Ending Balance	$ 0	$ 0
Impairment of Intangible Assets (Excluding Goodwill), Total	$ 0	0
Number of Reporting Units	1
Goodwill, Impairment Loss	$ 0	0
Accrual for Environmental Loss Contingencies, Ending Balance	$ 0	$ 0
Blueknight Energy Partners GP LLC Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized (in shares) | shares	8.1
Maximum [Member]
Lessee, Operating Lease, Term of Contract (Year)	25 years
Customer Relationships [Member] | Minimum [Member]
Finite-Lived Intangible Asset, Useful Life (Year)	5 years
Customer Relationships [Member] | Maximum [Member]
Finite-Lived Intangible Asset, Useful Life (Year)	10 years

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Note 4 - Revenue (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Billed Contracts Receivable	$ 2.2	$ 2.1
Contract with Customer, Liability, Total	3.4	$ 3.2
Contract with Customer, Liability, Revenue Recognized	$ 2.3

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Note 4 - Revenue - Future Performance Obligations (Details) $ in Thousands	Dec. 31, 2021 USD ($)
2022, Revenue from Leases	$ 59,647
Total, 2022	99,344
2023, Revenue from Leases	47,952
Total, 2023	79,886
2024, Revenue from Leases	47,164
Total, 2024	78,368
2025, Revenue from Leases	41,095
Total, 2025	70,091
2026, Revenue from Leases	24,759
Total, 2026	44,707
Thereafter, Revenue from Leases	22,352
Total, Thereafter	41,186
Revenue related to future performance obligation	170,613	[1]
Revenue from Leases	242,969
Total revenue related to future performance obligations	$ 413,582

[1] Excluded from the table is revenue that is either constrained or related to performance obligations that are wholly unsatisfied as of December 31, 2021.

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Note 4 - Revenue - Future Performance Obligations 2 (Details) $ in Thousands	Dec. 31, 2021 USD ($)
Revenue related to future performance obligation	$ 170,613	[1]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue related to future performance obligation	$ 39,697	[1]
Expected Timing of Satisfaction, Period (Year)	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue related to future performance obligation	$ 31,934	[1]
Expected Timing of Satisfaction, Period (Year)	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue related to future performance obligation	$ 31,204	[1]
Expected Timing of Satisfaction, Period (Year)	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue related to future performance obligation	$ 28,996	[1]
Expected Timing of Satisfaction, Period (Year)	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue related to future performance obligation	$ 19,948	[1]
Expected Timing of Satisfaction, Period (Year)	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue related to future performance obligation	$ 18,834	[1]
Expected Timing of Satisfaction, Period (Year)

[1] Excluded from the table is revenue that is either constrained or related to performance obligations that are wholly unsatisfied as of December 31, 2021.

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Note 4 - Revenue - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Total revenue	$ 115,417	$ 110,245
Fixed Storageand Throughput Revenue [Member]
Total revenue	39,198	34,834
Fixed Lease Revenue [Member]
Total revenue	58,405	56,754
Variable Cost Recovery Revenue [Member]
Total revenue	12,066	12,664
Variable Throughput Revenue [Member]
Total revenue	5,748	5,993
Third Party [Member]
Revenue	30,715	29,171
Operating Lease, Lease Income, Total	35,065	36,630
Third Party [Member] | Fixed Storageand Throughput Revenue [Member]
Revenue	20,315	20,303
Operating Lease, Lease Income, Total	0	0
Third Party [Member] | Fixed Lease Revenue [Member]
Revenue	0	0
Operating Lease, Lease Income, Total	31,263	32,207
Third Party [Member] | Variable Cost Recovery Revenue [Member]
Revenue	8,616	6,620
Operating Lease, Lease Income, Total	1,816	2,205
Third Party [Member] | Variable Throughput Revenue [Member]
Revenue	1,784	2,248
Operating Lease, Lease Income, Total	1,986	2,218
Related Party [Member]
Revenue	20,195	18,028
Operating Lease, Lease Income, Total	29,442	26,416
Related Party [Member] | Fixed Storageand Throughput Revenue [Member]
Revenue	18,883	14,531
Operating Lease, Lease Income, Total	0	0
Related Party [Member] | Fixed Lease Revenue [Member]
Revenue	0	0
Operating Lease, Lease Income, Total	27,142	24,547
Related Party [Member] | Variable Cost Recovery Revenue [Member]
Revenue	680	3,076
Operating Lease, Lease Income, Total	954	763
Related Party [Member] | Variable Throughput Revenue [Member]
Revenue	632	421
Operating Lease, Lease Income, Total	$ 1,346	$ 1,106

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Note 5 - Discontinued Operations (Details Textual) - USD ($) $ in Thousands			2 Months Ended	3 Months Ended	12 Months Ended
		Dec. 15, 2020	Feb. 02, 2021	Mar. 31, 2020	Dec. 31, 2021	Dec. 21, 2021	Dec. 31, 2020
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax, Total					$ (0)		$ (39,096)
Pipeline Linefill [Member]
Asset Impairment Charges, Total				$ 4,900
Crude Oil Trucking Services [Member]
Asset Impairment Charges, Total							1,300
Discontinued Operations, Held-for-sale [Member]
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax, Total	[1]						(39,096)
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member]
Proceeds from Divestiture of Businesses, Held in Escrow						$ 1,400
Exit and Disposal Costs						$ 1,900
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax, Total	[1]						(37,249)
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member]
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax, Total		$ (1,100)	$ (700)				$ (1,847)	[1]

[1] Included in the crude oil trucking services segment is a loss on disposal recorded during December 2020 for the first phase closing of $1.1 million, and a loss on the classification on assets held for sale as of December 31, 2020, for the second phase closing on February 2, 2021, of $0.7 million.

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Note 5 - Discontinued Operations - Financial Information (Details) - USD ($) $ in Thousands			2 Months Ended	12 Months Ended
		Dec. 15, 2020	Feb. 02, 2021	Dec. 31, 2021	Dec. 31, 2020
Loss on disposal/classification as held for sale(1)				$ 0	$ 39,096
Net income (loss) from discontinued operations				75,772	(42,175)
Discontinued Operations, Held-for-sale [Member]
Accounts receivable, net					13,959
Plant, property, and equipment					76,837
Other assets				2	6,149
Total assets of discontinued operations				2	96,945
Current liabilities				240	17,248
Total liabilities of discontinued operations				240	17,248
Operating expense				5,169	34,374
General and administrative expense				173	669
Asset impairment expense				155	6,417
Gain on sale of assets				(75,196)	(1,190)
Interest expense				707	5,319
Loss on disposal/classification as held for sale(1)	[1]				39,096
Income (loss) before income taxes				75,769	(42,174)
Provision for income taxes				(3)	1
Net income (loss) from discontinued operations				75,772	(42,175)
Income (loss) before income taxes				75,769	(42,174)
Depreciation and amortization				58	9,652
Capital expenditures				136	7,349
Discontinued Operations, Held-for-sale [Member] | Intersegment Eliminations [Member]
Operating expense				409	5,587
Discontinued Operations, Held-for-sale [Member] | Service [Member] | Intersegment Eliminations [Member]
Revenue				409	5,587
Discontinued Operations, Held-for-sale [Member] | Third Party [Member]
Cost of product sales				4,994	52,624
Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Service [Member]
Revenue				5,641	23,838
Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Product [Member]
Revenue				15,591	157,544
Discontinued Operations, Held-for-sale [Member] | Related Party [Member]
Cost of product sales				9,461	86,247
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member]
Accounts receivable, net					81
Plant, property, and equipment					442
Other assets				0	331
Total assets of discontinued operations				0	854
Current liabilities				12	1,017
Total liabilities of discontinued operations				12	1,017
Operating expense				1,416	12,386
General and administrative expense				61	284
Asset impairment expense				92	1,330
Gain on sale of assets				23	(11)
Interest expense				0	11
Loss on disposal/classification as held for sale(1)		$ 1,100	$ 700		1,847	[1]
Income (loss) before income taxes				(1,174)	(4,967)
Provision for income taxes				(3)	3
Net income (loss) from discontinued operations				(1,171)	(4,970)
Income (loss) before income taxes				(1,174)	(4,967)
Depreciation and amortization				3	719
Capital expenditures				0	2,074
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member] | Intersegment Eliminations [Member]
Operating expense				0	0
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member] | Service [Member] | Intersegment Eliminations [Member]
Revenue				409	5,587
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member]
Cost of product sales				0	0
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Service [Member]
Revenue				9	5,293
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Product [Member]
Revenue				0	0
Crude Oil Trucking Services [Member] | Discontinued Operations, Held-for-sale [Member] | Related Party [Member]
Cost of product sales				0	0
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member]
Accounts receivable, net					13,711
Plant, property, and equipment					23,541
Other assets				1	547
Total assets of discontinued operations				1	37,799
Current liabilities				218	14,921
Total liabilities of discontinued operations				218	14,921
Operating expense				1,564	13,427
General and administrative expense				112	385
Asset impairment expense				40	2,821
Gain on sale of assets				(1,720)	(445)
Interest expense				72	960
Loss on disposal/classification as held for sale(1)	[1]				37,249
Income (loss) before income taxes				1,194	(39,622)
Provision for income taxes				0	(2)
Net income (loss) from discontinued operations				1,194	(39,620)
Income (loss) before income taxes				1,194	(39,622)
Depreciation and amortization				14	4,550
Capital expenditures				30	4,555
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member] | Intersegment Eliminations [Member]
Operating expense				409	5,587
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member] | Service [Member] | Intersegment Eliminations [Member]
Revenue				0	0
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member]
Cost of product sales				4,994	52,624
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Service [Member]
Revenue				535	1,689
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Product [Member]
Revenue				15,591	157,544
Crude Oil Pipeline Services [Member] | Discontinued Operations, Held-for-sale [Member] | Related Party [Member]
Cost of product sales				9,461	86,247
Crude Oil Terminalling Services [Member] | Discontinued Operations, Held-for-sale [Member]
Accounts receivable, net					167
Plant, property, and equipment					52,854
Other assets				1	5,271
Total assets of discontinued operations				1	58,292
Current liabilities				10	1,310
Total liabilities of discontinued operations				10	1,310
Operating expense				2,189	8,561
General and administrative expense				0	0
Asset impairment expense				23	2,266
Gain on sale of assets				(73,499)	(734)
Interest expense				635	4,348
Loss on disposal/classification as held for sale(1)	[1]				0
Income (loss) before income taxes				75,749	2,415
Provision for income taxes				0	0
Net income (loss) from discontinued operations				75,749	2,415
Income (loss) before income taxes				75,749	2,415
Depreciation and amortization				41	4,383
Capital expenditures				106	720
Crude Oil Terminalling Services [Member] | Discontinued Operations, Held-for-sale [Member] | Intersegment Eliminations [Member]
Operating expense				0	0
Crude Oil Terminalling Services [Member] | Discontinued Operations, Held-for-sale [Member] | Service [Member] | Intersegment Eliminations [Member]
Revenue				0	0
Crude Oil Terminalling Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member]
Cost of product sales				0	0
Crude Oil Terminalling Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Service [Member]
Revenue				5,097	16,856
Crude Oil Terminalling Services [Member] | Discontinued Operations, Held-for-sale [Member] | Third Party [Member] | Product [Member]
Revenue				0	0
Crude Oil Terminalling Services [Member] | Discontinued Operations, Held-for-sale [Member] | Related Party [Member]
Cost of product sales				$ 0	$ 0

[1] Included in the crude oil trucking services segment is a loss on disposal recorded during December 2020 for the first phase closing of $1.1 million, and a loss on the classification on assets held for sale as of December 31, 2020, for the second phase closing on February 2, 2021, of $0.7 million.

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Note 6 - Property, Plant and Equipment (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Property, Plant, and Equipment, Lessor Asset under Operating Lease, before Accumulated Depreciation	$ 305.4
Property, Plant, and Equipment, Lessor Asset under Operating Lease, Accumulated Depreciation	199.3
Depreciation, Total	$ 9.4	$ 11.0

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Note 6 - Property, Plant and Equipment - Property, Plant and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Property, plant and equipment, gross	$ 310,490	$ 302,270
Accumulated depreciation	(204,101)	(197,561)
Property, plant and equipment, net	106,389	104,709
Land [Member]
Property, plant and equipment, gross	21,826	21,826
Land Improvements [Member]
Property, plant and equipment, gross	$ 5,125	$ 5,024
Land Improvements [Member] | Minimum [Member]
Estimated Useful Lives (Year)	10 years
Land Improvements [Member] | Maximum [Member]
Estimated Useful Lives (Year)		20 years
Storage and Terminal Facilities [Member]
Property, plant and equipment, gross	$ 257,433	$ 249,977
Storage and Terminal Facilities [Member] | Minimum [Member]
Estimated Useful Lives (Year)	10 years
Storage and Terminal Facilities [Member] | Maximum [Member]
Estimated Useful Lives (Year)		35 years
Office Equipment [Member]
Property, plant and equipment, gross	$ 21,751	$ 23,278
Office Equipment [Member] | Minimum [Member]
Estimated Useful Lives (Year)	3 years
Office Equipment [Member] | Maximum [Member]
Estimated Useful Lives (Year)		30 years
Construction in Progress [Member]
Property, plant and equipment, gross	$ 4,355	$ 2,165

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Note 7 - Intangible Assets, Net (Details Textual) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Mar. 31, 2018	Feb. 29, 2016	Dec. 31, 2021	Dec. 31, 2020
Amortization of Intangible Assets, Total			$ 2.4	$ 2.4
Customer Relationships [Member] | Minimum [Member]
Finite-Lived Intangible Asset, Useful Life (Year)			5 years
Customer Relationships [Member] | Maximum [Member]
Finite-Lived Intangible Asset, Useful Life (Year)			10 years
Asphalt Terminalling Services [Member] | Customer Relationships [Member]
Finite-lived Intangible Assets Acquired	$ 7.6	$ 8.4

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Note 7 - Intangible Assets, Net - Net of Accumulated Depreciation (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Customer contracts	$ 16,022	$ 16,022
Accumulated amortization of intangible assets	(10,934)	(8,491)
Total estimated aggregate amortization expense	$ 5,088	$ 7,531

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Note 7 - Intangible Assets, Net - Net Estimated Aggregate Amortization Expense On Intangible Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
December 31, 2022	$ 4,033
December 31, 2023	387
December 31, 2024	387
December 31, 2025	281
December 31, 2026	0
Thereafter	0
Total estimated aggregate amortization expense	$ 5,088	$ 7,531

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Note 8 - Debt (Details Textual) - Credit Agreement [Member] $ in Millions		12 Months Ended
	May 26, 2021 USD ($)	Dec. 31, 2021 USD ($)	Mar. 01, 2022 USD ($)
Line of Credit Facility, Maximum Borrowing Capacity Including Additional Lenders		$ 450.0
Debt Instrument Covenant, Issued Qualified Senior Notes		$ 200.0
Debt Instrument Covenant, Prior to Issuance of Qualified Senior Notes, Maximum Permitted Consolidated Total Leverage Ratio		4.75
Debt Instrument Covenant, Prior to Issuance of Qualified Senior Notes, Based on Occurence of Acquisition, Maximum Permitted Consolidated Total Leverage Ratio		5.25
Debt Instrument Covenant, Specified Acquisition, Aggregate Consideration		$ 15.0
Debt Instrument Covenant, Prior to Issuance of Qualified Senior Notes, Maximum Permitted Consolidated Total Leverage Ratio		5.00
Debt Instrument Covenant, After Issuance of Qualified Senior Notes, Based on Occurence of Acquisition, Maximum Permitted Consolidated Total Leverage Ratio		5.50
Debt Instrument Covenant, Maximum Permitted Consolidated Senior Secured Leverage Ratio		3.50
Debt Instrument Covenant, Minimum Permitted Consolidated Interest Coverage Ratio		2.50
Consolidated Total Leverage Ratio		1.84
Consolidated Interest Coverage Ratio		15.79
Debt Instrument, Covenant, Maximum Aggregate Unit Repurchases		$ 40.0
Debt Instrument, Covenant, Maximum Yearly Unit Repurchases		$ 10.0
Debt Instrument, Covenant, Unit Repurchases, Maximum Total Leverage Ratio		4.00
Debt Instrument, Covenant, Unit Repurchases, Minimum Percentage of Revolving Credit Facility to Total Commitments		20.00%
Debt Instrument Covenant, Default, Percentage of General Partner Interest Cease		100.00%
Line of Credit Assumed	$ 2.9
Debt Issuance Costs Incurred During Noncash or Partial Noncash Transaction	2.5
Ergon [Member]
Debt Instrument Covenant, Default, Percentage of Membership Interest Cease		50.00%
Federal Funds Effective Rate [Member]
Debt Instrument, Basis Spread on Variable Rate		0.50%
Eurodollar Rate [Member]
Debt Instrument, Basis Spread on Variable Rate		1.00%
Minimum [Member]
Line of Credit Facility, Commitment Fee Percentage		0.375%
Minimum [Member] | Applicable Margin Based on Eurodollar Rate [Member]
Debt Instrument, Basis Spread on Variable Rate		2.00%
Minimum [Member] | Applicable Margin on Based on Alternate Base Rate [Member]
Debt Instrument, Basis Spread on Variable Rate		1.00%
Maximum [Member]
Line of Credit Facility, Commitment Fee Percentage		0.50%
Maximum [Member] | Applicable Margin Based on Eurodollar Rate [Member]
Debt Instrument, Basis Spread on Variable Rate		3.25%
Maximum [Member] | Applicable Margin on Based on Alternate Base Rate [Member]
Debt Instrument, Basis Spread on Variable Rate		2.25%
Revolving Credit Facility [Member]
Line of Credit Facility, Maximum Borrowing Capacity	$ 300.0
Revolving Credit Facility [Member] | Subsequent Event [Member]
Long-term Line of Credit, Total			$ 110.0
Letters of Credit Outstanding, Amount			0.6
Line of Credit Facility, Remaining Borrowing Capacity			$ 189.4

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Note 8 - Debt - Credit Agreement (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020
Interest expense related to amortization of debt issuance costs		$ 1,586	$ 1,004
Credit Agreement [Member]
Debt issuance costs capitalized		3,100	0
Interest expense related to amortization of debt issuance costs		856	1,004
Credit facility interest expense(1)	[1]	$ 3,350	$ 4,611
Weighted average interest rate under credit facility(1)	[1]	3.70%	3.97%
Credit Agreement [Member] | Debt Issuance Costs Due to Amendments [Member]
Write off of debt issuance costs		$ 147	$ 0
Credit Agreement [Member] | Debt Issuance Costs Due to New Credit Facility [Member]
Write off of debt issuance costs		$ 583	$ 0

[1] Excludes interest expense related to amortization and write-off of debt issuance costs for the year ending December 31, 2021.

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Note 9 - Net Income Per Limited Partner Unit - Earning Per Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Net income (loss)	$ 110,530	$ (13,480)
General partner interest in net income (loss)	1,751	(213)
Preferred interest in net income	24,824	25,115
Net income (loss) available to limited partners	$ 83,955	$ (38,382)
Common units (in shares)	41,484	41,104
Restricted and phantom units (in shares)	1,453	1,285
Total units (in shares)	42,937	42,389
Basic and diluted net income (loss) from discontinued operations per common unit (in dollars per share)	$ 1.74	$ (0.98)
Basic and diluted net income from continuing operations per common unit (in dollars per share)	0.22	0.07
Basic and diluted net income (loss) per common unit (in dollars per share)	$ 1.96	$ (0.91)

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Note 10 - Partners' Capital (Deficit) and Distributions (Details Textual) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2021
Common Unit, Cash Distribution [Member]
Distribution Made to Limited Partner, Declaration Date	Jan. 25, 2022
Distribution Made to Limited Partner, Distributions Declared, Per Unit (in dollars per share)	$ 0.0425
Distribution Made to Limited Partner, Distribution Date	Feb. 14, 2022
Distribution Made to Limited Partner, Date of Record	Feb. 07, 2022
Distribution Made to Limited Partner, Cash Distributions Declared	$ 1.9
Preferred Unit, Cash Distribution [Member]
Distribution Made to Limited Partner, Declaration Date	Jan. 25, 2022
Distribution Made to Limited Partner, Distributions Declared, Per Unit (in dollars per share)	$ 0.17875
Distribution Made to Limited Partner, Distribution Date	Feb. 14, 2022
Distribution Made to Limited Partner, Date of Record	Feb. 07, 2022
Distribution Made to Limited Partner, Cash Distributions Declared	$ 6.2
Holders of Phantom and Restricted Units [Member] | Common Unit, Cash Distribution [Member]
Distribution Made to Limited Partner, Cash Distributions Declared	0.1
Preferred Partner [Member] | First Tier Cash Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		98.40%
Preferred Partner [Member] | Second Tier Cash Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		98.40%
Preferred Partner [Member] | Quarterly Distributions [Member]
Guaranteed Distribution Per Preferred Unit Per Quarter (in dollars per share)		$ 0.17875
Preferred Partner [Member] | Preferred Unit, Cash Distribution [Member]
Distribution Made to Limited Partner, Cash Distributions Declared	6.2
General Partner [Member] | First Tier Cash Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		1.60%
General Partner [Member] | Second Tier Cash Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		1.60%
General Partner [Member] | Third Tier Cash Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		1.60%
General Partner [Member] | First Tier Incentive Distribution Rights Percentage Increase [Member]
Incentive Distribution Rights, Percentage Increase		13.00%
General Partner [Member] | Second Tier Incentive Distribution Rights Percentage Increase [Member]
Incentive Distribution Rights, Percentage Increase		23.00%
General Partner [Member] | Third Tier Incentive Distribution Rights Percentage Increase [Member]
Incentive Distribution Rights, Percentage Increase		48.00%
General Partner [Member] | First Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		1.60%
General Partner [Member] | Second Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		14.60%
General Partner [Member] | Third Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		24.60%
General Partner [Member] | Fourth Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		49.60%
General Partner [Member] | Common Unit, Cash Distribution [Member]
Distribution Made to Limited Partner, Cash Distributions Declared	0.1
General Partner [Member] | Preferred Unit, Cash Distribution [Member]
Distribution Made to Limited Partner, Cash Distributions Declared	0.1
Limited Partner [Member]
Minimum Distribution, Per Common Unit Per Quarter (in dollars per share)		$ 0.11
Limited Partner [Member] | Third Tier Cash Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		98.40%
Limited Partner [Member] | First Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		98.40%
Limited Partner [Member] | Second Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		85.40%
Limited Partner [Member] | Third Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		75.40%
Limited Partner [Member] | Fourth Tier Target Distribution [Member]
Partners' Capital Account, Distributions, Allocation Percentage		50.40%
Limited and General Partners [Member] | First Tier Target Distribution [Member]
Target Quarterly Distribution (in dollars per share)		$ 0.1265
Limited and General Partners [Member] | Second Tier Target Distribution [Member]
Target Quarterly Distribution (in dollars per share)		0.1375
Limited and General Partners [Member] | Third Tier Target Distribution [Member]
Target Quarterly Distribution (in dollars per share)		$ 0.1825
Common Unitholder [Member] | Common Unit, Cash Distribution [Member]
Distribution Made to Limited Partner, Cash Distributions Declared	$ 1.8

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Note 10 - Partners' Capital (Deficit) and Distributions - Distributions (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Preferred Unit, Cash Distribution [Member]
Distributions	$ 25,138	$ 25,519
Preferred Unit, Cash Distribution [Member] | Preferred Partner [Member]
Distributions	24,740	25,115
Preferred Unit, Cash Distribution [Member] | General Partner [Member]
Distributions	398	404
Common Unit, Cash Distribution [Member]
Distributions	6,977	6,887
Common Unit, Cash Distribution [Member] | General Partner [Member]
Distributions	111	109
Common Unit, Cash Distribution [Member] | Limited Partner [Member]
Distributions	6,637	6,576
Common Unit, Cash Distribution [Member] | Phantom and Restricted Units Holders [Member]
Distributions	$ 229	$ 202

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Note 11 - Major Customers and Concentration of Credit Risk (Details Textual) - Customer Concentration Risk [Member] - Revenue Benchmark [Member]	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Ergon [Member]
Concentration Risk, Percentage	43.00%	40.00%
One Third Party Customer [Member]
Concentration Risk, Percentage	14.00%	12.00%
Two Other Third Party Customer [Member]
Concentration Risk, Percentage	13.00%	15.00%

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Note 12 - Related-party Transactions (Details Textual) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Due from Related Parties, Current, Total	$ 369	$ 507
Ergon [Member]
Revenue from Related Parties	49,600	44,400
Due from Related Parties, Current, Total	400	500
Deferred Revenue, Total	9,300	8,800
Ergon [Member] | Cimarron Express [Member]
Due to Related Parties, Contingent Liability			$ 12,200
Ergon [Member] | Crude Oil Purchase Agreement [Member]
Related Party Transaction, Purchases from Related Party	9,500	92,100
Ergon [Member] | Ergon 2020 Master Storage, Throughput and Handling Agreement [Member]
Operating Lease, Lease Income, Total	39,500	16,800
Ergon [Member] | Ergon Operating and Maintenance Agreement [Member]
Related Party Transaction, Expenses from Transactions with Related Party	$ 18,600	7,700
Ergon [Member] | Ergon Lessee Operated Facility Lease Agreement [Member]
Operating Lease, Lease Income, Total		4,400
Ergon [Member] | Ergon 2016 Storage and Handling Agreement [Member]
Revenue from Related Parties		12,000
Ergon [Member] | Ergon Fontana and Las Vegas Storage Throughput and Handling Agreement [Member]
Revenue from Related Parties		$ 3,500

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Note 13 - Long-term Incentive Plan (Details Textual) - Long-Term Incentive Plan [Member] - USD ($) $ / shares in Units, $ in Millions		1 Months Ended	12 Months Ended
	Jan. 01, 2022	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized (in shares)		8,100,000	8,100,000
Share-based Payment Arrangement, Expense			$ 0.8	$ 0.8
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period (Year)			3 years
Restricted Stock [Member] | Share-based Payment Arrangement, Tranche Two [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage			33.33%
Restricted Stock [Member] | Share-based Payment Arrangement, Tranche One [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage			33.33%
Restricted Stock [Member] | Share-based Payment Arrangement, Tranche Three [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage			33.33%
Phantom and Restricted Units Holders [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)			$ 2.75
Share-based Payment Arrangement, Nonvested Award, Excluding Option, Cost Not yet Recognized, Amount		$ 1.1	$ 1.1
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)			369,482
Phantom and Restricted Units Holders [Member] | Subsequent Event [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	426,297
Director [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Granted (in shares)		21,228
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)		$ 3.26
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Grant Date Fair Value, Without Vesting Requirement		$ 0.1	$ 0.1
Director [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)			$ 3.26	$ 2.06	$ 1.07

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Note 13 - Long-term Incentive Plan - Information on Outstanding Grants Made to Directors Under the LTIP (Details) - Long-Term Incentive Plan [Member] - Director [Member] - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Granted, weighted average grant date fair value (in dollars per share)	$ 3.26
Restricted Stock [Member]
Granted, number of units (in shares)		22,743	7,500	7,500
Granted, weighted average grant date fair value (in dollars per share)		$ 3.26	$ 2.06	$ 1.07
Grant Date Total Fair Value	$ 74	$ 74	$ 15	$ 8

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Note 13 - Long-term Incentive Plan - Information on Outstanding Grants Made to Employees Under the LTIP (Details) - Long-Term Incentive Plan [Member] - Phantom Share Units (PSUs) [Member] - Employees [Member] - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended
	Mar. 31, 2021	Oct. 31, 2020	Mar. 31, 2020	Jun. 30, 2019	Mar. 31, 2019
Granted, number of units (in shares)	530,435	16,339	600,396	46,168	524,997
Granted, weighted average grant date fair value (in dollars per share)	$ 2.71	$ 1.53	$ 0.90	$ 1.08	$ 1.14
Grant Date Total Fair Value	$ 1,437	$ 25	$ 540	$ 50	$ 598

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Note 13 - Long-term Incentive Plan - Activity Pertaining to Phantom and Restricted Common Stock Unit Awards (Details) - Long-Term Incentive Plan [Member] - Phantom and Restricted Units Holders [Member]	12 Months Ended
	Dec. 31, 2021 $ / shares shares
Nonvested, number of units, beginning balance (in shares) | shares	1,350,366
Nonvested, weighted average grant date fair value, beginning balance (in dollars per share) | $ / shares	$ 1.81
Granted, number of units (in shares) | shares	574,406
Granted, weighted average grant date fair value (in dollars per share) | $ / shares	$ 2.75
Vested, number of units (in shares) | shares	369,482
Vested, weighted average grant date fair value (in dollars per share) | $ / shares	$ 4.00
Forfeited, number of units (in shares) | shares	0
Forfeited, weighted average grant date fair value (in dollars per share) | $ / shares	$ 0
Nonvested, number of units, ending balance (in shares) | shares	1,555,290
Nonvested, weighted average grant date fair value, ending balance (in dollars per share) | $ / shares	$ 1.66

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Note 14 - Employee Benefit Plan (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Partnership's Employee Unit Purchase Plan [Member]
Employee Stock Ownership Plan (ESOP), Shares in ESOP, Total (in shares)	1,000,000	1,000,000
Partnership's 401(k) Plan [Member]
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 0.5	$ 0.6
Defined Contribution Plan, Employer Discretionary Profit Sharing Contribution Amount	$ 0.5	$ 0.6

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Note 18 - Leases - Maturity of Lease Liabilities (Details) $ in Thousands	Dec. 31, 2021 USD ($)
Twelve months ending December 31, 2022	$ 1,708
Twelve months ending December 31, 2023	1,615
Twelve months ending December 31, 2024	989
Twelve months ending December 31, 2025	887
Twelve months ending December 31, 2026	869
Thereafter, operating leases	4,716
Total, operating leases	10,784
Less: Interest, operating leases	2,663
Present value of operating lease liabilities	$ 8,121

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Note 18 - Leases - Total Lease Cost by Type (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020
Operating lease cost(1)	[1]	$ 1,920	$ 1,953
Short-term lease cost		122	172
Net lease cost		2,042	2,125
Payments on operating leases		1,895	1,400
Leased assets obtained in exchange for new operating lease liabilities		$ 884	$ 119
Weighted-average remaining operating lease term (years) (Year)		10 years
Weighted-average discount rate		5.50%

[1] Includes variable lease costs, which are immaterial.