10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

___________________________________________

FORM 10-K

 ___________________________________________

x ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2018

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: 001-33292

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CORENERGY INFRASTRUCTURE TRUST, INC.

______________________________________________________________________

(Exact name of registrant as specified in its charter)

Maryland	20-3431375
(State or other jurisdiction of incorporation or organization)	(IRS Employer Identification No.)

1100 Walnut, Ste. 3350 Kansas City, MO	64106
(Address of Principal Executive Offices)	(Zip Code)

(816) 875-3705

(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class	Name of Each Exchange On Which Registered
Common Stock, par value $0.001 per share	New York Stock Exchange
7.375% Series A Cumulative Redeemable Preferred Stock	New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: None

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Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes  oNo  x

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  oNo  x

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  xNo o

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  x    No  o

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K 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. x

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a 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.

Large accelerated filer	o	Accelerated filer	x	Non-accelerated filer	o
Smaller reporting company	x	Emerging growth company	o

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. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act)     Yes  oNo  x

The aggregate market value of common stock held by non-affiliates of the registrant on June 29, 2018, the last business day of the registrant's most recently completed second fiscal quarter, based on the closing price on that date of $37.60 on the New York Stock Exchange was $445,335,846. Common shares held by each executive officer and director and by each person who owns 10% or more of the outstanding common shares (as determined by information provided to the registrant) have been excluded in that such persons may be deemed to be affiliates. This determination of affiliate status is not necessarily a conclusive determination for other purposes.

As of February 27, 2019, the registrant had 12,797,265 common shares outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant's Proxy Statement for its 2019 Annual Meeting of Stockholders to be filed not later than 120 days after the end of the fiscal year covered by this Annual Report on Form 10-K are incorporated by reference into Part III of this Form 10-K.

Index to Financial Statements Glossary of Defined Terms

CorEnergy Infrastructure Trust, Inc.

FORM 10-K

FOR THE FISCAL YEAR ENDED DECEMBER 31, 2018

TABLE OF CONTENTS

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			Page No.
PART I
	Glossary of Defined Terms		3
	Item 1.	Business	6
	Item 1A.	Risk Factors	11
	Item 1B.	Unresolved Staff Comments	33
	Item 2.	Properties	33
	Item 3.	Legal Proceedings	36
	Item 4.	Mine Safety Disclosures	36
PART II
	Item 5.	Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	36
	Item 6.	Selected Financial Data	39
	Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations	39
	Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	61
	Item 8.	Financial Statements and Supplementary Data	61
	Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	61
	Item 9A.	Controls and Procedures	61
	Item 9B.	Other Information	64
PART III
	Item 10.	Directors, Executive Officers and Corporate Governance	64
	Item 11.	Executive Compensation	64
	Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	64
	Item 13.	Certain Relationships and Related Transactions, and Director Independence	64
	Item 14.	Principal Accountant Fees and Services	64
PART IV
	Item 15.	Exhibits and Financial Statement Schedules	65
	Item 16.	Form 10-K Summary	F-42
		Signatures	F-42

2

PART I

Table of Contents GLOSSARY OF DEFINED TERMS

Certain of the defined terms used in this Report are set forth below:

Accretion Expense: the expense recognized when adjusting the present value of the GIGS ARO for the passage of time.

Administrative Agreement: the Administrative Agreement dated December 1, 2011, as amended effective August 7, 2012, between the Company and Corridor.

Amended Pinedale Term Credit Facility: Pinedale LP's $41.0 million Second Amended and Restated Term Credit Agreement and Note Purchase Agreement with Prudential as lender, effective December 29, 2017.

Arc Logistics: Arc Logistics Partners LP, a wholly-owned subsidiary of Zenith Energy U.S., LP. as a result of the completion of a previously announced merger on December 21, 2017.

ARO: the Asset Retirement Obligation liabilities assumed with the acquisition of GIGS.

ASC: FASB Accounting Standards Codification.

ASU: Accounting Standard Update.

Bbls: standard barrel containing 42 U.S. gallons.

BB Intermediate: Black Bison Intermediate Holdings, LLC, the holding company of Black Bison Water Services.

Black Bison Loans: the financing notes between Corridor Bison and CorEnergy BBWS and BBWS.

BBWS: Black Bison Water Services, LLC, the borrower of the Black Bison financing notes, as well as the owner of all of the other collateral securing the Black Bison Loans.

BOEM: U.S. Federal Bureau of Ocean Energy Management.

BSEE: U.S. Federal Bureau of Safety and Environmental Enforcement.

Code: the Internal Revenue Code of 1986, as amended.

Company or CorEnergy: CorEnergy Infrastructure Trust, Inc. (NYSE: CORR).

Convertible Notes: the Company's 7.00% Convertible Senior Notes Due 2020.

CorEnergy BBWS: CorEnergy BBWS, Inc., a wholly-owned taxable REIT subsidiary of CorEnergy.

CorEnergy Credit Facility: the Company's upsized $160.0 million CorEnergy Revolver and the $1.0 million MoGas Revolver with Regions Bank.

CorEnergy Revolver: the Company's $160.0 million secured revolving line of credit facility with Regions Bank.

CorEnergy Term Loan: the Company's $45.0 million secured term loan with Regions Bank that was paid off in conjunction with the amendment and restatement of the CorEnergy Credit Facility on July 28, 2017.

Corridor: Corridor InfraTrust Management, LLC, the Company's external manager pursuant to the Management Agreement.

Corridor Bison: Corridor Bison, LLC a wholly-owned subsidiary of CorEnergy.

Corridor MoGas: Corridor MoGas, Inc., a wholly-owned taxable REIT subsidiary of CorEnergy and the holding company of MoGas, United Property Systems and CorEnergy Pipeline Company, LLC.

Corridor Private: Corridor Private Holdings, Inc., an indirect wholly-owned taxable REIT subsidiary of CorEnergy.

Cox Acquiring Entity: MLCJR LLC, an affiliate of Cox Oil, LLC.

Cox Oil: Cox Oil, LLC.

CPI: Consumer Price Index.

Exchange Act: the Securities Exchange Act of 1934, as amended.

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Table of Contents GLOSSARY OF DEFINED TERMS (Continued from previous page)

EGC: Energy XXI Ltd, the parent company (and guarantor) of our tenant on the Grand Isle Gathering System lease, emerged from a reorganization under Chapter 11 of the US Bankruptcy Code on December 30, 2016, with the succeeding company named Energy XXI Gulf Coast, Inc. Effective October 18, 2018, EGC became an indirect wholly-owned subsidiary of MLCJR LLC ("Cox Acquiring Entity"), an affiliate of Cox Oil, LLC, as a result of a merger transaction. Throughout this document, references to EGC will refer to both the pre- and post-bankruptcy entities and, for dates on and after October 18, 2018, to EGC as an indirect wholly-owned subsidiary of the Cox Acquiring Entity.

EGC Tenant: Energy XXI GIGS Services, LLC, a wholly-owned operating subsidiary of Energy XXI Gulf Coast, Inc. that is the tenant under Grand Isle Corridor's triple-net lease of the Grand Isle Gathering System.

FASB: Financial Accounting Standards Board.

FERC: Federal Energy Regulatory Commission.

Four Wood Corridor: Four Wood Corridor, LLC, a wholly-owned subsidiary of CorEnergy.

Four Wood Energy: Four Wood Energy Partners LLC, a wholly-owned subsidiary of Four Wood Capital Partners LLC.

Four Wood Notes: the financing notes between Four Wood Corridor and Corridor Private and SWD, which were satisfied upon sale of the assets securing the financing notes to Compass SWD, LLC for a new financing note from Compass SWD, LLC on December 12, 2018.

GAAP: U.S. generally accepted accounting principles.

GIGS: the Grand Isle Gathering System, owned by Grand Isle Corridor LP and triple-net leased to a wholly-owned subsidiary of Energy XXI Gulf Coast, Inc.

GOM: Gulf of Mexico.

Grand Isle Corridor: Grand Isle Corridor LP, an indirect wholly-owned subsidiary of the Company.

Grand Isle Gathering System: a subsea midstream pipeline gathering system located in the shallow Gulf of Mexico shelf and storage and onshore processing facilities.

Grand Isle Lease Agreement: the June 2015 agreement pursuant to which the Grand Isle Gathering System assets are triple-net leased to EGC Tenant.

Indenture: collectively, that certain Base Indenture, dated June 29, 2015, as supplemented by the related First Supplemental Indenture, dated as of June 29, 2015, between the Company and Computershare Trust Company, N.A., as Trustee for the Convertible Notes.

IRS: U.S. Internal Revenue Service.

Joliet: Zenith Energy Terminals Joliet Holdings LLC, an indirect subsidiary of Zenith Energy U.S., LP.

Leeds Path West: Corridor Leads Path West, Inc., a wholly-owned subsidiary of CorEnergy.

Lightfoot: collectively, Lightfoot Capital Partners, LP and Lightfoot Capital Partners GP LLC.

Management Agreement: the current management agreement between the Company and Corridor entered into May 8, 2015, effective as of May 1, 2015.

MoGas: MoGas Pipeline LLC, an indirect wholly-owned subsidiary of CorEnergy.

MoGas Pipeline System: an approximately 263-mile interstate natural gas pipeline system in and around St. Louis and extending into central Missouri, owned and operated by MoGas.

MoGas Revolver: a $1.0 million secured revolving line of credit facility at the MoGas subsidiary level with Regions Bank.

Mowood: Mowood, LLC, a wholly-owned subsidiary of CorEnergy and the holding company of Omega Pipeline Company, LLC.

Mowood/Omega Revolver: a $1.5 million secured revolving line of credit facility at the Mowood subsidiary level with Regions Bank.

NAREIT: National Association of Real Estate Investment Trusts.

Omega: Omega Pipeline Company, LLC, a wholly-owned subsidiary of Mowood, LLC.

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Table of Contents GLOSSARY OF DEFINED TERMS (Continued from previous page)

Omega Pipeline: Omega's natural gas distribution system in south central Missouri.

OCS: the Outer Continental Shelf.

Pinedale Credit Facility: a $70.0 million secured term credit facility, with the Company and Prudential as refinance lenders, used by Pinedale Corridor, LP to finance a portion of the acquisition of the Pinedale LGS.

Pinedale LGS: the Pinedale Liquids Gathering System, a system consisting of approximately 150 miles of pipelines and four above-ground central gathering facilities located in the Pinedale Anticline in Wyoming, owned by Pinedale LP and triple-net leased to a wholly-owned subsidiary of Ultra Petroleum.

Pinedale Lease Agreement: the December 2012 agreement pursuant to which the Pinedale LGS assets are triple-net leased to a wholly owned subsidiary of Ultra Petroleum.

Pinedale LP: Pinedale Corridor, LP, an indirect wholly-owned subsidiary of CorEnergy.

Pinedale LP I: Pinedale LP I, LLC, a wholly-owned subsidiary of CorEnergy, which purchased the 18.95 percent outstanding equity interest in Pinedale LGS from Prudential.

Pinedale GP: the general partner of Pinedale LP and a wholly-owned subsidiary of CorEnergy.

Portland Lease Agreement: the January 2014 agreement pursuant to which the Portland Terminal Facility was triple-net leased to Zenith Terminals, which terminated on December 21, 2018 upon sale of the facility.

Portland Terminal Facility: a petroleum products terminal located in Portland, Oregon.

PNM: Public Service Company of New Mexico, a subsidiary of PNM Resources Inc. (NYSE: PNM).

PNM Lease Agreement: a triple-net lease agreement for the Eastern Interconnect Project.

Prudential: the Prudential Insurance Company of America.

QDI: qualified dividend income.

REIT: real estate investment trust.

SEC: Securities and Exchange Commission.

Series A Preferred Stock: the Company's 7.375% Series A Cumulative Redeemable Preferred Stock, par value $0.001 per share, of which there currently are outstanding approximately 50,222 shares represented by 5,022,227 depositary shares, each representing 1/100th of a whole share of Series A Preferred Stock.

SWD: SWD Enterprises, LLC, a wholly-owned subsidiary of Four Wood Energy Partners, LLC.

TRS: taxable REIT subsidiary.

UPL: Ultra Petroleum Corp.

Ultra Wyoming: Ultra Wyoming LGS LLC, an indirect wholly-owned subsidiary of Ultra Petroleum.

United Property Systems: United Property Systems, LLC, an indirect wholly-owned subsidiary of CorEnergy, acquired with the MoGas transaction in November 2014.

VIE: Variable Interest Entity.

VantaCore: VantaCore Partners LP.

Zenith: Zenith Energy U.S., LP.

Zenith Terminals: Zenith Energy Terminals Holdings, LLC (f/k/a Arc Terminal Holdings, LLC), a wholly-owned operating subsidiary of Arc Logistics LP (and, subsequent to December 21, 2017, an indirect wholly-owned subsidiary of Zenith).

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Table of Contents Glossary of Defined Terms

ITEM 1. BUSINESS

GENERAL

CorEnergy Infrastructure Trust, Inc. ("CorEnergy") was organized as a Maryland corporation and commenced operations on December 8, 2005. As used in this Annual Report on Form 10-K ("Report"), the terms "we", "us", "our" and the "Company" refer to CorEnergy and its subsidiaries.

COMPANY OVERVIEW

CorEnergy primarily owns and seeks to own assets in the U.S. energy sector that perform utility-like functions, such as pipelines, storage terminals, rail terminals and gas and electric transmission and distribution assets. Our objective is to generate long-term contracted revenue from operators of our assets, primarily under triple-net participating leases without direct commodity price exposure. We believe our leadership team's energy and utility expertise provides CorEnergy with a competitive advantage to acquire, own and lease U.S. energy infrastructure assets in a tax-efficient, transparent and investor-friendly REIT. Our leadership team also utilizes a disciplined investment philosophy developed through an average of over 25 years of relevant industry experience.

We expect our leases to provide us with contracted base rent, plus participating rent based upon asset-specific criteria. The energy industry commonly employs contracts with participating features, and we provide exposure to both the risk and opportunity of utilization of our assets, which we believe is a hallmark of infrastructure assets of all types. Our participating triple-net leases require the operator to pay all expenses of the business including maintaining our assets in good working order.

The majority of our assets leased to tenants under triple-net leases are dependent upon the tenants' exploitation of hydrocarbon reserves in the fields where our assets are located. These reserves are depleted over time, and therefore, may economically diminish the value of our assets over the period that the underlying reserves are exploited. Accordingly, we expect the contracted base rents under these leases, including fair market renewal rent expectations, to provide for a return-on-capital, as well as a return of our invested capital, over the life of the asset. The portion of rents we believe to constitute a return of our invested capital are utilized for debt repayment and/or are reserved for capital reinvestment activities in order to maintain our long-term earnings and dividend paying capacity. The return-on-capital is that portion of rents which are available for distribution to our stockholders through dividend payouts.

Base rents under our leases are structured on an estimated fair market value rent structure over the initial term, which includes assumptions related to the terminal value of our assets and expectations of tenant renewals. At the conclusion of the initial lease term, our leases often contain fair market value repurchase options or fair market rent renewal terms. These clauses also act as safeguards against our tenants pursuing activities which would undermine or degrade the value of our assets faster than the underlying reserves are depleted. Our participating rents are structured to provide exposure to the successful commercial activity of the tenant, and as such, also provide protection in the event that the economic life of our assets is reduced based on accelerated production by our tenants.

Our assets are predominately mission-critical to our customers, in that utilization of our assets is necessary for the business they seek to conduct and their rental payments are an essential operating expense. For example, our crude oil gathering system assets are necessary to the exploitation of upstream crude oil reserves, so the operators' lease of those assets is economically critical to their operations. Some of our assets are subject to rate regulation by FERC or state public utility commissions. Further, energy infrastructure assets are an essential and growing component of the U.S. economy that give us the opportunity to assist the capital expansion plans and meet the capital needs of various midstream and upstream participants.

We intend to distribute substantially all of our cash available for distribution, less prudent reserves, on a quarterly basis. We regularly assess our ability to pay and to grow our dividend to common stockholders. We target long-term revenue growth of 1-3 percent annually from existing contracts through inflation escalations and participating rents, and additional growth from acquisitions. There can be no assurance that any potential acquisition opportunities will result in consummated transactions. Our management contract includes incentive provisions, aligning our leadership team with our stockholders' interests in raising the dividend only if we believe the rate is sustainable.

We believe these characteristics align CorEnergy with the attractive attributes of other globally listed infrastructure companies, including high barriers to entry and contracts with predictable revenue streams, while mitigating risks and volatility experienced by other companies engaged in the midstream energy sector.

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Table of Contents Glossary of Defined Terms

2018 Highlights

Our 2018 fiscal year was highlighted by a number of transactions being completed which enhanced our liquidity and positioned the Company for future growth. These and other key transactions and events during our fiscal year ended December 31, 2018 are highlighted below:

• During 2018, we received participating rent of $4.3 million on the Pinedale Lease Agreement based on the volumes of condensate and water that flowed through the Pinedale LGS.

• During the fourth quarter of 2018, we repurchased 177,773 depository shares of preferred stock for approximately $4.3 million in cash.

• On December 21, 2018, we closed on the sale of the Portland Terminal Facility and our remaining interest in the Joliet Terminal to Zenith Terminals for an aggregate consideration of $61.0 million. For the year ended December 31, 2018, the sale of the Portland Terminal Facility resulted in a gain on the sale of leased asset, net of approximately $11.7 million while the sale of the Joliet interest resulted in a realized loss on other equity securities of approximately $715 thousand.

Significant 2019 Developments

• Thus far in 2019, we have repurchased 2,500 depository shares of preferred stock for approximately $61 thousand in cash.

• On January 16, 2019, we agreed with three holders of our Convertible Notes to exchange $43.8 million face amount of such notes for an aggregate of 837,040 shares of our common stock, par value $0.001 per share, plus aggregate cash consideration of $19.8 million.

Assets

Most of our REIT qualifying and other energy infrastructure assets have been acquired at various times since June of 2011, while our legacy private equity investments generally have been liquidated in accordance with the plans of those entities. Our business currently consists of the assets summarized below. For additional details concerning our energy infrastructure real property, see Item 2, "Properties" in this Report.

Energy Infrastructure Real Property Investments

• Grand Isle Gathering System: a subsea, midstream 153-mile pipeline system located in the Gulf of Mexico and a 16-acre onshore terminal facility triple-net leased on a long-term basis to a subsidiary of EGC, pursuant to the Grand Isle Lease Agreement. The EGC Tenant's obligations under the lease agreement are guaranteed by EGC.

• Pinedale LGS: a system consisting of approximately 150 miles of pipelines and four above-ground central gathering facilities located in the Pinedale Anticline in Wyoming triple-net leased on a long-term basis to a subsidiary of, and guaranteed by, Ultra Petroleum Corp. and Ultra Resources, Inc. pursuant to the Pinedale Lease Agreement.

• MoGas Pipeline System: MoGas is the owner and operator of the MoGas Pipeline System, an approximately 263 mile FERC-regulated interstate natural gas pipeline in and around St. Louis and extending into central Missouri.

• Omega Pipeline: Omega Pipeline Company, LLC is a natural gas service provider located primarily on the US Army's Fort Leonard Wood military post in south-central Missouri.

Energy Infrastructure Financing Investments

We have provided financing loans to owners and operators of energy infrastructure real property assets, secured by such assets and related equipment, as well as by the outstanding equity of the borrowers. These loans may include participating features pursuant to which we may receive additional interest tied to increases in utilization of the underlying facilities. See Part IV, Item 15, Note 5 ("Financing Notes Receivable") included in this Report for additional information concerning these investments.

Private Equity Investments

Our legacy private equity investments generally have been liquidated in accordance with the plans of those entities. Certain of our private equity investments were sold or disposed of by the end of 2018. For additional information, see Part IV, Item 15, Note 10 ("Fair Value") included in this Report.

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Table of Contents Glossary of Defined Terms

Acquisition Strategies and Due Diligence

We primarily rely on our own analysis to determine whether to make an acquisition. In evaluating net lease transactions, we consider, among other things, the following aspects of each transaction:

• Tenant/Borrower Evaluation – We evaluate each potential tenant or borrower for its creditworthiness, typically considering factors such as management experience, industry position and fundamentals, operating history, and capital structure, as well as other factors that may be relevant to a particular acquisition. We seek opportunities in which we believe the tenant may have a stable or improving credit profile or credit potential that has not been recognized by the market. In evaluating a possible investment, the creditworthiness of a tenant or borrower often will be balanced with the value of the underlying real estate, particularly if the underlying property is specifically suited to the needs of the tenant. Whether a prospective tenant or borrower is creditworthy will be determined by our management team and reviewed by the investment committee, as described below. Creditworthy does not necessarily mean "investment grade."

• Importance to Tenant/Borrower Operations – We predominately will focus on properties that we believe are essential or important to the ongoing operations of the tenant and/or for the economic production of hydrocarbon resources, which would remain necessary to any owner of the assets. We believe that this type of property will provide a relatively low risk of loss in the case of a potential bankruptcy or abandonment scenario since a tenant/borrower is less likely to risk the loss of a critically important lease or property.

• Diversification – We attempt to diversify our portfolio to avoid dependence on any one particular tenant, borrower, collateral type, and geographic location within the U.S. or tenant/borrower industry. By diversifying, we seek to reduce the adverse effect of a single under-performing investment or a downturn in any particular asset or geographic region within the U.S.

• Lease Terms – Typically, the net leased properties we will acquire will be leased on a full recourse basis to the tenants or their affiliates. In addition, we often seek to include a clause in each lease that provides for increases in rent over the term of the lease. These increases are fixed or tied to increases in indices such as the CPI. In many cases the lease will also seek to provide for participation in gross revenues of the tenant at the property, thereby providing exposure to the commercial activity of the tenant through features such as participating rent. Alternatively, a lease may provide for mandated rental increases on specific dates, and we may adopt other methods in the future.

• Asset Evaluation – We review the physical condition of the property and assess the likelihood of replacing the rental payment stream if the tenant defaults. We also engage a third party to conduct, or require the seller to conduct, a preliminary examination, or Phase 1 assessment, of the site to determine the potential for contamination or similar environmental site assessments in an attempt to identify potential environmental liabilities associated with a property prior to its acquisition.

• Transaction Provisions to Enhance and Protect Value – We attempt to include provisions in the leases that we believe may help protect a real property asset from changes in the operating and financial characteristics of a tenant that may affect its ability to satisfy its obligations or reduce the value of the real property asset. Such provisions include requiring our consent to specified tenant activity, requiring the tenant to provide indemnification protections, and requiring the tenant to utilize good operating practices consistent with objective criteria. We seek to enhance the likelihood of a tenant's lease obligations being satisfied through a guaranty of obligations from the tenant's corporate parent or other entity or a letter of credit. In some circumstances, we may provide tenants with repurchase options on the leased property. We expect, in those situations that the option purchase price will generally be the greater of the contract purchase price or the fair market value of the property at the time the option is exercised.

• Equity Enhancements – We may attempt to obtain equity enhancements in connection with transactions. These equity enhancements may involve warrants exercisable at a future time to purchase stock of the tenant or borrower or their parent. If warrants are obtained, and become exercisable, and if the value of the stock subsequently exceeds the exercise price of the warrant, equity enhancements can help achieve the goal of increasing investor returns.

• Other Real Estate Related Assets – As other opportunities arise, we may also seek to expand the portfolio to include other types of real estate-related investments, in all cases within the energy infrastructure sector, such as:

• equity investments in real properties that are not long-term net leased to a single-tenant and may include partially leased properties, undeveloped properties and properties subject to short-term net leases, among others;

• mortgage loans secured by real properties including loans to our taxable REIT subsidiaries;

• subordinated interests in first mortgage real estate loans, or B-notes;

• mezzanine loans related to real estate, which are senior to the borrower's equity position but subordinated to other third-party financing;

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Table of Contents Glossary of Defined Terms

• other operating energy infrastructure assets; and

• equity and debt securities (including preferred equity, limited partnership interests, trusts and other higher-yielding structured debt and equity investments) issued by companies that are engaged in real-estate-related businesses as defined by regulations promulgated under the Code, including other REITs.

Use of Taxable REIT Subsidiaries

We operate as a REIT and therefore are generally not subject to U.S. federal corporate income taxes on the income and gains that we distribute to our stockholders, including the income derived through leasing fees and financing revenue from our REIT qualifying investments in energy infrastructure assets. However, even as a REIT, we remain obligated to pay income taxes on earnings from our taxable REIT subsidiaries. The use of TRSs enables us to own certain assets and engage in certain businesses while maintaining compliance with the REIT qualification requirements under the Code. We may, from time to time, change the election of previously designated TRSs to be treated as qualified REIT subsidiaries, and may reorganize and transfer certain assets or operations from our TRSs to other subsidiaries, including qualified REIT subsidiaries. For example, through a series of reorganization events, and based on a favorable IRS private letter ruling received, Omega was converted from a TRS entity to a qualified REIT subsidiary in 2017. Refer to the "Omega Pipeline (Mowood, LLC)" section in Item 2 of this Report for additional details.

Regulatory and Environmental Matters

Our energy infrastructure assets and operations, as well as those of our tenants, are subject to numerous federal, state and local laws and regulations concerning the protection of public health and safety, zoning and land use, and pricing and other matters related to certain of our business operations. For a discussion of the current effects and potential future impacts of such regulations on our business and properties, see the discussion presented in Item 1A of this Report under the subheading "Risks Related to Our Investments in Real Estate and the U.S. Energy Infrastructure Sector." In particular, for a discussion of the current and potential future effects of compliance with federal, state and local environmental regulations, see the discussion titled "Costs of complying with governmental laws and regulations, including those relating to environmental matters, may adversely affect our income and the cash available for distribution" within such section.

Financing Strategies

Consistent with our asset acquisition policies, we use leverage when available on terms we believe are favorable. The amount of leverage that we may employ will depend on our assessment of market conditions and other factors at the time of any proposed borrowing. Although we currently do not anticipate doing so, the amount of total funded debt leverage we employ may exceed 50 percent of our total assets. Secured loans which we obtain, could be recourse or non-recourse to us. A lender on non-recourse mortgage debt often has recourse only to the property collateralizing such debt and not to any of our other assets, while full recourse financing would give the lender recourse to all of our assets. The use of non-recourse debt, helps us to limit the exposure of all of our assets to any one debt obligation. Lenders may, however, have recourse to our other assets in limited circumstances not related to the repayment of the indebtedness, such as under an environmental indemnity. We may have an unsecured line of credit that can be used in connection with refinancing existing debt and making new acquisitions, as well as to meet other working capital needs. We generally intend to incur debt which bears interest at fixed rates, or is effectively converted to fixed rates through interest rate caps or swap agreements.

Competition

We compete with public and private funds, commercial and investment banks and commercial financing companies to make the types of investments that we plan to make in the U.S. energy infrastructure sector. Many of our competitors are substantially larger and have considerably greater financial, technical and marketing resources than us. For example, some competitors may have a lower cost of funds and access to a greater variety of funding sources than are available to us. In addition, some of our competitors may have higher risk tolerances or different risk assessments, allowing them to consider a wider variety of investments and establish more relationships than us. These competitive conditions may adversely affect our ability to make investments in the energy infrastructure sector and could adversely affect our distributions to stockholders.

MANAGEMENT

Our Manager

We are externally managed by Corridor. Corridor is a real property asset manager with a focus on U.S. energy infrastructure real property assets. Corridor assists us in identifying infrastructure real property asset acquisition opportunities, and is generally responsible for our day-to-day operations.

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Corridor Team

Each of our officers is an employee of Corridor or one of its affiliates. Corridor is not obligated to dedicate certain of its employees exclusively to us, nor are it or its employees obligated to dedicate any specific portion of its or their time to our business. Following the resignation of Richard C. Green as a director and Chairman of the Board of the Company, effective January 1, 2019, Mr. Green continues to be involved in the management services that Corridor provides to the Company in his capacity as a Managing Director of Corridor. As described below, we pay a management fee and certain other fees to Corridor, which it uses in part to pay compensation to its officers and employees who, notwithstanding that some of them also are our officers, receive no cash compensation directly from us.

We pay Corridor a management fee based on total assets under management. Additionally, in aligning our strategy to focus on distributions and distribution growth, Corridor is paid an incentive fee based on increases in distributions to our stockholders. A percentage of the Corridor incentive fee is reinvested in CorEnergy's common stock. Pursuant to the Management Agreement and Administrative Agreement, Corridor has agreed to use its reasonable best efforts to present us with suitable acquisition opportunities consistent with our investment objectives and policies and is generally responsible, subject to the supervision and review of our Board of Directors, for our day-to-day operations.

Energy Infrastructure Real Property Asset Management

The Corridor team has experience across several segments of the energy sector and is primarily responsible for investigating, analyzing and selecting potential infrastructure asset acquisition opportunities. Acquisitions and transactions are submitted to our Board of Directors for final approval following a recommendation from the management team.

We believe that effective management of our assets is essential to maintain and enhance property values. Important aspects of asset management include meeting the evolving needs of current tenants, re-leasing properties, refinancing debt, selling properties and knowledge of the bankruptcy process.

We monitor, on an ongoing basis, compliance by tenants with their lease obligations and other factors that could affect the financial performance of any of our properties. Monitoring involves receiving assurances that each tenant has paid real estate taxes, assessments and other expenses relating to the properties it occupies and confirming that appropriate insurance coverage is being maintained by the tenant. We review financial statements of tenants and undertake regular physical inspections of the condition and maintenance of properties. In addition, we periodically analyze each tenant's financial condition and the industry in which each tenant operates.

Management Agreement

Under our Management Agreement, Corridor (i) presents us with suitable acquisition opportunities consistent with our investment policies and our objectives, (ii) is responsible for our day-to-day operations and (iii) performs such services and activities relating to our assets and operations as may be appropriate. The Management Agreement does not have a specific term, and will remain in place unless terminated by us or Corridor in the manner permitted pursuant to the agreement.

The terms of the Management Agreement include a quarterly management fee equal to 0.25 percent (1.00 percent annualized) of the value of our Managed Assets as of the end of each quarter. For purposes of the Management Agreement, "Managed Assets" means our total assets (including any securities receivables, other personal property or real property purchased with or attributable to any borrowed funds) minus (A) the initial invested value of all non-controlling interests, (B) the value of any hedged derivative assets, (C) any prepaid expenses and (D) all of the accrued liabilities other than (1) deferred taxes and (2) debt entered into for the purpose of leverage. For purposes of the definition of Managed Assets, our securities portfolio will be valued at then-current market value. For purposes of the definition of Managed Assets, other personal property and real property assets will include real and other personal property owned and our assets invested, directly or indirectly, in equity interests in or loans secured by real estate or personal property (including acquisition-related costs and acquisition costs that may be allocated to intangibles or are unallocated), valued at the aggregate historical cost, before reserves for depreciation, amortization, impairment charges or bad debts or other similar noncash reserves.

The Management Agreement includes a quarterly incentive fee of 10 percent of the increase in distributions paid over a threshold distribution equal to $0.625 per share per quarter. The Management Agreement also requires at least half of any incentive fees to be reinvested in our common stock. Corridor received an incentive fee of $597 thousand during 2018.

Administrative Agreement

Under our Administrative Agreement, Corridor, as our administrator, performs (or oversees or arranges for the performance of) the administrative services necessary for our operation, including without limitation providing us with equipment, clerical,

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bookkeeping and record keeping services. For these services we pay our administrator an annual fee equal to 0.04 percent of the value of the Company's Managed Assets as of the end of each quarter, with a minimum annual fee of $30 thousand.

Pursuant to the Management and Administrative Agreement, Corridor furnishes us with office facilities and clerical and administrative services necessary for our operation (other than services provided by our custodian, accounting agent, dividend and interest-paying agent and other service providers). Corridor is authorized to enter into agreements with third parties to provide such services. To the extent we request, Corridor will (i) oversee the performance and payment of the fees of our service providers and make such reports and recommendations to the Board of Directors concerning such matters as the parties deem desirable; (ii) respond to inquiries and otherwise assist such service providers in the preparation and filing of regulatory reports, proxy statements, and stockholder communications, and the preparation of materials and reports for the Board of Directors; (iii) establish and oversee the implementation of borrowing facilities or other forms of leverage authorized by the Board of Directors; and (iv) supervise any other aspect of our administration as may be agreed upon by us and Corridor. We have agreed, pursuant to the Management Agreement, to reimburse Corridor for all out-of-pocket expenses incurred in providing the foregoing.

We bear all expenses not specifically assumed by Corridor and incurred in our operations. The compensation and allocable routine overhead expenses of all management professionals of Corridor and its staff, when and to the extent engaged in providing us management services, is provided and paid for by Corridor and not us.

Employees

As we are externally managed, we have no employees at the corporate level. Our subsidiary, Omega, has one part-time and three full-time employees. Our subsidiary MoGas has one part-time employee and 17 full-time employees.

AVAILABLE INFORMATION

We are required to file reports, proxy statements and other information with the SEC. We will make available free of charge our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to those reports on or through our web site at http://corenergy.reit as soon as reasonably practicable after such material is electronically filed with, or furnished to, the SEC. This information may also be obtained, without charge, upon request by calling us at (816) 875-3705 or toll-free at (877) 699-2677. The SEC maintains an Internet site that contains reports, proxy and information statements and other information filed by us with the SEC which is available on the SEC's Internet site at www.sec.gov. Please note that any Internet addresses provided in this Form 10-K are for informational purposes only and are not intended to be hyperlinks. Accordingly, no information found and/or provided at such Internet address is intended or deemed to be included by reference herein.

ITEM 1A. RISK FACTORS

There are many risks and uncertainties that can affect our future business, financial performance or share price. Many of these are beyond our control. A description follows of some of the important factors that could have a material negative impact on our future business, operating results, financial condition or share price. This discussion includes a number of forward-looking statements. You should refer to the description of the qualifications and limitations on forward-looking statements in the first paragraph under Item 7 "Management's Discussion and Analysis of Financial Condition and Results of Operations" of this Form 10-K.

Risks Related to Our Investments in Real Estate and the U.S. Energy Infrastructure Sector

Risks Related to Our Two Largest Investments

The Grand Isle Gathering System and the Pinedale LGS constitute the largest components of our leased infrastructure real property assets and associated lease revenues and will materially impact the results of our business.

The Grand Isle Gathering System represented approximately 35 percent of our total assets as of December 31, 2018, and the lease under the Grand Isle Lease Agreement with the EGC Tenant represented approximately 46 percent of our total revenue for the year ended December 31, 2018. The Pinedale LGS represented approximately 28 percent of our total assets as of December 31, 2018, and the lease payments under the Pinedale Lease Agreement with Ultra Wyoming represented approximately 29 percent of our total revenue for the year ended December 31, 2018. Accordingly, the financial condition of these tenants and related parent guarantors and the ability and willingness of each to satisfy their obligations under the respective lease agreements and guaranties will have an ongoing material impact on our results of operations, ability to service our indebtedness and ability to make distributions.

EGC, the corporate parent and guarantor of the obligations of EGC Tenant under the Grand Isle Lease Agreement and certain entities affiliated with it filed for bankruptcy on April 14, 2016. The EGC Tenant did not file for bankruptcy. On December 13, 2016, EGC announced the confirmation of its Plan of Reorganization by the bankruptcy court and, effective December 30, 2016, EGC emerged from its bankruptcy reorganization under the successor company name Energy XXI Gulf Coast, Inc., and we entered into related agreements effective December 30, 2016 pursuant to which the new EGC entity succeeded to the rights and obligations of pre-

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bankruptcy EGC under the original purchase agreement for the GIGS and as guarantor of the obligations of our tenant under the Grand Isle Lease Agreement. All payments due to us from the EGC Tenant were timely paid throughout the bankruptcy proceedings. EGC subsequently was acquired by an affiliate of Cox Oil, effective October 18, 2018.

Ultra Wyoming, the lessee of the Pinedale LGS, as well as Ultra Petroleum and Ultra Resources, the guarantors of Ultra Wyoming's obligations as tenant under the Pinedale Lease Agreement, each filed for bankruptcy on April 29, 2016. During the bankruptcy proceedings, Ultra Wyoming agreed to accept our lease without amendment, which was approved by the bankruptcy court on November 28, 2016. On March 14, 2017 the bankruptcy court approved Ultra Petroleum's Plan of Reorganization, and on April 12, 2017, the company announced its successful emergence from bankruptcy. All payments due to us under the Pinedale LGS lease were paid timely throughout the bankruptcy proceedings.

Despite their emergence from bankruptcy, Ultra Petroleum and, prior to its October 2018 acquisition by Cox Oil, EGC, have disclosed a number of risks related to their business in their respective filings with the SEC. A complete discussion of the risks related to Ultra Petroleum's business can be found in its Exchange Act reports filed with the SEC (NASDAQ: UPL). Prior to the filing by EGC of a Form 15 with the SEC on October 29, 2018, following its acquisition by an affiliate of Cox Oil, to suspend its SEC reporting obligations, EGC had also disclosed a discussion of risks related to its business in the Exchange Act reports that EGC had filed with the SEC as a public reporting company (NASDAQ: EGC). Since EGC ceased to be a public reporting company on and after such date, it has not disclosed any updates to such risks following the Cox Oil acquisition.

We are subject to the risk of EGC Tenant and Ultra Wyoming transferring their obligations under the Grand Isle Lease Agreement and the Pinedale Lease Agreement, respectively.

Under the terms of the Grand Isle Lease Agreement and the terms of the Pinedale Lease Agreement, both the EGC Tenant and Ultra Wyoming may transfer their respective rights and obligations under the Grand Isle Lease Agreement and the Pinedale Lease Agreement at any time, subject to certain conditions. We thus bear the risk that EGC Tenant will transfer its rights and obligations under the Grand Isle Lease Agreement, or that Ultra Wyoming will transfer its rights and obligations under the Pinedale Lease Agreement, in each case to a third party whose creditworthiness may not be on par with that of our current tenant, which could inhibit such transferee's ability to make timely lease payments under the Grand Isle Lease Agreement or the Pinedale Lease Agreement (as applicable), or increase the likelihood that a downturn in the business of such transferee could give rise to a default under the applicable lease agreement. The occurrence of either of these events could have a material adverse impact on our business and financial condition.

Additional Risks Related to Our Real Estate and Energy Infrastructure Investments

Our focus on the energy infrastructure sector will subject us to more risks than if we were broadly diversified.

Because we specifically focus on the energy infrastructure sector, investments in our common stock may present more risks than if we were broadly diversified over numerous sectors of the economy. Therefore, a downturn in the U.S. energy infrastructure sector would have a larger impact on our assets and performance than on a company that does not concentrate in one sector of the economy. The energy infrastructure sector can be significantly affected by the supply of and demand for specific products and services; the supply and demand for crude oil, natural gas, and other energy commodities; the price of crude oil, natural gas, and other energy commodities; exploration, production and other capital expenditures; government regulation; world and regional events, politics and economic conditions.

Production declines and volume decreases could be caused by various factors, including decreased access to capital or loss of economic incentive to drill and complete wells, depletion of resources, catastrophic events affecting production, labor difficulties, political events, OPEC actions, environmental proceedings, increased regulations, equipment failures and unexpected maintenance problems, failure to obtain necessary permits, unscheduled outages, unanticipated expenses, inability to successfully carry out new construction or acquisitions, import or export supply and demand disruptions, or increased competition from alternative energy sources.

We are subject to risks involved in single tenant leases.

A significant portion of our acquisition activities are focused on real properties that are triple-net leased to single tenants. Therefore, the financial failure of, or other default by, a single tenant under its lease: (i) is likely to cause a significant reduction in the operating cash flow generated by the property leased to that tenant, (ii) might decrease the value of that property, and (iii) could expose us to 100 percent of all applicable operating costs.

In addition, if we determine that a renewal of a lease with any present or future tenant of any of our energy infrastructure assets is not in the best interests of our stockholders, if a tenant determines it no longer wishes to be the tenant under a lease upon its expiration, if we desire to terminate a lease as a result of a breach of that lease by the tenant or if we lose any tenant as a result of such tenant's bankruptcy, then in each circumstance we would need to identify a new tenant for the lease. We may not be able to identify a new tenant, as interest in leasing certain of our assets would be dependent on ownership of an interest in nearby mineral rights. In addition, any new tenant would need to be a qualified and reputable operator of such energy infrastructure assets with the wherewithal and

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capability of acting as our tenant. There is no assurance that we would be able to identify a tenant that meets these criteria, or that we could enter into a new lease with any such tenant on terms that are as favorable as the lease terms that were in place with the prior tenant.

We may be unable to identify and complete acquisitions of real property assets.

Our ability to identify and complete acquisitions of real property assets on favorable terms and conditions are subject to the following risks:

• we may be unable to acquire a desired asset because of competition from other investors with significant capital, including both publicly traded and non-traded REITs and institutional investment funds;

• competition from other investors may significantly increase the purchase price of a desired real property asset or result in less favorable terms;

• we may not complete the acquisition of a desired real property asset even if we have signed an agreement to acquire such real property asset because such agreements are subject to customary conditions to closing, including completion of due diligence investigations to our satisfaction; and

• we may be unable to finance acquisitions of real property assets on favorable terms or at all.

Net leases may not result in fair market lease rates over time.

We expect a large portion of our future income to come from net leases. Net leases typically have longer lease terms and, thus, there is an increased risk that if market rental rates increase in future years, the rates under our net leases will be less than fair market rental rates during those years. As a result, our income and distributions could be lower than they would otherwise be if we did not engage in net leases. We often will seek to include a clause in each lease that provides increases in rent over the term of the lease, as well as participating features based on increases in the tenant's utilization of the underlying asset, but there can be no assurance we will be successful in obtaining such a clause.

If a tenant declares bankruptcy and such action results in a rejection of the lease, or if the sale-leaseback transaction is challenged as a fraudulent transfer or re-characterized in the lessee company's bankruptcy proceeding, our business, financial condition and cash flows could be adversely affected.

We enter into sale-leaseback transactions, whereby we purchase an energy infrastructure property and then simultaneously lease the same property back to the seller. If a lessee company declares bankruptcy, our business could be adversely affected by one or both of the following:

• A sale-leaseback transaction may be re-characterized by a bankruptcy court as either a disguised financing transaction or a functional joint venture. If the sale-leaseback were re-characterized as a financing transaction, we might not be considered the owner of the subject property and, as a result, we should have the status of a secured creditor of the lessee company with regard to the subject property, assuming the securitization measures we take as described below are respected by the bankruptcy court. In that event, we would no longer have the right to sell or encumber our ownership interest in the property. Instead, we would have a claim against the lessee company for the amounts owed under the lease. Although we believe each of our lease agreements constitutes a true lease that should not be subject to recharacterization, there is no guaranty that a bankruptcy court would agree. In the event of recharacterization, our claim under a lease agreement would either be secured or unsecured. As a preventative measure, we take steps to create and perfect a security interest in property made the subject of our lease agreements to ensure that our claim against the bankrupt lessee would be secured in the event of a recharacterization, but such attempts could be subject to challenge by the debtor or creditors and there is no assurance that a court would find our claim to be secured. The bankrupt lessee under this scenario might have the ability to restructure the terms, interest rate and amortization schedule of its outstanding balance owed under the lease. If approved by the bankruptcy court, we could be bound by the new terms, and prevented from foreclosing any lien on the property, so long as the lessee adhered to the new terms. If the sale-leaseback were re-characterized as a joint venture under applicable, non-bankruptcy law, we and the lessee company could be treated as co-venturers with regard to the property. As a result, we could be held liable, under some circumstances, for debts incurred by the lessee company relating to the property.

• A lessee could either assume, assign or reject a lease in a bankruptcy case. The bankrupt lessee is required to make rent payments to us during its bankruptcy until it rejects the commercial real property lease (for leases that are personal property leases, the lessee need not make rental payments that arise from the petition date until 60 days after the order for relief is entered in the bankruptcy case). If the lessee assumes the lease, the bankrupt debtor must pay or “cure” all existing monetary defaults under the lease. Further, the lease can only be assumed “as is”. The bankruptcy court would not be able to change the rental amount or any other lease provision that could financially impact us. However, if the lessee rejects the lease, the facility would be returned to us. If a lease is rejected, we may not be able to identify a new tenant, as interest in leasing

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certain of our assets would be dependent on ownership of an interest in nearby mineral rights. In addition, any new tenant would need to be a qualified reputable operator of such energy infrastructure assets with the wherewithal and capability of acting as our tenant. There is no assurance that we would be able to identify a tenant that meets these criteria, or that we could enter into a new lease with any such tenant on terms that are as favorable as the lease terms that were in place with the prior tenant. If we were able to re-lease the affected facility to a new tenant only on unfavorable terms or after a significant delay, we could lose some or all of the revenue from that facility for an extended period of time. Further, if the lease agreement is rejected, our claim against the lessee and/or parent guarantor could be, in some courts, subject to a statutory cap under section 502(b)(6) of the Bankruptcy Code to the extent the lease agreement is deemed to be a lease for real property rather than a lease for personal property. Such cap generally limits the amount of a claim for lease-based damages in the event of a termination of a commercial real property lease to the greater of one year's rent or 15 percent of the rent reserved for the remaining lease term, not to exceed 3 years. There is a national split of authority as to whether a rejection of such a lease equates a termination, so the outcome will depend on where the bankrupt lessee files its bankruptcy. We believe that any of our lease agreements would be characterized as real property leases rather than personal property leases, though a court could hold to the contrary.

Energy infrastructure companies are and will be subject to extensive regulation because of their participation in the energy infrastructure sector, which could adversely impact the business and financial performance of our tenants and the value of our assets.

Companies in the energy infrastructure sector are subject to significant federal, state and local government regulation in virtually every aspect of their operations, including how facilities are constructed, maintained and operated, environmental and safety controls, and the prices they may charge for the products and services they provide. Various governmental authorities have the power to enforce compliance with these regulations and the permits issued under them, and violators are subject to administrative, civil and criminal penalties, including civil fines, injunctions or both. Stricter laws, regulations or enforcement policies could be enacted in the future that likely would increase compliance costs, which could adversely affect the business and financial performance of our tenants in the energy infrastructure sector and the value or quality of our assets.

Costs of complying with governmental laws and regulations, including those relating to environmental matters, may adversely affect our income and the cash available for distribution to our stockholders.

We have invested, and expect to continue to invest, in real property assets, which are subject to laws and regulations relating to the protection of the environment and human health and safety. These laws and regulations generally govern the gathering, storage, handling, and transportation of petroleum and other hazardous substances, the emission and discharge of materials into the environment, including wastewater discharges and air emissions, the operation and removal of underground and aboveground storage tanks, the generation, use, storage, treatment, transportation and disposal of solid and hazardous materials and wastes, and the remediation of any contamination associated with such disposals. We own assets related to the storage and distribution of oil and gas, natural gas and natural gas liquids, and storage and throughput of crude oil, which are subject to all of the inherent hazards and risks normally incidental to such assets, such as fires, well site blowouts, cratering and explosions, pipe and other equipment and system failures, uncontrolled flows of oil, gas or well fluids, formations with abnormal pressures, environmental risks and hazards such as gas leaks, oil spills and pipeline ruptures and discharges of toxic gases. Environmental laws and regulations may impose joint and several liability on tenants, owners or operators for the costs to investigate or remediate contaminated properties, regardless of fault or whether the acts causing the contamination were legal. This liability could be substantial. Moreover, if one or more of these hazards occur, there can be no assurance that a response will be adequate to limit or reduce any resulting damage. In addition, the presence of hazardous substances, or the failure to properly remediate these substances, may adversely affect our ability to sell, rent or pledge such property as collateral for future borrowings. We also may be required to comply with various local, state and federal fire, health, life-safety and similar regulations.

Local, state and federal laws in this area are constantly evolving. Compliance with new or more stringent laws or regulations, or stricter interpretation of existing laws, may impose material environmental liability and/or require material expenditures by us to avoid such liability. Further, our tenant companies' operations, the existing condition of land when we buy it or operations in the vicinity of our properties (each of which could involve the presence of underground storage tanks), or activities of unrelated third parties may affect our properties. We intend to monitor these laws and take commercially reasonable steps to protect ourselves from the impact of these laws, including, where deemed necessary, obtaining environmental assessments of properties that we acquire. In addition, any such assessment that we do obtain may not reveal all environmental liabilities or whether a prior owner of a property created a material environmental condition not known to us and may not offer any protection against liability for known or unknown environmental conditions.

Failure to comply with applicable environmental, health, and safety laws and regulations may result in the assessment of sanctions, including administrative, civil or criminal fines or penalties, permit revocations, and injunctions limiting or prohibiting some or all

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of the operations at our facilities. Any material compliance expenditures, fines, or damages we must pay could materially and adversely affect our business, assets or results of operations and, consequently, would reduce our ability to make distributions.

Regulation of greenhouse gases and climate change could have a negative impact on our and our tenants' businesses.

We cannot predict with certainty the rate at which climate change is occurring. However, scientific studies have suggested that emissions of certain gases, commonly referred to as greenhouse gases ("GHGs") and including carbon dioxide and methane, may be contributing to warming of the earth's atmosphere and other climatic changes. In response to such studies, the issue of the effect of GHG emissions on climate change, in particular emissions from fossil fuels, is attracting increasing attention worldwide. We are aware of the increasing focus of local, state, national and international regulatory bodies on GHG emissions and climate change issues. The U.S. Environmental Protection Agency ("EPA") has adopted rules requiring GHG reporting and permitting, and the United States Congress and EPA may consider additional legislation or regulations that could ultimately require new, modified, and reconstructed facilities, and/or existing facilities, to meet emission standards by installing control technologies, adopting work practices, or otherwise reducing GHG emissions. Although it is not possible at this time to predict whether proposed legislation or regulations will be adopted, any such future laws and regulations could result in increased compliance costs or additional operating restrictions that could adversely impact our energy infrastructure assets as well as the businesses of our tenants and customers. If we or our tenants are unable to recover or pass through a significant level of the costs related to complying with any such future climate change and GHG regulatory requirements, it could have a material adverse impact on our or our tenants' business, financial condition and results of operations. Further, to the extent financial markets view climate change and GHG emissions as a financial risk, this could negatively impact our cost of or access to capital. Climate change and GHG regulation could also reduce the demand for hydrocarbons and, ultimately, demand for utilization of our energy infrastructure assets related to the production and distribution of hydrocarbons.  Finally, it should be noted that studies suggest that increasing concentrations of GHGs in the Earth's atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of hurricanes and other storms, floods and related climatic events. If any such effects were to occur, they could have an adverse effect on our assets and operations, particularly an offshore asset such as the GIGS.

Our operations, as well as those of our tenants, are subject to operational hazards and unforeseen interruptions. If a significant accident or event occurs that results in a business interruption or shutdown for which we or our tenant operators are not adequately insured, such operations and our financial results could be materially adversely affected.

Our assets are subject to many hazards inherent in the transmission of energy products and provision of related services, including:

• aging infrastructure, mechanical or other performance problems;

• damage to pipelines, facilities and related equipment caused by tornadoes, hurricanes, floods, fires and other natural disasters, explosions and acts of terrorism;

• inadvertent damage from third parties, including from construction, farm and utility equipment;

• leaks of natural gas and other hydrocarbons or losses of natural gas as a result of the malfunction of equipment or facilities;

• operator error;

• environmental hazards, such as natural gas leaks, product and waste spills, pipeline and tank ruptures, and unauthorized discharges of products, wastes and other pollutants into the surface and subsurface environment, resulting in environmental pollution; and explosions.

These risks could result in substantial losses due to personal injury and/or loss of life, severe damage to and destruction of property and equipment and pollution or other environmental damage and may result in curtailment or suspension of our or our tenants' related operations or services. A natural disaster or other hazard affecting the areas in which we or our tenants operate could have a material adverse effect on our operations and the financial results of our business.

Both we and our tenants depend on certain key customers for a significant portion of our respective revenues. The loss of any such key customers could result in a decline in our business.

Both we and our tenants are subject to risks of loss resulting from nonperformance by customers. We depend on certain key customers for a significant portion of our revenues, particularly operating revenues from MoGas. Our tenants are similarly dependent on revenues from key customers to support their operations and ability to make lease payments to us. The loss of all or even a portion of the contracted volumes of such customers, as a result of competition, creditworthiness, inability to negotiate extensions or replacements of contracts or otherwise, could have a material adverse effect on the business, financial condition and results of operations of us or our tenants (as applicable), unless we or they are able to contract for comparable volumes from other customers at favorable rates.

We are exposed to the credit risk of our tenants and customers and our credit risk management may not be adequate to protect against such risk.

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We are subject to the risk of loss resulting from nonpayment and/or nonperformance by our tenants and customers. Our credit procedures and policies may not be adequate to fully eliminate such credit risk. If we fail to adequately assess the creditworthiness of existing or future tenants or customers, unanticipated deterioration in their creditworthiness and any resulting increase in nonpayment and/or nonperformance by them and inability to re-market the resulting capacity, or re-lease the underlying assets, could have a material adverse effect on our business, financial condition and results of operations. We may not be able to effectively re-market such capacity, or re-lease such assets, during and after bankruptcy or insolvency proceedings involving a tenant or customer.

Our assets and operations, as well as those of our tenants and other investees and customers, can be affected by extreme weather patterns and other natural phenomena.

Our assets and operations, as well as those of our tenants and other investees and customers, can be adversely affected by floods, hurricanes, earthquakes, landslides, tornadoes and other natural phenomena and weather conditions, including extreme or unseasonable temperatures, making it more difficult for us to realize the historic rates of return associated with our assets and operations. These events also could result in significant volatility in the supply of energy and power, which might create fluctuations in commodity prices and earnings of companies in the energy infrastructure sector. A significant disruption in our operations or those of our tenants, investees or customers, or a significant liability for which we or any affected tenant or investee is not fully insured, could have a material adverse effect on our business, results of operations, and financial condition. Moreover, extreme weather events could adversely impact the valuation of our energy infrastructure assets.

The operation of our energy infrastructure assets could be adversely affected if third-party pipelines, railroads or other facilities interconnected to our facilities become partially or fully unavailable.

Our facilities, as well as those of our tenants, may connect to other pipelines, railroads or facilities owned by third parties. Both we and our tenants depend upon third-party pipelines and other facilities that provide delivery options to and from such facilities. For example, MoGas' pipeline interconnects, directly or indirectly, with most major interstate pipelines in the eastern portion of the U.S. and a significant number of intrastate pipelines. Because we do not own these third-party facilities, their continuing operation is not within our control. Accordingly, these pipelines and other facilities may become unavailable, or available only at a reduced capacity. If these pipeline connections were to become unavailable to us or our tenants for current or future volumes of products due to repairs, damage, lack of capacity or any other reason, our ability, or the ability of our tenants, to operate efficiently and continue shipping products to end markets could be restricted, thereby reducing revenues. Likewise, if any of these third-party pipelines or facilities becomes unable to transport any products distributed or transported through our or our tenants' facilities, our or our tenants' business, results of operations and financial condition could be adversely affected, which could adversely affect our ability to make cash distributions to our stockholders.

The relative illiquidity of our real property and energy infrastructure asset investments may interfere with our ability to sell our assets when we desire.

Investments in real property and energy infrastructure assets are relatively illiquid compared to other investments. Accordingly, we may not be able to sell such assets when we desire or at prices acceptable to us in response to changes in economic or other conditions. This could substantially reduce the funds available for satisfying our obligations and for distribution to our stockholders.

Additional Risks Related to the Grand Isle Gathering System and Grand Isle Lease Agreement

Requirements imposed by the BOEM and BSEE related to the decommissioning, plugging, and abandonment of offshore facilities could significantly impact our cost of owning the Grand Isle Gathering System, which could have a material adverse impact on our financial condition and ability to make distributions to our stockholders.

The Bureau of Ocean Energy Management (the "BOEM") issued guidance effective October 15, 2010, following the Deepwater Horizon accident, that effectively established a more stringent regimen for the timely decommissioning of what is known as "idle iron"-wells, platforms and pipelines that are no longer producing or serving exploration or support functions related to an operator's lease-in the GOM. This guidance includes decommissioning requirements providing that pipelines, platforms or other facilities, which would include various components of the Grand Isle Gathering System, that are no longer useful for operations must be removed within five years of the cessation of operations, or as otherwise specified therein. A higher than normal level of decommissioning activity in the GOM at a time when the Grand Isle Gathering System is decommissioned may result in increased demand for salvage contractors and equipment, which in turn could result in increased estimates of plugging, abandonment and removal costs related to these regulatory asset retirement obligations.

To cover these asset retirement obligations, the BOEM generally requires that OCS lessees, pipeline right-of-way holders and other facility owners demonstrate financial strength and reliability according to regulations or post bonds or other acceptable assurances that such obligations will be satisfied. In July 2016, the BOEM issued a new Notice to Lessees ("NTL") with an effective date of September 12, 2016, requiring additional security for decommissioning activities. The BOEM announced on June 22, 2017 that, pending its review of the NTL, the implementation timeline would be indefinitely extended, subject to certain exceptions. At this

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time it seems uncertain when or if the new NTL will be implemented. The cost of these bonds or assurances can be substantial and could increase under the BOEM's latest policies, depending on the outcome of the Trump administration's review during the extended implementation period. There is no assurance that such bonds or assurances can be obtained in all cases. While EGC historically has satisfied these requirements with respect to its ownership and operation of the Grand Isle Gathering System, and the terms of the Grand Isle Lease Agreement require EGC to continue to do so, given continued volatility in commodity prices and the unwillingness of the surety companies to post bonds without the requisite collateral from operators such as EGC, there is no assurance that EGC will be able to continue to satisfy the demands for additional collateral for its current bonds or comply with any new supplemental bonding requirements. If EGC were financially unable to satisfy these requirements, Grand Isle Corridor, LP, as the owner of the Grand Isle Gathering System, would be required to do so. There can be no assurance that we would be able to meet any such increased bonding requirements. Under some circumstances, the BOEM may require any of our or our lessee's operations on federal leases, rights-of-way or facilities to be suspended or terminated. Any such suspension or termination could materially adversely affect our financial condition and results of operations. In addition, the BOEM can require supplemental bonding from operators for decommissioning, plugging, and abandonment liabilities if financial strength and reliability criteria are not met. If EGC is unable to fund any such supplemental bonding requirements and our subsidiary were required to bear the cost as owner of the Grand Isle Gathering System, such cost could have a material adverse impact on our financial condition and ability to make distributions to our stockholders.

The Bureau of Safety and Environmental Enforcement ("BSEE") administers regulations governing blowout preventer systems and well control for oil and gas and sulfur operations on the OCS; lease term requirements for continuing operations; and production safety systems. BSEE regulations also require offshore oil and gas lessees and owners of operating rights to submit summaries of their actual expenditures for decommissioning pipelines and wells, platforms, and other facilities on the OCS. These regulations may require capital expenditures and other compliance costs and could result in liability for non-compliance.

Failure to comply with these laws and regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations. In addition, increases in penalty amounts and limits of liability for damages to reflect inflation and/or increases in the CPI may result in increased exposure to EGC and its indirect parent, Cox Oil. EGC and Cox Oil may be unable to recover some or all of the resulting costs through insurance or increased revenues, which could have a material adverse effect on its business, results of operations and financial condition.

Additional Risks Related to Our Ownership and Operation of MoGas

MoGas' operations are subject to extensive regulation, including those relating to environmental matters, which may adversely affect our income and the cash available for distribution.

In addition to the regulations discussed above and pipeline safety regulations discussed below, MoGas' operations are subject to extensive federal, regional, state and local environmental laws including, for example, the Clean Air Act (CAA), the Clean Water Act (CWA), the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), the Resource Conservation and Recovery Act (RCRA), the Oil Pollution Act (OPA), the Occupational Safety and Health Administration (OSHA) and analogous state and local laws. These laws and their implementing regulations may restrict or impact MoGas' business activities in many ways, including requiring the acquisition of permits or other approvals to conduct regulated activities, limiting emissions and discharges of pollutants, restricting the manner in which it disposes of wastes, requiring remedial action to remove or mitigate contamination, requiring capital expenditures to comply with pollution control or workplace safety requirements, and imposing substantial liabilities for pollution resulting from its operations. In addition, the regulations implementing these laws are constantly evolving, and the potential impact of recent regulatory actions is unclear. For instance, EPA adopted final rules establishing new source performance standards for methane emissions from new, modified, or reconstructed oil and gas sources, although a stay and the amendment of certain requirements have been proposed. Compliance with new or more stringent laws or regulations, or stricter interpretation of existing laws, may require material expenditures by MoGas.

Failure to comply with these laws and regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial requirements and the issuance of orders enjoining future operations. In addition, increases in penalty amounts and limits of liability for damages to reflect inflation and/or increases in the CPI may result in increased exposure to MoGas. MoGas may be unable to recover some or all of the resulting costs through insurance or increased revenues, which could have a material adverse effect on its business, results of operations and financial condition.

MoGas' natural gas transmission operations are subject to regulation by FERC.

MoGas' business operations are subject to regulation by FERC, including the types and terms of services MoGas may offer to its customers, construction of new facilities, expansion of current facilities, creation, modification or abandonment of services or facilities, record keeping and relationships with affiliated companies. Compliance with these requirements can be costly and burdensome and FERC action in any of these areas could adversely affect MoGas' ability to compete for business, construct new

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facilities, expand current facilities, offer new services, recover the full cost of operating its pipelines or earn its authorized rate of return. This regulatory oversight can result in longer lead times or additional costs to develop and complete any future project than competitors that are not subject to FERC's regulations.

In addition, the rates MoGas can charge for its natural gas transmission operations are regulated by FERC pursuant to the Natural Gas Act of 1938 ("NGA") as follows:

• MoGas may only charge rates that have been determined to be just and reasonable by FERC, subject to a prescribed maximum and minimum, and is prohibited from unduly preferring or unreasonably discriminating against any person with respect to its rates or terms and conditions of service.

• MoGas' existing rates may be challenged in a proceeding before FERC, which may reduce MoGas' rates if FERC finds the rates are not just and reasonable or are unduly preferential or unduly discriminatory. Proposed rate increases may be challenged by protest and allowed to go into effect subject to refund. Even if a rate increase is permitted by FERC to become effective, the rate increase may not be adequate.

To the extent MoGas' costs increase in an amount greater than its revenues increase, or there is a lag between MoGas' cost increases and its ability to file for and obtain rate increases, MoGas' operating results would be negatively affected.

Should FERC find that MoGas has failed to comply with all applicable FERC-administered statutes, rules, regulations, and orders, or with the terms of MoGas' tariffs on file with FERC, MoGas could be subject to substantial penalties and fines. Under the Energy Policy Act of 2005 ("EPAct 2005"), FERC has civil penalty authority under the NGA and Natural Gas Policy Act of 1978 ("NGPA") to impose penalties for violations of up to approximately $1.3 million per day for each violation, to revoke existing certificate authority and to order disgorgement of profits associated with any violation.

On May 31, 2018, MoGas filed a general rate case with FERC seeking to (i) recover increases in capital, operating and maintenance expenditures incurred; (ii) mitigate the revenue impact from the substantial decrease in volumes due to the loss of a firm transportation contract with a St. Louis natural gas marketing entity; (iii) mitigate the substantial decrease in revenue from the negotiated rate charged to MoGas' largest customer; and (iv) reflect changes in the corporate income tax rate associated with the 2017 Tax Cuts and Jobs Act. MoGas' filing proposed an increase in MoGas' revenue requirement of approximately $8.7 million. The parties are currently engaged in settlement discussions.

The proposed rates went into effect on December 1, 2018, subject to refund. If the proposed increase in MoGas' revenue requirement is not approved by FERC, or if FERC determines to utilize a set of volume assumptions (billing determinants) to calculate MoGas' rates different from those proposed by MoGas, the rates finally approved by FERC could be less than those proposed by MoGas and placed into effect subject to refund. Should that be the case, MoGas would have a refund obligation, to its customers with respect to the difference between the approved rates and those collected subject to refund, plus interest at FERC's prescribed refund interest rate. If the rates finally approved by FERC are less than those proposed by MoGas, MoGas could be unable to earn the rate of return MoGas proposed in its rate filing.

We cannot give any assurance regarding the outcome of the pending rate case or potential future regulations under which MoGas will operate its natural gas transmission business or the effect the pending rate case or such future regulations could have on MoGas' business, financial condition and results of operations.

The revenues of MoGas' business are generated under contracts that are subject to cancellation on an annual basis.

Other than MoGas' revenues from its largest customer, Spire, the next two largest customers' revenues for MoGas' business are generated under transportation contracts which have an initial term of at least one year and renew automatically on a year-to-year basis, but are subject to cancellation by the customer on 365 days' notice. If MoGas is unable to succeed in replacing any contracts canceled by local distribution companies ("LDCs") or other customers that account for a significant portion of its revenues, or in renegotiating such contracts on terms substantially as favorable as the existing contracts, MoGas could suffer a material reduction in its revenues, financial results and cash flows. The maintenance or replacement of existing contracts with MoGas' customers at rates sufficient to maintain current or projected revenues and cash flows ultimately depends on a number of factors beyond its control, including competition from other pipelines, the proximity of supplies to the markets, and the price of, and demand for, natural gas. In addition, changes in state regulation of LDCs may cause them to exercise their cancellation rights in order to turn back their capacity when the contracts expire.

Effective March 1, 2017, MoGas entered in to a long-term firm transportation services agreement with Spire, its largest customer, which accounts for approximately 44 percent of MoGas' revenue. The amended agreement extends the termination date for Spire's existing firm transportation agreement from October 31, 2017 to October 31, 2030. During the entire extended term, Spire will continue to reserve 62,800 dekatherms per day of firm transportation on MoGas. This service continued at the full tariff rate of $12.385 per dekatherm per month until October 31, 2018, at which time the rate was reduced to $6.386 per dekatherm per month

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for the remainder of the agreement. If MoGas is unable to execute on its plans to offset the reduction in revenue resulting from the reduced rate under the long-term Spire contract beginning in November of 2018, its business and cash flows could be materially adversely affected.

Pipeline safety integrity programs and repairs may impose significant costs and liabilities on MoGas.

Regulations administered by the Federal Office of Pipeline Safety within the U.S. Department of Transportation's Pipeline and Hazardous Materials Safety Administration ("PHMSA") require pipeline operators to develop integrity management programs to comprehensively evaluate certain areas along their pipelines and to take additional measures to protect pipeline segments located in "high consequence areas" where a leak or rupture could potentially do the most harm. As an operator, MoGas is required to:

• perform ongoing assessments of pipeline integrity;

• identify and characterize applicable threats to pipeline segments that could impact a high consequence area;

• improve data collection, integration and analysis;

• repair and remediate the pipeline as necessary; and

• implement preventative and mitigating actions.

MoGas is required to maintain pipeline integrity testing programs that are intended to assess pipeline integrity. Any repair, remediation, preventative or mitigating actions could require significant capital and operating expenditures. The regulations implementing these laws are constantly evolving; pursuant to its reauthorization under the Protecting our Infrastructure of Pipelines and Enhancing Safety Act of 2016, PHMSA has adopted rules implementing its emergency order authority over pipelines, revising federal pipeline safety regulations related to underground natural gas storage facilities, and imposing additional requirements on the transportation of natural gas and hazardous liquids by pipeline, including more stringent standards for plastic pipe. A rule amending the safety regulations applicable to gas transmission and gathering pipelines has also been proposed, and a notice of proposed rulemaking to harmonize the hazardous materials regulations with international regulations and standards has been issued. Compliance with new or more stringent laws or regulations, or stricter interpretation of existing laws, could significantly increase compliance costs. Should MoGas fail to comply with the Federal Office of Pipeline Safety's rules and related regulations and orders, it could be subject to significant penalties and fines, including potential future increases in applicable penalty amounts to reflect inflation, which could have a material adverse effect on MoGas' business, results of operations and financial condition.

MoGas competes with other pipelines.

The principal elements of competition among pipelines are availability of capacity, rates, terms of service, access to supplies, flexibility, and reliability of service. Additionally, FERC's policies promote competition in natural gas markets by increasing the number of natural gas transmission options available to MoGas' customer base. Any current or future pipeline system or other form of transmission that delivers natural gas into the areas that MoGas serves could offer transmission services that are more desirable to shippers than those MoGas provides because of price, location, facilities or other factors. Increased competition could reduce the volumes of product MoGas transports, result in a reduction in the rates MoGas is able to negotiate with its customers, or cause customers to choose to ship their product on a different competing pipeline. Any one of these consequences could have a material adverse impact on MoGas, or on the operations of any other pipeline owned by the Company. These competitive considerations also could intensify the negative impact of factors that adversely affect the demand for MoGas' services, such as adverse economic conditions, weather, higher fuel costs and taxes or other regulatory actions that increase the cost, or limit the use, of products MoGas transports.

Risks Related to Our Financing Arrangements

Our indebtedness could have important consequences, including impairing our ability to obtain additional financing or pay future distributions, as well as subjecting us to the risk of foreclosure on any mortgaged properties in the event of non-payment of the related debt.

As of December 31, 2018, we had outstanding consolidated indebtedness of approximately $151.4 million. Our leverage could have important consequences. For example, it could:

• result in the acceleration of a significant amount of debt for non-compliance with the terms of such debt or, if such debt contains cross-default or cross-acceleration provisions, other debt;

• materially impair our ability to borrow undrawn amounts under existing financing arrangements or to obtain additional financing or refinancing on favorable terms or at all;

• require us to dedicate a substantial portion of our cash flow to paying principal and interest on our indebtedness, thereby reducing the cash flow available to fund our business, to pay distributions, including those necessary to maintain REIT qualification, or to use for other purposes;

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• increase our vulnerability to economic downturns;

• limit our ability to withstand competitive pressures; or

• reduce our flexibility to respond to changing business and economic conditions.

It is also important to note that our variable rate indebtedness under the CorEnergy Credit Facility and the Mowood/Omega Revolver use LIBOR as a benchmark for establishing the rate. LIBOR is the subject of recent national, international and other regulatory guidance and proposals for reform. These reforms and other pressures may cause LIBOR to disappear entirely or to perform differently than in the past. The consequences of these developments cannot be entirely predicted, but could include an increase in the cost of our variable rate indebtedness.

Further, we expect to mortgage many of our properties to secure payment of indebtedness. If we are unable to meet mortgage payments, such failure could result in the loss of assets due to foreclosure and transfer to the mortgagee or sale on unfavorable terms with a consequent loss of income and asset value. A foreclosure of one or more of our properties could create taxable income without accompanying cash proceeds, and could adversely affect our financial condition, results of operations, cash flow, and ability to service debt and make distributions and the market price of our stock.

We face risks associated with our dependence on external sources of capital.

In order to qualify as a REIT, we are required each year to distribute to our stockholders at least 90 percent of our REIT taxable income, and we will be subject to tax on our income to the extent it is not distributed. Because of this distribution requirement, we may not be able to fund all future capital needs from cash retained from operations. As a result, to fund capital needs, we must rely on third-party sources of capital, which we may not be able to obtain on favorable terms, if at all. Our access to third-party sources of capital depends upon a number of factors, including (i) general market conditions; (ii) the market's perception of our growth potential; (iii) our current and potential future earnings and cash distributions; and (iv) the market price of our capital stock. Additional debt financing may substantially increase our debt-to-total capitalization ratio. Additional equity issuances may dilute the holdings of our current stockholders.

Covenants in our loan documents could limit our flexibility and adversely affect our financial condition.

The terms of our various credit agreements and other indebtedness require us to comply with a number of customary financial and other covenants, such as maintaining debt service coverage and leverage ratios and maintaining insurance coverage. These covenants may limit our flexibility in our operations, and breaches of these covenants could result in defaults under the instruments governing the applicable indebtedness even if we had satisfied our payment obligations. If we were to default under credit agreements or other debt instruments, our financial condition would be adversely affected.

We face risks related to "balloon payments" and refinancings.

Certain of our mortgages will have significant outstanding principal balances on their maturity dates, commonly known as "balloon payments." There can be no assurance that we will be able to refinance the debt on favorable terms or at all. To the extent we cannot refinance this debt on favorable terms or at all, we may be forced to dispose of properties on disadvantageous terms or pay higher interest rates, either of which would have an adverse impact on our financial performance and ability to service debt and make distributions.

Risk Related to Our Convertible Notes

We expect that the trading value of the Convertible Notes will be significantly affected by the price of our common stock, which may be volatile.

The market price of our common stock, as well as the general level of interest rates and our credit quality, will likely significantly affect the market price of the Convertible Notes. This may result in significantly greater volatility in the trading value of the Convertible Notes than would be expected for nonconvertible debt securities we may issue.

We cannot predict whether the price of our common stock or interest rates will rise or fall. Trading prices of our common stock will be influenced by our operating results and prospects and by economic, financial, regulatory and other factors. General market conditions, including the level of, and fluctuations in, the trading prices of stocks generally, could affect the price of our common stock.

Holders who receive shares of our common stock upon the conversion of their Convertible Notes will be subject to the risk of volatile and depressed market prices of our common stock. There can be no assurances that the market price of our common stock will not fall in the future.

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The Convertible Notes are structurally subordinated to all liabilities of our existing or future subsidiaries.

Holders of the Convertible Notes do not and will not have any claim as a creditor against any of our present or future subsidiaries. Indebtedness and other liabilities of those subsidiaries, including trade payables, whether secured or unsecured, are structurally senior to our obligations to holders of the Convertible Notes. In the event of a bankruptcy, liquidation, reorganization or other winding up of any of our subsidiaries, such subsidiaries will pay the holders of their debts, holders of any equity interests, including fund investors, and their trade creditors before they will be able to distribute any of their assets to us (except to the extent we have a claim as a creditor of such subsidiary). Any right that we have to receive any assets of any of the subsidiaries upon the bankruptcy, liquidation, reorganization or other winding up of those subsidiaries, and the consequent rights of holders of Convertible Notes to realize proceeds from the sale of any of those subsidiaries' assets, will be effectively structurally subordinated to the claims of those subsidiaries' creditors, including trade creditors and holders of any preferred equity interests of those subsidiaries.

Servicing our debt requires a significant amount of cash, and we may not have sufficient cash flow from our business to pay our substantial debt.

Our ability to make scheduled payments of the principal of, to pay interest on or to refinance our indebtedness, including the Convertible Notes, depends on our future performance, which is subject to economic, financial, competitive and other factors beyond our control. Our business may not continue to generate cash flow from operations in the future sufficient to service our debt and make necessary capital expenditures. If we are unable to generate such cash flow, we may be required to adopt one or more alternatives, such as selling assets, restructuring debt or obtaining additional equity capital on terms that may be onerous or highly dilutive. Our ability to refinance our indebtedness will depend on the capital markets and our financial condition at such time. We may not be able to engage in any of these activities or engage in these activities on desirable terms, which could result in a default on our debt obligations.

Regulatory actions may adversely affect the trading price and liquidity of the Convertible Notes.

Current and future regulatory actions and other events may adversely affect the trading price and liquidity of the Convertible Notes. We expect that many investors in, and potential purchasers of, the Convertible Notes will employ, or seek to employ, a convertible arbitrage strategy with respect to the Convertible Notes. Investors would typically implement such a strategy by selling short the common stock underlying the Convertible Notes and dynamically adjusting their short position while continuing to hold the Convertible Notes. Investors may also implement this type of strategy by entering into swaps on our common stock in lieu of or in addition to short selling the common stock.

The SEC and other regulatory and self-regulatory authorities have implemented various rules and taken certain actions, and may in the future adopt additional rules and take other actions, which may impact those engaging in short selling activity involving equity securities (including our common stock). Such rules and actions include Rule 201 of SEC Regulation SHO, the adoption by the Financial Industry Regulatory Authority, Inc. and the national securities exchanges of a "Limit Up-Limit Down" program, the imposition of market-wide circuit breakers that halt trading of securities for certain periods following specific market declines, and the implementation of certain regulatory reforms required by the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010. Any governmental or regulatory action that restricts the ability of investors in, or potential purchasers of, the Convertible Notes to effect short sales of our common stock, borrow our common stock or enter into swaps on our common stock could adversely affect the trading price and the liquidity of the Convertible Notes.

We may still incur substantially more debt or take other actions which would intensify the risks discussed above.

We and our subsidiaries may be able to incur substantial additional debt in the future, subject to the restrictions contained in our debt instruments, some of which may be secured debt. We are not restricted under the terms of the Indenture governing the Convertible Notes from incurring additional debt, securing existing or future debt, recapitalizing our debt or taking a number of other actions that are not limited by the terms of the Indenture governing the Convertible Notes that could have the effect of diminishing our ability to make payments on the Convertible Notes when due. Our existing credit facilities restrict our ability to incur additional indebtedness, including secured indebtedness, but we may be able to obtain waivers of such restrictions or may not be subject to such restrictions under the terms of any subsequent indebtedness.

We may not have the ability to raise the funds necessary to repurchase the Convertible Notes, including upon a fundamental change.

Holders of the Convertible Notes have the right to require us to repurchase their Convertible Notes upon the occurrence of certain events constituting a fundamental change, as set forth in the Indenture, at a repurchase price equal to 100 percent of the principal amount of the Convertible Notes to be repurchased, plus accrued and unpaid interest, if any, thereon to (but excluding) the fundamental change purchase date. However, we may not have enough available cash or be able to obtain financing at the time we are required to make repurchases of Convertible Notes surrendered therefor. Our failure to repurchase Convertible Notes at a time when the

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repurchase is required by the Indenture would constitute a default under the Indenture. A default under the Indenture or the fundamental change itself could also lead to a default under agreements governing our existing or future indebtedness. If the repayment of the related indebtedness were to be accelerated after any applicable notice or grace periods, we may not have sufficient funds to repay the indebtedness and repurchase the Convertible Notes or make cash payments upon conversions thereof. Our ability to repurchase the Convertible Notes may also be limited by law or by regulatory authority.

Holders of Convertible Notes are not entitled to any rights with respect to our common stock, but are subject to all changes made with respect to our common stock.

Holders of Convertible Notes are not entitled to any rights with respect to our common stock (including, without limitation, voting rights and rights to receive any dividends or other distributions on the common stock) prior to the conversion date with respect to any Convertible Notes they surrender for conversion, but are subject to all changes affecting our common stock. For example, if an amendment is proposed to our charter or bylaws requiring stockholder approval and the record date for determining the stockholders of record entitled to vote on the amendment occurs prior to the conversion date with respect to any Convertible Notes surrendered for conversion, then the holder surrendering such Convertible Notes will not be entitled to vote on the amendment, although such holder will nevertheless be subject to any changes affecting our common stock.

The Convertible Notes are not protected by restrictive covenants.

The Indenture governing the Convertible Notes does not contain any financial or operating covenants or restrictions on the payments of dividends, the incurrence of indebtedness or the issuance or repurchase of securities by us or any of our subsidiaries. The Indenture contains no covenants or other provisions to afford protection to holders of the Convertible Notes in the event of a fundamental change or other corporate transaction involving us except in limited circumstances as set forth in the Indenture. For example, events such as leveraged recapitalizations, refinancings, restructurings or acquisitions initiated by us may not constitute a fundamental change requiring us to repurchase the Convertible Notes. In the event of any such events, the holders of the Convertible Notes would not have the right to require us to repurchase the Convertible Notes, even though each of these transactions could increase the amount of our indebtedness, or otherwise adversely affect our capital structure or any credit ratings, thereby adversely affecting the trading price of the Convertible Notes.

The adjustment to the conversion rate for Convertible Notes converted in connection with a Make Whole Adjustment Event may not adequately compensate the holders for any lost value of their Convertible Notes as a result of such transaction.

If a "Make Whole Adjustment Event" (as defined in the Indenture) occurs, under certain circumstances, we will increase the conversion rate by a number of additional shares of our common stock for Convertible Notes converted in connection with such Make Whole Adjustment Event. The increase in the conversion rate will be determined based on the date on which the specified corporate transaction becomes effective and the price paid (or deemed to be paid) per share of our common stock in such transaction, all as set forth in the Indenture. The adjustment to the conversion rate for Convertible Notes converted in connection with a make whole fundamental change may not adequately compensate the holders for any lost value of their Convertible Notes as a result of such transaction. In addition, if the price of our common stock in the transaction is greater than $45.00 per share or less than $30.00 per share (in each case, subject to adjustment), no additional shares will be added to the conversion rate. Moreover, in no event will the conversion rate per $1,000 principal amount of Convertible Notes as a result of this adjustment exceed 33.3333 shares, subject to adjustments in the same manner as the conversion rate under the terms of the Indenture.

Our obligation to increase the conversion rate upon the occurrence of a make whole fundamental change could be considered a penalty, in which case the enforceability thereof would be subject to general principles of reasonableness and equitable remedies.

The conversion rate of the Convertible Notes may not be adjusted for all dilutive events.

The conversion rate of the Convertible Notes is subject to adjustment for certain events, including, but not limited to, the issuance of certain stock dividends on our common stock, the issuance of certain rights or warrants, subdivisions, combinations, distributions of capital stock, indebtedness, or assets, cash dividends and certain issuer tender or exchange offers. However, the conversion rate will not be adjusted for other events, such as a third-party tender or exchange offer or an issuance of common stock for cash, that may adversely affect the trading price of the Convertible Notes or our common stock. An event that adversely affects the value of the Convertible Notes may occur, and that event may not result in an adjustment to the conversion rate.

Some significant restructuring transactions and significant changes in the composition of our board may not constitute a fundamental change, in which case we would not be obligated to offer to repurchase the Convertible Notes.

Upon the occurrence of a fundamental change, holders of Convertible Notes have the right to require us to repurchase their Convertible Notes. However, the fundamental change provisions of the Indenture do not afford protection to holders of Convertible Notes in the event of other transactions that could adversely affect the Convertible Notes. For example, transactions such as leveraged recapitalizations, refinancings, restructurings, or acquisitions initiated by us may not constitute a fundamental change requiring us

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to repurchase the Convertible Notes. In the event of any such transaction, the holders would not have the right to require us to repurchase the Convertible Notes, even though each of these transactions could increase the amount of our indebtedness, or otherwise adversely affect our capital structure or any credit ratings, thereby adversely affecting the holders of Convertible Notes.

An active trading market may not develop for the Convertible Notes or, if it develops, may not be maintained or be liquid.

We do not intend to apply to list the Convertible Notes on any securities exchange or to arrange for quotation on any automated dealer quotation system. The underwriters in our public offering of the Convertible Notes may cease their market-making of the Convertible Notes at any time without notice. In addition, the liquidity of the trading market in the Convertible Notes, and the market price quoted for the Convertible Notes, may be adversely affected by changes in the overall market for this type of security and by changes in our financial performance or prospects or in the prospects for companies in our industry generally. As a result, an active trading market may not develop for the Convertible Notes. If an active trading market does not develop or is not maintained, the market price and liquidity of the Convertible Notes may be adversely affected. In that case holders of the Convertible Notes may not be able to sell their Convertible Notes at a particular time or they may not be able to sell their Convertible Notes at a favorable price.

The liquidity of the trading market, if any, and future trading prices of the Convertible Notes will depend on many factors, including, among other things, the market price of our common stock, prevailing interest rates, our financial condition, results of operations, business, prospects and credit quality relative to our competitors, the market for similar securities and the overall securities market. The liquidity of the trading market of the Convertible Notes may be adversely affected by unfavorable changes in any of these factors, some of which are beyond our control and others of which would not affect debt that is not convertible into capital stock. Historically, the market for convertible debt has been subject to disruptions that have caused volatility in prices of securities similar to the Convertible Notes. Market volatility could materially and adversely affect the Convertible Notes, regardless of our financial condition, results of operations, business, prospects or credit quality.

The Convertible Notes are not rated. Any adverse rating of the Convertible Notes may cause their trading price to fall.

We do not intend to seek a rating on the Convertible Notes. However, if a rating service were to rate the Convertible Notes and if such rating service were to lower its rating on the Convertible Notes below the rating initially assigned to the Convertible Notes or otherwise announces its intention to put the Convertible Notes on credit watch or to withdraw the rating, the trading price of the Convertible Notes could decline.

Upon conversion of the Convertible Notes, holders may receive less valuable consideration than expected because the value of our common stock may decline after they exercise their conversion right.

Under the Convertible Notes, a converting holder will be exposed to fluctuations in the value of our common stock during the period from the date such holder surrenders Convertible Notes for conversion until the date we settle our conversion obligation. We will be required to deliver the shares of our common stock, together with cash for any fractional shares, on the third scheduled trading day following the relevant conversion date; and for any conversion that occurs on or after the record date for the payment of interest on the Convertible Notes at the maturity date, we will be required to deliver shares on the maturity date. Accordingly, if the price of our common stock decreases during this period, the value of the shares that the holders receive will be adversely affected and would be less than the conversion value of the Convertible Notes on the conversion date.

Conversion of the Convertible Notes may dilute the ownership interest of existing stockholders, including holders who had previously converted their Convertible Notes.

To the extent we issue shares of our common stock upon conversion of the Convertible Notes, the conversion of some or all of the Convertible Notes will dilute the ownership interests of existing stockholders. Any sales in the public market of shares of our common stock issuable upon such conversion of the Convertible Notes could adversely affect prevailing market prices of our common stock.

Provisions of the Convertible Notes could discourage an acquisition of us by a third party.

Certain provisions of the Indenture and the Convertible Notes could make it more difficult or more expensive for a third party to acquire us. Upon the occurrence of certain transactions constituting a fundamental change under the Indenture, holders of the Convertible Notes will have the right, at their option, to require us to repurchase all or a portion of their Convertible Notes. We may also be required to increase the conversion rate upon conversion or provide for conversion into the acquirer's capital stock in the event of certain fundamental changes. In addition, the Indenture and the Convertible Notes prohibit us from engaging in certain mergers or acquisitions unless, among other things, the surviving entity assumes our obligations under the Convertible Notes and the Indenture.

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Holders of the Convertible Notes may be subject to tax if we make or fail to make certain adjustments to the conversion rate of the Convertible Notes even though they do not receive a corresponding cash distribution.

The conversion rate of the Convertible Notes is subject to adjustment in certain circumstances, including the payment of cash dividends. If the conversion rate is adjusted as a result of a distribution that is taxable to our common stockholders, such as a cash dividend, holders of Convertible Notes may be deemed to have received a dividend subject to U.S. federal income tax without the receipt of any cash. In addition, a failure to adjust (or to adjust adequately) the conversion rate after an event that increases the proportionate interest in us could be treated as a deemed taxable dividend to holders of the Convertible Notes. If, pursuant to the terms of the Indenture, a make whole fundamental change occurs on or prior to the maturity date, under some circumstances, we will increase the conversion rate for Convertible Notes converted in connection with the make whole fundamental change. Such increase may also be treated as a distribution subject to U.S. federal income tax as a dividend. For a non-U.S. holder of the Convertible Notes, any deemed dividend may be subject to U.S. federal withholding tax at a 30 percent rate, or such lower rate as may be specified by an applicable treaty, which may be set off against subsequent payments on the Convertible Notes.

Risks Related to Our Preferred Stock

An active trading market for our depositary shares may not be maintained.

Our depositary shares, each of which represents 1/100th of a share of our Series A Preferred Stock, are listed on the NYSE; however, we can provide no assurance that an active trading market on the NYSE for the depositary shares may be maintained. As a result, the ability to transfer or sell the depositary shares and any trading price of the depositary shares could be adversely affected.

The market price of the depositary shares representing interests in our Series A Preferred Stock may be adversely affected by the future incurrence of debt or issuance of preferred stock by the Company.

In the future, we may increase our capital resources by making offerings of debt securities and preferred stock of the Company and other borrowings by the Company. The debt securities, preferred stock (if senior to our Series A Preferred Stock) and borrowings of the Company are senior in right of payment to our Series A Preferred Stock, and all payments (including dividends, principal and interest) and liquidating distributions on such securities and borrowings could limit our ability to pay dividends or make other distributions to the holders of depositary shares representing interests in our Series A Preferred Stock.

Because our decision to issue securities and make borrowings in the future will depend on market conditions and other factors, some of which may be beyond our control, we cannot predict or estimate the amount, timing or nature of our future offerings or borrowings. Thus, holders of the depositary shares representing interests in Series A Preferred Stock bear the risk of our future offerings or borrowings reducing the market price of the depositary shares representing interests in our Series A Preferred Stock.

A holder of depositary shares representing interests in the Series A Preferred Stock has extremely limited voting rights.

The voting rights of a holder of depositary shares are limited. Our common stock is the only class of our securities that carries full voting rights. Voting rights for holders of depositary shares exist primarily with respect to the ability to elect (together with the holders of other series of preferred stock on parity with the Series A Preferred Stock, if any) two additional directors to our Board of Directors in the event that six quarterly dividends (whether or not declared or consecutive) payable on the Series A Preferred Stock are in arrears, and with respect to voting on amendments to our Charter, including the articles supplementary creating our Series A Preferred Stock (in some cases voting together with the holders of Parity Preferred Stock as a single class) that materially and adversely affect the rights of the holders of depositary shares representing interests in the Series A Preferred Stock or create additional classes or series of our stock that are senior to the Series A Preferred Stock, provided that in any event adequate provision for redemption has not been made. Other than certain limited circumstances, holders of depositary shares do not have any voting rights.

The Change of Control conversion feature of Series A Preferred Stock may not adequately compensate the holders, and the Change of Control conversion and redemption features of the shares of Series A Preferred Stock underlying the depositary shares may make it more difficult for a party to take over the Company or discourage a party from taking over the Company.

Upon the occurrence of a Change of Control (as defined in the Articles Supplementary for Series A Preferred Stock), holders of the depositary shares representing interests in our Series A Preferred Stock will have the right (unless, prior to the Change of Control Conversion Date (as defined in the Articles Supplementary for Series A Preferred Stock), we have provided notice of our election to redeem the depositary shares either pursuant to our optional redemption right or our special optional redemption right) to convert some or all of their depositary shares into shares of our common stock (or equivalent value of Alternative Conversion Consideration). Upon such a conversion, the maximum number of shares of common stock that holders of depositary shares will receive for each depositary share converted will be limited to the Share Cap. These features of the Series A Preferred Stock may have the effect of inhibiting a third party from making an acquisition proposal for the Company or of delaying, deferring or preventing a Change of Control of the Company under circumstances that otherwise could provide the holders of our common stock and Series A Preferred

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Stock with the opportunity to realize a premium over the then-current market price or that stockholders may otherwise believe is in their best interests.

The market price of the depositary shares could be substantially affected by various factors.

The market price of the depositary shares will depend on many factors, which may change from time to time, including:

• Prevailing interest rates, increases in which may have an adverse effect on the market price of the depositary shares representing interests in our Series A Preferred Stock;

• The market for similar securities issued by other REITs;

• General economic and financial market conditions;

• The financial condition, performance and prospects of us, our tenants and our competitors;

• Any rating assigned by a rating agency to the depositary shares;

• Changes in financial estimates or recommendations by securities analysts with respect to us, our competitors or our industry; and

• Actual or anticipated variations in our quarterly operating results and those of our competitors.

In addition, over the last several years, prices of equity securities in the U.S. trading markets have been experiencing extreme price fluctuations. As a result of these and other factors, investors holding our depositary shares may experience a decrease, which could be substantial and rapid, in the market price of the depositary shares, including decreases unrelated to our financial condition, performance or prospects. Likewise, in the event that the depositary shares become convertible and are converted into shares of our common stock, holders of our common stock issued upon such conversion may experience a similar decrease, which also could be substantial and rapid, in the market price of our common stock.

Risks Related to REIT Qualification and Federal Income Tax Laws

We have elected to be taxed as a REIT for fiscal 2013 and subsequent years, but the IRS may challenge our qualification as a REIT.

We have elected to be a REIT for federal income tax purposes. In order to qualify as a REIT, a substantial percentage of our income must be derived from, and our assets consist of, real estate assets, and, in certain cases, other investment property. We have acquired and managed investments which satisfy the REIT tests. Whether a particular investment is considered a real estate asset for such purposes depends upon the facts and circumstances of the investment. Due to the factual nature of the determination, the IRS may challenge whether any particular investment will qualify as a real estate asset or realize income which satisfies the REIT income tests. In determining whether an investment is a real property asset, we will look at the Code and the IRS's interpretation of the Code in regulations, published rulings, private letter rulings and other guidance. In the case of a private letter ruling issued to another taxpayer, we would not be able to bind the IRS to the holding of such ruling. If the IRS successfully challenges our qualification as a REIT, we may not be able to achieve our objectives and the value of our stock may decline. As a REIT, our distributions from earnings and profits will be treated as ordinary income and a return of capital, and generally will not qualify as qualified dividend income ("QDI").

Fluctuations in the fair market value of the assets that we own and that are owned by our taxable REIT subsidiaries may adversely affect our continued qualification as a REIT.

We have to satisfy the asset tests at the end of each quarter. Although fluctuations in the fair market value of our assets should not adversely affect our qualification as a REIT, we must satisfy the asset tests immediately after effecting the REIT acquisition of any asset. Thus, we may be limited in our ability to purchase certain assets depending upon the potential fluctuations in the fair market value of our direct and indirect assets. As fair market value determinations are inherently factual, risks exist as to the fair market determination.

Although we believe that the Grand Isle Gathering System and Pinedale LGS constitute real estate assets under the REIT provisions of the Code, that belief is not binding on the IRS or any court and does not guarantee our qualification as a REIT.

On August 31, 2016, the IRS issued final regulations to define real property under the REIT provisions, which provide that interests in real estate include inherently permanent structures such as pipelines and certain related assets. The qualifying real estate assets in the energy infrastructure sector include electric transmission and distribution systems, pipeline systems, and storage and terminaling systems, among others. We believe that substantially all of the Grand Isle Gathering System and Pinedale LGS constitute real estate assets under the REIT provisions consistent with the final regulations and certain private letter rulings. We have not obtained any private letter rulings with respect to the Grand Isle Gathering System. We have received a private letter ruling and certain other

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confirmation from the IRS that certain Pinedale LGS assets qualify as real property for REIT purposes. If the Grand Isle Gathering System or Pinedale LGS does not constitute a real estate asset for federal income tax purposes, we would likely fail to continue to qualify as a REIT. If that should occur, it likely would prevent us from achieving our business objectives and could cause the value of our stock to decline.

Failure to qualify as a REIT would have significant adverse consequences to us and the value of our common stock.

Beginning with our fiscal year ended December 31, 2013, we believe our income and investments have allowed us to meet the income and asset tests necessary for us to qualify for REIT status and we have elected to be taxed as a REIT for fiscal years 2013 through 2018. Qualification as a REIT involves the application of highly technical and complex provisions of the Internal Revenue Code as to which there may only be limited judicial and administrative interpretations and involves the determination of facts and circumstances not entirely within our control. Future legislation, new regulations, administrative interpretations or court decisions may significantly change the tax laws or the application of the tax laws with respect to qualification as a REIT for federal income tax purposes or the federal income tax consequences of such qualification. Accordingly, we cannot assure you that we will be organized or will operate to qualify as a REIT for future fiscal years. If, with respect to any taxable year, we fail to qualify as a REIT, we would not be allowed to deduct distributions to stockholders in computing our taxable income. After our initial election and qualification as a REIT, if we later failed to so qualify and we were not entitled to relief under the relevant statutory provisions, we would also be disqualified from treatment as a REIT for four subsequent taxable years. If we fail to qualify as a REIT, corporate-level income tax, including any applicable alternative minimum tax (which alternative minimum tax has been repealed for tax years after 2017), would apply to our taxable income at regular corporate rates. As a result, the amount available for distribution to holders of equity securities would be reduced for the year or years involved, and we would no longer be required to make distributions. In addition, our failure to qualify as a REIT could impair our ability to expand our business and raise capital, and it could adversely affect the value of our common stock.

As a REIT, failure to make required distributions would subject us to federal corporate income tax.

In order to remain qualified for taxation as a REIT, we also are generally required to distribute at least 90 percent of our REIT taxable income (determined without regard to the dividends paid deduction and excluding net capital gain) each year, or in limited circumstances, the following year, to our stockholders. Beginning with our fiscal year ended December 31, 2013, we believe we have satisfied these requirements. While the amount, timing and form of any future distributions will be determined, and will be subject to adjustment, by our Board of Directors, we generally expect to distribute all or substantially all of our REIT taxable income. If our cash available for distribution falls short of our estimates, we may be unable to maintain distributions that approximate our REIT taxable income and may fail to remain qualified for taxation as a REIT. In addition, our cash flows from operations may be insufficient to fund required distributions as a result of differences in timing between the actual receipt of income and the payment of expenses and the recognition of income and expenses for federal income tax purposes, or the effect of nondeductible expenditures, such as capital expenditures, payments of compensation for which Section 162(m) of the Code denies a deduction, interest expense deductions limited by Section 163(j) of the Code, the creation of reserves or required debt service or amortization payments.

To the extent that we satisfy the 90 percent distribution requirement but distribute less than 100 percent of our REIT taxable income, we will be subject to federal corporate income tax on our undistributed taxable income. In addition, we will be subject to a 4 percent nondeductible excise tax on our undistributed taxable income if the actual amount that we distribute to our stockholders for a calendar year is less than the minimum amount specified under the Code.

Ownership limitation provisions in our charter may delay or prevent certain transactions in our shares, and could have the effect of delaying, deferring or preventing a transaction or change of control of our Company.

To maintain our qualification as a REIT for U.S. federal income tax purposes, among other purposes, our charter includes provisions designed to ensure that not more than 50 percent in value of our outstanding stock may be owned, directly or indirectly, by or for five or fewer individuals (as defined in the Internal Revenue Code to include certain entities such as private foundations) at any time during the last half of any taxable year. Subject to the exceptions described below, our charter generally prohibits any person (as defined under the Internal Revenue Code to include certain entities) from actually owning or being deemed to own by virtue of the applicable constructive ownership provisions of the Internal Revenue Code, (i) more than 9.8 percent (in value or in number of shares, whichever is more restrictive) of the issued and outstanding shares of our common stock or (ii) more than 9.8 percent in value of the aggregate of the outstanding shares of all classes and series of our stock, in each case, excluding any shares of our stock not treated as outstanding for federal income tax purposes. We refer to these restrictions as the "ownership limitation provisions." Our charter further prohibits any person from beneficially or constructively owning shares of our capital stock that would result in us being "closely held" under Section 856(h) of the Code or otherwise failing to qualify as a REIT. Our charter also provides that any transfer of shares of our capital stock which would, if effective, result in our capital stock being beneficially owned by fewer than 100 persons (as determined pursuant to the Internal Revenue Code) shall be void ab initio and the intended transferee shall acquire no rights in such shares. These ownership limitation provisions may prevent or delay individual transactions in our stock that would

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trigger such provisions, and also could have the effect of delaying, deferring or preventing a change in control and, as a result, could adversely affect our stockholders' ability to realize a premium for their shares of common stock. However, our Board of Directors may waive the ownership limitation provisions with respect to a particular stockholder and establish different ownership limitation provisions for such stockholder. In granting such waiver, our Board of Directors may also require the stockholder receiving such waiver to make certain representations, warranties and covenants related to our ability to qualify as a REIT.

Ownership limitations in our charter may impair the ability of holders to convert Convertible Notes into our common stock.

In order to assist us in maintaining our qualification as a REIT for U.S. federal income tax purposes, among other purposes, our charter restricts ownership of more than 9.8 percent (in value or in number, whichever is more restrictive) of our outstanding shares of common stock, or 9.8 percent in value of our outstanding capital stock, subject to certain exceptions. Notwithstanding any other provision of the Convertible Notes or the Indenture, no holder of Convertible Notes will be entitled to receive common stock following conversion of such Convertible Notes to the extent that receipt of such common stock would cause such holder (after application of certain constructive ownership rules) to exceed the ownership limit contained in our charter. We will not be able to deliver our common stock, even if we would otherwise choose to do so, to any holder of Convertible Notes if the delivery of our common stock would cause that holder to exceed the ownership limits described above.

Complying with REIT requirements may affect our profitability and may force us to liquidate or forgo otherwise attractive investments.

To qualify as a REIT, we must continually satisfy tests concerning, among other things, the nature and diversification of our assets, the sources of our income and the amounts we distribute to our stockholders. We may be required to liquidate or forgo otherwise attractive investments in order to satisfy the asset and income tests or to qualify under certain statutory relief provisions. We may also be required to make distributions to stockholders at disadvantageous times or when we do not have funds readily available for distribution. As a result, having to comply with the distribution requirement could cause us to sell assets in adverse market conditions, borrow on unfavorable terms or distribute amounts that would otherwise be invested in future acquisitions, capital expenditures or repayment of debt. Accordingly, satisfying the REIT requirements could materially and adversely affect us.

As a REIT, re-characterization of sale-leaseback transactions may cause us to lose our REIT status.

We intend to purchase certain properties and simultaneously lease those same properties back to the sellers. While we will use our best efforts to structure any such sale-leaseback transaction so that the lease will be characterized as a "true lease," thereby allowing us to be treated as the owner of the property for U.S. federal income tax purposes, the IRS could challenge such characterization. In the event that any sale-leaseback transaction is recharacterized as a financing transaction or loan for U.S. federal income tax purposes, deductions for depreciation and cost recovery relating to such property would be disallowed. If a sale-leaseback transaction were so recharacterized, we might fail to satisfy the REIT qualification "asset tests" or the "income tests" and, consequently, lose our REIT status effective with the year of re-characterization. Alternatively, the amount of our REIT taxable income could be recalculated which might also cause us to fail to meet the distribution requirement for a taxable year.

As a REIT, we are required to make distributions, other than capital gain distributions, to our stockholders each year in the amount of at least 90 percent of our REIT taxable income in order to deduct distributions to our stockholders. As a result, we will continue to need additional capital to make new investments. If additional funds are unavailable or not available on favorable terms, our ability to make new investments will be impaired.

As a REIT, we are required to distribute at least 90 percent of our REIT taxable income in order to deduct distributions to our stockholders, and as such we expect to continue to require additional capital to make new investments or carry existing investments. We may acquire additional capital from the issuance of securities senior to our common stock, including additional borrowings or other indebtedness or the issuance of additional securities. We may also acquire additional capital through the issuance of additional equity. However, we may not be able to raise additional capital in the future on favorable terms or at all. Unfavorable economic conditions could increase our funding costs, limit our access to the capital markets or result in a decision by lenders not to extend credit to us. We may issue debt securities, other instruments of indebtedness or preferred stock, and we may borrow money from banks or other financial institutions, which we refer to collectively as "senior securities." As a result of issuing senior securities, we will also be exposed to typical risks associated with leverage, including increased risk of loss. If we issue preferred securities which will rank "senior" to our common stock in our capital structure, the holders of such preferred securities may have separate voting rights and other rights, preferences or privileges more favorable than those of our common stock, and the issuance of such preferred securities could have the effect of delaying, deferring or preventing a transaction or a change of control that might involve a premium price for security holders or otherwise be in our best interest.

To the extent our ability to issue debt or other senior securities is constrained, we will depend on issuances of additional common stock to finance new investments. If we raise additional funds by issuing more of our common stock or senior securities convertible

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into, or exchangeable for, our common stock, the percentage ownership of our stockholders at that time would decrease, and you may experience dilution.

If we acquire C corporations in the future, we may inherit material tax liabilities and other tax attributes from such acquired corporations, and we may be required to distribute earnings and profits.

From time to time we may acquire C corporations or assets of C corporations in transactions in which the basis of the corporations' assets in our hands is determined by reference to the basis of the assets in the hands of the acquired corporations, or carry-over basis transactions.

In the case of assets we acquire from a C corporation in a carry-over basis transaction, if we dispose of any such asset in a taxable transaction (including by deed in lieu of foreclosure) during the five-year period beginning on the date of the carry-over basis transaction, then we will be required to pay tax at the highest regular corporate tax rate on the gain recognized to the extent of the excess of (1) the fair market value of the asset over (2) our adjusted tax basis in the asset, in each case determined as of the date of the carry-over basis transaction. Any taxes we pay as a result of such gain would reduce the amount available for distribution to our stockholders. The imposition of such tax may require us to forgo an otherwise attractive disposition of any assets we acquire from a C corporation in a carry-over basis transaction, and as a result may reduce the liquidity of our portfolio of investments. In addition, in such a carry-over basis transaction, we will succeed to any tax liabilities and earnings and profits of the acquired C corporation. To qualify as a REIT, we must distribute any non-REIT earnings and profits by the close of the taxable year in which such transaction occurs. If the IRS were to determine that we acquired non-REIT earnings and profits from a corporation that we failed to distribute prior to the end of the taxable year in which the carry-over basis transaction occurred, we could avoid disqualification as a REIT by paying a "deficiency dividend." Under these procedures, we generally would be required to distribute any such non-REIT earnings and profits to our stockholders within 90 days of the determination and pay a statutory interest charge at a specified rate to the IRS. Such a distribution would be in addition to the distribution of REIT taxable income necessary to satisfy the REIT distribution requirement and may require that we borrow funds to make the distribution even if the then-prevailing market conditions are not favorable for borrowings. In addition, payment of the statutory interest charge could materially and adversely affect us.

Legislative or other actions affecting REITs could have a negative effect on us.

The rules dealing with federal, state and local income taxation are constantly under review by persons involved in the legislative process and by the IRS and the U.S. Department of the Treasury. Changes to the tax laws, with or without retroactive application, could materially and adversely affect our investors or us. On December 22, 2017, the Tax Cuts and Jobs Act was signed into law by the U.S. President. Although we are not aware of any provision in the final tax reform legislation or any pending tax legislation that would adversely affect our ability to qualify as a REIT, we cannot predict how future changes in the tax laws might affect our investors or us. New legislation, Treasury Regulations, administrative interpretations or court decisions could significantly and negatively affect our ability to qualify as a REIT or the income tax consequences of such qualification.

Risks Related to Our Corporate Structure and Governance

Corridor may serve as a manager to other entities, which may create conflicts of interest not in the best interest of us or our stockholders.

Corridor's services under the Management Agreement are not exclusive, and, while it currently does not have any contractual arrangement to do so, it is free to furnish the same or similar services to other entities, including businesses that may directly or indirectly compete with us so long as its services to us are not impaired by the provision of such services to others. Corridor and its members may have obligations to other entities, the fulfillment of which might not be in the best interests of us or our stockholders.

We will be dependent upon key personnel of Corridor for our future success.

We have entered into a management agreement with Corridor to provide full management services to us for real property asset investments. We will be dependent on the diligence, expertise and business relationships of the management of Corridor to implement our strategy of acquiring real property assets. The departure of one or more investment professionals of Corridor could have a material adverse effect on our ability to implement this strategy and on the value of our common stock. There can be no assurance that we will be successful in implementing our strategy.

In addition to the ownership limit provisions discussed above, certain provisions of our charter and of Maryland law may limit the ability of stockholders to control our policies and effect a change of control of our Company.

Our charter authorizes our Board of Directors to amend our charter to increase or decrease the aggregate number of authorized shares of stock, to authorize us to issue additional shares of our common stock or preferred stock and to classify or reclassify unissued shares of our common stock or preferred stock and thereafter to authorize us to issue such classified or reclassified shares of stock. We believe that these provisions in our charter provide us with increased flexibility in structuring possible future financings and

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acquisitions and in meeting other needs that might arise. The additional classes or series, as well as the additional authorized shares of stock, will be available for issuance without further action by our stockholders, unless such action is required by applicable law or the rules of any stock exchange or automated quotation system on which our securities may be listed or traded. Although our Board of Directors does not currently intend to do so, it could authorize us to issue a class or series of stock that could, depending upon the terms of the particular class or series, delay, defer or prevent a transaction or a change of control of our company that might involve a premium price for holders of our common stock or that our common stockholders otherwise believe to be in their best interests.

Provisions of the Maryland General Corporation Law and our charter and bylaws could deter takeover attempts and have an adverse impact on the price of our common stock.

The following considerations related to provisions of Maryland General Corporation Law, and of our charter and bylaws, may have the effect of discouraging, delaying or making difficult a change in control of our Company or the removal of our incumbent directors:

• We are subject to the Business Combination Act of the Maryland General Corporation Law. However, pursuant to the statute, our Board of Directors has adopted a resolution exempting us from the Maryland Business Combination Act for any business combination between us and any person to the extent that such business combination receives the prior approval of our Board of Directors.

• Our bylaws exempt from the Maryland Control Share Acquisition Act acquisitions of stock by any person. If we amend our bylaws to repeal the exemption from the Maryland Control Share Acquisition Act, the Maryland Control Share Acquisition Act also may make it more difficult to obtain control of our Company.

• As described above, our charter includes a share ownership limit and other restrictions on ownership and transfer of shares, in each such case designed, among other purposes, to preserve our status as a REIT, which may have the effect of precluding an acquisition of control of us without the approval of our Board of Directors.

• Under our charter, our Board of Directors is divided into three classes serving staggered terms, which may make it more difficult for a hostile bidder to acquire control of us.

• Our charter contains a provision whereby we have elected to be subject to the provisions of Title 3, Subtitle 8 of the Maryland General Corporation Law relating to the filling of vacancies on our Board of Directors. Further, through provisions in our charter and bylaws unrelated to Subtitle 8, we (1) require a two-thirds vote for the removal of any director from the board, which removal must be for cause, (2) vest in the board the exclusive power to fix the number of directors, subject to limitations set forth in our charter and bylaws, (3) have a classified Board of Directors and (4) require that, unless a special meeting of stockholders is called by the chairman of our Board of Directors, our chief executive officer, our president or our Board of Directors, such a special meeting may only be called to consider and vote on any matter that may properly be considered at a meeting of stockholders at the request of stockholders entitled to cast not less than a majority of all votes entitled to be cast on a matter at such meeting.

• In addition, our Board of Directors may, without stockholder action, authorize the issuance of shares of stock in one or more classes or series, including preferred stock. Our Board of Directors also may, without stockholder action, amend our charter to increase the number of shares of stock of any class or series that we have authority to issue.

• Our bylaws include advance notice provisions, governing stockholders' director nominations or proposal of other business to be considered at an annual meeting of our stockholders, requiring the continuous ownership by the stockholder(s) putting forth any such nominee or proposal of at least one percent (1 percent) of our outstanding shares of beneficial interest for a minimum period of at least three years prior to the date of such nomination or proposal and through the date of the related annual meeting (including any adjournment or postponement thereof), each as specified in the bylaws.

• Our bylaws designate certain Maryland courts as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our stockholders, which could limit our stockholders' ability to obtain a judicial forum that our stockholders believe is favorable for disputes with us or our directors, officers or employees.

The existence of these provisions, among others, may have a negative impact on the price of our common stock and may discourage third party bids for ownership of our Company. These provisions may prevent any premiums being offered to you for our common stock.

Our ability to pay dividends is limited by the requirements of Maryland law.

Our ability to pay dividends on our common stock and Series A Preferred Stock is limited by the laws of Maryland. Under the Maryland General Corporation Law, a Maryland corporation generally may not make a distribution if, after giving effect to the distribution, the corporation would not be able to pay its debts as the debts become due in the usual course of business, or the corporation's total assets would be less than the sum of its total liabilities plus, unless the corporation's charter provides otherwise,

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the amount that would be needed, if the corporation were dissolved at the time of the distribution, to satisfy the preferential rights upon dissolution of stockholders whose preferential rights are superior to those receiving the distribution. Accordingly, we may not make a distribution on our common stock and the Series A Preferred Stock if, after giving effect to the distribution, we would not be able to pay our debts as they become due in the usual course of business or our total assets would be less than the sum of our total liabilities plus, unless the terms of such class or series provide otherwise, the amount that would be needed to satisfy the preferential rights upon dissolution of the holders of any shares of any class or series of preferred stock then outstanding, if any, with preferences senior to those of our common stock and the Series A Preferred Stock.

Additional Risks to Our Stockholders

Our use of leverage increases the risk of investing in our securities and will increase the costs borne by common stockholders.

Our use of leverage through the issuance of any preferred stock or debt securities, and any additional borrowings or other transactions involving indebtedness (other than for temporary or emergency purposes) are or would be considered "senior securities" and create risks. Leverage may adversely affect common stockholders. If the return on securities acquired with borrowed funds or other leverage proceeds does not exceed the cost of the leverage, the use of leverage could cause us to lose money.

Our issuance of senior securities involves offering expenses and other costs, including interest payments, which are borne indirectly by our common stockholders. Fluctuations in interest rates could increase interest or dividend payments on our senior securities, and could reduce cash available for distribution on common stock. Increased operating costs, including the financing cost associated with any leverage, may reduce our total return to common stockholders.

Rating agency guidelines applicable to any senior securities may impose asset coverage requirements, dividend limitations, voting right requirements (in the case of the senior equity securities), and restrictions on our portfolio composition and our use of certain investment techniques and strategies. The terms of any senior securities or other borrowings may impose additional requirements, restrictions and limitations that are more stringent than those required by a rating agency that rates outstanding senior securities. These requirements may have an adverse effect on us and may affect our ability to pay distributions on common stock and preferred stock. To the extent necessary, we may redeem our senior securities to maintain the required asset coverage. Doing so may require that we liquidate investments at a time when it would not otherwise be desirable to do so.

In addition, lenders from whom we may borrow money or holders of our debt securities may have fixed dollar claims on our assets that are superior to the claims of our stockholders, and we have granted, and may in the future grant, a security interest in our assets in connection with our debt. In the case of a liquidation event, those lenders or note holders would receive proceeds before our stockholders. If the value of our assets increases, then leveraging would cause the book value of our common stock to increase more than it otherwise would have had we not leveraged. Conversely, if the value of our assets decreases, leveraging would cause the book value of our common stock to decline more than it otherwise would have had we not leveraged. Similarly, any increase in our revenue in excess of interest expense on our borrowed funds would cause our net income to increase more than it would without the leverage. Any decrease in our revenue would cause our net income to decline more than it would have had we not borrowed funds and could negatively affect our ability to make distributions on our common stock. Our ability to service any debt that we incur will depend largely on our financial performance and the performance of our investments and will be subject to prevailing economic conditions and competitive pressures.

We cannot assure you that we will be able to pay dividends regularly.

Our ability to pay dividends in the future is dependent on our ability to operate profitably and to generate cash from our operations and the operations of our subsidiaries. We cannot guarantee that we will be able to pay dividends on a regular quarterly basis in the future. Furthermore, any new shares of common stock issued will substantially increase the cash required to continue to pay cash dividends at current levels. Any common stock or preferred stock that may in the future be issued to finance acquisitions, upon exercise of stock options or otherwise, would have a similar effect.

Future sales of shares of our common stock may depress its market price.

We may, in the future, sell additional shares of our common stock to raise capital. Sales of substantial amounts of additional shares of common stock, shares that may be sold by stockholders, shares of common stock underlying the Convertible Notes and shares issuable upon exercise of outstanding options as well as sales of shares that may be issued in connection with future acquisitions or for other purposes, including to finance our operations and business strategy, or the perception that such sales could occur, may have an adverse effect on prevailing market prices for our common stock and our ability to raise additional capital in the financial markets at a time and price favorable to us. The price of our common stock could also be affected by possible sales of our common stock by investors who view the Convertible Notes as a more attractive means of equity participation in our company and by hedging or arbitrage trading activity that we expect will develop involving our common stock.

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Risk Related to Terrorism and Cybersecurity

A terrorist attack, act of cyber-terrorism or armed conflict could harm our business.

Terrorist activities, anti-terrorist efforts and other armed conflicts involving the U.S., whether or not targeted at our assets or those of our tenants, investees or customers, could adversely affect the U.S. and global economies and could prevent us from meeting our financial and other obligations. Both we and our tenants and investees could experience loss of business, delays or defaults in payments from customers or disruptions of supplies and markets if domestic and global utilities or other energy infrastructure companies are direct targets or indirect casualties of an act of terror or war. Additionally, both we and our tenants and other investees rely on financial and operational computer systems to process information critically important for conducting various elements of our respective businesses. Any act of cyber-terrorism or other cyber-attack resulting in a failure of our computer systems, or those of our tenants, customers, suppliers or others with whom we do business, could materially disrupt our ability to operate our respective businesses and could result in a financial loss to the Company and possibly do harm to our reputation. Accordingly, terrorist activities and the threat of potential terrorist activities (including cyber-terrorism) and any resulting economic downturn could adversely affect our business, financial condition and results of operations. Any such events also might result in increased volatility in national and international financial markets, which could limit our access to capital or increase our cost of obtaining capital.

Some losses related to our real property assets, including, among others, losses related to potential terrorist activities, may not be covered by insurance and would adversely impact distributions to stockholders.

Our leases will generally require the tenant companies to carry comprehensive liability and casualty insurance on our properties comparable in amounts and against risks customarily insured against by other companies engaged in similar businesses in the same geographic region as our tenant companies. We believe the required coverage will be of the type, and amount, customarily obtained by an owner of similar properties. However, there are some types of losses, such as catastrophic acts of nature, acts of war or riots, for which we or our tenants cannot obtain insurance at an acceptable cost. If there is an uninsured loss or a loss in excess of insurance limits, we could lose both the revenues generated by the affected property and the capital we have invested in the property if our tenant company fails to pay us the casualty value in excess of such insurance limit, if any, or to indemnify us for such loss. This would in turn reduce the amount of income available for distributions. We would, however, remain obligated to repay any secured indebtedness or other obligations related to the property. Since September 11, 2001, the cost of insurance protection against terrorist acts has risen dramatically. The cost of coverage for acts of terrorism is currently mitigated by the Terrorism Risk Insurance Program Reauthorization Act of 2015 ("TRIPRA"), which extended such program through December 31, 2020. Under TRIPRA, the amount of terrorism-related insurance losses triggering the federal insurance threshold has been increasing gradually from its initial level of $100 million for acts occurring in 2015 to $160 million for acts occurring in 2018, with $180 million being the applicable threshold for acts occurring in 2019 and finally increasing to $200 million for 2020. Additionally, the bill increases insurers' co-payments for losses exceeding their deductibles, from 15 percent in 2015 to 16 percent beginning January 1, 2016, and increasing in annual one percent steps thereafter until reaching 20 percent for 2020. Each of these changes may have the effect of increasing the cost to insure against acts of terrorism for property owners, such as the Company, notwithstanding the other provisions of TRIPRA. Further, if TRIPRA is not continued beyond 2020 or is significantly modified, we may incur higher insurance costs and experience greater difficulty in obtaining insurance that covers terrorist-related damages. Our tenants may also have similar difficulties. There can be no assurance our tenant companies will be able to obtain terrorism insurance coverage, or that any coverage they do obtain will adequately protect our properties against loss from terrorist attack.

We face risks associated with security breaches through cyber attacks, cyber intrusions or otherwise, as well as other significant disruptions of our information technology (IT) networks and related systems.

We rely on information technology systems and network infrastructure, including the Internet, to process transmit and store electronic information and to manage or support a variety of our business processes, including financial transactions and maintenance of records. These systems and infrastructure are essential to the operation of our business and our ability to perform day-to-day operations and, in some cases, may be critical to the operations of certain of our tenants. Cyber attacks targeting our infrastructure could result in a full or partial disruption of our operations, as well as those of our tenants. Although we make efforts to maintain the security and integrity of our IT networks and related systems, and we have implemented various measures to manage the risk of a security breach or disruption, we cannot guarantee that our security efforts and measures will be effective at preventing or detecting any attempted or actual security breaches, or that disruptions caused by any such breaches or attempted breaches will not be successful or damaging to us or others.

A security breach or other significant disruption involving our IT networks and related systems could disrupt the proper functioning of our networks and systems; result in disruption of business operations and loss of service to our tenants and customers; result in significantly decreased revenues; result in increased costs associated in obtaining and maintaining cybersecurity investigations and testing, as well as in implementing protective measures and systems; result in increased insurance premiums and operating costs; result in misstated financial reports, violations of loan covenants and/or missed reporting deadlines; result in our inability to properly monitor our compliance with the rules and regulations regarding our qualification as a REIT; result in the unauthorized access to,

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and destruction, loss, theft, misappropriation or release of proprietary, confidential, sensitive or otherwise valuable information of ours or others, which others could use to compete against us or for disruptive, destructive or otherwise harmful purposes and outcomes; require significant management attention and resources to remedy any damages that result; subject us to claims for breach of contract, damages, credits, penalties or termination of leases or other agreements; subject us to regulatory investigations and actions; cause harm to our competitive position and business value; and damage our reputation among our tenants and investors generally.

In addition, as part of our business operations, we collect, store and process certain proprietary and sensitive information, including personal information about our customers, shareholders and employees. In some cases, we outsource administration of certain technology functions to vendors that could be targets of cyber attacks. Any theft, loss and/or fraudulent use of data of ours or of any tenant, customer, investor, employee or vendor as a result of a cyber attack on us or our vendors could subject us to significant litigation, liability and costs, as well as adversely impact our reputation.

Risks Related to Our Investments in Loans

Our loans may be impacted by unfavorable real estate market conditions, which could decrease the value of those loans and the return on your investment.

If we make or invest in mortgage loans, we will be at risk of defaults on those loans caused by many conditions beyond our control, including local and other economic conditions affecting real estate values and interest rate levels. We do not know whether the values of the property securing the loans will remain at the levels existing on the dates of origination of the loans. If the values of the underlying properties drop, our risk will increase because of the lower value of the security associated with such loans.

If our borrowers declare bankruptcy, we may be unable to collect interest and principal payments when due under the loan documents.

Either the borrowers under any loan documents we hold or any of borrowers' guarantor affiliates could become debtors under the bankruptcy laws of the United States. Such a bankruptcy filing would bar all efforts by us to collect pre-bankruptcy debts from these entities or their properties, unless we receive authorization from the bankruptcy court to proceed against the debtor entities under the respective loan documents. Post-bankruptcy debts (those debts that accrue after the bankruptcy was filed) are required to be paid on a current basis. Such a bankruptcy could delay efforts to collect past due balances under the loan documents, could ultimately preclude full collection of these sums, and could cause a decrease or cessation of principal and interest payments under the loan documents. If any of these events occur, our cash flow and funds available for distributions to our stockholders would be adversely affected.

Delays in liquidating defaulted mortgage loans could reduce our investment returns.

If there are defaults under our loans, we may not be able to repossess and sell under favorable market conditions any energy infrastructure real property securing such loans. The resulting time delay could reduce the value of our investment in the defaulted loans. An action to foreclose on a property securing a loan is regulated by state statutes and regulations and is subject to many of the delays and expenses of any lawsuit brought in connection with the foreclosure if the defendant raises defenses or counterclaims. If there is a default by a mortgagor, these restrictions, among other things, may impede our ability to foreclose on or sell the mortgaged property or to obtain proceeds sufficient to repay all amounts due to us on the loan.

A foreclosure on the energy infrastructure real property and equipment held by a borrower would create additional ownership risks that could adversely impact the return on our investment.

If we should acquire any of the energy infrastructure real property and/or related equity held by a borrower by foreclosure following a default under the loan documents, we will incur additional economic and liability risks as the owner of such assets, including, among other things, insurance costs, costs of maintenance and taxes relating to such property.

In the event of a foreclosure on the energy infrastructure real property assets held by a borrower, we may not be able to sell such assets at a price equal to, or greater than, the loan amount and accrued unpaid interest under the loan documents, which may lead to a decrease in the value of our assets.

Given the specialized nature of the borrowers' assets and the fact they are predominantly employed in support of the borrowers' operations, there can be no assurance that we would be able to find another buyer for these assets if financial distress on the part of a borrower forced us to foreclose on our security interest. Further, even if we were able to sell the assets, such sale may occur at a price less than the amount required to recover our loan balances and accrued unpaid interest under the loan documents, which could adversely impact the value of our assets and our ability to make distributions to our stockholders.

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We may experience an impairment in the value of our loan to a borrower related to a deterioration in the credit worthiness of the borrower or a decline in the fair market value of the energy infrastructure real property assets securing the loan.

A deterioration in the credit worthiness of a borrower, due to changing business conditions or otherwise, or a decline in the fair market value of the energy infrastructure real property assets securing any of our loans to a borrower, could require us to recognize an "other-than-temporary" impairment in the value of the promissory note secured by the assets if we were to determine that such loan was in an unrealized loss position and we did not have the ability and intent to hold such asset to maturity or for a period of time sufficient to allow for recovery of the value of the underlying assets. If such a determination were made, we would recognize unrealized losses through earnings and write down the asset value of such loan to a new cost basis, based on the fair value of the assets on the date they are considered to be other-than-temporarily impaired. Such impairment charges reflect non-cash losses at the time of recognition; a subsequent disposition or sale of the loan through foreclosure or otherwise could further affect our future losses or gains, as they would be based on the difference between the sales price received and the adjusted amortized cost of such loan at the time of sale.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES

Leased Energy Infrastructure Assets

We are primarily focused on acquiring and financing midstream and downstream real estate assets within the U.S. energy infrastructure sector and concurrently entering into long-term triple-net participating leases with energy companies. The following summarizes our investments in energy infrastructure assets that are leased on a triple-net basis to their respective operators as of December 31, 2018:

Asset Name	Owner/Landlord	Tenant	Asset Location	Asset Description	Encumbrances (1)
Grand Isle Gathering System	Grand Isle Corridor, LP	Energy XXI GIGS Services, LLC (2)	Gulf of Mexico / Louisiana	Approximately 153 miles of offshore pipeline with total capacity of 120 thousand Bbls/d, including a 16-acre onshore terminal and saltwater disposal system	Security for the Company's $160 million revolving credit facility with Regions Bank
Pinedale Liquids Gathering System	Pinedale LP	Ultra Wyoming LGS LLC (3)	The Pinedale Anticline in Wyoming	Approximately 150 miles of pipelines and four central storage facilities	Security for the Amended Pinedale Term Credit Facility
Portland Terminal Facility(4)	LCP Oregon Holdings, LLC	Zenith Energy Terminals Holdings, LLC	Portland, OR	A 39-acre rail and marine facility property adjacent to the Willamette River with 84 tanks and total storage capacity of approximately 1.5 million barrels
(1)    For additional information, see Part IV, Item 15, Note 11 ("Debt") included in this Report.
(2)    Energy XXI GIGS Services, LLC's obligations under the Grand Isle Lease Agreement are guaranteed by EGC. For additional information, see "Additional Information Concerning the Grand Isle Gathering System" below.
(3)    Ultra Wyoming's obligations under the Pinedale Lease Agreement are guaranteed by Ultra Petroleum and Ultra Petroleum's operating subsidiary, Ultra Resources. For additional information, see "Additional Information Concerning the Pinedale LGS" below.
(4)    On December 21, 2018, we sold the Portland Terminal Facility to our tenant, Zenith Energy Terminals Holdings, LLC. For additional information, see Part IV, Item 15, Note 3 ("Leased Properties and Leases") included in this Report. Prior to the sale, the Portland Terminal Facility was an asset securing the Company's revolving credit facility with Regions Bank.

Additional Information Concerning the Grand Isle Gathering System

Grand Isle Corridor, LP acquired the Grand Isle Gathering System on June 30, 2015 from Energy XXI USA, Inc., which has since become Energy XXI Gulf Coast, Inc. and an indirect wholly owned subsidiary of privately-held Cox Oil as discussed further below. The Grand Isle Gathering System's design capacity is approximately 120 thousand barrels per day. It includes 153 miles of undersea pipeline that transports oil and water from seven offshore fields and a 16-acre onshore terminal. The terminal includes four storage tanks, three saltwater injection wells, and associated pipelines, land, buildings and facilities.

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The subsea pipelines forming the majority of the Grand Isle Gathering System and certain other components, such as the buildings and saltwater disposal facilities, have useful lives that extend beyond the initial term of the Grand Isle Lease Agreement, and the system is critical to Cox Oil's central Gulf of Mexico operations. The Grand Isle Gathering System provides shoreline terminal access to 38 offshore platforms producing from seven fields. Some of these fields have produced for over 50 years, and continue to produce. During 2018, EGC, drilled and successfully completed three new wells. Future wells drilled will be dependent on economics, but several undrilled locations remain in fields served by the Grand Isle Gathering System. From its analysis, CORR assumes average Grand Isle Gathering System well lives of 10 to 20 years depending on the field, implying a long-term continued need for transport and terminaling services.

The primary term of the Grand Isle Lease Agreement is 11 years, with an initial renewal term of nine years, subject to certain conditions. During the initial term of the Grand Isle Lease Agreement, the EGC Tenant is required to make minimum monthly rental payments that were initially $2.6 million in year one, increasing to a maximum of $4.2 million in year seven and then declining to $3.5 million in year eleven. In 2019, the minimum monthly rental payments will be $2.9 million through June 2019, and beginning in July 2019, the minimum monthly rental payments will be $3.2 million for the remainder of the year. In addition, the EGC Tenant will pay variable rent payments based on a ten percent participation above a pre-defined threshold, which will be calculated monthly on the volumes of the EGC Tenant's oil that flow through the Grand Isle Gathering System, multiplied by the average daily closing price of crude oil for the applicable calendar month. Participating rent is capped at 39 percent of the total rent for each month. There were no participating rents paid in 2018.

Since the Grand Isle Gathers System represents a substantial portion of the Company's net leased property and is a significant source of revenues and operating income, the EGC Tenant's financial condition and ability and willingness to satisfy its obligations under its lease with the Company are expected to have a considerable impact on our results of operations and cash flows.

We believe the terms of the Grand Isle Lease Agreement require we be provided with copies of certain financial statement information that we are required to file pursuant to SEC Regulation S-X, as described in Section 2340 of the SEC Financial Reporting Manual. Prior to October 29, 2018, EGC was subject to the reporting requirements of the Exchange Act and was required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. So long as EGC remained a public reporting company, the Grand Isle Lease Agreement provided this requirement was fulfilled by EGC making its financial statements and reports publicly available through the SEC's EDGAR system, in lieu of delivering such information directly to us. On October 18, 2018, EGC was acquired by an affiliate of Cox Oil. Upon the filing by EGC of a Form 15 with the SEC on October 29, 2018, EGC's SEC reporting obligations were suspended and it ceased to file such reports.

As EGC's financial information is no longer publicly available, we are engaged in discussions with Cox Oil/EGC concerning satisfaction of its obligations under the Grand Isle Lease Agreement to provide the required information to us for inclusion in our SEC reports. To date, Cox Oil has not yet fulfilled these obligations. It is our intention to enforce the obligations of EGC to provide the financial statement information that we believe are required under the terms of the Grand Isle Lease Agreement. We expect to file the financial statement information that is required by Regulation S-X by amendment to this Annual Report on Form 10-K once such information is made available to us in accordance with the terms of the lease.

EGC's SEC filings prior to October 29, 2018 can be found at www.sec.gov. We make no representation as to the accuracy or completeness of the audited and unaudited financial statements of EGC but we have no reason to doubt the accuracy or completeness of such information. In addition, EGC has no duty, contractual or otherwise, to advise us of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. None of the information in the public reports of EGC that are filed with the SEC is incorporated by reference into, or in any way form, a part of this filing.

Additional Information Concerning the Pinedale LGS

Pinedale LP acquired the Pinedale LGS with associated real property rights in the Pinedale Anticline in Wyoming from an indirect wholly-owned subsidiary of Ultra Petroleum on December 20, 2012. Prudential owned an 18.95 percent economic interest in the Pinedale LGS as a co-investor with us through December 29, 2017, at which point Pinedale LP I, our wholly-owned subsidiary, purchased the 18.95 percent economic interest from Prudential.

The Pinedale LGS consists of more than 150 miles of pipelines and four central storage facilities that are utilized by Ultra Petroleum as a method for the gathering of a commingled hydrocarbon and produced water stream. The Pinedale LGS has a current capacity of approximately 52 thousand barrels per day. This stream is separated into its components of water, condensate and natural gas, for the purpose of subsequently storing, selling or disposing of these separated components. Condensate is a valuable hydrocarbon commodity that is sold by Ultra Petroleum; water is transported to disposal wells or a treatment facility for re-use; and natural gas is sold by Ultra Petroleum or otherwise used by Ultra Petroleum for fueling on-site operational equipment. Ultra Petroleum's non-

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operating working interest partners in the Pinedale field where the Pinedale LGS is located pay Ultra Petroleum a fee for the use of Ultra Petroleum's LGS. To date, no major operational issues have been reported with respect to the Pinedale LGS. We believe that the Pinedale LGS is critically necessary to support the production of reserves for Ultra Petroleum, which reports the rental expense as part of its Facility Lease Expense.

The underground pipelines constituting the majority of the Pinedale LGS and certain other components, such as the separators, have useful lives that extend beyond the initial term of the Pinedale Lease Agreement. Additionally, we believe that the Pinedale LGS is capable of being expanded at a relatively low incremental cost by, for example, adding additional separating equipment. Operators in the Pinedale field have indicated estimated average well lives as high as 40 years. For its internal analysis, CORR assumes average Pinedale well lives of 30 years. In November 2018, UPL described Pinedale as having over 4,000 vertical well drilling locations. Actual wells drilled will be dependent on economics, but these data suggest the potential for multiple decades of drilling location inventory with the last of these wells continuing to produce for 30 years thereafter, providing a long-term perspective on the utility of the Pinedale LGS.

Most of Ultra Petroleum's exploration and development in the Pinedale field takes place on land under the jurisdiction of the Bureau of Land Management ("BLM"). The BLM has the authority to approve or deny oil and gas leases or to impose environmental restrictions on leases where appropriate. The BLM issued the Pinedale Record of Decision ("ROD") in September 2008. Under the ROD, Ultra Petroleum gained year-round access to the Pinedale field for drilling and completion activities in development areas, provided Ultra Petroleum conducts an environmental mitigation effort, which includes the use of a liquids gathering system. This additional access resulted in increased drilling efficiencies and allowed for accelerated development of the field.

During the initial fifteen-year term of the Pinedale Lease Agreement, we will receive a fixed minimum annual rent ("base rent"), adjusted annually for changes based on the CPI (subject to a 2.00 percent annual cap). On January 1, 2019, the base rent increased by 2.00 percent to approximately $21.7 million annually. We also are eligible for a participating rent component based on the increase in volumes, if any, of condensate and water that flowed through the Pinedale LGS over a baseline established at inception of the lease, subject to a maximum annual rental payment during the initial fifteen-year term of $27.5 million. Beginning in the third quarter 2017, we received our first variable rent payments since lease inception. Total variable rent payments recorded for the years ended December 31, 2018 and 2017 were $4.3 million and $587 thousand, respectively.

In view of the fact that Ultra Petroleum leases a substantial portion of our net leased property, which is a significant source of revenues and operating income, its financial condition and ability and willingness to satisfy its obligations under its lease with us are expected to have a considerable impact on our results of operations and cash flows.

Ultra Petroleum is currently subject to the reporting requirements of the Exchange Act and is required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. The audited financial statements and unaudited financial statements of Ultra Petroleum can be found on the SEC's website at www.sec.gov. We make no representation as to the accuracy or completeness of the audited and unaudited financial statements of Ultra Petroleum, but we have no reason to doubt the accuracy or completeness of such information. In addition, Ultra Petroleum has no duty, contractual or otherwise, to advise us of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information.

Additional Information Concerning the Portland Terminal Facility

In January 2014, the Company entered into a triple-net lease with Zenith Terminals (f/k/a Arc Terminals) for use of the Portland Terminal Facility, with the tenant's obligations under the lease guaranteed by Arc Logistics. The Portland Terminal Facility is capable of receiving, storing and delivering crude oil and refined petroleum products. Products are received and delivered via railroad or marine (up to Panamax size vessels). The marine facilities are accessed through a neighboring terminal facility via an owned pipeline. The Portland Terminal Facility offers heating systems, emulsions and an on-site product testing laboratory as ancillary services. Our ownership interest in the Portland Terminal Facility partially secured borrowings under the CorEnergy Credit Facility up until its sale on December 21, 2018 discuss further below.

Our fixed minimum base rents ("base rent") for the initial fifteen-year term increased to approximately $6.2 million following the completion of certain improvement projects. The base rent was subject to a cumulative CPI adjustment in year five of the initial term, with annual CPI adjustments thereafter. We were also eligible for a variable rent component based on daily volume increases over base daily volumes defined in the lease. Under the terms of the lease, the lessee had a purchase option on the Portland Terminal Facility that it could exercise beginning in February 2017 with 90 days' notice, as well as lease termination options on the fifth and tenth anniversary of the lease. The purchase option and termination options under the lease were subject to prescribed payment provisions and termination fees.

On December 21, 2017, Arc Logistics completed its previously announced merger, whereby it was acquired by Zenith. The following year on December 21, 2018, we entered into a Purchase and Sale Agreement with Zenith Terminals, the tenant under the Portland

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Lease Agreement, and sold the Portland Terminal Facility. For additional information on the sale of the Portland Terminal Facility, see Part IV, Item 15, Note 3 ("Leased Properties and Leases") included in this Report.

Other Energy Infrastructure Assets

MoGas Pipeline System

Our wholly-owned TRS, Corridor MoGas, Inc., owns all of the membership interests in a subsidiary that owns and operates the MoGas Pipeline System, which consists of an approximately 263-mile interstate natural gas pipeline system in and around St. Louis and extending into central Missouri, and certain related real and personal property. The MoGas Pipeline System, which is regulated by FERC, receives natural gas at three separate receipt points from third party interstate gas pipelines and delivers that gas through 24 different delivery points to investor-owned natural gas distribution companies, municipalities and end users. MoGas has eight firm transportation customers. We provide REIT-qualifying intercompany mortgage financing secured by the real property assets of MoGas and United Property Systems, which allows for a maximum principal balance of $90.0 million. Our ownership interest in the MoGas Pipeline System partially secures borrowings under the CorEnergy Credit Facility.

Omega Pipeline (Mowood, LLC)

We indirectly hold 100 percent of the equity interests in Omega through Mowood, which was a TRS of the Company until December 31, 2017, as discussed further below. Mowood is the holding company of Omega, a natural gas service provider located primarily on the Department of Defense's Fort Leonard Wood military post in south-central Missouri. Omega has a long-term contract with the Department of Defense, which was renewed for an additional 10-year term in January 2016, to provide natural gas distribution to Fort Leonard Wood through Omega's approximately 75-mile pipeline distribution system on the post. In addition, Omega has historically provided natural gas marketing services to several customers in the surrounding area.

During 2017, we received a private letter ruling from the IRS which, among other items, qualified the revenue from our long-term contract with Fort Leonard Wood as representing rents from real property. Accordingly, the revenue from the Fort Leonard Wood contract is considered REIT-qualifying income. As a result of the favorable ruling, we converted Omega from a taxable REIT subsidiary to a qualified REIT subsidiary. Omega's natural gas marketing service contracts with customers other than Fort Leonard Wood were sold to a newly created indirect wholly-owned TRS of the Company, Omega Gas Marketing, LLC.

Principal Location

Our principal executive office is located at 1100 Walnut Street, Suite 3350, Kansas City, MO 64106.

ITEM 3. LEGAL PROCEEDINGS

We are not currently subject to any material legal proceedings, nor, to our knowledge, is any material legal proceeding threatened against us.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

PART II

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Our common stock is traded on the New York Stock Exchange ("NYSE"), under the symbol "CORR".

On December 1, 2015, we completed a 1-for-5 reverse stock split, which was previously approved by our Board of Directors. All issued and outstanding common stock and per share amounts reflected in this Report have been retroactively adjusted to reflect this reverse stock split for all periods presented. As of December 31, 2018, we had 28 stockholders of record.

Dividends

Our portfolio of real property assets and promissory notes generates cash flow to us from which we pay dividends to stockholders. The amount of any dividend is recorded on the ex-dividend date.

The character of dividends made during the year may differ from their ultimate characterization for federal income tax purposes. Although there is no assurance that we will continue to make regular dividend payments, we believe that a number of actions can be taken to maintain 2019 dividends on a quarterly basis, and an estimated total 2019 annualized dividend of $3.00 per share, consistent with 2018 dividend payments. Refer to Item 7, "Dividend Discussion," for further discussion of our dividend.

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Stock Repurchase Plan

The following table presents information with respect to repurchases of preferred stock made by the Company during the three months ended December 31, 2018:

Period	Total Number of Depository Shares Purchased(1)	Average Price Paid per Depository Share(2)		Total Number of Depository Shares Purchased as Part of a Publicly Announced Plan	Maximum Number of Depository Shares that May Yet Be Purchased Under the Plan(3)
October 1-31, 2018	—	$	—	—	413,564
November 1-30, 2018	80,680	24.00		80,680	338,655
December 1-31, 2018	97,093	24.09		97,093	243,593
Total	177,773	$	24.05	177,773
(1) Includes shares repurchased by the Company pursuant to the $10.0 million preferred stock repurchase plan approved by the Company's Board of Directors, which commenced August 6, 2018. Purchases may be made through the program through August 5, 2019.
(2) Represents the weighted average price per share of preferred stock on the repurchase dates.
(3) Represents the maximum number of shares of preferred stock that may be repurchased as of the end of each respective period, pursuant to the August 2018 plan referenced in Note (1) prior to its expiration in August 2019. Such maximum number of shares has been estimated, based on the closing market price for the Company's preferred stock on the New York Stock Exchange on (a) October 31, 2018 ($24.18 per share), (b) November 30, 2018 ($23.81 per share) and (c) December 31, 2018 ($23.50 per share)

Federal and State Income Taxation

We have elected to be taxed as a REIT under sections 856 through 860 of the Code and applicable Treasury regulations, which set forth the requirements for qualifying as a REIT, commencing with our taxable year beginning January 1, 2013. We believe that we have been organized and operated in a manner so as to qualify for taxation as a REIT under the Code and we intend to continue to operate in such a manner.

For as long as we qualify for taxation as a REIT, we generally will not be subject to federal corporate income taxes on net income that we currently distribute to stockholders. This treatment substantially eliminates the "double taxation" (at the corporate and security holder levels) that can result from investment in a "C" corporation. A "C" corporation is a corporation that is generally required to pay tax at the corporate level. Double taxation means taxation once at the corporate level when income is earned and once again at the stockholder level when the income is distributed.

As long as we qualify as a REIT, distributions made to our taxable U.S. stockholders out of current or accumulated earnings and profits (and not designated as capital gain dividends or retained capital gains) will be taken into account by them as ordinary income, and corporate stockholders will not be eligible for the dividends received deduction as to such amounts. If we received qualified dividend income and designate such portion of our distributions as qualified dividend income in a written notice mailed no later than 60 days after the close of its taxable year, an individual U.S. stockholder may qualify (provided holding period and certain other requirements are met) to treat such portion of the distribution as qualified dividend income, eligible to be taxed at the reduced maximum rate of 20 percent. Distributions in excess of current and accumulated earnings and profits will not be taxable to a stockholder to the extent that they do not exceed the adjusted basis of such stockholder's common stock, but rather will reduce the adjusted basis of such shares as a return of capital. To the extent that such distributions exceed the adjusted basis of a stockholder's common stock, they will be included in income as long-term capital gains (or short-term capital gain if the shares have been held for one year or less), assuming the shares are a capital asset in the hands of the stockholder. Distributions that we properly designate as capital gain dividends will be taxable to stockholders as gains (to the extent they do not exceed our actual net capital gain for the taxable year) from the sale or disposition of a capital asset held for greater than one year. If we designate any portion of a dividend as a capital gain dividend, a U.S. stockholder will receive an Internal Revenue Service Form 1099-DIV indicating the amount that will be taxable to the stockholder as a capital gain. As a REIT, we will be subject to corporate level tax on certain built-in gains if such assets are sold during the 5-year period following conversion. Built-in gain assets are assets whose fair market value exceeds the REIT's adjusted tax basis at the time of conversion or the asset was acquired from a C corporation and our initial tax basis in the asset is less than the fair market value of the asset. In addition, a REIT may not have earnings and profits accumulated in a non-REIT year. Thus, upon conversion to a REIT, we paid sufficient dividends in 2013 to distribute all accumulated earnings and profits.

We may, from time to time, own and operate certain properties through C corporation subsidiaries and will treat those subsidiaries as either "qualified REIT subsidiaries," or "taxable REIT subsidiaries." If a REIT owns a corporate subsidiary that is a "qualified REIT subsidiary," the separate existence of that subsidiary generally will be disregarded for Federal income tax purposes. A "taxable REIT subsidiary" is an entity taxable as a corporation in which we own stock and that elected with us to be treated as a taxable REIT

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subsidiary under Section 856(1) of the Code. A taxable REIT subsidiary is subject to Federal income tax, and state and local income tax where applicable, as a regular "C" corporation.

Our tax expense or benefit attributable to the taxable REIT subsidiary is included in the Consolidated Statements of Income. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes.

Recent Sales of Unregistered Securities

We did not sell any securities during the fourth quarter ended December 31, 2018 that were not registered under the Securities Act of 1933.

Performance Graph

We operate as a REIT and primarily own assets in the midstream and downstream U.S. Energy sectors that perform utility-like functions, such as pipelines, storage terminals, rail terminals and gas transmission and distribution assets. The following graph sets forth the cumulative return on our common stock between January 1, 2014 and December 31, 2018, as compared to the following set of relevant indices: FTSE NAREIT All Equity REIT Index ("FTSE NAREIT"), the Dow Jones Utilities Average Index ("DJ UTIL"), the S&P Global Infrastructure Index ("SPGTIND") and the Alerian MLP Index ("AMZ"). The graph assumes a $100 investment was made on December 31, 2013 in each of our common stock, the FTSE NAREIT, the DJ UTIL, the SPGTIND and the AMZ, and assumes the reinvestment of all cash dividends. The comparisons in the graph below are based on historical data and are not intended to forecast future performance.

The performance graph shall not be deemed "filed" for purposes of Section 18 of the Exchange Act, or otherwise subject to the liabilities under that section, and shall not be deemed to be incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Exchange Act.

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	Cumulative Value of $100 Investment, through December 31,
	2013		2014		2015		2016		2017		2018
CorEnergy Infrastructure Trust, Inc.	$	100.00	$	101.50	$	49.43	$	145.77	$	179.61	$	160.42
FTSE NAREIT All Equity REIT Index	100.00		128.03		130.90		143.25		158.33		146.03
Dow Jones Utilities Average Index	100.00		132.35		124.70		144.95		162.22		158.02
S&P Global Infrastructure Index	100.00		113.29		99.75		111.79		134.08		118.67
Alerian MLP Index	100.00		105.45		74.27		93.51		89.66		74.97

Our shares began trading on the New York Stock Exchange ("NYSE") on February 2, 2007. Since December 3, 2012, our common stock has traded under the symbol "CORR".

ITEM 6. SELECTED FINANCIAL DATA

The selected financial data set forth below should be read in conjunction with "Management's Discussion and Analysis of Financial Condition and Results of Operations," and the financial statements and related notes included in this Report. Our consolidated financial statements include our accounts and our wholly-owned subsidiaries. The financial information presented below has been derived from our audited consolidated financial statements, which financial statements have been audited by Ernst & Young LLP, our independent registered public accounting firm. The historical data is not necessarily indicative of results to be expected for any future period. The balance sheet data below reflects the reclassification of deferred financing costs under FASB Accounting Standards Update (ASU) No. 2015-03, Simplifying the Presentation of Debt Issue Costs, which was adopted on January 1, 2016, retrospectively.

	For the Years Ended December 31,
	2018		2017		2016		2015		2014
Operating Data
Total revenue	$	89,231,598	$	88,749,377	$	89,250,586	$	71,288,935	$	40,308,573
Net income attributable to CorEnergy stockholders	43,711,876		32,602,790		29,663,200		12,319,911		7,013,856
Net income attributable to CorEnergy Common stockholders	34,163,499		24,648,802		25,514,763		8,471,083		7,013,856
Per Share Data
Net income attributable to CorEnergy Common stockholders:
Basic	$	2.86	$	2.07	$	2.14	$	0.79	$	1.06
Diluted	2.79		2.07		2.14		0.79		1.06
Cash dividends declared per common share	3.000		3.000		3.000		2.750		2.570
Other Data
AFFO attributable to Common stockholders(1)
Basic	$	4.11	$	4.25	$	4.41	$	3.77	$	2.82
Diluted	3.70		3.81		3.93		3.56		2.82
(1) We believe that net income, as defined by U.S. GAAP, is the most appropriate earnings measurement. However, we consider Adjusted Funds From Operations ("AFFO") to be an appropriate measure of operating performance of an equity REIT. See "Management's Discussion and Analysis of Financial Condition and Results of Operations - Non-GAAP Financial Measures" included in Item 7 of this Report for a reconciliation of AFFO to our GAAP earnings.

	As of December 31,
	2018		2017		2016		2015		2014
Balance sheet data
Total assets	$	624,883,180	$	633,418,113	$	650,732,571	$	677,979,621	$	443,815,842
Current debt maturities	3,528,000		3,528,000		7,128,556		66,132,000		3,528,000
Long-term debt	146,510,380		149,249,437		193,504,324		150,732,752		63,532,000
CorEnergy equity - Preferred	125,555,675		130,000,000		56,250,000		56,250,000		—
CorEnergy equity - Common	329,455,630		331,785,632		350,218,436		361,784,244		310,450,347

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Certain statements included or incorporated by reference in this Annual Report on Form 10-K may be deemed "forward-looking statements" within the meaning of the federal securities laws. In many cases, these forward-looking statements may be identified by the use of words such as "will," "may," "should," "could," "believes," "expects," "anticipates," "estimates," "intends," "projects,"

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"goals," "objectives," "targets," "predicts," "plans," "seeks," or similar expressions. Any forward-looking statement speaks only as of the date on which it is made and is qualified in its entirety by reference to the factors discussed throughout this Report.

Although we believe the expectations reflected in any forward-looking statements are based on reasonable assumptions, forward-looking statements are not guarantees of future performance or results and we can give no assurance that these expectations will be attained. Our actual results may differ materially from those indicated by these forward-looking statements due to a variety of known and unknown risks and uncertainties. Such risks and uncertainties include, without limitation, the risk factors discussed in Part I, Item 1A of this Report. We disclaim any obligation to update or revise any forward-looking statements to reflect actual results or changes in the factors affecting the forward-looking information.

BUSINESS OBJECTIVE

CorEnergy primarily owns and seeks to own assets in the U.S. energy sector that perform utility-like functions, such as pipelines, storage terminals, rail terminals and gas and electric transmission and distribution assets. We also may provide other types of capital, including loans secured by energy infrastructure assets. Our objective is to generate long-term contracted revenue from operators of our assets, primarily under triple-net participating leases without direct commodity price exposure.

The assets are primarily mission-critical, in that utilization of the assets is necessary for the business the operators of those assets seek to conduct and their rental payments are an essential operating expense. We acquire assets that will enhance the stability of our dividend through diversification, while offering the potential for long-term distribution growth. These sale-leaseback or real property mortgage transactions provide the energy company with a source of capital that is an alternative to sources such as corporate borrowing, bond offerings, or equity offerings. We believe our leadership team's energy and utility expertise provides CorEnergy with a competitive advantage to acquire, own and lease U.S. energy infrastructure assets in a tax-efficient, transparent and investor-friendly REIT.

Basis of Presentation

The consolidated financial statements include CorEnergy Infrastructure Trust, Inc., as of December 31, 2018, and its direct and indirect wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated in consolidation.

RESULTS OF OPERATIONS

The following table summarizes the financial data and key operating statistics for CorEnergy for the years ended December 31, 2018, 2017 and 2016. We believe the Operating Results detail presented below provides investors with information that will assist them in analyzing our operating performance. The following data should be read in conjunction with our consolidated financial statements and the notes thereto included in Part IV, Item 15 of this Report.

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The following table and discussion are a summary of our results of operations for the years ended December 31, 2018, 2017 and 2016:

	For the Years Ended December 31,
	2018			2017			2016
Revenue
Lease revenue	$	72,747,362		$	68,803,804		$	67,994,130
Transportation and distribution revenue	16,484,236			19,945,573			21,094,112
Financing revenue	—			—			162,344
Total Revenue	89,231,598			88,749,377			89,250,586
Expenses
Transportation and distribution expenses	7,210,748			6,729,707			6,463,348
General and administrative	13,042,847			10,786,497			12,270,380
Depreciation, amortization and ARO accretion expense	24,947,453			24,047,710			22,522,871
Provision for loan (gain) loss	(36,867		)	—			5,014,466
Total Expenses	45,164,181			41,563,914			46,271,065
Operating Income	$	44,067,417		$	47,185,463		$	42,979,521
Other Income (Expense)
Net distributions and dividend income	$	106,795		$	680,091		$	1,140,824
Net realized and unrealized gain (loss) on other equity securities	(1,845,309		)	1,531,827			824,482
Interest expense	(12,759,010		)	(12,378,514		)	(14,417,839		)
Gain on the sale of leased property, net	11,723,257			—			—
Loss on extinguishment of debt	—			(336,933		)	—
Total Other Expense	(2,774,267		)	(10,503,529		)	(12,452,533		)
Income before income taxes	41,293,150			36,681,934			30,526,988
Income tax expense (benefit), net	(2,418,726		)	2,345,318			(464,420		)
Net Income	43,711,876			34,336,616			30,991,408
Less: Net Income attributable to non-controlling interest	—			1,733,826			1,328,208
Net Income attributable to CorEnergy Stockholders	$	43,711,876		$	32,602,790		$	29,663,200
Preferred dividend requirements	9,548,377			7,953,988			4,148,437
Net Income attributable to Common Stockholders	$	34,163,499		$	24,648,802		$	25,514,763
Other Financial Data(1)
Adjusted EBITDAre	$	69,395,739		$	67,944,360		$	67,768,945
NAREIT FFO	46,796,201			46,308,969			45,573,219
FFO	47,959,311			46,046,781			45,396,401
AFFO	49,024,120			50,536,194			52,438,268
(1) Refer to the "Non-GAAP Financial Measures" section that follows for additional details.

Year Ended December 31, 2018 Compared to Year Ended December 31, 2017

Revenue. Consolidated revenues were $89.2 million for the year ended December 31, 2018 compared to $88.7 million for the year ended December 31, 2017, representing an increase of $482 thousand. Lease revenue was $72.7 million and $68.8 million for the years ended December 31, 2018 and 2017, respectively, with the increase of approximately $3.9 million driven primarily by variable rent collected on the Pinedale lease during 2018. Transportation and distribution revenue from our subsidiaries MoGas and Omega was $16.5 million and $19.9 million for the years ended December 31, 2018 and 2017, respectively. The $3.5 milliondecrease primarily resulted from a change to straight-line revenue recognition on MoGas' long-term contract with Spire under the new revenue recognition standard that was adopted on January 1, 2018. Revenue recognized for the year ended December 31, 2018 was approximately $3.2 million lower under the new accounting standard. Refer to Part IV, Item 15, Note 4 ("Transportation And Distribution Revenue") for additional details.

Transportation and Distribution Expenses. Transportation and distribution expenses were $7.2 million and $6.7 million for the years ended December 31, 2018 and 2017, respectively, representing an increase of $481 thousand. The increase relates primarily to MoGas, which had higher legal and consulting costs during 2018 related to the FERC rate case. The increase was partially offset by lower costs from the timing of projects performed by Omega for Fort Leonard Wood.

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General and Administrative Expenses. General and administrative expenses were $13.0 million for the year ended December 31, 2018 compared to $10.8 million for the year ended December 31, 2017. The most significant components of the variance from the prior-year period are outlined in the following table and explained below:

	For the Years Ended December 31,
	2018		2017
Management fees	$	7,591,750	$	7,213,720
Acquisition and professional fees	3,759,505		2,380,918
Other expenses	1,691,592		1,191,859
Total	$	13,042,847	$	10,786,497

Management fees are directly proportional to our asset base. For the year ended December 31, 2018, management fees increased $378 thousand compared to the prior-year period due to the acquisition of the non-controlling interest in Pinedale LP, which closed on December 29, 2017. See Part IV, Item 15, Note 9 ("Management Agreement") for additional information.

Acquisition and professional fees for the year ended December 31, 2018increased$1.4 million from the prior-year period primarily due to an increase in professional fees. The increase in professional fees for the year ended December 31, 2018 is primarily attributable to (i) higher legal and consulting costs in the current-year related to monitoring our GIGS asset, (ii) higher legal and consulting fees related to the sale of the Portland Terminal Facility and (iii) a prior-year reimbursement of legal fees received in 2017 for costs incurred during UPL's bankruptcy.

Asset acquisition costs for the year ended December 31, 2018 were relatively consistent with the prior-year period, decreasing $71 thousand, due to continued focus on potential acquisition opportunities. Generally, we expect asset acquisition expenses to be repaid over time from income generated by acquisitions. However, any particular period may reflect significant expenses arising from third party legal, engineering, and consulting fees that are incurred in the early to mid-stages of due diligence.

Other expenses for the for the year ended December 31, 2018increased$500 thousand compared to the prior-year period. The increase is primarily related to (i) a loss on settlement of ARO related to the decommissioning of a segment of the GIGS pipeline system during the current period and (ii) a non-cash gain recorded on settlement of accounts payable in the prior-year period.

Depreciation, Amortization and ARO Accretion Expense. Depreciation, amortization and ARO accretion expense was $24.9 million for the year ended December 31, 2018 compared to $24.0 million for the year ended December 31, 2017. This $900 thousand increase was primarily driven by an increase in ARO depreciation based on updates made to the estimated useful lives of certain segments of GIGS at the end of 2017.

Provision for loan gain. For the year ended December 31, 2018, we recorded a provision for loan gain of approximately $37 thousand related to the satisfaction of the SWD loans with Four Wood Corridor upon sale of the assets securing the loans to Compass SWD, LLC in exchange for (i) a new loan agreement with Compass SWD, LLC for $1.3 million and (ii) cash proceeds from the sale recognized as principal payments on the SWD loans. For additional information, see Part IV, Item 15, Note 5 ("Financing Notes Receivable"). There were no loan (gain) loss provisions recorded for the year ended December 31, 2017.

Net Distributions and Dividend Income. Net distributions and dividend income for the year ended December 31, 2018 was $107 thousand compared to $680 thousand for the year ended December 31, 2017. The portion of distributions and dividends deemed to be income versus a return of capital in any period are estimated at the time such distributions are received. These estimates may be subsequently revised based on information received from the portfolio company after their tax reporting periods are concluded. The following table provides a reconciliation of the gross cash distributions and dividend income received from our investment securities for the years ended December 31, 2018 and 2017 to the net distributions and dividends recorded as income on the Consolidated Statements of Income.

	For the Years Ended December 31,
	2018		2017
Gross cash distributions and dividend income received from investment securities	$	770,734	$	949,646
Add:
Cash distributions received in prior period previously deemed a return of capital (dividend income) which have been reclassified as income (return of capital) in a subsequent period	—		(148,649		)
Less:
Cash distributions and dividends received in current period deemed a return of capital and not recorded as income (recorded as a cost reduction) in the current period	663,939		120,906
Net distributions and dividends recorded as income	$	106,795	$	680,091

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For the year ended December 31, 2018 compared to the year ended December 31, 2017, the decline in net distributions and dividends recorded as income versus the prior-year period was primarily due to (i) the sale of a large portion of the Lightfoot investment as a result of the Arc Logistics merger with Zenith, completed on December 21, 2017 and (ii) Lightfoot's disposition of its remaining asset interest at the end of 2018.

Net Realized and Unrealized Gain (Loss) on Other Equity Securities. For the years ended December 31, 2018 and 2017, we recorded a net loss on other equity securities of $1.8 million and a net gain on other equity securities of $1.5 million, respectively, resulting in a decrease of $3.4 million. The net gain and loss recorded are directly related to fluctuations in the valuation, sale and liquidation plan of our investments in private securities. The net loss recorded during the year ended December 31, 2018 related to (i) the sale of our equity interest in Joliet to Zenith Terminals and (ii) Lightfoot's disposition of its remaining asset interest at the end of 2018. The net gain recorded during the year ended December 31, 2017 was primarily due to gains realized related to Lightfoot upon completion of the Arc Logistics merger and valuation of the remaining investment in the Lightfoot LP and GP interests. See Part IV, Item 15, Note 10 ("Fair Value") for additional information.

Interest Expense. For the years ended December 31, 2018 and 2017, interest expense totaled approximately $12.8 million and $12.4 million, respectively. This increase was attributable to (i) increased interest on the Amended Pinedale Term Credit Facility during the current year as a result of the refinancing with Prudential on December 29, 2017, partially offset by (ii) interest incurred on outstanding borrowings on the CorEnergy Revolver and CorEnergy Term Loan during the prior year.

Gain on the sale of leased property. For the year ended December 31, 2018, a gain on the sale of leased property totaling approximately $11.7 million was recorded in connection with the sale of the Portland Terminal Facility to Zenith Terminals on December 21, 2018. For additional information, see Part IV, Item 15, Note 3 ("Leased Properties And Leases"). There was no gain on the sale of leased property recorded for the year ended December 31, 2017.

Loss on Extinguishment of Debt. For the year ended December 31, 2017, a loss on extinguishment of debt totaling approximately $337 thousand was recorded in connection with entering into the amended and restated CorEnergy Credit Facility on July 28, 2017 and Amended Pinedale Term Credit Facility on December 29, 2017. For additional information, see Part IV, Item 15, Note 11 ("Debt"). There was no loss on extinguishment of debt recorded for the year ended December 31, 2018.

Income Tax Expense (Benefit). Income tax benefit was $2.4 million for the year ended December 31, 2018 compared to an income tax expense of $2.3 million for the year ended December 31, 2017. The increased benefit in the current year was primarily attributable to (i) higher losses generated by our TRS subsidiaries and (ii) the capital losses generated from the sale of our interest in Joliet to Zenith Terminals and Lightfoot's disposition of its remaining asset interest that will be carried back against capital gains generated from the sale of a portion of the Lightfoot investment in the prior year. Income tax expense for the year ended December 31, 2017 was primarily attributable to (i) the transition tax adjustment associated with application of lower effective tax rates from the Tax Cuts and Jobs Act enacted in December 2017 to existing deferred tax asset balances at our TRS entities, (ii) the write-off of certain deferred tax assets in connection with the reorganization of Omega from a TRS subsidiary to a qualified REIT subsidiary and (iii) realized and unrealized gains recorded associated with our Lightfoot investment.

Net Income. Net income was $43.7 million and $34.3 million for the years ended December 31, 2018 and 2017, respectively, representing an increase of $9.4 million. For the years ended December 31, 2018 and 2017, net income attributable to CorEnergy stockholders was $43.7 million and $32.6 million, respectively. After deducting $9.5 million and $8.0 million for the portion of preferred dividends that are allocable to each respective period, net income attributable to common stockholders for the year ended December 31, 2018 was $34.2 million, or $2.86 per basic and $2.79 diluted common share, as compared to $24.6 million, or $2.07 per basic and diluted common share, for the prior-year period.

Year Ended December 31, 2017 Compared to Year Ended December 31, 2016

Revenue. Consolidated revenues were $88.7 million for the year ended December 31, 2017 compared to $89.3 million for the year ended December 31, 2016, representing a decrease of $501 thousand. Lease revenue was $68.8 million and $68.0 million for the years ended December 31, 2017 and 2016, respectively, with the increase of approximately $810 thousand driven primarily by variable rent collected on the Pinedale lease during 2017. Transportation and distribution revenue from our subsidiaries MoGas and Omega was $19.9 million and $21.1 million for the years ended December 31, 2017 and 2016, respectively. The $1.1 million decrease primarily resulted from projects performed in the prior year by Omega for Fort Leonard Wood and other construction projects at MoGas.

Transportation and Distribution Expenses. Transportation and distribution expenses were $6.7 million and $6.5 million for the years ended December 31, 2017 and 2016, respectively, representing an increase of $266 thousand. The increase relates primarily to planned pipeline integrity maintenance work at MoGas during 2017, partially offset by decreased costs at Omega due to projects performed at Fort Leonard Wood and other construction projects at MoGas.

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General and Administrative Expenses. General and administrative expenses were $10.8 million for the year ended December 31, 2017 compared to $12.3 million for the year ended December 31, 2016. The most significant components of the variance from the prior-year period are outlined in the following table and explained below:

	For the Years Ended December 31,
	2017		2016
Management fees	$	7,213,720	$	7,174,243
Acquisition and professional fees	2,380,918		3,320,581
Other expenses	1,191,859		1,775,556
Total	$	10,786,497	$	12,270,380

Management fees are directly proportional to our asset base. For the year ended December 31, 2017, management fees were consistent with the prior year due to minor fluctuations in the asset base. Incremental management fee resulting from the acquisition of the non-controlling interest in Pinedale LP, which closed on December 29, 2017, was waived by Corridor for the fourth quarter of 2017, given the timing of the acquisition. See Part IV, Item 15, Note 9 ("Management Agreement") for additional information.

Acquisition and professional fees for the year ended December 31, 2017decreased$940 thousand from the prior-year period due to a $1.0 million decrease in professional fees. The decrease in professional fees for the year ended December 31, 2017 is primarily attributable to lower legal fees compared to the prior-year period related to legal fees incurred in the monitoring of our assets at Pinedale and GIGS during the bankruptcy proceedings.

Generally, we expect asset acquisition expenses to be repaid over time from income generated by acquisitions. However, any particular period may reflect significant expenses arising from third party legal, engineering, and consulting fees that are incurred in the early to mid-stages of due diligence. Asset acquisition costs for the year ended December 31, 2017 were relatively consistent with the prior-year period, increasing $72 thousand primarily due to increased focus on potential acquisition opportunities.

Other expenses for the for the year ended December 31, 2017decreased$584 thousand compared to the prior-year period. The decrease is primarily related to (i) a non-cash gain recorded on settlement of accounts payable in the current-year period and (ii) higher expenses at Black Bison in the prior period due to the foreclosure and sale activities.

Depreciation, Amortization and ARO Accretion Expense. Depreciation, amortization and ARO accretion expense was $24.0 million for the year ended December 31, 2017 compared to $22.5 million for the year ended December 31, 2016. This $1.5 million increase was primarily driven by (i) a reduction in the useful life of GIGS property to 26.5 years at the end of 2016 ($1.2 million) and (ii) a $433 thousand adjustment recorded in the prior-year period which reduced depreciation expense.

Provision for loan loss. For the year ended December 31, 2016, we recorded a provision for loan loss of approximately $5.0 million. The prior-year provision for loan losses related primarily to a write-down of $3.5 million on the SWD loans, with additional provisions recorded related to the Black Bison financing notes. For additional information, see Part IV, Item 15, Note 5 ("Financing Notes Receivable"). There were no loan (gain) loss provisions recorded for the year ended December 31, 2017.

Net Distributions and Dividend Income. Net distributions and dividend income for the year ended December 31, 2017 was $680 thousand compared to $1.1 million for the year ended December 31, 2016. The portion of distributions and dividends deemed to be income versus a return of capital in any period are estimated at the time such distributions are received. These estimates may be subsequently revised based on information received from the portfolio company after their tax reporting periods are concluded. The following table provides a reconciliation of the gross cash distributions and dividend income received from our investment securities for the years ended December 31, 2017 and 2016 to the net distributions and dividends recorded as income on the Consolidated Statements of Income.

	For the Years Ended December 31,
	2017			2016
Gross cash distributions and dividend income received from investment securities	$	949,646		$	1,028,452
Add:
Cash distributions received in prior period previously deemed a return of capital (dividend income) which have been reclassified as income (return of capital) in a subsequent period	(148,649		)	117,004
Less:
Cash distributions and dividends received in current period deemed a return of capital and not recorded as income (recorded as a cost reduction) in the current period	120,906			4,632
Net distributions and dividends recorded as income	$	680,091		$	1,140,824

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For the year ended December 31, 2017 compared to the year ended December 31, 2016, the decline in net distributions and dividends recorded as income versus the prior-year period was primarily due to a $266 thousand decrease in adjustments recorded in the first quarter of each year to reclassify previously unrealized gains as dividend income upon the receipt of the annual K-1s, which depict our share of income and losses from the investment in the security and a change in the characterization of our distributions received from Lightfoot. In 2017, a higher percentage of the cash we received was deemed return of capital, whereas in 2016, nearly all distributions received were recorded as dividend income.

Net Realized and Unrealized Gain on Other Equity Securities. For the years ended December 31, 2017 and 2016, we recorded net gains on other equity securities of $1.5 million and $824 thousand, respectively, resulting in an increase of $707 thousand. The net gains recorded are directly related to fluctuations in the valuation of Lightfoot, which was dependent on the historical public share price of Arc Logistics, the valuation of its Gulf LNG interest and its GP interest. In August 2017, Arc Logistics and Lightfoot entered into a purchase agreement and plan of merger with Zenith, completed in December 2017, pursuant to which Zenith acquired the outstanding units of Arc Logistics held by Lightfoot, as well as Lightfoot's Gulf LNG and GP interests. The net gain recorded during the year ended December 31, 2017 is primarily due to gains realized related to Lightfoot upon completion of the Arc Logistics merger and valuation of the remaining investment in the Lightfoot LP and GP interests. The increase in the prior-year period was primarily the result of fluctuations in the public share price of Arc Logistics.

Interest Expense. For the years ended December 31, 2017 and 2016, interest expense totaled approximately $12.4 million and $14.4 million, respectively. This decrease was attributable to (i) the Company internally refinancing its pro rata share of the Pinedale Credit Facility on March 30, 2016, which resulted in a reduction of the outstanding debt balance with third parties, (ii) lower outstanding borrowings on the CorEnergy Revolver during 2017 and (iii) refinancing the CorEnergy Credit Facility during 2017, which included the payment of outstanding borrowings on the CorEnergy Term Loan.

Loss on Extinguishment of Debt. For the year ended December 31, 2017, a loss on extinguishment of debt totaling approximately $337 thousand was recorded in connection with entering into the amended and restated CorEnergy Credit Facility on July 28, 2017 and Amended Pinedale Term Credit Facility on December 29, 2017. There was no loss on extinguishment of debt recorded for the year ended December 31, 2016. For additional information, see Part IV, Item 15, Note 11 ("Debt").

Income Tax Expense (Benefit). Income tax expense was $2.3 million for the year ended December 31, 2017 compared to an income tax benefit of $464 thousand for the year ended December 31, 2016. Income tax expense for the year ended December 31, 2017 was primarily attributable to (i) the transition tax adjustment associated with application of lower effective tax rates from the Tax Cuts and Jobs Act enacted in December 2017 to existing deferred tax asset balances at our TRS entities, (ii) the write-off of certain deferred tax assets in connection with the reorganization of Omega from a TRS subsidiary to a qualified REIT subsidiary and (iii) realized and unrealized gains recorded associated with our Lightfoot investment. The prior year tax benefit was the result of taxable losses incurred in certain of our TRS subsidiaries.

Net Income. Net income was $34.3 million and $31.0 million for the years ended December 31, 2017 and 2016, respectively, representing an increase of $3.3 million. For the years ended December 31, 2017 and 2016, net income attributable to CorEnergy stockholders was $32.6 million and $29.7 million, respectively. After deducting $8.0 million and $4.1 million for the portion of preferred dividends that are allocable to each respective period, net income attributable to common stockholders for the year ended December 31, 2017 was $24.6 million, or $2.07 per basic and diluted common share, as compared to $25.5 million, or $2.14 per basic and diluted common share, for the prior-year period.

Common Equity Attributable to CorEnergy Stockholders per Share

As of December 31, 2018, our common equity decreased by approximately $2.3 million to $329.5 million from $331.8 million as of December 31, 2017. This decrease principally consists of: (i) dividends paid to our stockholders of approximately $35.8 million; and (ii) the cumulative transition adjustment related to the adoption of ASC 606 for approximately $2.5 million, offset by (iii) net income attributable to CorEnergy common stockholders of approximately $34.2 million; (iv) $158 thousand related to a reduction in the carrying value of preferred stock related to the Series A Preferred Stock repurchases and (v) $1.6 million of common stock issued pursuant to reinvestment of dividends through the dividend reinvestment plan, Board of Directors compensation plan and conversion of Convertible Notes.

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Book Value Per Common Share
Analysis of Equity	December 31, 2018			December 31, 2017
Series A Cumulative Redeemable Preferred Stock 7.375%, $125,555,675 and $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 50,222 and 52,000 issued and outstanding at December 31, 2018 and December 31, 2017, respectively	$	125,555,675		$	130,000,000
Capital stock, non-convertible, $0.001 par value; 11,960,225 and 11,915,830 shares issued and outstanding at December 31, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,960			11,916
Additional paid-in capital	320,295,969			331,773,716
Retained earnings	9,147,701			—
Total CorEnergy Stockholders' Equity	$	455,011,305		$	461,785,632
Subtract: 7.375% Series A Preferred Stock	(125,555,675		)	(130,000,000		)
Total CorEnergy Common Equity	$	329,455,630		$	331,785,632
Common shares outstanding	11,960,225			11,915,830
Book Value per Common Share	$	27.55		$	27.84

NON-GAAP FINANCIAL MEASURES

We use certain financial measures that are not recognized under GAAP. The non-GAAP financial measures used in this Report include earnings before interest, taxes, depreciation and amortization as defined by the National Association of Real Estate Investment Trusts ("EBITDAre"); EBITDAre as adjusted in the manner described below ("Adjusted EBITDAre"); NAREIT funds from operations ("NAREIT FFO"); funds from operations adjusted for securities investments ("FFO"); and FFO as further adjusted in the manner described below ("AFFO"). These supplemental measures are used by our management team and are presented because we believe they help investors understand our business, performance and ability to earn and distribute cash to our stockholders by providing perspectives not immediately apparent from net income. The presentation of EBITDAre, Adjusted EBITDAre, NAREIT FFO, FFO and AFFO are not intended to be considered in isolation or as a substitute for, or superior to, the financial information prepared and presented in accordance with GAAP.

We offer these measures to assist the users of our financial statements in assessing our operating performance under U.S. GAAP, but these measures are non-GAAP measures and should not be considered measures of liquidity, alternatives to net income or indicators of any other performance measure determined in accordance with GAAP, nor are they indicative of funds available to fund our cash needs, including capital expenditures (if any), to make payments on our indebtedness or to make distributions. Our method of calculating these measures may be different from methods used by other companies and, accordingly, may not be comparable to similar measures as calculated by other companies. Investors should not rely on these measures as a substitute for any GAAP measure, including net income, cash flows from operating activities or revenues.

EBITDAre and Adjusted EBITDAre

EBITDAre and Adjusted EBITDAre are non-GAAP financial measures that management and external users of our consolidated financial statements, such as industry analysts, investors and lenders may use to evaluate our ongoing operating results, including (i) the performance of our assets without regard to the impact of financing methods, capital structure or historical cost basis of our assets and (ii) the overall rates of return on alternative investment opportunities. EBITDAre, as established by NAREIT, is defined as net income (calculated in accordance with GAAP) excluding interest expense, income tax, depreciation and amortization, gains or losses on disposition of depreciated property (including gains or losses on change of control), impairment write-downs of depreciated property and of investments in unconsolidated affiliates caused by a decrease in value of depreciated property in the affiliate, and adjustments to reflect the entity's pro rata share of EBITDAre of unconsolidated affiliates. Our presentation of Adjusted EBITDAre represents EBITDAre adjusted for net realized and unrealized (gain) loss on securities, non-cash; (gain) loss on extinguishment of debt; provision for loan (gain) loss; preferred dividend requirements; distributions and dividends received in prior period previously deemed a return of capital (recorded as a cost reduction) and reclassified as income in a subsequent period; (gain) loss on settlement of ARO; and non-cash settlement of accounts payable.

We believe that the presentation of EBITDAre and Adjusted EBITDAre provide useful information to investors in assessing our financial condition and results of operations. Our presentation of EBITDAre is calculated in accordance with standards established by NAREIT, which may not be comparable to measures calculated by other companies that do not use the NAREIT definition of EBITDAre. In addition, although EBITDAre is a useful measure when comparing our results to other REITs, it may not be helpful to investors when comparing to non-REITs. Adjusted EBITDAre presented by other companies may not be comparable to our presentation, since each company may define these terms differently. EBITDAre and Adjusted EBITDAre should not be considered measures of liquidity and should not be considered as alternatives to operating income, net income or other indicators of performance determined in accordance with GAAP.

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The following table presents a reconciliation of Income Attributable to Common Stockholders, as reported in the Consolidated Statements of Income and Comprehensive Income to EBITDAre and Adjusted EBITDAre:

	For the Years Ended December 31,
	2018			2017			2016
Income Attributable to Common Stockholders	$	34,163,499		$	24,648,802		$	25,514,763
Add:
Interest expense, net	12,759,010			12,378,514			14,417,839
Depreciation, amortization, and ARO accretion	24,947,453			24,047,710			22,522,871
Less:
Gain on the sale of leased property, net	11,723,257			—			—
Income tax (expense) benefit	2,418,726			(2,345,318		)	464,420
Non-controlling interest attributable to depreciation, amortization, and interest expense(1)	—			2,283,024			2,448,157
EBITDAre(2)	57,727,979			61,137,320			59,542,896
Add:
Loss on extinguishment of debt	—			336,933			—
Provision for loan (gain) loss	(36,867		)	—			5,014,466
Preferred dividend requirements	9,548,377			7,953,988			4,148,437
Distributions and dividends received in prior period previously deemed a return of capital (recorded as a cost reduction) and reclassified as income in a subsequent period(3)	—			148,649			(117,004		)
Loss on settlement of ARO	310,941			—			—
Less:
Net realized and unrealized gain (loss) on securities, non-cash(4)	(1,845,309		)	1,410,921			819,850
Non-cash settlement of accounts payable	—			221,609			—
Adjusted EBITDAre(2)	$	69,395,739		$	67,944,360		$	67,768,945
(1) ARO accretion expense has no impact on non-controlling interest. For the year ended December 31, 2018, there is no noncontrolling interest outstanding.
(2) Effective March 31, 2018, we now present EBITDAre, reported in accordance with NAREIT guidelines, and Adjusted EBITDAre as supplemental measures of our performance. Our prior year presentation has been updated to conform with the current year presentation.
(3)We characterize distributions received from private investments estimated based on prior year activity. After receiving the K-1s, which depict our share of income and losses from the investment in the security, previously unrealized gains can be reclassified as dividend income.
(4) Realized gains of $1.2 million related to the sale of interests in Lightfoot LP and Lightfoot GP have been excluded from Adjusted EBITDA for the year ended December 31, 2017. Refer to Part IV, Item 15, Note 10 ("Fair Value") for additional discussion.

NAREIT FFO

FFO is a widely used measure of the operating performance of real estate companies that supplements net income determined in accordance with GAAP. As defined by NAREIT, NAREIT FFO represents net income (computed in accordance with GAAP), excluding gains (or losses) from sales of depreciable operating property, impairment losses of depreciable properties, real estate-related depreciation and amortization (excluding amortization of deferred financing costs or loan origination costs) and after adjustments for unconsolidated partnerships and non-controlling interests. Adjustments for non-controlling interests are calculated on the same basis. We define FFO attributable to common stockholders as defined above by NAREIT less dividends on preferred stock. Our method of calculating FFO attributable to common stockholders may differ from methods used by other REITs and, as such, may not be comparable.

FFO ADJUSTED FOR SECURITIES INVESTMENTS (FFO)

Due to the legacy investments that we hold, we have also historically presented a measure of FFO, to which we refer herein as FFO Adjusted for Securities Investments which is derived by further adjusting NAREIT FFO for distributions received from investment securities, income tax expense (benefit) from investment securities, net distributions and dividend income and net realized and unrealized gain or loss on other equity securities.

We present NAREIT FFO and FFO Adjusted for Securities Investments because we consider it an important supplemental measure of our operating performance and believe that it is frequently used by securities analysts, investors, and other interested parties in the evaluation of REITs, many of which present FFO when reporting their results. FFO is a key measure we use in assessing performance and in making resource allocation decisions.

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Both NAREIT FFO and FFO Adjusted for Securities Investments are intended to exclude GAAP historical cost depreciation and amortization of real estate and related assets, which assumes that the value of real estate diminishes ratably over time. Historically, however, real estate values have risen or fallen with market conditions, and that may also be the case with certain of the energy infrastructure assets in which we invest. NAREIT FFO and FFO Adjusted for Securities Investments exclude depreciation and amortization unique to real estate and gains and losses from property dispositions and extraordinary items. As such, these performance measures provide a perspective not immediately apparent from net income when compared to prior-year periods. These metrics reflect the impact to operations from trends in base and participating rents, company operating costs, development activities, and interest costs.

We calculate NAREIT FFO in accordance with standards established by the Board of Governors of the National Association of Real Estate Investment Trusts in its March 1995 White Paper (as amended in November 1999 and April 2002) and FFO Adjusted for Securities Investment as NAREIT FFO with additional adjustments described above due to our legacy investments. This may differ from the methodology for calculating FFO utilized by other equity REITs and, accordingly may not be comparable to such other REITs. NAREIT FFO and FFO Adjusted for Securities Investments do not represent amounts available for management's discretionary use because of needed capital for replacement or expansion, debt service obligations, or other commitments and uncertainties. NAREIT FFO and FFO Adjusted for Securities Investments, as we have historically reported, should not be considered as an alternative to net income (computed in accordance with GAAP), as an indicator of our financial performance, or to cash flow from operating activities (computed in accordance with GAAP), as an indicator of our liquidity, or as an indicator of funds available for our cash needs, including our ability to make distributions or to service our indebtedness.

AFFO

Management uses AFFO as a measure of long-term sustainable operational performance. AFFO in excess of dividends is used for debt repayment, capital reinvestment activities, funding our ARO liability, or other commitments and uncertainties which are necessary to sustain our dividend over the long term. AFFO should not be considered as an alternative to net income (computed in accordance with GAAP), as an indicator of our financial performance, or as an alternative to cash flow from operating activities (computed in accordance with GAAP), as an indicator of our liquidity, or as an indicator of funds available for our cash needs, including our ability to make distributions or service our indebtedness.

For completeness, the following table sets forth a reconciliation of our net income as determined in accordance with GAAP and our calculations of NAREIT FFO, FFO Adjusted for Securities Investments, and AFFO for the years ended December 31, 2018, 2017 and 2016. AFFO is a supplemental, non-GAAP financial measure which we define as FFO Adjusted for Securities Investment plus (gain) loss on extinguishment of debt, provision for loan (gain) loss, net of tax, transaction costs, amortization of debt issuance costs, amortization of deferred lease costs, accretion of asset retirement obligation, amortization of above market leases, income tax expense (benefit) unrelated to securities investments, non-cash costs associated with derivative instruments, (gain) loss on the settlement of ARO, and certain costs of a nonrecurring nature, less maintenance, capital expenditures (if any), amortization of debt premium, and other adjustments as deemed appropriate by Management. Also presented is information regarding the weighted-average number of shares of our common stock outstanding used for the computation of per share data:

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NAREIT FFO, FFO Adjusted for Securities Investment, and AFFO Reconciliation
	For the Years Ended December 31,
	2018			2017			2016
Net Income attributable to CorEnergy Stockholders	$	43,711,876		$	32,602,790		$	29,663,200
Less:
Preferred Dividend Requirements	9,548,377			7,953,988			4,148,437
Net Income attributable to Common Stockholders	$	34,163,499		$	24,648,802		$	25,514,763
Add:
Depreciation	24,355,959			23,292,713			21,704,275
Less:
Gain on the sale of leased property, net	11,723,257			—			—
Non-Controlling Interest attributable to NAREIT FFO reconciling items	—			1,632,546			1,645,819
NAREIT funds from operations (NAREIT FFO)	$	46,796,201		$	46,308,969		$	45,573,219
Add:
Distributions received from investment securities	106,795			949,646			1,028,452
Income tax expense (benefit) from investment securities	(682,199		)	1,000,084			760,036
Less:
Net distributions and dividend income	106,795			680,091			1,140,824
Net realized and unrealized gain (loss) on other equity securities	(1,845,309		)	1,531,827			824,482
Funds from operations adjusted for securities investments (FFO)	$	47,959,311		$	46,046,781		$	45,396,401
Add:
Loss of extinguishment of debt	—			336,933			—
Provision for loan (gain) loss, net of tax	(36,867		)	—			4,409,359
Transaction costs	521,311			592,068			520,487
Amortization of debt issuance costs	1,414,457			1,661,181			2,025,478
Amortization of deferred lease costs	91,932			91,932			91,932
Accretion of asset retirement obligation	499,562			663,065			726,664
Non-cash (gain) loss associated with derivative instruments	—			33,763			(75,591		)
Loss on settlement of ARO	310,941			—			—
Less:
Non-cash settlement of accounts payable	—			221,609			—
Income tax (expense) benefit	1,736,527			(1,345,234		)	619,349
Non-Controlling Interest attributable to AFFO reconciling items	—			13,154			37,113
Adjusted funds from operations (AFFO)	$	49,024,120		$	50,536,194		$	52,438,268
Weighted Average Shares of Common Stock Outstanding:
Basic	11,935,021			11,900,516			11,901,985
Diluted	15,389,180			15,355,061			15,368,370
NAREIT FFO attributable to Common Stockholders
Basic	$	3.92		$	3.89		$	3.83
Diluted (1)	$	3.61		$	3.59		$	3.54
FFO attributable to Common Stockholders
Basic	$	4.02		$	3.87		$	3.81
Diluted (1)	$	3.69		$	3.57		$	3.53
AFFO attributable to Common Stockholders
Basic	$	4.11		$	4.25		$	4.41
Diluted (2)	$	3.70		$	3.81		$	3.93
(1) Diluted per share calculations include dilutive adjustments for convertible note interest expense, discount amortization and deferred debt issuance amortization. Refer to the Convertible Note Interest Expense table in Part IV, Item 15, Note 11 ("Debt") for additional details.
(2) Diluted per share calculations include a dilutive adjustment for convertible note interest expense. Refer to the Convertible Note Interest Expense table in Part IV, Item 15, Note 11 ("Debt") for additional details.

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NAREIT FFO, FFO Adjusted for Securities Investment, and AFFO Reconciliation
	For the Fiscal 2018 Quarters Ended
	March 31			June 30		September 30		December 31
Net Income attributable to CorEnergy Stockholders	$	7,707,708		$	7,810,849	$	7,697,324	$	20,495,995
Less:
Preferred Dividend Requirements	2,396,875			2,396,875		2,396,875		2,357,752
Net Income attributable to Common Stockholders	$	5,310,833		$	5,413,974	$	5,300,449	$	18,138,243
Add:
Depreciation	6,138,419			6,139,171		6,138,548		5,939,821
Less:
Gain on the sale of leased property, net	—			—		—		11,723,257
NAREIT funds from operations (NAREIT FFO)	$	11,449,252		$	11,553,145	$	11,438,997	$	12,354,807
Add:
Distributions received from investment securities	3,951			55,714		5,627		41,503
Net realized and unrealized (gain) loss on other equity securities	(13,966		)	881,100		930,147		48,028
Less:
Net distributions and dividend income	3,951			55,714		5,627		41,503
Income tax benefit from investment securities	21,487			220,500		249,420		190,792
Funds from operations adjusted for securities investments (FFO)	$	11,413,799		$	12,213,745	$	12,119,724	$	12,212,043
Add:
Provision for loan (gain) loss, net of tax	500,000			—		—		(536,867		)
Transaction costs	32,281			24,615		66,895		397,520
Amortization of debt issuance costs	353,544			353,637		353,639		353,637
Amortization of deferred lease costs	22,983			22,983		22,983		22,983
Accretion of asset retirement obligation	127,928			127,928		127,928		115,778
Loss on settlement of ARO	—			—		—		310,941
Less:
Income tax benefit	423,339			394,349		497,247		421,592
Adjusted funds from operations (AFFO)	$	12,027,196		$	12,348,559	$	12,193,922	$	12,454,443
Weighted Average Shares of Common Stock Outstanding:
Basic	11,918,904			11,928,297		11,939,360		11,953,098
Diluted	15,373,450			15,382,843		15,393,644		15,406,371
NAREIT FFO attributable to Common Stockholders
Basic	$	0.96		$	0.97	$	0.96	$	1.03
Diluted (1)	$	0.89		$	0.89	$	0.89	$	0.94
FFO attributable to Common Stockholders
Basic	$	0.96		$	1.02	$	1.02	$	1.02
Diluted (1)	$	0.89		$	0.94	$	0.93	$	0.93
AFFO attributable to Common Stockholders
Basic	$	1.01		$	1.04	$	1.02	$	1.04
Diluted (2)	$	0.91		$	0.93	$	0.92	$	0.94
(1) Diluted per share calculations include dilutive adjustments for convertible note interest expense, discount amortization and deferred debt issuance amortization.
(2) Diluted per share calculations include a dilutive adjustment for convertible note interest expense.

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RECENT TRANSACTIONS

We engaged in a number of asset and junior capital transactions between December 2018 and February 2019. On December 21, 2018, we entered into a Purchase and Sale Agreement with Zenith Terminals, our tenant under the Portland Lease Agreement and the operator of the Joliet Terminal, to sell the Portland Terminal Facility and our remaining interest in the Joliet Terminal for an aggregate consideration of $61.0 million. We purchased the Portland Terminal Facility in January 2014 for $41.7 million, and we invested an additional $10.0 million for improvements in the asset. We acquired the equity interest in Joliet in conjunction with the reinvestment requirements from the Arc Logistics merger with Zenith in December 2017. The Joliet equity interest was valued at its transacted value of $1.2 million. For additional information, refer to Part IV, Item 15, Note 3 ("Leased Properties And Leases") and Note 10 ("Fair Value") included in this Report.

The sale resulted in the removal of the net carrying value of the Portland Terminal Facility of approximately $45.7 million from leased property and a reduction to other equity securities, at fair value, of approximately $1.2 million on the Consolidated Balance Sheets. In return, cash increased by an aggregate of $56.0 million, net of transaction costs. The remaining $5.0 million in consideration was in the form of a note receivable, which was paid on January 7, 2019. The Portland Terminal Facility had been generating lease revenue of approximately $6.2 million annually. Depreciation expense is expected to decrease by approximately $1.2 million annually. Given the triple-net lease of the Portland Terminal Facility, we incurred minimal expenses and we do not expect a significant cost savings following the sale, other than a potential reduction in management fee if the assets are not replaced with other Managed Assets. We do not anticipate receiving a material gain, or loss, on equity securities investments from our current portfolio going forward.

On January 16, 2019, we announced that, pursuant to privately negotiated agreements, three holders of our Convertible Notes had exchanged approximately $43.8 million of Convertible Notes for an aggregate amount of 837,040 shares of our common stock and aggregate cash considerations of $19.8 million. Subsequent to the exchange, the face value of the Convertible Notes outstanding was reduced from approximately $114.0 million to approximately $70.2 million, while equity increased $28.9 million as a result of the issuance of common stock. The increase in equity is expected to be reduced by a loss on extinguishment of debt of approximately $5.0 million. We anticipate the exchange transaction will reduce interest expense on the Consolidated Statements of Income by approximately $3.1 million annually. Dividend payments would be expected to increase by approximately $2.5 million annually, at the current dividend rate of $3.00 per share.

Over the course of 2018 and early 2019, we repurchased an aggregate of $4.5 million par value of Series A Preferred Stock. These repurchases are expected to save approximately $332 thousand annually in dividend payments. We have approximately $5.7 million remaining on our Board of Directors' authorization to repurchase preferred stock, through August 5, 2019. If preferred share repurchases were completed up to the authorized $10.0 million limit and at prices consistent with the repurchases to date, the total dividend savings is estimated to be approximately $770 thousand. There can be no assurance that we will continue to repurchase preferred securities.

DIVIDENDS

Our portfolio of real property assets and promissory notes generates cash flow to us from which we pay distributions to stockholders. For the period ended December 31, 2018, the primary sources of our stockholder distributions include lease revenue and transportation and distribution revenue from our real property assets. Deterioration in the cash flows generated by any of these sources may impact our ability to fund distributions to stockholders.

We believe that (i) the accretion from our 2017 acquisition of Prudential's 18.95 percent equity interest in Pinedale LP, (ii) revenue growth from existing contracts through inflation-based escalators and participating rents, as well as (iii) the results of the MoGas FERC rate case proceedings initiated in the second quarter of 2018, will adequately offset the lost revenue from the step-down in rate associated with the new Spire contract effective in November 2018. We also believe that a number of actions can be taken to adequately offset the lost revenue from the sale of the Portland Terminal, which include the combination of (i) additional investments in revenue generating assets and (ii) deleveraging of the Company's balance sheet through preferred equity and convertible debt repurchases, at attractive market prices. However, we regularly assess our ability to pay and to grow our dividend to common stockholders, and there is no assurance that we will continue to make regular dividend payments at current levels.

Distributions to common stockholders are recorded on the ex-dividend date and distributions to preferred stockholders are recorded when declared by the Board of Directors. The characterization of any distribution for federal income tax purposes will not be determined until after the end of the taxable year. Refer to Part IV, Item 15, Note 6 ("Income Taxes") included in this Report for information on characterization of distributions for federal income tax purposes for the years ended December 31, 2018, 2017 and 2016.

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A REIT is generally required to distribute during the taxable year an amount equal to at least 90 percent of the REIT taxable income (determined under Internal Revenue Code section 857(b)(2), without regard to the deduction for dividends paid). We intend to adhere to this requirement in order to maintain our REIT status. The Board of Directors will continue to determine the amount of any distribution that we expect to pay our stockholders. Dividend payouts may be affected by cash flow requirements and remain subject to other risks and uncertainties.

The following table sets forth common stock distributions for the years ended December 31, 2018, 2017 and 2016. Distributions are shown in the period in which they were declared.

Common Dividends
	Amount
2018
Fourth Quarter	$	0.7500
Third Quarter	0.7500
Second Quarter	0.7500
First Quarter	0.7500
2017
Fourth Quarter	$	0.7500
Third Quarter	0.7500
Second Quarter	0.7500
First Quarter	0.7500
2016
Fourth Quarter	$	0.7500
Third Quarter	0.7500
Second Quarter	0.7500
First Quarter	0.7500

The following table sets forth preferred stock distributions for the years ended December 31, 2018, 2017 and 2016:

Preferred Dividends
	Amount
2018
Fourth Quarter	$	0.4609
Third Quarter	0.4609
Second Quarter	0.4609
First Quarter	0.4609
2017
Fourth Quarter	$	0.4609
Third Quarter	0.4609
Second Quarter	0.4609
First Quarter	0.4609
2016
Fourth Quarter	$	0.4609
Third Quarter	0.4609
Second Quarter	0.4609
First Quarter	0.4609

On February 28, 2019, we paid fourth quarter dividends of $0.75 per share of common stock and $0.4609375 per depositary share for our 7.375% Series A Cumulative Redeemable Preferred Stock.

FEDERAL AND STATE INCOME TAXATION

In 2013 we qualified, and in March 2014 elected (effective as of January 1, 2013), to be treated as a REIT for federal income tax purposes (which we refer to as the "REIT Election"). Because certain of our assets may not produce REIT-qualifying income or be

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treated as interests in real property, those assets are held in wholly-owned TRSs in order to limit the potential that such assets and income could prevent us from qualifying as a REIT.

We elected to be taxed as a REIT for 2013 and subsequent years and generally will not pay federal income tax on taxable income of the REIT that is distributed to our stockholders. As a REIT, our distributions from earnings and profits will be treated as ordinary income and a return of capital, and generally will not qualify as qualified dividend income ("QDI"). To the extent that the REIT had accumulated C corporation earnings and profits from the periods prior to 2013, we distributed such earnings and profits in 2013. In addition, to the extent we receive taxable distributions from our TRSs, or the REIT received distributions of C corporation earnings and profits, such portion of our distribution will be treated as QDI. While regular REIT dividends are not eligible for the reduced QDI tax rates, with respect to taxable years beginning after December 31, 2017 and before January 1, 2026, Section 199A of the Code typically permits a 20 percent deduction against taxable income for noncorporate taxpayers for qualified business income, which includes dividends from a REIT received during the tax year that is not a capital gain dividend or a dividend qualifying for the QDI rate, subject to certain income limitations.

As a REIT, we hold and operate certain of our assets through one or more wholly-owned TRSs. Our use of TRSs enables us to continue to engage in certain businesses while complying with REIT qualification requirements and also allows us to retain income generated by these businesses for reinvestment without the requirement of distributing those earnings. As was done with our subsidiary Omega in 2017, and as warranted in the future, we may elect to reorganize and transfer certain assets or operations from our TRSs to our C corporation or other subsidiaries, including qualified REIT subsidiaries.

Our other equity securities are limited partnerships or limited liability companies which are treated as partnerships for federal and state income tax purposes. As a limited partner, we report our allocable share of taxable income in computing our taxable income. To the extent held by a TRS, the TRS's tax expense or benefit is included in the Consolidated Statements of Income based on the component of income or gains and losses to which such expense or benefit relates. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. A valuation allowance is recognized if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized.

If we cease to qualify as a REIT, we, as a C corporation, would be obligated to pay federal and state income tax on our taxable income. For 2018, the federal income tax rate for a corporation was 21 percent.

The Tax Cuts and Jobs Act (the "2017 Tax Act") was enacted on December 22, 2017. The 2017 Tax Act reduced the US federal corporate tax rate from 35 percent to 21 percent. The 2017 Tax Act also repealed the alternative minimum tax for corporations. At December 31, 2018, we have completed our accounting for the tax effects of enactment of the 2017 Tax Act. We have remeasured deferred tax assets and liabilities based on the updated rates at which they are expected to reverse in the future, which resulted in a $1.3 million transition adjustment that reduced net deferred tax assets. We will continue to assess the impact of new tax legislation, as well as any future regulations and updates provided by the tax authorities. Refer to Part IV, Item 15, Note 6 ("Income Taxes") for additional information.

MAJOR TENANTS

As of December 31, 2018, we had two significant leases following the sale of the Portland Terminal Facility and termination of Portland Lease Agreement on December 21, 2018. For additional information concerning these leases, see Part I, Item 2, "Properties" and Part IV, Item 15, Note 3 ("Leased Properties And Leases") included in this Report. The table below displays the impact of significant leases on total leased properties and total lease revenues for the periods presented.

	As a Percentage of (1)
	Leased Properties				Lease Revenues
	As of December 31,				For the Years Ended December 31,
	2018		2017		2018		2017		2016
Pinedale LGS (2)	44.5	%	39.9	%	35.2	%	31.2	%	30.4	%
Grand Isle Gathering System	55.2	%	49.7	%	55.9	%	59.1	%	59.8	%
Portland Terminal Facility (3)	—	%	10.1	%	8.8	%	9.6	%	9.7	%
(1) Insignificant leases are not presented; thus percentages may not sum to 100%.
(2) Pinedale LGS lease revenues include variable rent of $4.3 million and $587 thousand for the years ended December 31, 2018 and 2017, respectively.
(3) On December 21, 2018, the Portland Terminal Facility was sold to Zenith Terminals, terminating the Portland Lease Agreement. Refer to Part IV, Item 15, Note 3 ("Leased Properties and Leases") for additional information.

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ASSET PORTFOLIO AND RELATED DEVELOPMENTS

Descriptions of our asset portfolio and related operations, are included in Part I, Item 2, "Properties" and in Part IV, Item 15, Note 3 ("Leased Properties And Leases") and Note 5 ("Financing Notes Receivable") included in this Report. This section provides additional information concerning material developments related to our asset portfolio during the year ended December 31, 2018 and through the date of this Report.

Grand Isle Gathering System

On October 18, 2018, EGC completed its previously announced acquisition by the privately-held Gulf of Mexico operator, Cox Oil, for approximately $322.0 million. With the purchase of EGC by Cox Oil, it is anticipated that EGC will remain a separate subsidiary owned by an affiliate of Cox Oil and that EGC (not Cox Oil) will continue to be the guarantor of the tenant's obligation under the Lease Agreement. As a material contract for EGC, we expect all terms and conditions under the lease will continue to be met, including asset maintenance and reporting requirements.

Pinedale LGS

UPL continues to make strides to strengthen its balance sheet. On December 26, 2018, UPL closed on a debt exchange agreement to reduce its long-term debt by approximately $235.0 million. Following incremental agreements, UPL exchanged a total of approximately $549.6 million aggregate principal amount of its 6.875% Senior Notes, due 2022 and $275.0 million aggregate principal amount of its 7.125% Senior Notes due 2025 for approximately $572.0 million of new 9.00% Cash and 2.00% paid-in-kind Senior Secured Second Lien Notes due July 2024 and approximately 10.9 million new warrants, entitling each holder thereof to purchase one common share of UPL. On January 17, 2019, UPL announced that the U.S. Court of Appeals for the Fifth Circuit reversed a bankruptcy court decision on make-whole claims which had required UPL to pay approximately $400.0 million to various creditors following its emergence from Chapter 11 bankruptcy.

UPL announced that it secured an amendment on its credit facility that increases the allowed leverage metric and provides certain adjustments to the calculation of EBITDAX in its leverage calculation. With the amendment, UPL also accelerated the semi-annual redetermination of its borrowing base, which was reaffirmed at $1.3 billion for the spring of 2019.

UPL stated that in the third quarter of 2018, vertical well costs trended downward and that they are focusing drilling and operations on these wells. Results from UPL's horizontal wells were mixed and its team is analyzing the technical data in order to unlock future material incremental value from the Pinedale field. UPL maintained a three-rig program in the fourth quarter of 2018, drilling 23 vertical wells and announced production within its guidance range. Production for 2018 totaled 275.1 Bcfe and UPL brought online 94 vertical wells and 16 horizontal wells. At the end of 2018, UPL's total proved reserves were 3,062.5 Bcfe, which they valued at $2.4 billion, before tax PV-10 percent.

On January 29, 2019, UPL received notification from the NASDAQ Stock Market LLC ("NASDAQ") that its common shares were not fulfilling the $1.00 per share minimum bid price requirement. The notice has no immediate effect on the stock, which will continue to trade on the NASDAQ under the symbol "UPL". The company has 180 days from that date to comply with the minimum bid price requirement and UPL has stated that it will continue to monitor its share price and will consider all available options to regain compliance.

UPL has named David Honeyfield as Chief Financial Officer and Andrew Kidd as General Counsel. UPL also moved its headquarters to Englewood, Colorado, from Houston Texas.

MoGas Pipeline

Effective March 1, 2017, MoGas entered into a long-term firm transportation services agreement with Spire, its largest customer. The agreement, which amends a prior agreement, extends the termination date for Spire's existing firm transportation agreement from October 31, 2017 to October 31, 2030. During the entire extended term, Spire will continue to reserve 62,800 dekatherms per day of firm transportation capacity on MoGas. This service continued at the full tariff rate of $12.385 per dekatherm per month until October 31, 2018, at which time the rate was reduced to $6.386 per dekatherm per month for the remainder of the agreement.

On May 31, 2018, MoGas filed a general rate case before FERC. The proposed change in rates seeks to (i) recover increases in capital, operating and maintenance expenditures incurred; (ii) mitigate for the substantial decrease in volumes due to the loss of a firm transportation contract with a St. Louis natural gas marketing entity; (iii) mitigate for the substantial decrease in revenue from Spire; and (iv) reflect changes in the corporate income tax rate associated with the 2017 Tax Cuts and Jobs Act. MoGas' proposed revenue requirement is approximately $20.0 million annually, and the proposed rates went into effect on December 1, 2018, subject to refund upon final ruling.

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CONTRACTUAL OBLIGATIONS

The following table summarizes our significant contractual payment obligations as of December 31, 2018:

Contractual Obligations
	Notional Value		Less than 1 year		1-3 years		3-5 years		More than 5 years
Pinedale LP Debt	$	37,472,000	$	3,528,000	$	7,056,000	$	26,888,000	$	—
Interest payments on Pinedale LP Debt			2,324,499		3,979,053		1,735,353		—
Convertible Debt(1)	113,958,000		—		113,958,000		—		—
Interest payments on Convertible Debt(1)			7,977,060		3,988,530		—		—
Totals			$	13,829,559	$	128,981,583	$	28,623,353	$	—
(1) Subsequent to December 31, 2018, the Company agreed to exchange $43.8 million face amount of Convertible Notes for cash and common stock, reducing (i) convertible debt outstanding to $70.2 million and (ii) projected convertible note interest expense to approximately $5.2 million and $2.5 million for the years ended December 31, 2019 and 2020, respectively.

Fees paid to Corridor under the Management Agreement and the Administrative Agreement are not included because they vary as a function of the value of our total asset base. For additional information see Part IV, Item 15, Note 9 ("Management Agreement") included in this Report.

SEASONALITY

Our operating companies, MoGas and Omega, have stable revenues throughout the year and will complete necessary pipeline maintenance during the "non-heating" season, or quarters two and three. Therefore, operating results for the interim periods are not necessarily indicative of the results that may be expected for the full year.

OFF-BALANCE SHEET ARRANGEMENTS

We do not have, and are not expected to have, any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

IMPACT OF INFLATION AND DEFLATION

Deflation can result in a decline in general price levels, often caused by a decrease in the supply of money or credit. The predominant effects of deflation are high unemployment, credit contraction, and weakened consumer demand. Restricted lending practices could impact our ability to obtain financings or to refinance our properties and our tenants' ability to obtain credit. During inflationary periods, we intend for substantially all of our tenant leases to be designed to mitigate the impact of inflation. Often, our leases include rent escalators that are based on the CPI, or other agreed upon metrics that increase with inflation.

LIQUIDITY AND CAPITAL RESOURCES

Overview

At December 31, 2018, we had liquidity of approximately $192.0 million comprised of cash of $69.3 million plus revolver availability of $122.7 million. During 2018, our liquidity was enhanced through the sale of the Portland Terminal Facility and equity interest in Joliet to Zenith Terminals, which generated proceeds of approximately $61.0 million. Of the proceeds, approximately $56.0 million was received in cash while the remaining $5.0 million was in the form of a promissory note, which was paid on January 7, 2019.

We use cash flows generated from our operations to fund current obligations, projected working capital requirements, debt service payments and dividend payments. Management expects that future operating cash flows, along with access to financial markets, will be sufficient to fund future operating requirements and acquisition opportunities. If our ability to access the capital markets is restricted or if debt or equity capital were unavailable on favorable terms, or at all, our ability to fund acquisition opportunities or to comply with the REIT distribution rules could be adversely affected.

There are acquisition opportunities that are in preliminary stages of review, and consummation of any of these opportunities may depend on a number of factors beyond our control. There can be no assurance that any of these acquisition opportunities will result in consummated transactions. As part of our disciplined investment philosophy, we plan to use a moderate level of leverage, approximately 25 percent to 50 percent of assets, supplemented with accretive equity issuance as needed, subject to current market conditions. We may invest in assets subject to greater leverage which could be both recourse and non-recourse to us.

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Cash Flows - Operating, Investing, and Financing Activities

The following table presents our consolidated cash flows for the periods indicated below:

	For the Years Ended December 31,
	2018			2017			2016
Net cash provided by (used in):
Operating activities	$	48,622,740		$	56,791,571		$	51,108,652
Investing activities	56,816,490			7,595,477			479,090
Financing activities	(51,939,122		)	(56,495,063		)	(58,311,398		)
Net increase (decrease) in cash and cash equivalents	$	53,500,108		$	7,891,985		$	(6,723,656	)

Cash Flows from Operating Activities

Net cash flows provided by operating activities for the year ended December 31, 2018 were primarily generated by (i) lease receipts of $62.3 million ($72.7 million lease revenue, net of $7.0 million of straight-line rent accrued during the period and $3.4 million of unearned revenue received in 2017), (ii) $12.5 million in net contributions from our operating subsidiaries MoGas and Omega, partially offset by (iii) $13.0 million in general and administrative expenses, (iv) $11.2 million in cash paid for interest and (v) a $1.3 million increase in accounts and other receivables during the period.

Net cash flows provided by operating activities for the year ended December 31, 2017 were primarily generated by (i) lease receipts of $61.6 million ($68.8 million lease revenue, net of $7.2 million of straight-line rent accrued during the period), (ii) $13.2 million in net contributions from our operating subsidiaries MoGas and Omega, (iii) an additional $2.9 million in unearned lease receipts associated with January 2018 revenues received in 2017 and (iv) $853 thousand in distributions and dividends received, partially offset by (v) $10.8 million in general and administrative expenses and (vi) $10.8 million in cash paid for interest.

Net cash flows provided by operating activities for the year ended December 31, 2016 were primarily generated by (i) lease receipts of $59.6 million ($68.0 million lease revenue, net of $8.4 million of straight-line rent accrued during the period), (ii) $14.6 million in net contributions from our operating subsidiaries MoGas and Omega, (iii) $1.4 million in escrow proceeds associated with the sale of VantaCore and (iv) $1.0 million in distributions and dividends received, partially offset by (v) $12.9 million in cash paid for interest and (vi) $12.3 million in general and administrative expenses.

Cash Flows from Investing Activities

Net cash flows provided by investing activities for the year ended December 31, 2018 were primarily attributed to (i) the proceeds from the sale of the Portland Terminal Facility and equity interest in Joliet to Zenith Terminals, which generated proceeds of approximately $56.0 million, (ii) return of capital distributions on our Lightfoot investment of $664 thousand and (iii) principal payments associated with the Four Wood financing note receivable of $237 thousand.

Net cash flows provided by investing activities for the year ended December 31, 2017 were primarily attributed to $7.6 million in proceeds received from the sale of the majority of our equity securities. Refer to Part IV, Item 15, Note 10 ("Fair Value") for additional details.

Net cash flows provided by investing activities for the year ended December 31, 2016 were primarily attributable to (i) net proceeds from the sale of assets and liabilities held for sale of $645 thousand and (ii) proceeds received on foreclosure of BB Intermediate of $223 thousand, partially offset by (iii) funding to close operations of Black Bison and Four Wood financing notes of $202 thousand and (iv) purchases of property and equipment of $192 thousand.

Cash Flows from Financing Activities

Net cash flows used in financing activities for the year ended December 31, 2018 were primarily attributable to (i) common and preferred dividends paid of $34.3 million and $9.6 million, respectively, (ii) cash used to repurchase Series A Preferred Stock of $4.3 million, (iii) principal payments of $3.5 million on our secured credit facilities and (iv) $264 thousand of payments related to debt financing costs.

Net cash flows used in financing activities for the year ended December 31, 2017 were primarily attributable to (i) net payments on the CorEnergy Revolver of $44.0 million, (ii) principal payments of $45.6 million on our secured credit facilities, (iii) common and preferred dividends paid of $34.7 million and $8.2 million, respectively, (iv) purchase of the non-controlling interest in Pinedale LP for $32.8 million, (v) payment of $1.5 million for debt issuance costs related to the CorEnergy Credit Facility and Amended Pinedale Term Credit Facility refinancings and (vi) distributions of $1.8 million to our non-controlling interest, partially offset by (vii) net

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offering proceeds on Series A Preferred Stock of $71.2 million and (viii) $41.0 million in proceeds from the Amended Pinedale Term Credit Facility.

Net cash flows used in financing activities for the year ended December 31, 2016 were primarily attributable to (i) principal payments of $60.1 million on our secured credit facilities, (ii) common and preferred dividends paid of $34.9 million and $4.1 million, respectively, (iii) repurchases of common stock of approximately $2.0 million and (iv) repurchases of convertible debt of approximately $900 thousand, partially offset by (v) $44.0 million drawn on the CorEnergy Revolver.

Revolving and Term Credit Facilities

CorEnergy Credit Facility

On July 8, 2015, we amended and upsized our then current $93.0 million credit facility with Regions Bank (as lender and administrative agent for the other participating lenders) to provide borrowing commitments of $153.0 million, consisting of (i) an increase in the CorEnergy Revolver to $105.0 million, (ii) the existing $3.0 million MoGas Revolver at the subsidiary entity level (as detailed below) and (iii) a $45.0 million term loan at the CorEnergy parent entity level (the "CorEnergy Term Loan" and, collectively with the upsized CorEnergy Revolver and the MoGas Revolver, the "CorEnergy Credit Facility"). Upon closing the CorEnergy Credit Facility, we drew $45.0 million on the CorEnergy Term Loan at the parent level to pay down the balance on the CorEnergy Revolver that had been used in funding the GIGS acquisition in June 2015.

Effective as of March 4, 2016, we, and the required lenders under the CorEnergy Revolver, executed a Limited Consent and Amendment (the "Consent"). Pursuant to such Consent, among other things, the lenders consented to our use of up to $49.0 million, up to $44.0 million of which could come from the proceeds of draws under the CorEnergy Revolver, in connection with the refinancing of Pinedale LP's outstanding indebtedness due under the $70.0 million secured term credit facility on March 30, 2016, as discussed below. We paid fees to the lenders in connection with the Consent in an aggregate amount of $193 thousand. We subsequently drew $44.0 million on the CorEnergy Revolver in conjunction with the refinancing of the Pinedale Credit Facility.

On July 28, 2017, we entered into an amended and restated CorEnergy Credit Facility with Regions Bank (as lender and administrative agent for other participating lenders). The amended facility provides for commitments of up to $161.0 million, comprised of (i) increased commitments on the CorEnergy Revolver of up to $160.0 million, subject to borrowing base limitations, and (ii) a $1.0 million commitment on the MoGas Revolver. The amended facility has a 5-year term maturing on July 28, 2022, and provides for a springing maturity on February 28, 2020, and thereafter, if we fail to meet certain liquidity requirements from the springing maturity date through the maturity of our convertible notes on June 15, 2020.

Under the terms of the amended and restated CorEnergy Credit Facility, we are subject to certain financial covenants as follows: (i) a minimum debt service coverage ratio of 2.0 to 1.0; (ii) a maximum total leverage ratio of 5.0 to 1.0; (iii) a maximum senior secured recourse leverage ratio (which generally excludes debt from certain subsidiaries that are not obligors under the CorEnergy Credit Facility) of 3.0 to 1.0.; and (iv) a maximum total funded debt to capitalization ratio of 50 percent. In addition, there is a covenant related to our ability to make distributions that is tied to AFFO and applicable REIT distribution requirements, and provides that, in the absence of any acceleration of maturity following an Event of Default, we may make distributions equal to the greater of the amount required to maintain our REIT status and 100 percent of AFFO for the trailing 12-month period.

Borrowings under the credit facility will typically bear interest on the outstanding principal amount using a LIBOR pricing grid that is expected to equal a LIBOR rate plus an applicable margin of 2.75 percent to 3.75 percent, based on our senior secured recourse leverage ratio. The facility contains, among other restrictions, certain default and cross-default provisions customary for transactions of this nature (with applicable customary grace periods), all of which are substantially the same as under the prior facility.

We were in compliance with all covenants at December 31, 2018 and had approximately $122.7 million of available borrowing capacity on the CorEnergy Revolver. For a summary of the additional material terms of the CorEnergy Credit Facility, please see Part IV, Item 15, Note 11 ("Debt") included in this Report.

Amended Pinedale Term Credit Facility

In December 2012, Pinedale LP entered into a $70.0 million secured term credit facility with a lender that provided for monthly payments of principal and interest. Under the original agreement, outstanding balances under the credit facility typically accrued interest at a variable annual rate equal to LIBOR plus 3.25 percent and were secured by the Pinedale LGS. Pinedale LP was obligated each month to pay all accrued interest as well as principal payments of $294 thousand. The facility was set to expire at the end of December 2015, however, we extended the facility through March 30, 2016. Under the December 31, 2015 extension amendment, outstanding balances accrued interest at a variable annual rate equal to LIBOR plus 4.25 percent. Pinedale LP made principal payments totaling approximately $3.2 million during the extension period through March 30, 2016.

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In connection with the original credit facility, in December 2012, we executed two interest rate swap derivatives covering $52.5 million of notional value of the Pinedale Credit Facility to add stability to our interest expense and to manage our exposure to interest rate movements on LIBOR-based borrowings. Through March 30, 2016, the interest rate swap derivatives remained in place at a fixed rate of 0.865 percent less a floating, 1-month LIBOR rate. As part of the March 30, 2016 refinancing discussed below, we terminated one of the derivative contracts, representing half of the amount hedged. The remaining derivative with a notional amount of $26.3 million was de-designated from hedge accounting and marked to market through its expiration in December 2017.

On March 30, 2016, we and Prudential (collectively, "the Refinancing Lenders"), refinanced the remaining $58.5 million principal balance of the $70.0 million credit facility (on a pro rata basis equal to the respective equity interests in Pinedale LP, with our 81.05 percent share being approximately $47.4 million) and executed a series of agreements assigning the credit facility to the Refinancing Lenders, with CorEnergy Infrastructure Trust, Inc. as Agent for the Refinancing Lenders. The facility was further modified to extend the maturity date to March 30, 2021; to increase the LIBOR Rate to the greater of (i) 1.00 percent and (ii) the one-month LIBOR rate; and to increase the LIBOR Rate Spread to seven percent (7.00 percent) per annum. Our portion of the debt and interest was eliminated in consolidation and Prudential's portion of the debt was shown as a related-party liability.

On December 29, 2017, Pinedale LP entered into the Amended Pinedale Term Credit Facility, with Prudential and a group of lenders affiliated with Prudential as lenders and Prudential serving as administrative agent. The new amended facility is a 5-year $41.0 million term loan facility, bearing interest at a fixed rate of 6.5 percent, which matures on December 29, 2022. Principal payments of $294 thousand, plus accrued interest, are payable monthly. Proceeds from the Amended Pinedale Term Credit Facility were utilized by Pinedale LP to pay off the balance due to the Refinancing Lenders under the previously existing Pinedale LP credit facility. We utilized our portion of the proceeds from the repayment of the prior facility to finance the purchase of Prudential's 18.95 percent outstanding equity interest in Pinedale LP.

The Amended Pinedale Term Credit Facility limits distributions by Pinedale LP to us, although such distributions are permitted to the extent required for us to maintain REIT qualification so long as Pinedale LP's obligations under the credit facility have not been accelerated following an Event of Default (as defined in the Amended Term Credit Facility).

Outstanding balances under the facility are secured by the Pinedale LGS assets. The Amended Term Credit Facility is subject to (i) a minimum interest coverage ratio of 3.0 to 1.0, (ii) a maximum leverage ratio of 3.25 to 1.0 and (iii) a minimum net worth of $115.0 million, each measured at the Pinedale LP level and not at the Company level. We were in compliance with all covenants at December 31, 2018. For a summary of the additional material terms of the Pinedale Credit Facility, please see Part IV, Item 15, Note 11 ("Debt") included in this Report for additional information.

Convertible Notes

On June 29, 2015, we completed a public offering of $115.0 million aggregate principal amount of 7.00% Convertible Senior Notes Due 2020. The Convertible Notes mature on June 15, 2020 and bear interest at a rate of 7.0 percent per annum, payable semi-annually in arrears on June 15 and December 15 of each year, beginning on December 15, 2015.

At the present time, we may not redeem the Convertible Notes prior to the maturity date without the consent of the agent and lenders of the CorEnergy Credit Facility. Holders may convert their Convertible Notes into shares of our common stock at their option until the close of business on the second scheduled trading day immediately preceding the maturity date. The current conversion rate for the Convertible Notes is 30.3030 shares of Common Stock per $1,000 principal amount of the Convertible Notes, equivalent to an initial conversion price of $33.00 per share of Common Stock. Such conversion rate will be subject to adjustment in certain events as specified in the Indenture.

As authorized by the Board of Directors, during May 2016, we repurchased $1.0 million of face value of the Convertible Notes. During the year ended December 31, 2018, certain holders elected to convert approximately $42 thousand of Convertible Notes for 1,271 shares of CorEnergy common stock. As of December 31, 2018, we had approximately $114.0 million of face value of the Convertible Notes outstanding. Refer to Part IV, Item 15, Note 17 ("Subsequent Events") included in this Report for information regarding the exchange of Convertible Notes for cash and common stock, with the requisite consent of the agent and lenders under the CorEnergy Credit Facility, subsequent to December 31, 2018.

Refer to Part IV, Item 15, Note 11 ("Debt") included in this Report for additional information concerning the Convertible Notes.

MoGas Revolver

In conjunction with the MoGas Transaction, MoGas Pipeline LLC and United Property Systems, LLC, as co-borrowers, entered into a revolving credit agreement dated November 24, 2014 (the "MoGas Revolver"), with certain lenders, including Regions Bank as agent for such lenders. Following subsequent amendments and restatements made on July 8, 2015 and July 28, 2017 in connection with the amendments and restatements of the CorEnergy Credit Facility, discussed above, commitments under the MoGas Revolver

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were reduced from the original level of $3.0 million to a current total of $1.0 million. Interest accrues under the MoGas Revolver at the same rate and pursuant to the same terms as it accrues under the CorEnergy Revolver. Refer to Part IV, Item 15, Note 11 ("Debt") for further information. As of December 31, 2018, the co-borrowers were in compliance with all covenants and there were no borrowings outstanding on the MoGas Revolver.

Mowood/Omega Revolver

On July 31, 2015, a $1.5 million revolving line of credit ("Mowood/Omega Revolver") was established with Regions Bank with a maturity date of July 31, 2016. Following annual extensions, the current maturity of the facility has been amended and extended to July 31, 2019. The Mowood/Omega Revolver is used by Omega for working capital and general business purposes and is guaranteed and secured by the assets of Omega. Interest accrues at LIBOR plus 4 percent and is payable monthly in arrears with no unused fee. There was no outstanding balance at December 31, 2018.

Shelf Registration Statements

On October 30, 2018, we registered 1,000,000 shares of common stock for issuance under our dividend reinvestment plan pursuant to a separate shelf registration statement filed with the SEC. As of December 31, 2018, we have issued 10,927 shares of common stock under our dividend reinvestment plan pursuant to the shelf resulting in remaining availability of approximately 989,073 shares of common stock.

On November 9, 2018, we had a new shelf registration statement declared effective by the SEC replacing our previously filed shelf registration statement, pursuant to which we may publicly offer additional debt or equity securities with an aggregate offering price of up to $600.0 million. As of December 31, 2018, we have not issued any securities under this new shelf registration statement, so total availability remains at $600.0 million.

Liquidity and Capitalization

Our principal investing activities are acquiring and financing midstream and downstream real estate assets within the U.S. energy infrastructure sector and concurrently entering into long-term triple-net participating leases with energy companies. These investing activities have often been financed from the proceeds of our public equity and debt offerings as well as the term and credit facilities mentioned above. Continued growth of our asset portfolio will depend in part on our continued ability to access funds through additional borrowings and securities offerings.

The following table presents our liquidity and capitalization as of December 31, 2018 and 2017. In addition, as a result of certain transactions that have occurred subsequent to December 31, 2018, including (i) the receipt of the $5.0 million payment on the Portland Terminal sale promissory note on January 7, 2019, (ii) the convertible debt exchange transaction on January 16, 2019, which is discussed within "Recent Transactions" above and (iii) additional preferred stock repurchases in January 2019, the "As Adjusted" column in the table presents our liquidity and capitalization after giving effect to these transactions:

Liquidity and Capitalization
	As Adjusted		December 31, 2018		December 31, 2017
Cash and cash equivalents	$	54,395,406	$	69,287,177	$	15,787,069
Revolver availability	$	122,721,258	$	122,721,258	$	140,499,846
Revolving credit facility	—		—		—
Long-term debt (including current maturities) (1)	106,738,286		150,038,380		152,777,437
Stockholders' equity:
Series A Cumulative Redeemable Preferred Stock 7.375%, $0.001 par value	125,493,175		125,555,675		130,000,000
Capital stock, non-convertible, $0.001 par value	12,797		11,960		11,916
Additional paid-in capital	349,164,642		320,295,969		331,773,716
Retained earnings	4,107,970		9,147,701		—
CorEnergy equity	478,778,584		455,011,305		461,785,632
Total CorEnergy capitalization	$	585,516,870	$	605,049,685	$	614,563,069
(1) Long-term debt is presented net of discount and deferred debt costs.

We also have two lines of credit for working capital purposes for two of our subsidiaries with maximum availability of $1.5 million and $1.0 million at December 31, 2018 and 2017, respectively.

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SUBSEQUENT EVENTS

For additional information regarding transactions that occurred subsequent to December 31, 2018, see Part IV, Item 15, Note 17 ("Subsequent Events") included in this annual Report on Form 10-K.

CRITICAL ACCOUNTING ESTIMATES

The financial statements included in this Report are based on the selection and application of critical accounting policies, which require management to make significant estimates and assumptions. Critical accounting policies are those that are both important to the presentation of our financial condition and results of operations and require management's most difficult, complex, or subjective judgments. The preparation of the consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, recognition of revenues and expenses, and disclosure of contingent assets and liabilities at the date of the consolidated financial statements. Actual results could differ from those estimates.

See Part IV, Item 15, Note 2 ("Significant Accounting Policies") included in this Report for further information related to our significant accounting policies.

Long-Lived Assets

Our long-lived assets consist primarily of a subsea midstream pipeline system, liquids gathering system and natural gas pipelines that have been obtained through a business combination and asset acquisitions. Depreciation is computed using the straight-line method over the estimated useful life of the asset. Expenditures for repairs and maintenance are charged to operations as incurred, and improvements, which extend the useful lives of our assets, are capitalized and depreciated over the remaining estimated useful life of the asset.

We continually monitor our business, the business environment, and performance of our operations to determine if an event has occurred that indicates that the carrying value of a long-lived asset may be impaired. When a triggering event occurs, which is a determination that involves judgment, we utilize cash flow projections to assess the ability to recover the carrying value of our assets based on our long-lived assets' ability to generate future cash flows on an undiscounted basis. This differs from the evaluation of goodwill, for which the recoverability assessment utilizes fair value estimates that include discounted cash flows in the estimation process, and accordingly any goodwill impairment recognized may not be indicative of a similar impairment of the related underlying long-lived assets.

The projected cash flows of long-lived assets are primarily based on contractual cash flows relating to existing leases that extend many years into the future. If those cash flow projections indicate that the long-lived asset's carrying value is not recoverable, we record an impairment charge for the excess of carrying value of the asset over its fair value. The estimate of fair value considers a number of factors, including the potential value that would be received if the asset were sold, discount rates, and projected cash flows. Due to the imprecise nature of these projections and assumptions, actual results can differ from our estimates. There were no impairments of long-lived assets recorded during the years ended December 31, 2018, 2017 or 2016.

Asset Retirement Obligations

We follow ASC 410-20, Asset Retirement Obligations, which requires that an asset retirement obligation ("ARO") associated with the retirement of a long-lived asset be recognized as a liability in the period in which it is incurred and becomes determinable, with an offsetting increase in the carrying amount of the associated asset. We recognized an existing ARO in conjunction with the acquisition of the GIGS in June 2015.

We measure changes in the ARO liability due to passage of time by applying an interest method of allocation to the amount of the liability at the beginning of the period. The increase in the carrying amount of the liability is recognized as an expense classified as an operating item in the Consolidated Statements of Income, hereinafter referred to as ARO accretion expense. We periodically reassess the timing and amount of cash flows anticipated associated with the ARO and adjusts the fair value of the liability accordingly under the guidance in ASC 410-20.

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The fair value of the obligation at the acquisition date was capitalized as part of the carrying amount of the related long-lived assets and is being depreciated over the asset's remaining useful life. The useful lives of most pipeline gathering systems are primarily derived from available supply resources and ultimate consumption of those resources by end users. Adjustments to the ARO resulting from reassessments of the timing and amount of cash flows will result in changes to the retirement costs capitalized as part of the carrying amount of the asset.

Upon decommissioning of the ARO or a portion thereof, we reduce the fair value of the liability and recognize a (gain) loss on settlement of ARO as an operating item in the Consolidated Statements of Income for the difference between the liability and actual decommissioning costs incurred.

Federal and State Income Taxation

We qualify as a REIT under Sections 856 to 860 of the Internal Revenue Code of 1986, and intend to continue to remain so qualified. For further information, see "Federal and State Income Taxation" above in this Item 7 and "Federal and State Income Taxation" under Item 5 "Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities" of this Report.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our business activities contain elements of market risk. Historically, we have considered fluctuations in the value of our securities portfolio to be our principal market risk. With respect to our equity securities as of December 31, 2018, there has been a substantial decline in our market risk exposure as compared to prior periods, as certain private equity investments were sold or disposed of by the end of 2018. Refer to Part IV, Item 15, Note 10 ("Fair Value") for additional details.

Historically, our securities portfolio was reported at fair value. The fair value of securities was determined using readily available market quotations from the principal market, if available. Because there were no readily available market quotations for any of the securities in our portfolio, we valued our securities at fair value as determined in good faith under a valuation policy and a consistently applied valuation process, which has been approved by our Board of Directors. Due to the inherent uncertainty of determining the fair value of securities that do not have readily available market quotations, the fair value of our securities in prior periods may differ significantly from the fair values that would have been used had a ready market quotation existed for such securities, and these differences could be material.

Long-term debt used to finance our acquisitions may be based on floating or fixed rates. As of December 31, 2018, we had long-term debt (net of current maturities) with a carrying value of $146.5 million, all of which represents fixed-rate debt. Borrowings under our CorEnergy Revolver are variable-rate, based on a LIBOR pricing spread. There were no outstanding borrowings under the CorEnergy Revolver at December 31, 2018, and accordingly, no market risk exposure on outstanding variable rate debt.

We consider the management of risk essential to conducting our businesses. Accordingly, our risk management systems and procedures are designed to identify and analyze our risks, to set appropriate policies and limits and to continually monitor these risks and limits by means of reliable administrative and information systems and other policies and programs.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Our financial statements and financial statement schedules are set forth beginning on page F-1 in this Annual 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

Our management is responsible for the preparation, consistency, integrity, and fair presentation of the financial statements. The financial statements have been prepared in accordance with U.S. generally accepted accounting principles applied on a consistent basis and, in management's opinion, are fairly presented. The financial statements include amounts that are based on management's informed judgments and best estimates.

Conclusion Regarding Effectiveness of Disclosure Controls and Procedures

Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Accounting Officer (our principal executive and principal financial officers, respectively), we have evaluated the effectiveness of our disclosure controls and procedures, as defined in Rule 13a-15(e) under the Exchange Act, as of the end of the period covered by this Report. Based on that evaluation, these officers concluded that our disclosure controls and procedures were effective to ensure that the

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information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms, and is accumulated and communicated to our management, including our Chief Executive Officer and Chief Accounting Officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

There have been no changes in our internal control over financial reporting, as defined in rule 13a-15(f) and 15d-15(f) of the Exchange Act, that occurred during the quarterly period ending December 31, 2018, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Management's Report on Internal Control over Financial Reporting

Our management, under the supervision and with the participation of our Chief Executive Officer and Chief Accounting Officer (our principal executive and principal financial officers, respectively), is responsible for establishing and maintaining adequate internal control over our financial reporting. Our management has established and maintains comprehensive systems of internal control designed to provide reasonable assurance as to the consistency, integrity, and reliability of the preparation and presentation of financial statements and the safeguarding of assets. The concept of reasonable assurance is based upon the recognition that the cost of the controls should not exceed the benefit derived. Our management monitors the systems of internal control and maintains an internal auditing program that assesses the effectiveness of internal control.

Our management assessed our systems of internal control over financial reporting for financial presentations in conformity with U.S. generally accepted accounting principles as of December 31, 2018. This assessment was based on criteria for effective internal control established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (the COSO Report). Based on this assessment, our management has determined that our internal control over financial reporting was effective as of December 31, 2018.

The Board of Directors exercises its oversight role with respect to the systems of internal control primarily through its Audit Committee, which is comprised solely of independent outside directors. The Committee oversees systems of internal control and financial reporting to assess whether their quality, integrity, and objectivity are sufficient to protect stockholders' investments.

Ernst & Young has issued an audit report on our internal control over financial reporting. This report begins on the next page.

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Report of Independent Registered Public Accounting Firm

To the Stockholders and the Board of Directors of CorEnergy Infrastructure Trust, Inc.

Opinion on Internal Control over Financial Reporting

We have audited CorEnergy Infrastructure Trust, Inc. internal control over financial reporting as of December 31, 2018, 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, CorEnergy Infrastructure Trust, Inc. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2018, 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 CorEnergy Infrastructure Trust, Inc. as of December 31, 2018 and 2017, the related consolidated statements of income and comprehensive income, equity and cash flow for each of the three years in the period ended December 31, 2018, and the related notes and financial statement schedules listed in the Index at Item 15 and our report dated February 28, 2019 expressed an unqualified opinion thereon.

Basis for Opinion

The Company'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 Company'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 Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.

Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control Over Financial Reporting

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ Ernst & Young LLP

Kansas City, Missouri

February 28, 2019

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ITEM 9B. OTHER INFORMATION

None.

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

Codes of Ethics

We have adopted a code of ethics, which applies to our principal executive officer and principal financial officer. We have also adopted a code of ethics that establishes procedures for personal investments and restricts certain personal securities transactions. Personnel subject to the code of ethics may invest in securities for their personal investment accounts, including securities that may be purchased or held by us, so long as such investments are made in accordance with the code of ethics. This information may be obtained, without charge, upon request by calling us at (816) 875-3705 or toll-free at (877) 699-2677 and on our web site at http://corenergy.reit. The codes of ethics are available on the EDGAR Database on the Securities and Exchange Commission's Internet site at http://www.sec.gov.

Sarbanes-Oxley Act of 2002

The Sarbanes-Oxley Act of 2002 (the "Sarbanes-Oxley Act") imposes a wide variety of regulatory requirements on publicly-held companies and their insiders. The Sarbanes-Oxley Act requires us to review our policies and procedures to determine whether we comply with the Sarbanes-Oxley Act and the regulations promulgated thereunder. We will continue to monitor our compliance with all future regulations that are adopted under the Sarbanes-Oxley Act and will take actions necessary to ensure that we are in compliance therewith.

As of December 31, 2018, we are an accelerated filer. As an accelerated filer for the fiscal year ended December 31, 2018, we are required to prepare and include in our annual report to stockholders for such period a report regarding management's assessment of our internal control over financial reporting under the Exchange Act and have included this report in Item 9A of this Annual Report on Form 10-K.

Additional information is incorporated herein by reference to the sections captioned "Nominees for Directors," "Incumbent Directors Continuing in Office," "Information About Executive Officers," "Board of Directors Meetings and Committees," "Section 16(a) Beneficial Ownership Reporting Compliance" and "Stockholder Proposals and Nominations for the 2020 Annual Meeting" in our proxy statement for our 2019 Annual Stockholder Meeting, which will be filed with the Securities and Exchange Commission within 120 days after the end of the fiscal year covered by this Annual Report.

ITEM 11. EXECUTIVE COMPENSATION

Incorporated by reference to the sections captioned "Director Compensation Table" and "Compensation Committee Interlocks and Insider Participation" in our proxy statement for our 2019 Annual Stockholder Meeting to be filed with the Securities and Exchange Commission within 120 days after the end of the fiscal year covered by this Annual Report.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

Incorporated by reference to the sections captioned "Security Ownership of Management and Certain Beneficial Owners" and "Director Compensation" in our proxy statement for our 2019 Annual Stockholder Meeting to be filed with the Securities and Exchange Commission within 120 days after the end of the fiscal year covered by this Annual Report.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

Incorporated by reference to the sections captioned "Nominees for Director," "Incumbent Directors Continuing in Office," "Board of Directors Meetings and Committees" and "Certain Relationships and Related Party Transactions" in our proxy statement for our 2019 Annual Stockholder Meeting to be filed with the Securities and Exchange Commission within 120 days after the end of the fiscal year covered by this Annual Report.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES

Incorporated by reference to the section captioned "Independent Registered Public Accounting Firm Fees and Services" in our proxy statement for our 2019 Annual Stockholder Meeting to be filed with the Securities and Exchange Commission within 120 days after the end of the fiscal year covered by this Annual Report.

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PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

The following documents are filed as part of this Annual Report on Form 10-K:

1. The Financial Statements listed in the Index to Financial Statements on Page F-1.

2. The Exhibits listed in the Exhibit Index below.

Exhibit No.	Description of Document
3.1	Articles of Amendment and Restatement of CorEnergy Infrastructure Trust, Inc., as amended (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2015, filed March 14, 2016).
3.2	Third Amended and Restated Bylaws (incorporated by reference to the Registrant's current report on Form 8-K, filed August 7, 2017).
3.3	Articles Supplementary, dated January 22, 2015, Establishing and Fixing the Rights and Preferences of the Registrant’s 7.375% Series A Cumulative Redeemable Preferred Stock (incorporated by reference to the Registrant's Form 8-A, filed January 26, 2015).
3.4	Articles Supplementary, dated April 12, 2017, Establishing and Fixing the Rights and Preferences of Additional Shares of the Registrant’s 7.375% Series A Cumulative Redeemable Preferred Stock (incorporated by reference to the Registrant's current report on Form 8-K, filed April 18, 2017).
4.1	Form of Stock Certificate for Common Stock of CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's current report on Form 8-K, filed January 14, 2014 (the first Form 8-K filing on such date)).
4.2	Form of Certificate of CorEnergy Infrastructure Trust, Inc.'s 7.375% Series A Cumulative Redeemable Preferred Stock (incorporated by reference to the Registrant's Form 8-A, filed January 26, 2015).
4.3.1	Base Indenture, dated as of June 29, 2015, between CorEnergy Infrastructure Trust, Inc. and Computershare Trust Company, N.A. (incorporated by reference to the Registrant's current report on Form 8-K, filed June 29, 2015).
4.3.2	First Supplemental Indenture, dated as of June 29, 2015, between CorEnergy Infrastructure Trust, Inc. and Computershare Trust Company, N.A. (incorporated by reference to the Registrant's current report on Form 8-K, filed June 29, 2015).
4.4	Global note evidencing the 7.00% Convertible Notes due 2020 (incorporated by reference to the Registrant's current report on Form 8-K, filed June 29, 2015).
10.1	Dividend Reinvestment Plan (incorporated by reference to the Registrant's Quarterly Report on Form 10-Q for the quarter ended August 31, 2007 and filed on October 12, 2007).
10.2.1	Management Agreement dated April 30, 2014, effective January 1, 2014, between Corridor InfraTrust Management, LLC and CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2014, filed May 12, 2014).
10.2.2	Management Agreement dated May 8, 2015, effective May 1, 2015 between Corridor InfraTrust Management, LLC and CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2015, filed May 11, 2015).
10.2.3	Letter Agreement, dated March 31, 2017, concerning Incentive Fee for March 31, 2017 under Management Agreement, dated May 8, 2015 and effective as of May 1, 2015, between Corridor InfraTrust Management, LLC and CorEnergy Infrastructure Trust, Inc. (incorporated by reference from the Registrant's Quarterly Report on Form 10-Q for the quarter ended March 31, 2017, filed May 3, 2017).
10.2.4	Letter Agreement, dated June 30, 2017, concerning Incentive Fee for June 30, 2017 under Management Agreement, dated May 8, 2015 and effective as of May 1, 2015, between Corridor InfraTrust Management, LLC and CorEnergy Infrastructure Trust, Inc. (incorporated by reference from the Registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2017, filed August 2, 2017).
10.2.5	Letter Agreement, dated September 30, 2017, concerning Incentive Fee for September 30, 2017 under Management Agreement, dated May 8, 2015 and effective as of May 1, 2015, between Corridor InfraTrust Management, LLC and CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Quarterly Report on Form 10-Q for the quarter ended September 30, 2017, filed November 1, 2017).
10.2.6	Letter Agreement, dated December 31, 2017, concerning Incentive Fee for December 31, 2017 under Management Agreement, dated May 8, 2015 and effective as of May 1, 2015, between Corridor InfraTrust Management, LLC and CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2017, filed February 28, 2018).
10.2.7	Letter Agreement, dated December 31, 2017, concerning Management Fee for December 31, 2017 under Management Agreement, dated May 8, 2015 and effective as of May 1, 2015, between Corridor InfraTrust Management, LLC and CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2017, filed February 28, 2018).
10.3.1	Second Amended Administration Agreement dated December 1, 2011 (incorporated by reference to the Registrant’s current report on Form 8-K, filed December 1, 2011).
10.3.2	Amendment and Assignment to the Second Amended Administration Agreement dated August 7, 2012 (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended November 30, 2012, filed February 13, 2013).
10.4.1	Purchase and Sale Agreement, dated December 7, 2012, by and between Ultra Wyoming, Inc. and Pinedale Corridor, LP (incorporated by reference to the Registrant’s current report on Form 8-K, filed December 10, 2012 (the first Form 8-K filing on such date)).
10.4.2	Amendment to Purchase and Sale Agreement, dated December 12, 2012, by and between Ultra Wyoming, Inc. and Pinedale Corridor, LP (incorporated by reference to the Registrant’s current report on Form 8-K, filed December 17, 2012).
10.5	Second Amended and Restated Term Credit Agreement and Note Purchase Agreement, dated December 29, 2017, between Pinedale Corridor, LP and Prudential Insurance Company of America (incorporated by reference to the Registrant's current report on Form 8-K, filed January 4, 2018).

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10.6.1	Lease Agreement dated December 20, 2012 by and between Pinedale Corridor, LP and Ultra Wyoming LGS, LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed December 21, 2012).
10.6.2	First Amendment to Lease, dated June 19, 2013, by and between Pinedale Corridor, LP and Ultra Wyoming LGS, LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed August 27, 2013).
10.6.3	Amended and Restated Limited Guaranty of Collection, dated November 28, 2016, between Ultra Resources, Inc., and Pinedale Corridor, L.P. (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2016, filed March 2, 2017).
10.7	First Amended and Restated Limited Partnership Agreement of Pinedale Corridor, LP, dated December 20, 2012, by and between Pinedale GP, Inc. and Ross Avenue Investments, LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed December 21, 2012).
10.8	Membership Interest Purchase Agreement, dated January 14, 2014, by and among Lightfoot Capital Partners, LP, CorEnergy Infrastructure Trust, Inc. and Arc Terminals Holdings LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed January 14, 2014 (the second Form 8-K filing on such date)).
10.9	Lease, dated January 21, 2014, by and between LCP Oregon Holdings, LLC and Arc Terminals Holdings LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed January 22, 2014).
10.9.1	First Amendment to Lease, dated January 30, 2018, by and between LCP Oregon Holdings, LLC and Zenith Energy Terminals Holdings LLC f/k/a Arc Terminals Holdings LLC (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2017, filed February 28, 2018).
10.9.2	Second Amendment to Lease, dated June 28, 2018, by and between LCP Oregon Holdings, LLC and Zenith Energy Terminals Holdings LLC f/k/a Arc Terminals Holdings LLC (incorporated by reference to the Registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2018, filed August 2, 2018).
10.10	Asset Purchase Agreement, dated January 21, 2014, by and between LCP Oregon Holdings, LLC and Arc Terminals Holdings LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed January 22, 2014).
10.10.1	Asset Purchase and Sale Agreement, dated December 21, 2018, by and between LCP Oregon Holdings, LLC, Corridor Private Holdings, LLC and Zenith Energy Terminals Holdings LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed December 28, 2018).
10.11.1	Director Compensation Plan of CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2014, filed August 11, 2014). *
10.11.2	Amendment No. 1 to Director Compensation Plan of CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Registration Statement on Form S-8, filed September 17, 2014 (File No. 333-198799)). *
10.11.3	Amendment No. 2 to Director Compensation Plan of CorEnergy Infrastructure Trust, Inc. (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2015, filed March 14, 2016). *
10.12.1	Revolving Credit Agreement dated as of September 26, 2014 by and among the Company and Regions Bank, et al (incorporated by reference to the Registrant's current report on Form 8-K, filed September 30, 2014).
10.12.2	First Amendment to Revolving Credit Agreement, dated November 24, 2014 by and among the Company and Regions Bank, et al (incorporated by reference to the Registrant's current report on Form 8-K, filed November 25, 2014).
10.12.3	Amended and Restated Revolving Credit Agreement, dated July 8, 2015, by and among the Company and Regions Bank, et al (incorporated by reference to the Registrant's current report on Form 8-K, filed July 8, 2015).
10.12.4	First Amendment, dated November 4, 2015, and effective as of September 30, 2015, to Amended and Restated Revolving Credit Agreement, dated July 8, 2015, by and among the Company and Regions Bank, et al (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2015, filed March 14, 2016).
10.12.5	Limited Consent and Amendment, dated March 4, 2016 by and among the Company and Regions Bank, et al (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2015, filed March 14, 2016).
10.12.6	Second Amendment to Amended and Restated Revolving Credit Agreement, dated July 28, 2017, by and among the Company and Regions Bank, et al (incorporated by reference from the Registrant's Quarterly Report on Form 10-Q for the quarter ended June 30, 2017, filed August 2, 2017).
10.13.1	Limited Liability Company Interests Purchase Agreement, dated November 17, 2014 between CorEnergy Infrastructure Trust, Inc. and Mogas Energy, LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed November 17, 2014).
10.13.2	Amendment to Limited Liability Company Interests Purchase Agreement, dated November 18, 2014 between CorEnergy Infrastructure Trust, Inc. and Mogas Energy, LLC (incorporated by reference to the Registrant's current report on Form 8-K, filed November 20, 2014).
10.14	Firm Service Transportation Agreement, Contract No. FRM-LGC-1001, dated March 1, 2017, between MoGas Pipeline LLC and Laclede Gas Company (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2016, filed March 2, 2017).
10.15.1	Purchase and Sale Agreement, dated June 22, 2015, by and between Grand Isle Corridor, LP and Energy XXI USA, Inc. (incorporated by reference to the Registrant's current report on Form 8-K, filed June 22, 2015).
10.15.2	Guaranty, dated June 22, 2015, by CorEnergy Infrastructure Trust, Inc. in favor Energy XXI USA, Inc. (incorporated by reference to the Registrant's current report on Form 8-K, filed June 22, 2015).
10.15.3	Guaranty, dated June 22, 2015, by Energy XXI Ltd in favor of Grand Isle Corridor, LP (incorporated by reference to the Registrant's current report on Form 8-K, filed June 22, 2015).
10.15.4	Assignment and Assumption Agreement, dated December 30, 2016, between Energy XXI USA, Inc., Energy XXI Gulf Coast, Inc., and Grand Isle Corridor, L.P. (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2016, filed March 2, 2017).
10.15.5	Assignment and Assumption of Guaranty and Release, dated December 30, 2016, between Energy XXI Ltd, Energy XXI Gulf Coast, Inc., and Grand Isle Corridor, L.P. (incorporated by reference to the Registrant's Annual Report on Form 10-K, for the year ended December 31, 2016, filed March 2, 2017).
10.16	Lease, dated June 30, 2015, by and between Grand Isle Corridor, LP and Energy XXI GIGS Services, LLC. Confidential information has been omitted and filed separately with the Securities and Exchange Commission. Confidential treatment has been granted with respect to this omitted information. (incorporated by reference to the Registrant's current report on Form 8-K, filed June 30, 2015).

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21.1	Subsidiaries of the Company - filed herewith
23.1	Consent of Ernst & Young LLP dated February 28, 2019 - filed herewith
31.1	Certification by Chief Executive Officer pursuant to Exchange Act Rule 13a-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - filed herewith
31.2	Certification by Chief Accounting Officer pursuant to Exchange Act Rule 13a-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - filed herewith
32.1	Certification by Chief Executive Officer and Chief Accounting Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - furnished herewith
101	The following materials from CorEnergy Infrastructure Trust, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2018, formatted in XBRL (Extensible Business Reporting Language): (i) the Consolidated Balance Sheets, (ii) the Consolidated Statements of Income and Comprehensive Income, (iii) the Consolidated Statement of Equity, (iv) the Consolidated Statements of Cash Flows and (v) the Notes to Consolidated Financial Statements - furnished herewith
*	Management contract or compensatory plan or arrangement.

All exhibits incorporated by reference were filed under SEC File No. 001-33292.

All other exhibits for which provision is made in the applicable regulations of the Securities and Exchange Commission are not required under the related instruction or are inapplicable and therefore have been omitted.

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INDEX TO FINANCIAL STATEMENTS

			Page No.
Report of Independent Registered Public Accounting Firm			F-2
Consolidated Balance Sheets as of December 31, 2018 and 2017			F-3
Consolidated Statements of Income and Comprehensive Income for the years ended December 31, 2018, 2017 and 2016			F-4
Consolidated Statements of Equity for the years ended December 31, 2018, 2017 and 2016			F-5
Consolidated Statements of Cash Flow for the years ended December 31, 2018, 2017 and 2016			F-6
Notes to Consolidated Financial Statements			F-8
	1.	Introduction and Basis of Presentation	F-8
	2.	Significant Accounting Policies	F-8
	3.	Leased Properties and Leases	F-14
	4.	Transportation and Distribution Revenue	F-17
	5.	Financing Notes Receivable	F-19
	6.	Income Taxes	F-20
	7.	Property and Equipment	F-23
	8.	Concentrations	F-23
	9.	Management Agreement	F-23
	10.	Fair Value	F-25
	11.	Debt	F-27
	12.	Asset Retirement Obligation	F-31
	13.	Interest Rate Hedge Swaps	F-32
	14.	Stockholder's Equity	F-32
	15.	Earnings Per Share	F-33
	16.	Quarterly Financial Data (Unaudited)	F-34
	17.	Subsequent Events	F-36
Schedule I - Condensed Financial Information of Registrant			F-37
Schedule III - Real Estate and Accumulated Depreciation			F-40
Schedule IV - Mortgage Loans on Real Estate			F-41

F-1

Table of Contents Index to Financial Statements Glossary of Defined Terms

Report of Independent Registered Public Accounting Firm

To the Stockholders and the Board of Directors of CorEnergy Infrastructure Trust, Inc.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of CorEnergy Infrastructure Trust, Inc. (the Company) as of December 31, 2018 and 2017, the related consolidated statements of income and comprehensive income, equity and cash flow for each of the three years in the period ended December 31, 2018, and the related notes and financial statement schedules listed in the Index at Item 15 (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 Company at December 31, 2018 and 2017, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2018, 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 Company's internal control over financial reporting as of December 31, 2018, 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 February 28, 2019 expressed an unqualified opinion thereon.

Basis for Opinion

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company'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 Company 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.

/s/ Ernst & Young LLP

We have served as the Company's auditor since 2006.

Kansas City, Missouri

February 28, 2019

F-2

Table of Contents Index to Financial Statements Glossary of Defined Terms

CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED BALANCE SHEETS

	December 31, 2018		December 31, 2017
Assets
Leased property, net of accumulated depreciation of $87,154,095 and $72,155,753	$	398,214,355	$	465,956,467
Property and equipment, net of accumulated depreciation of $15,969,346 and $12,643,636	109,881,552		113,158,872
Financing notes and related accrued interest receivable, net of reserve of $600,000 and $4,100,000	1,300,000		1,500,000
Note receivable	5,000,000		—
Other equity securities, at fair value	—		2,958,315
Cash and cash equivalents	69,287,177		15,787,069
Deferred rent receivable	25,942,755		22,060,787
Accounts and other receivables	5,083,243		3,786,036
Deferred costs, net of accumulated amortization of $1,290,236 and $623,764	2,838,443		3,504,916
Prepaid expenses and other assets	668,584		742,154
Deferred tax asset, net	4,948,203		2,244,629
Goodwill	1,718,868		1,718,868
Total Assets	$	624,883,180	$	633,418,113
Liabilities and Equity
Secured credit facilities, net of debt issuance costs of $210,891 and $254,646	37,261,109		40,745,354
Unsecured convertible senior notes, net of discount and debt issuance costs of $1,180,729 and $1,967,917	112,777,271		112,032,083
Asset retirement obligation	7,956,343		9,170,493
Accounts payable and other accrued liabilities	3,493,490		2,333,782
Management fees payable	1,831,613		1,748,426
Income tax liability	—		2,204,626
Unearned revenue	6,552,049		3,397,717
Total Liabilities	$	169,871,875	$	171,632,481
Equity
Series A Cumulative Redeemable Preferred Stock 7.375%, $125,555,675 and $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 50,222 and 52,000 issued and outstanding at December 31, 2018 and December 31, 2017, respectively	$	125,555,675	$	130,000,000
Capital stock, non-convertible, $0.001 par value; 11,960,225 and 11,915,830 shares issued and outstanding at December 31, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,960		11,916
Additional paid-in capital	320,295,969		331,773,716
Retained earnings	9,147,701		—
Total Equity	455,011,305		461,785,632
Total Liabilities and Equity	$	624,883,180	$	633,418,113
See accompanying Notes to Consolidated Financial Statements.

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CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

	For the Years Ended December 31,
	2018			2017			2016
Revenue
Lease revenue	$	72,747,362		$	68,803,804		$	67,994,130
Transportation and distribution revenue	16,484,236			19,945,573			21,094,112
Financing revenue	—			—			162,344
Total Revenue	89,231,598			88,749,377			89,250,586
Expenses
Transportation and distribution expenses	7,210,748			6,729,707			6,463,348
General and administrative	13,042,847			10,786,497			12,270,380
Depreciation, amortization and ARO accretion expense	24,947,453			24,047,710			22,522,871
Provision for loan (gain) loss	(36,867		)	—			5,014,466
Total Expenses	45,164,181			41,563,914			46,271,065
Operating Income	$	44,067,417		$	47,185,463		$	42,979,521
Other Income (Expense)
Net distributions and dividend income	$	106,795		$	680,091		$	1,140,824
Net realized and unrealized gain (loss) on other equity securities	(1,845,309		)	1,531,827			824,482
Interest expense	(12,759,010		)	(12,378,514		)	(14,417,839		)
Gain on the sale of leased property, net	11,723,257			—			—
Loss on extinguishment of debt	—			(336,933		)	—
Total Other Expense	(2,774,267		)	(10,503,529		)	(12,452,533		)
Income before income taxes	41,293,150			36,681,934			30,526,988
Taxes
Current tax expense (benefit)	(585,386		)	2,831,658			(313,107		)
Deferred tax benefit	(1,833,340		)	(486,340		)	(151,313		)
Income tax expense (benefit), net	(2,418,726		)	2,345,318			(464,420		)
Net Income	43,711,876			34,336,616			30,991,408
Less: Net Income attributable to non-controlling interest	—			1,733,826			1,328,208
Net Income attributable to CorEnergy Stockholders	$	43,711,876		$	32,602,790		$	29,663,200
Preferred dividend requirements	9,548,377			7,953,988			4,148,437
Net Income attributable to Common Stockholders	$	34,163,499		$	24,648,802		$	25,514,763
Net Income	$	43,711,876		$	34,336,616		$	30,991,408
Other comprehensive income (loss):
Changes in fair value of qualifying hedges / AOCI attributable to CorEnergy stockholders	—			11,196			(201,993		)
Changes in fair value of qualifying hedges / AOCI attributable to non-controlling interest	—			2,617			(47,226		)
Net Change in Other Comprehensive Income (Loss)	$	—		$	13,813		$	(249,219	)
Total Comprehensive Income	43,711,876			34,350,429			30,742,189
Less: Comprehensive income attributable to non-controlling interest	—			1,736,443			1,280,982
Comprehensive Income attributable to CorEnergy Stockholders	$	43,711,876		$	32,613,986		$	29,461,207
Earnings Per Common Share:
Basic	$	2.86		$	2.07		$	2.14
Diluted	$	2.79		$	2.07		$	2.14
Weighted Average Shares of Common Stock Outstanding:
Basic	11,935,021			11,900,516			11,901,985
Diluted	15,389,180			11,900,516			11,901,985
Dividends declared per share	$	3.000		$	3.000		$	3.000
See accompanying Notes to Consolidated Financial Statements.

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CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENTS OF EQUITY

	Capital Stock					Preferred Stock			Additional Paid-in Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-Controlling Interest			Total
	Shares		Amount			Amount
Balance at December 31, 2015	11,939,697		$	11,940		$	56,250,000		$	361,581,507		$	190,797		$	—		$	26,160,062		$	444,194,306
Net Income	—		—			—			—			—			29,663,200			1,328,208			30,991,408
Net change in cash flow hedges	—		—			—			—			(201,993		)	—			(47,226		)	(249,219		)
Total comprehensive income (loss)	—		—			—			—			(201,993		)	29,663,200			1,280,982			30,742,189
Repurchase of common stock	(90,613	)	(91		)	—			(2,041,760		)	—			—			—			(2,041,851		)
Series A preferred stock dividends	—		—			—			—			—			(4,148,437		)	—			(4,148,437		)
Common stock dividends	—		—			—			(10,197,853		)	—			(25,514,763		)	—			(35,712,616		)
Common stock issued under director's compensation plan	2,551		2			—			59,998			—			—			—			60,000
Reinvestment of dividends paid to common stockholders	34,581		35			—			815,854			—			—			—			815,889
Balance at December 31, 2016	11,886,216		11,886			56,250,000			350,217,746			(11,196		)	—			27,441,044			433,909,480
Net income	—		—			—			—			—			32,602,790			1,733,826			34,336,616
Amortization related to de-designated cash flow hedges	—		—			—			—			11,196			—			2,617			13,813
Total comprehensive income	—		—			—			—			11,196			32,602,790			1,736,443			34,350,429
Issuance of Series A cumulative redeemable preferred stock, 7.375% - redemption value	—		—			73,750,000			(2,588,469		)	—			—			—			71,161,531
Series A preferred stock dividends	—		—			—			(727,001		)	—			(7,500,733		)	—			(8,227,734		)
Common stock dividends	—		—			—			(10,592,143		)	—			(25,102,057		)	—			(35,694,200		)
Common stock issued under director's compensation plan	1,979		2			—			67,498			—			—			—			67,500
Distributions to Non-controlling interest	—		—			—			—			—			—			(1,833,650		)	(1,833,650		)
Purchase of Non-controlling interest	—		—			—			(5,566,195		)	—			—			(27,343,837		)	(32,910,032		)
Reinvestment of dividends paid to common stockholders	27,635		28			—			962,280			—			—			—			962,308
Balance at December 31, 2017	11,915,830		11,916			130,000,000			331,773,716			—			—			—			461,785,632
Cumulative transition adjustment upon the adoption of ASC 606, net of tax	—		—			—			(2,449,245		)	—			—			—			(2,449,245		)
Net income	—		—			—			—			—			43,711,876			—			43,711,876
Series A preferred stock dividends	—		—			—			—			—			(9,587,500		)	—			(9,587,500		)
Preferred stock repurchases(1)	—		—			(4,444,325		)	158,218			—			10,554			—			(4,275,553		)
Common stock dividends	—		—			—			(10,806,660		)	—			(24,987,229		)	—			(35,793,889		)
Common stock issued under director's compensation plan	1,807		2			—			67,498			—			—			—			67,500
Common stock issued upon conversion of convertible notes	1,271		1			—			42,653			—			—			—			42,654
Reinvestment of dividends paid to common stockholders	41,317		41			—			1,509,789			—			—			—			1,509,830
Balance at December 31, 2018 (2)	11,960,225		$	11,960		$	125,555,675		$	320,295,969		$	—		$	9,147,701		$	—		$	455,011,305
See accompanying Notes to Consolidated Financial Statements.
(1) In connection with the repurchases of Series A Preferred Stock during 2018, the deduction to preferred dividends of $10,554 represents the discount in the repurchase price paid compared to the carrying amount derecognized.
(2) The retained earnings balance at December 31, 2018 was generated due to the timing of quarterly dividends and quarterly net income. In the fourth quarter of 2018, net income was greater than dividends due to the gain on sale of leased property, net from the sale of the Portland Terminal Facility resulting in a retained earnings balance as of December 31, 2018.

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CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENTS OF CASH FLOW

	For the Years Ended December 31,
	2018			2017			2016
Operating Activities
Net Income	$	43,711,876		$	34,336,616		$	30,991,408
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income tax, net	(1,845,710		)	(486,340		)	(151,313		)
Depreciation, amortization and ARO accretion	26,361,907			25,708,891			24,548,350
Gain on sale of leased property, net	(11,723,257		)	—			—
Provision for loan (gain) loss	(36,867		)	—			5,014,466
Loss on extinguishment of debt	—			336,933			—
Non-cash settlement of accounts payable	—			(221,609		)	—
(Gain) loss on sale of equipment	(8,416		)	4,203			—
Gain on repurchase of convertible debt	—			—			(71,702		)
Net distributions and dividend income, including recharacterization of income	—			148,649			(117,004		)
Net realized and unrealized (gain) loss on other equity securities	1,845,309			(1,531,827		)	(781,153		)
Unrealized gain on derivative contract	—			—			(75,591		)
Settlement of derivative contract	—			—			(95,319		)
Loss on settlement of asset retirement obligation	310,941			—			—
Common stock issued under directors compensation plan	67,500			67,500			60,000
Changes in assets and liabilities:
Increase in deferred rent receivables	(7,038,848		)	(7,184,005		)	(8,360,036		)
(Increase) decrease in accounts and other receivables	(1,297,207		)	752,848			(174,390		)
Decrease in financing note accrued interest receivable	—			—			95,114
(Increase) decrease in prepaid expenses and other assets	73,505			(16,717		)	329,735
Increase (decrease) in management fee payable	83,187			13,402			(28,723		)
Increase (decrease) in accounts payable and other accrued liabilities	476,223			(225,961		)	(231,151		)
Increase (decrease) in income tax liability	(2,204,626		)	2,204,626			—
Increase (decrease) in unearned revenue	(152,777		)	2,884,362			155,961
Net cash provided by operating activities	$	48,622,740		$	56,791,571		$	51,108,652
Investing Activities
Proceeds from the sale of leased property	55,553,975			—			—
Proceeds from sale of other equity securities	449,067			7,591,166			—
Proceeds from assets and liabilities held for sale	—			—			644,934
Purchases of property and equipment, net	(105,357		)	(116,595		)	(191,926		)
Proceeds from asset foreclosure and sale	17,999			—			223,451
Principal payment on financing note receivable	236,867			—			—
Increase in financing notes receivable	—			—			(202,000		)
Return of capital on distributions received	663,939			120,906			4,631
Net cash provided by investing activities	$	56,816,490		$	7,595,477		$	479,090
Financing Activities
Debt financing costs	(264,010		)	(1,462,741		)	(193,000		)
Net offering proceeds on Series A preferred stock	—			71,161,531			—
Repurchases of common stock	—			—			(2,041,851		)
Repurchases of convertible debt	—			—			(899,960		)
Repurchases of Series A preferred stock	(4,275,553		)	—			—
Dividends paid on Series A preferred stock	(9,587,500		)	(8,227,734		)	(4,148,437		)
Dividends paid on common stock	(34,284,059		)	(34,731,892		)	(34,896,727		)
Distributions to non-controlling interest	—			(1,833,650		)	—
Advances on revolving line of credit	—			10,000,000			44,000,000
Payments on revolving line of credit	—			(54,000,000		)	—

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	For the Years Ended December 31,
	2018			2017			2016
Proceeds from term debt	—			41,000,000			—
Principal payments on secured credit facilities	(3,528,000		)	(45,600,577		)	(60,131,423		)
Purchase of non-controlling interest	—			(32,800,000		)	—
Net cash used in financing activities	$	(51,939,122	)	$	(56,495,063	)	$	(58,311,398	)
Net Change in Cash and Cash Equivalents	$	53,500,108		$	7,891,985		$	(6,723,656	)
Cash and Cash Equivalents at beginning of period	15,787,069			7,895,084			14,618,740
Cash and Cash Equivalents at end of period	$	69,287,177		$	15,787,069		$	7,895,084
Supplemental Disclosure of Cash Flow Information
Interest paid	$	11,200,835		$	10,780,150		$	12,900,901
Income taxes paid (net of refunds)	2,136,563			199,772			37,736
Non-Cash Investing Activities
Note receivable in consideration of the sale of leased property	$	5,000,000		$	—		$	—
Investment in other equity securities	—			(1,161,034		)	—
Change in accounts and other receivables	—			—			(450,000		)
Net change in Assets Held for Sale, Property and equipment, Prepaid expenses and other assets, Accounts payable and other accrued liabilities and Liabilities held for sale	—			—			(1,776,549		)
Non-Cash Financing Activities
Change in accounts payable and accrued expenses related to debt financing costs	$	(255,037	)	$	255,037		$	—
Reinvestment of distributions by common stockholders in additional common shares	1,509,830			962,308			815,889
Common stock issued upon conversion of convertible notes	42,654			—			—
See accompanying Notes to Consolidated Financial Statements.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

December 31, 2018

1.INTRODUCTION AND BASIS OF PRESENTATION

Introduction

CorEnergy Infrastructure Trust, Inc. (referred to as "CorEnergy" or "the Company"), was organized as a Maryland corporation and commenced operations on December 8, 2005. The Company's common shares are listed on the New York Stock Exchange ("NYSE") under the symbol "CORR" and its depositary shares representing Series A Preferred Stock are listed on the NYSE under the symbol "CORR PrA".

The Company is primarily focused on acquiring and financing real estate assets within the U.S. energy infrastructure sector and concurrently entering into long-term triple-net participating leases with energy companies. The Company also may provide other types of capital, including loans secured by energy infrastructure assets. Targeted assets include pipelines, storage tanks, transmission lines, and gathering systems, among others. These sale-leaseback or real property mortgage transactions provide the energy company with a source of capital that is an alternative to other sources such as corporate borrowing, bond offerings, or equity offerings. Many of the Company's leases contain participation features in the financial performance or value of the underlying infrastructure real property asset. The triple-net lease structure requires that the tenant pay all operating expenses of the business conducted by the tenant, including real estate taxes, insurance, utilities, and expenses of maintaining the asset in good working order. CorEnergy considers its investments in these energy infrastructure assets to be a single business segment and reports them accordingly in its financial statements.

Basis of Presentation

The accompanying consolidated financial statements include CorEnergy accounts and the accounts of its wholly-owned subsidiaries and have been prepared in accordance with U.S. generally accepted accounting principles ("GAAP") set forth in the Accounting Standards Codification ("ASC"), as published by the Financial Accounting Standards Board ("FASB"), and with the Securities and Exchange Commission ("SEC") instructions to Form 10-K. The accompanying consolidated financial statements reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the Company's financial position, results of operations and cash flows for the periods presented. There were no adjustments that, in the opinion of management, were not of a normal and recurring nature. All intercompany transactions and balances have been eliminated in consolidation, and the Company's net earnings have been reduced by the portion of net earnings attributable to non-controlling interests, when applicable.

The FASB issued ASU 2015-02 Consolidations (Topic 810) - Amendments to the Consolidation Analysis ("ASU 2015-02"), which amended previous consolidation guidance, including introducing a separate consolidation analysis specific to limited partnerships and other similar entities. Under this analysis, limited partnerships and other similar entities are considered a variable interest entity ("VIE") unless the limited partners hold substantive kick-out rights or participating rights. Management determined that Pinedale LP and Grand Isle Corridor LP are VIEs under the amended guidance because the limited partners of both partnerships lack both substantive kick-out rights and participating rights. As such, management evaluated the qualitative criteria under FASB ASC Topic 810 in conjunction with ASU 2015-02 to make a determination whether these partnerships should be consolidated in the Company's financial statements. ASC Topic 810-10 requires the primary beneficiary of a variable interest entity's activities to consolidate the VIE. The primary beneficiary is identified as the enterprise that has a) the power to direct the activities of the VIE that most significantly impact the entity's economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. The standard requires an ongoing analysis to determine whether the variable interest gives rise to a controlling financial interest in the VIE. Based on the general partners' roles and rights as afforded by the partnership agreements and its exposure to losses and benefits of each of the partnerships through its significant limited partner interests, management determined that CorEnergy is the primary beneficiary of both Pinedale LP and Grand Isle Corridor LP. Based upon this evaluation and the Company's 100 percent ownership interest in Pinedale LP (2018) and Grand Isle Corridor LP (2016-2018) and the majority ownership interest in Pinedale LP (2016-2017) of the limited partnership interests, the consolidated financial statements presented include full consolidation with respect to both of the partnerships.

2.SIGNIFICANT ACCOUNTING POLICIES

A. Use of Estimates – The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, the disclosure of contingent assets and

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liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

B. Leased Property – The Company includes assets subject to lease arrangements within leased property, net of accumulated depreciation, in the Consolidated Balance Sheets. Lease payments received are reflected in lease revenue on the Consolidated Statements of Income, net of amortization of any off-market adjustments. Costs in connection with the creation and execution of a lease are capitalized and amortized over the lease term. See Note 3 ("Leased Properties And Leases") for further discussion.

C. Property and Equipment – Property and equipment are stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful life of the asset. Expenditures for repairs and maintenance are charged to operations as incurred, and improvements, which extend the useful lives of assets, are capitalized and depreciated over the remaining estimated useful life of the asset. The Company initially records long-lived assets at their purchase price plus any direct acquisition costs, unless the transaction is accounted for as a business combination, in which case the acquisition costs are expensed as incurred. If the transaction is accounted for as a business combination, the Company allocates the purchase price to the acquired tangible and intangible assets and liabilities based on their estimated fair values.

D. Long-Lived Asset Impairment – The Company's long-lived assets consist primarily of a subsea midstream pipeline system, liquids gathering system and natural gas pipelines that have been obtained through asset acquisitions and a business combination. Management continually monitors its business, the business environment and performance of its operations to determine if an event has occurred that indicates that the carrying value of a long-lived asset may be impaired. When a triggering event occurs, which is a determination that involves judgment, management utilizes cash flow projections to assess its ability to recover the carrying value of its assets based on the Company's long-lived assets' ability to generate future cash flows on an undiscounted basis. This differs from the evaluation of goodwill, for which the recoverability assessment utilizes fair value estimates that include discounted cash flows in the estimation process and accordingly any goodwill impairment recognized may not be indicative of a similar impairment of the related underlying long-lived assets.

Management's projected cash flows of long-lived assets are primarily based on contractual cash flows relating to existing leases that extend many years into the future. If those cash flow projections indicate that the long-lived asset's carrying value is not recoverable, management records an impairment charge for the excess of carrying value of the asset over its fair value. The estimate of fair value considers a number of factors, including the potential value that would be received if the asset were sold, discount rates and projected cash flows. Due to the imprecise nature of these projections and assumptions, actual results can differ from management's estimates. There were no impairments of long-lived assets recorded during the years ended December 31, 2018, 2017 or 2016.

E. Financing Notes Receivable – Financing notes receivable are presented at face value plus accrued interest receivable and deferred loan origination costs and net of related direct loan origination income. Each quarter the Company reviews its financing notes receivable to determine if the balances are realizable based on factors affecting the collectability of those balances. Factors may include credit quality, timeliness of required periodic payments, past due status and management discussions with obligors. The Company evaluates the collectability of both interest and principal of each of its loans to determine if an allowance is needed. An allowance will be recorded when based on current information and events, the Company determines it is probable that it will be unable to collect all amounts due according to the existing contractual terms. If the Company does determine an allowance is necessary, the amount deemed uncollectable is expensed in the period of determination. An insignificant delay or shortfall in the amount of payments does not necessarily result in the recording of an allowance. Generally, when interest and/or principal payments on a loan become past due, or if the Company does not otherwise expect the borrower to be able to service its debt and other obligations, the Company will place the loan on non-accrual status and will typically cease recognizing financing revenue on that loan until all principal and interest have been brought current. Interest income recognition is resumed if and when the previously reserved-for financing notes become contractually current and performance has been demonstrated. Payments received subsequent to the recording of an allowance will be recorded as a reduction to principal. During the years ended December 31, 2018, 2017 and 2016, the Company recorded provisions for loan (gain) loss of approximately $(37) thousand, $0 and 5.0 million, respectively. The Company's financing notes receivable are discussed more fully in Note 5 ("Financing Notes Receivable").

F. Investment Securities – The Company's investments in securities are classified as other equity securities and represent interests in private companies which the Company has elected to report at fair value under the fair value option. These investments are subject to restrictions on resale, have no established trading market and are valued on a quarterly basis. Because of the inherent uncertainty of valuation, the fair values of such investments, which are determined in accordance with procedures approved by the Company's Board of Directors, may differ materially from the values that would have been used had a ready market existed for the investments.

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The Company determines fair value to be the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Company has determined the principal market, or the market in which the Company exits its private portfolio investments with the greatest volume and level of activity, to be the private secondary market. Typically, private companies are bought and sold based on multiples of EBITDA, cash flows, net income, revenues, or in limited cases, book value.

For private company investments, value is often realized through a liquidity event. Therefore, the value of the company as a whole (enterprise value) at the reporting date often provides the best evidence of the value of the investment and is the initial step for valuing the Company's privately issued securities. For any one company, enterprise value may best be expressed as a range of fair values, from which a single estimate of fair value will be derived. In determining the enterprise value of a portfolio company, an analysis is prepared consisting of traditional valuation methodologies including market and income approaches. The Company considers some or all of the traditional valuation methods based on the individual circumstances of the portfolio company in order to derive its estimate of enterprise value.

The fair value of investments in private portfolio companies is determined based on various factors, including enterprise value, observable market transactions, such as recent offers to purchase a company, recent transactions involving the purchase or sale of the equity securities of the company, or other liquidation events. The determined equity values may be discounted when the Company has a minority position, or is subject to restrictions on resale, has specific concerns about the receptivity of the capital markets to a specific company at a certain time, or other comparable factors exist.

G. Fair Value Measurements – FASB ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. Various inputs are used in determining the fair value of the Company's assets and liabilities. These inputs are summarized in the three broad levels listed below:

• Level 1 - quoted prices in active markets for identical investments

• Level 2 - other significant observable inputs (including quoted prices for similar investments, market corroborated inputs, etc.)

• Level 3 - significant unobservable inputs (including the Company's own assumptions in determining the fair value of investments)

See Note 10 ("Fair Value") for further discussion of the Company's fair value measurements.

H. Cash and Cash Equivalents – The Company maintains cash balances at financial institutions in amounts that regularly exceed FDIC insured limits. The Company's cash equivalents are comprised of short-term, liquid money market instruments.

I. Accounts and other receivables – Accounts receivable are presented at face value net of an allowance for doubtful accounts within accounts and other receivables on the balance sheet. Accounts are considered past due based on the terms of sale with the customers. The Company reviews accounts for collectability based on an analysis of specific outstanding receivables, current economic conditions and past collection experience. For the years ended December 31, 2018 and 2017, the Company determined that an allowance for doubtful accounts was not necessary.

J. Deferred rent receivables – Lease receivables are determined according to the terms of the lease agreements entered into by the Company and its lessees, as discussed within Note 3 ("Leased Properties And Leases"). Lease receivables primarily represent timing differences between straight-line revenue recognition and contractual lease receipts. As of December 31, 2018, lease payments by the Company's tenants have remained timely and without lapse.

K. Goodwill – Goodwill represents the excess of the amount paid for the MoGas business over the fair value of the net identifiable assets acquired. To comply with ASC 350, Intangibles - Goodwill and Other ("ASC 350"), the Company performs an impairment test for goodwill annually, or more frequently in the event that a triggering event has occurred. December 31st is the Company's annual testing date associated with its MoGas reporting unit.

In January 2017, the FASB issued ASU 2017-04, Simplifying the Test for Goodwill Impairment, which simplifies how an entity is required to test goodwill for impairment by eliminating step two from the goodwill impairment test. Effective January 1, 2017, the Company elected to early adopt this standard.

In accordance with ASC 350, a company may elect to perform a qualitative assessment to determine whether the quantitative impairment test is required. If the company elects to perform a qualitative assessment, the quantitative impairment test is required only if the conclusion is that it is more likely than not that the reporting unit's fair value is less than its carrying amount. If a company bypasses the qualitative assessment, the quantitative goodwill impairment test should be followed in step one.

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Step one compares the fair value of the reporting unit to its carrying value to identify and measure any potential impairment. The reporting unit fair value is based upon consideration of various valuation methodologies, one of which is projecting future cash flows discounted at rates commensurate with the risks involved ("Discounted Cash Flow" or "DCF"). Assumptions used in a DCF require the exercise of significant judgment, including judgment about appropriate discount rates and terminal values, growth rates and the amount and timing of expected future cash flows. Forecasted cash flows require management to make judgments and assumptions, including estimates of future volumes and rates. Declines in volumes or rates from those forecasted, or other changes in assumptions, may result in a change in management's estimate and result in an impairment.

The Company elected to perform a qualitative goodwill impairment assessment for the years ended December 31, 2018 and 2017. In performing the qualitative assessment, the Company analyzed the key drivers and other external factors that impact the business in order to determine if any significant events, transactions or other factors had occurred or are expected to occur that would impair earnings or competitiveness, therefore impairing the fair value of the MoGas reporting unit. After assessing the totality of events and circumstances, it was determined that it was not more likely than not that the fair value of the MoGas reporting unit was less than the carrying value, and so it was not necessary to perform the quantitative step one valuation. Key drivers that were considered in the qualitative evaluation of the MoGas reporting unit included: general economic conditions, continued recovery of the energy markets, natural gas pricing, input costs, liquidity and capital resources and customer outlook. Additionally, the Company considered the quantitative impairment analysis performed as of December 31, 2016, including potential updates to key valuation assumptions, in determining that it was not more likely than not that goodwill was impaired for the current year assessment.

L. Debt Discount and Debt Issuance Costs – Costs incurred for the issuance of new debt are capitalized and amortized into interest expense over the debt term. Issuance costs related to long-term debt are recorded as a direct deduction from the carrying amount of that debt liability, net of accumulated amortization. Issuance costs related to line-of-credit arrangements however, are presented as an asset instead of a direct deduction from the carrying amount of the debt. In accordance with ASC 470, Debt ("ASC 470"), the Company recorded its Convertible Senior Notes at the aggregate principal amount, less discount. The Company is amortizing the debt discount over the life of the convertible notes as additional non-cash interest expense utilizing the effective interest method. Refer to Note 11 ("Debt") for additional information.

M. Asset Retirement Obligations – The Company follows ASC 410-20, Asset Retirement Obligations, which requires that an asset retirement obligation ("ARO") associated with the retirement of a long-lived asset be recognized as a liability in the period in which it is incurred and becomes determinable, with an offsetting increase in the carrying amount of the associated asset. The Company recognized an existing ARO in conjunction with the acquisition of the GIGS in June 2015.

The Company measures changes in the ARO liability due to passage of time by applying an interest method of allocation to the amount of the liability at the beginning of the period. The increase in the carrying amount of the liability is recognized as an expense classified as an operating item in the Consolidated Statements of Income, hereinafter referred to as ARO accretion expense. The Company periodically reassesses the timing and amount of cash flows anticipated associated with the ARO and adjusts the fair value of the liability accordingly under the guidance in ASC 410-20.

The fair value of the obligation at the acquisition date was capitalized as part of the carrying amount of the related long-lived assets and is being depreciated over the asset's remaining useful life. The useful lives of most pipeline gathering systems are primarily derived from available supply resources and ultimate consumption of those resources by end users. Adjustments to the ARO resulting from reassessments of the timing and amount of cash flows will result in changes to the retirement costs capitalized as part of the carrying amount of the asset.

Upon decommissioning of the ARO or a portion thereof, the Company reduces the fair value of the liability and recognizes a (gain) loss on settlement of ARO as an operating item in the Consolidated Statements of Income for the difference between the liability and actual decommissioning costs incurred.

Refer to Note 12 ("Asset Retirement Obligation") for additional information.

N. Revenue Recognition – In May 2014, the FASB issued ASU No. 2014-09 Revenue from Contracts with Customers ("ASU 2014-09" or "ASC 606"), which became effective for all public entities on January 1, 2018. ASC 606 supersedes previously existing revenue recognition standards with a single model unless those contracts are within the scope of other standards (e.g. leases). The model requires an entity to recognize as revenue the amount of consideration to which it expects to be entitled for the transfer of promised goods or services to customers. A substantial portion of the Company's revenue consists of rental income from leasing arrangements, which is specifically excluded from ASC 606. However, the Company's transportation and distribution revenue is within the scope of the new guidance. The Company adopted ASC 606 effective on January 1, 2018 using the modified retrospective method. The Company elected to apply the guidance only to open contracts as of the effective date. The Company recognized the cumulative effect of applying the new standard as an adjustment to the opening balance of stockholders' equity. The comparative information has not been restated and continues to be reported under accounting standards in effect for those periods. Refer to

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Note 4 ("Transportation And Distribution Revenue") for further discussion of the transition impact and related disclosures under ASC 606.

Specific recognition policies for the Company's revenue items are as follows:

• Lease revenue – Base rent related to the Company's leased property is recognized on a straight-line basis over the term of the lease when collectability is reasonably assured. Participating rent is recognized when it is earned, based on the achievement of specified performance criteria. Rental payments received in advance are classified as unearned revenue and included as a liability within the Consolidated Balance Sheets. Unearned revenue is amortized ratably over the lease period as revenue recognition criteria are met. Rental payments received in arrears are accrued and classified as deferred rent receivable and included in assets within the Consolidated Balance Sheets.

• Transportation and distribution revenue – The Company's contracts related to transportation and distribution revenue are primarily comprised of a mix of natural gas supply, transportation and distribution performance obligations, as well as limited performance obligations related to system maintenance and expansion. Transportation revenues are recognized by MoGas and distribution revenues are recognized by Omega and Omega Gas Marketing, LLC.

◦ Under the Company's natural gas supply, transportation and distribution performance obligations, the customer simultaneously receives and consumes the benefit of the services as natural gas is delivered. Therefore, the transaction price is allocated proportionally over the series of identical performance obligations with each contract. The transaction price is calculated based on (i) index price, plus a contractual markup in the case of natural gas supply agreements (considered variable due to fluctuations in the index), (ii) FERC regulated rates or negotiated rates in the case of transportation agreements and (iii) contracted amounts (with annual CPI escalators) in the case of the Company's distribution agreement. Based on the nature of the agreements, revenue for all but one of the Company's natural gas supply, transportation and distribution performance obligations is recognized on a right to invoice basis as the performance obligations are met, which represents what the Company expects to receive in consideration and is representative of value delivered to the customer. The Company has a contract with one customer, Spire, that has fixed pricing which varies over the contract term. For this specific contract, the transaction price has been allocated ratably over the contractual performance obligation beginning in 2018 with the adoption of ASC 606. All invoicing is done in the month following service, with payment typically due a month from invoice date.

◦ The Company's contracts also contain performance obligations related to system maintenance and expansion, which are completed on an as-needed basis. The work performed is specific and tailored to the customer's needs and there are no alternative uses for the services provided. Therefore, as the work is being completed, control is transferring to the customer. These services are billed at the Company's cost, plus an agreed upon margin, and the Company has an enforceable right to payment for services provided. The Company invoices for this service on a monthly basis according to an agreed upon billing schedule. Revenue is recognized on an input method, based on the actual cost of a service as a measure of performance obligations satisfaction, which the Company determined to be the method which faithfully depicts the transfer of services. Differences between the amounts invoiced and revenue recognized under the input method are reflected as an asset or liability on the Consolidated Balance Sheets. Any differences are typically expected to be recognized within a year.

◦ Beginning February 1, 2016, due to changes that commenced under a new contract with the Department of Defense ("DOD"), gas sales and cost of gas sales are presented on a net basis in the transportation and distribution revenue line. The Company continues to present the gas sales and cost of gas sales on a net basis upon adoption of ASC 606.

• Financing revenue – Historically, financing notes receivable have been considered a core product offering and therefore the related income is presented as a component of operating income. For increasing rate loans, base interest income is recorded ratably over the life of the loan, using the effective interest rate. The net amount of deferred loan origination income and costs are amortized on a straight-line basis over the life of the loan and reported as an adjustment to yield in financing revenue. Participating financing revenues are recorded when specific performance criteria have been met.

O. Transportation and distribution expense –Included here are both MoGas' costs of operating and maintaining the natural gas transmission line and Omega's costs of operating and maintaining the natural gas distribution system, including any necessary expansion of the distribution system. These costs are incurred both internally and externally. The internal costs relate to system control, pipeline operations, maintenance, insurance and taxes. Other internal costs include payroll for employees associated with gas control, field employees and management. The external costs consist of professional services such as audit and accounting, legal and regulatory and engineering.

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Historically, Omega's amounts paid for gas and propane delivered to customers were presented as cost of sales. Beginning February 1, 2016, under a new contract with the DOD, amounts paid by Omega for gas and propane are netted against sales and are presented in the transportation and distribution revenue line. See paragraph (N) above.

P. Other Income Recognition –Specific policies for the Company's other income items are as follows:

• Net distributions and dividend income from investments – Distributions and dividends from investments are recorded on their ex-dates and are reflected as other income within the accompanying Consolidated Statements of Income. Distributions received from the Company's investments are generally characterized as ordinary income, capital gains and distributions received from investment securities. The portion characterized as return of capital is paid by the Company's investees from their cash flow from operations. The Company records investment income, capital gains and distributions received from investment securities based on estimates made at the time such distributions are received. Such estimates are based on information available from each company and other industry sources. These estimates may subsequently be revised based on information received from the entities after their tax reporting periods are concluded, as the actual character of these distributions is not known until after the fiscal year end of the Company.

• Net realized and unrealized gain (loss) from investments – Securities transactions are accounted for on the date the securities are purchased or sold. Realized gains and losses are reported on an identified cost basis. The Company records investment income and return of capital based on estimates made at the time such distributions are received. Such estimates are based on information available from the portfolio company and other industry sources. These estimates may subsequently be revised based on information received from the portfolio company after their tax reporting periods are concluded, as the actual character of these distributions are not known until after the Company's fiscal year end.

Q. Asset Acquisition Expenses – Costs incurred in connection with the research of real property acquisitions not accounted for as business combinations are expensed until it is determined that the acquisition of the real property is probable. Upon such determination, costs incurred in connection with the acquisition of the property are capitalized as described in paragraph (C) above. Deferred costs related to an acquisition that the Company has determined, based on management's judgment, not to pursue are expensed in the period in which such determination is made. Costs incurred in connection with a business combination are expensed as incurred.

R. Offering Costs – Offering costs related to the issuance of common or preferred stock are charged to additional paid-in capital when the stock is issued.

S. Derivative Instruments and Hedging Activities – The Company has used forward swap contracts primarily to reduce exposure to changes in interest rates on a portion of its variable-rate debt and to provide a cash flow hedge. In accordance with FASB ASC 815, Derivatives and Hedging ("ASC 815"), these derivative contracts have been recorded on the balance sheet at fair value. Historically, these derivative instruments have been designated as hedges for accounting purposes. The measurement of the cash flow hedge ineffectiveness has historically been recognized in earnings, when applicable. The effective portion of the gain or loss on qualifying swaps has been reported in accumulated other comprehensive income ("AOCI"), in accordance with ASC 815. For swaps de-designated as cash flow hedges, changes in fair value of the swaps have been fully recognized in earnings. See Note 13 ("Interest Rate Hedge Swaps") for further discussion.

T. Earnings Per Share – Basic earnings per share ("EPS") is computed using the weighted average number of common shares outstanding during the period. Diluted EPS is computed using the weighted average number of common and dilutive common equivalent shares outstanding during the period except for periods of net loss for which no common share equivalents are included because their effect would be anti-dilutive. Dilutive common equivalent shares consist of shares issuable upon conversion of the Convertible Notes calculated using the if-converted method.

U. Federal and State Income Taxation – In 2013 the Company qualified for REIT status, and in March 2014 elected (effective as of January 1, 2013), to be treated as a REIT for federal income tax purposes. Because certain of its assets may not produce REIT-qualifying income or be treated as interests in real property, those assets are held in wholly-owned TRSs in order to limit the potential that such assets and income could prevent the Company from qualifying as a REIT.

As a REIT, the Company holds and operates certain of its assets through one or more wholly-owned TRSs. The Company's use of TRSs enables it to continue to engage in certain businesses while complying with REIT qualification requirements and also allows it to retain income generated by these businesses for reinvestment without the requirement of distributing those earnings. In the future, the Company may elect to reorganize and transfer certain assets or operations from its TRSs to the Company or other subsidiaries, including qualified REIT subsidiaries.

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The Company's other equity securities are limited partnerships or limited liability companies which are treated as partnerships for federal and state income tax purposes. As a limited partner, the Company reports its allocable share of taxable income in computing its own taxable income. To the extent held by a TRS, the TRS's tax expense or benefit is included in the Consolidated Statements of Income based on the component of income or gains and losses to which such expense or benefit relates. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. A valuation allowance is recognized if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized. It is expected that for the year ended December 31, 2018, and future periods, any deferred tax liability or asset generated will be related entirely to the assets and activities of the Company's TRSs.

If the Company ceased to qualify as a REIT, the Company, as a C corporation, would be obligated to pay federal and state income tax on its taxable income.

V. Recent Accounting Pronouncements – In February 2016, the FASB issued ASU 2016-02, Leases ("ASU 2016-02" or "ASC 842"), which amends the existing accounting standards for lease accounting, including requiring lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. ASU 2016-02 is effective for fiscal years and interim periods beginning after December 15, 2018, with early adoption permitted. At adoption, the standard will be applied using a modified retrospective approach. Alternatively, ASU 2018-11, Leases (Topic 842) Targeted Improvements, allows the Company to initially apply the new lease standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings and to continue to apply legacy guidance in ASC 840, Leases, including its disclosures requirements, in the comparative periods presented in the year of adoption. The Company has substantially completed its evaluation of the impact of the standard on its consolidated financial statements and related disclosures and expects that it will record a right of use asset and lease liability of less than $100 thousand on January 1, 2019 for its lessee operating leases.

The Company also concluded that Omega's long-term contract with the DOD to provide natural gas distribution to Fort Leonard Wood through Omega's pipeline distribution system on the military post meets the definition of a lease under ASC 842. Omega is the lessor in the contract and the lease is expected to be classified as an operating lease. The Company noted the non-lease component is the predominant component in the lease, and the timing and pattern of transfer of the lease component and the associated non-lease components are the same. Therefore, the Company expects to elect a practical expedient that allows lessors to not separate lease and related non-lease components if the non-lease components otherwise would be accounted for in accordance with the revenue standard under ASC 606. With the expected election of this practical expedient, the Company is expected to account for the DOD contract under the revenue standard, which is consistent with the Company's current accounting for the contract.

In August 2018, the FASB issued ASU 2018-13, Changes to the Disclosure Requirements for Fair Value Measurement ("ASU 2018-13"), which modifies the disclosure requirements on fair value measurements. The amendments add disclosure requirements for the changes in unrealized gains and losses for the period that are held in other comprehensive income for recurring Level 3 fair value measurements as well as disclosure requirements for the range and weighted average of significant observable inputs used to develop Level 3 fair value measurements. The amendments also clarify that the measurement uncertainty disclosure is to communicate information about the uncertainty in measurement as of the reporting date. ASU 2018-13 is effective for annual reporting periods, and interim periods within those annual periods, beginning after December 15, 2019. Management does not expect the adoption of this standard to have a material impact on the Company's consolidated financial statements.

3.LEASED PROPERTIES AND LEASES

As of December 31, 2018, the Company had two significant leases following the sale of the Portland Terminal Facility and termination of Portland Lease Agreement on December 21, 2018. The properties, located in Wyoming, Louisiana and the Gulf of Mexico, are leased on a triple-net basis to major tenants, described in the table below. These major tenants are responsible for the payment of all taxes, maintenance, repairs, insurance and other operating expenses relating to the leased properties. The long-term, triple-net leases generally have an initial term of 11 to 15 years with options for renewals. Lease payments are scheduled to increase at varying intervals during the initial term of the leases. The following table summarizes the significant leased properties, major tenants and lease terms:

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Summary of Leased Properties, Major Tenants and Lease Terms
Property	Grand Isle Gathering System	Pinedale LGS
Location	Gulf of Mexico/Louisiana	Pinedale, WY
Tenant	Energy XXI GIGS Services, LLC	Ultra Wyoming LGS, LLC
Asset Description	Approximately 153 miles of offshore pipeline with total capacity of 120 thousand Bbls/d, including a 16-acre onshore terminal and saltwater disposal system.	Approximately 150 miles of pipelines and four central storage facilities.
Date Acquired	June 2015	December 2012
Initial Lease Term	11 years	15 years
Renewal Option	Equal to the lesser of 9-years or 75 percent of the remaining useful life	5-year terms
Current Monthly Rent Payments	7/1/17 - 6/30/18: $2,854,667 7/1/18 - 6/30/19: $2,860,917	$1,776,772(1)
Estimated Useful Life	27 years	26 years
(1) Monthly rent payments increased to $1,812,307 beginning January 1, 2019.

The future contracted minimum rental receipts for all leases as of December 31, 2018, are as follows:

Future Minimum Lease Receipts
Year Ending December 31,	Amount
2019	$	58,347,190
2020	65,383,190
2021	71,345,190
2022	70,322,690
2023	67,274,690
Thereafter	193,639,760
Total	$	526,312,710

The table below displays the Company's individually significant leases as a percentage of total leased properties and total lease revenues for the periods presented:

	As a Percentage of (1)
	Leased Properties				Lease Revenues
	As of December 31,				For the Years Ended December 31,
	2018		2017		2018		2017		2016
Pinedale LGS (2)	44.5	%	39.9	%	35.2	%	31.2	%	30.4	%
Grand Isle Gathering System	55.2	%	49.7	%	55.9	%	59.1	%	59.8	%
Portland Terminal Facility (3)	—	%	10.1	%	8.8	%	9.6	%	9.7	%
(1) Insignificant leases are not presented; thus percentages may not sum to 100%.
(2) Pinedale LGS lease revenues include variable rent of $4.3 million and $587 thousand for the years ended December 31, 2018 and 2017, respectively.
(3) On December 21, 2018, the Portland Terminal Facility was sold to Zenith Terminals, terminating the Portland Lease Agreement. Refer to "Sale of the Portland Terminal Facility" section below.

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The following table reflects the depreciation and amortization included in the accompanying Consolidated Statements of Income associated with the Company's leases and leased properties:

	For the Years Ended December 31,
	2018		2017		2016
Depreciation Expense
GIGS	$	10,836,590	$	9,754,596	$	8,605,506
Pinedale	8,869,440		8,869,440		8,869,440
Portland Terminal Facility (1)	1,243,769		1,275,660		843,084
United Property Systems	36,662		36,298		32,424
Total Depreciation Expense	$	20,986,461	$	19,935,994	$	18,350,454
Amortization Expense - Deferred Lease Costs
GIGS	$	30,564	$	30,564	$	30,564
Pinedale	61,368		61,368		61,368
Total Amortization Expense - Deferred Lease Costs	$	91,932	$	91,932	$	91,932
ARO Accretion Expense
GIGS	$	499,562	$	663,065	$	726,664
Total ARO Accretion Expense	$	499,562	$	663,065	$	726,664
(1) On December 21, 2018, the Portland Terminal Facility was sold to Zenith Terminals, terminating the Portland Lease Agreement. Refer to "Sale of the Portland Terminal Facility" section below.

The following table reflects the deferred costs that are included in the accompanying Consolidated Balance Sheets associated with the Company's leased properties:

	December 31, 2018		December 31, 2017
Net Deferred Lease Costs
GIGS	$	229,319	$	259,883
Pinedale	550,349		611,717
Total Deferred Lease Costs, net	$	779,668	$	871,600

TENANT INFORMATION

Substantially all of the lease tenants' financial results are driven by exploiting naturally occurring oil and natural gas hydrocarbon deposits beneath the Earth's surface. As a result, the tenants' financial results are highly dependent on the performance of the oil and natural gas industry, which is highly competitive and subject to volatility. During the terms of the leases, management monitors credit quality of its tenants by reviewing their published credit ratings, if available, reviewing publicly available financial statements, or reviewing financial or other operating statements, monitoring news reports regarding the tenants and their respective businesses and monitoring the timeliness of lease payments and the performance of other financial covenants under their leases.

Ultra Petroleum

On March 14, 2017, the bankruptcy court issued an order confirming its plan of reorganization and on April 12, 2017, UPL emerged from bankruptcy. UPL is currently subject to the reporting requirements under the Exchange Act and is required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. Its SEC filings can be found at www.sec.gov. Its stock is trading on the NASDAQ under the symbol UPL. The Company makes no representation as to the accuracy or completeness of the audited and unaudited financial statements of UPL but has no reason to doubt the accuracy or completeness of such information. In addition, UPL has no duty, contractual or otherwise, to advise the Company of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. None of the information in the public reports of UPL that are filed with the SEC is incorporated by reference into, or in any way form, a part of this filing.

Energy Gulf Coast/Cox Oil

The Company believes the terms of the Grand Isle Lease Agreement require copies of certain financial statement information be provided that the Company is required to file pursuant to SEC Regulation S-X, as described in Section 2340 of the SEC Financial Reporting Manual. Prior to October 29, 2018, EGC was subject to the reporting requirements of the Exchange Act and was required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. So long as EGC remained a public reporting company, the Grand Isle Lease Agreement provided this requirement was fulfilled by EGC making its financial statements and reports publicly available through the SEC’s EDGAR system, in lieu of

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delivering such information directly to the Company. On October 18, 2018, EGC was acquired by an affiliate of privately-held Cox Oil. Upon the filing by EGC of a Form 15 with the SEC on October 29, 2018, EGC's SEC reporting obligations were suspended and it ceased to file such reports.

As EGC's financial information is no longer publicly available, the Company is engaged in discussions with Cox Oil/EGC concerning satisfaction of its obligations under the Grand Isle Lease Agreement to provide the required information to the Company for inclusion in its SEC reports. To date, Cox Oil has not yet fulfilled these obligations. It is the Company's intention to enforce the obligations of EGC to provide the financial statement information that the Company believes are required under the terms of the Grand Isle Lease Agreement. The Company expects to file the financial statement information that is required by Regulation S-X by amendment to this Annual Report on Form 10-K once such information is made available in accordance with the terms of the lease.

EGC's SEC filings prior to October 29, 2018 can be found at www.sec.gov. The Company makes no representation as to the accuracy or completeness of the audited and unaudited financial statements of EGC but has no reason to doubt the accuracy or completeness of such information. In addition, EGC has no duty, contractual or otherwise, to advise the Company of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. None of the information in the public reports of EGC that are filed with the SEC is incorporated by reference into, or in any way form, a part of this filing.

Sale of the Portland Terminal Facility

On December 21, 2018, the Company entered into a Purchase and Sale Agreement with Zenith Energy Terminals Holdings, LLC ("Zenith Terminals"), the Company's tenant under the Portland Lease Agreement, to sell the Portland Terminal Facility and remaining interest in the Joliet Terminal ("Joliet") for an aggregate consideration of $61.0 million, net of transaction costs. Of the negotiated sale price of $61.0 million, approximately $56.0 million was paid in cash at closing, with the balance of $5.0 million in a promissory note, which was paid on January 7, 2019. The Company would be entitled to receive certain additional consideration, under a formula prescribed in the Agreement, in the event Zenith sells, or enters into a definitive agreement to sell, the Portland Terminal Facility to a third party for a price greater than $60.0 million within six months following December 21, 2018. The sale of the Portland Terminal Facility effectively terminated the Portland Lease Agreement, dated January 14, 2014, between the Company and Zenith Terminals.

The consideration was allocated to the Portland Terminal Facility ($60.6 million) and Joliet ($0.4 million) based on fair value information utilized in negotiating the transaction. As of December 21, 2018, the Portland Terminal Facility had a carrying value of $45.7 million. The sale of the Portland Terminal Facility resulted in a gain on sale of leased asset of approximately $11.7 million, net of deferred rent receivable of approximately $3.2 million. Prior to the sale of the Joliet interest, the equity interest was valued at its transacted value of $1.2 million from the required reinvestment during the Arc Logistics merger with Zenith in December 2017. The sale of the Joliet interest resulted in a realized loss on other equity securities of approximately $715 thousand. Both the gain on sale of leased asset, net and the realized loss on other equity securities are included as items in other income (expense) in the Consolidated Statements of Income for the year ended December 31, 2018. Refer to Note 10 ("Fair Value") for additional information on the sale of the interest in Joliet.

Acquisition of Pinedale LGS Non-Controlling Interest

On December 29, 2017, Pinedale LP I, a wholly-owned subsidiary of the Company, purchased Prudential's 18.95 percent non-controlling equity interest in Pinedale LP for considerations of approximately $32.9 million. The carrying value of Prudential's non-controlling interest at the transaction date was $27.3 million. As the transaction resulted in an increase in the Company's interest in Pinedale LP, but not a change in control, the purchase was accounted for as an equity transaction. The difference between the fair value of the purchase consideration and the carrying value of the non-controlling interest of $5.6 million was recognized in additional paid-in-capital and attributable to the Company. Upon closing the transaction, the Company indirectly owns 100 percent of Pinedale LP through its wholly-owned subsidiaries Pinedale GP and Pinedale LP I and there is no longer a noncontrolling interest in the Company's consolidated financial statements.

4.TRANSPORTATION AND DISTRIBUTION REVENUE

The Company's contracts related to transportation and distribution revenue are primarily comprised of a mix of natural gas supply, transportation and distribution performance obligations, as well as limited performance obligations related to system maintenance and expansion. Refer to Note 2 ("Significant Accounting Policies") for additional details on the Company's revenue recognition guidance under ASC 606.

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The table below summarizes the Company's contract asset and contract liability balances related to its transportation and distribution revenue contracts as of December 31, 2018:

	Contract Asset(1)			Contract Liability(2)
Beginning Balance January 1, 2018	$	328,033		$	—
Cumulative Transition Adjustment Upon Adoption of ASC 606	—			3,307,109
Unrecognized Performance Obligations	(836,628		)	3,307,109
Recognized Performance Obligations	689,174			(91,864		)
Ending Balance December 31, 2018	$	180,579		$	6,522,354
(1) The contract asset balance is included in prepaid expenses and other assets in the Consolidated Balance Sheets.
(2) The contract liability balance is included in unearned revenue in the Consolidated Balance Sheets.

Based on a downward revision of the rate during the Company's long-term natural gas transportation contract with Spire, ASC 606 requires the Company to record the contractual transaction price, and therefore aggregate revenue, from the contract ratably over the term of the contract. Accordingly, on January 1, 2018, the Company recorded a cumulative adjustment to recognize a contract liability of approximately $3.3 million, and a corresponding reduction to beginning equity (net of deferred tax impact). The adjustment reflects the difference in amounts previously recognized as invoiced, versus cumulative revenues earned under the contract on a straight-line basis in accordance with ASC 606, as of the date of adoption. The contract liability continued to accumulate additional unrecognized performance obligations at a rate of approximately $992 thousand per quarter until the contractual rate decrease took effect in November 2018. Following the rate decline, recognized performance obligations exceeded amounts invoiced and the contract liability will decline at a rate of approximately $138 thousand per quarter through the end of the contract in October 2030. As of December 31, 2018, the revenue allocated to the remaining performance obligation under this contract is approximately $63.5 million.

The following is a breakout of the Company's transportation and distribution revenue for the years ended December 31, 2018, 2017 and 2016:

	For the Years Ended December 31,
	2018		2017		2016
Natural gas transportation contracts	64.3	%	71.5	%	67.6	%
Natural gas distribution contracts	26.8	%	20.4	%	19.0	%

In accordance with ASC 606 transition disclosure requirements, the cumulative effect of changes made to the Consolidated Balance Sheet as of January 1, 2018 for the adoption of ASC 606 were as follows:

Balance Sheet	Balance at December 31, 2017		Adjustments Due to ASC 606			Balance at January 1, 2018
Assets
Deferred Tax Asset	$	2,244,629	$	857,864		$	3,102,493
Liabilities
Unearned revenue	3,397,717		3,307,109			6,704,826
Equity
Additional paid in capital	331,773,716		(2,449,245		)	329,324,471

The tables below disclose the impact of adoption on the Consolidated Balance Sheet and Consolidated Statement of Income as of and for the year ended December 31, 2018:

	As of December 31, 2018
Balance Sheet	As Reported		Balances Without Adoption of ASC 606		Effect of Change Higher/(Lower)
Assets
Deferred Tax Asset	$	4,948,203	$	3,256,304	$	1,691,899
Liabilities
Unearned revenue	6,552,049		29,695		6,522,354
Equity
Additional paid in capital	320,295,969		325,126,424		(4,830,455		)

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	For the Year Ended December 31, 2018
Statement of Income	As Reported			Balances Without Adoption of ASC 606			Effect of Change Higher/(Lower)
Revenues
Transportation and distribution revenue	$	16,484,236		$	19,699,481		$	(3,215,245	)
Taxes
Deferred tax benefit	(1,833,340		)	(999,305		)	(834,035		)

5.FINANCING NOTES RECEIVABLE

Four Wood Financing Note Receivable

On December 31, 2014, a subsidiary of the Company, Four Wood Corridor, LLC ("Four Wood Corridor"), entered into a Loan Agreement with SWD Enterprises, LLC ("SWD Enterprises"), a wholly-owned subsidiary of Four Wood Energy, pursuant to which Four Wood Corridor made a loan to SWD Enterprises for $4.0 million (the "REIT Loan"). Concurrently, the Company's TRS, Corridor Private entered into a TRS Loan Agreement with SWD Enterprises, pursuant to which Corridor Private made a loan to SWD Enterprises for $1.0 million (the "TRS Loan"). The proceeds of the REIT Loan and the TRS Loan were used by SWD Enterprises and its affiliates to finance the acquisition of real and personal property that provides saltwater disposal services for the oil and natural gas industry, and to pay related expenses. For the REIT Loan from Four Wood Corridor, interest initially accrued on the outstanding principal at an annual base rate of 12 percent. For the TRS Loan from Corridor Private, interest initially accrued on the outstanding principal at an annual base rate of 13 percent. The base rates of both loans were to increase by 2 percent of the current base rate per year. The REIT Loan and the TRS Loan are secured by the real property and equipment held by SWD Enterprises and the outstanding equity in SWD Enterprises and its affiliates. The REIT Loan and the TRS Loan are also guaranteed by all affiliates of SWD Enterprises.

As a result of the decreased economic activity by SWD Enterprises, the Company recorded a provision for loan loss with respect to the SWD loans. The Consolidated Statement of Income for the year ended December 31, 2016 reflects a provision for loan loss of $3.5 million, which includes $71 thousand of deferred origination income and $98 thousand of interest accrued under the original loan agreements. The loans were placed on non-accrual status during the first quarter of 2016. During the first quarter of 2018, the Company recorded an additional provision for loan loss on the SWD loans of $500 thousand. Prior to the sale of the real property and equipment securing the loans to a new third-party debtor in the fourth quarter of 2018 as discussed further below, the balance of the SWD loans was valued based on the enterprise value of SWD Enterprises, the collateral value supporting the loans, at $1.0 million during 2018 and $1.5 million as of December 31, 2017, respectively.

On December 12, 2018, Four Wood Corridor granted SWD Enterprises approval to sell the assets securing the REIT Loan and the TRS Loan, as described above, to Compass SWD, LLC ("Compass SWD") in exchange for Compass SWD executing a new loan agreement with Four Wood Corridor for $1.3 million (the "Compass REIT Loan") and approximately $237 thousand in cash consideration, net of costs facilitating the close. The Compass REIT Loan is scheduled to mature on June 15, 2019 and interest is accrued on the outstanding principal at an annual rate of LIBOR plus 6 percent. As of December 31, 2018, the Compass REIT Loan is valued at $1.3 million. As a result of the transaction, SWD Enterprises was released from the terms of the REIT Loan and the TRS Loan, and the Company recognized a provision for loan gain of $37 thousand in the Consolidated Statements of Income for the year ended December 31, 2018.

Black Bison Financing Notes

During 2014, the Company's wholly-owned subsidiaries, Corridor Bison and CorEnergy BBWS, entered into loan agreements with Black Bison Water Services, LLC ("Black Bison WS") totaling $12.0 million and $3.3 million, respectively (the "Black Bison WS Loan" and the "TRS Loan" and, together the "Black Bison Loans"). The purpose of the loans was to finance the acquisition and development of real property to provide water sourcing, water disposal, or water treating and recycling services for the oil and natural gas industry. The Black Bison Loans were set to mature on March 31, 2024, and were set to amortize by quarterly payments beginning on March 31, 2015. The Loans were secured by the real property and equipment held by Black Bison WS and the outstanding equity in Black Bison WS and its affiliates. The Black Bison Loans were also guaranteed by all affiliates of Black Bison WS and further secured by all assets of those guarantors.

Due to reduced drilling activity in the Black Bison area of operations, Black Bison WS requested, and the Company granted, certain temporary forbearance waivers in June 2015 and August 2015 that had the effect of excusing the borrower from full performance under the terms of the Black Bison Loans while such waivers were in effect. None of the granted forbearance agreements were deemed to be concessions. As a result of the continued inability of the borrower to perform under the terms of these loans, even as temporarily modified by the waivers, effective December 31, 2015, the Company recorded a provision for loan loss with respect to the Black Bison Loans of $13.8 million.

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On February 29, 2016, the Company foreclosed on 100 percent of the equity of BB Intermediate, the borrower of the Black Bison financing notes, as well as all of the other collateral securing the Black Bison Loans. The foreclosure was accepted in satisfaction of the $2.0 million total outstanding loan balance. On June 16, 2016, the Company entered into an asset sale agreement with Expedition Water Solutions for the sale of specified disposal wells and related equipment as outlined in the sale agreement. Consideration received by the company included $748 thousand cash, net of fees, and the future right to royalty payments, which was recorded at its fair value of $450 thousand. The rights to future cash payments are tied to the future volumes of water disposed of in each of the wells sold. The Company did not record any financing revenue related to the Black Bison Loans for the year ended December 31, 2016 or any subsequent period. These notes were considered by the Company to be on non-accrual status and were reflected as such in the financial statements. For the year ended December 31, 2016, the Company recorded $832 thousand in provision for loan loss related to the Black Bison Loans.

6.INCOME TAXES

Deferred income taxes reflect the net tax effect of temporary differences between the carrying amount of assets and liabilities for financial reporting and tax purposes. Components of the Company's deferred tax assets and liabilities as of December 31, 2018 and 2017, are as follows:

Deferred Tax Assets and Liabilities
	December 31, 2018			December 31, 2017
Deferred Tax Assets:
Deferred contract revenue	$	1,691,899		$	—
Net operating loss carryforwards	5,424,671			957,719
Loan loss provision	263,508			247,814
Basis reduction of investment in partnerships	—			261,549
Other	95,695			2,965,321
Sub-total	$	7,475,773		$	4,432,403
Deferred Tax Liabilities:
Net unrealized gain on investment securities	$	—		$	(342,669	)
Cost recovery of leased and fixed assets	(2,508,547		)	(1,845,105		)
Other	(19,023		)	—
Sub-total	$	(2,527,570	)	$	(2,187,774	)
Total net deferred tax asset	$	4,948,203		$	2,244,629

As of December 31, 2018, the total deferred tax assets and liabilities presented above relate to the Company's TRSs. The Company recognizes the tax benefits of uncertain tax positions only when the position is "more likely than not" to be sustained upon examination by the tax authorities based on the technical merits of the tax position. The Company's policy is to record interest and penalties on uncertain tax positions as part of tax expense. Tax years subsequent to the year ended December 31, 2014, remain open to examination by federal and state tax authorities.

The Tax Cuts and Jobs Act (the "2017 Tax Act") was enacted on December 22, 2017. The 2017 Tax Act reduced the US federal corporate tax rate from 35 percent to 21 percent. The 2017 Tax Act also repealed the alternative minimum tax for corporations. In December 2018, the Company completed its accounting for the tax effects of enactment of the 2017 Tax Act as allowed under SEC Staff Accounting Bulletin 118. The Company remeasured deferred tax assets and liabilities based on the updated rates at which they are expected to reverse in the future, which resulted in a $1.3 million transition adjustment that reduced net deferred tax assets. One of the Company's TRSs qualifies for the regulated utility and real property business exceptions under the new proposed treasury regulations for Section 163(j). Therefore, previously disqualified interest from years prior to 2018 was deducted and resulted in a reclassification from other deferred tax assets to deferred tax assets for net operating loss carryforwards during the year ended December 31, 2018. Refer to additional discussion of the Company's net operating loss carryforwards below. The Company will continue to assess the impact of new tax legislation, as well as any future regulations and updates provided by the tax authorities.

Total income tax expense (benefit) differs from the amount computed by applying the federal statutory income tax rate of 21 percent for the year ended December 31, 2018 and 35 percent for the years ended December 31, 2017 and 2016, to income or loss from operations and other income and expense for the years presented, as follows:

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Income Tax Expense (Benefit)
	For the Years Ended December 31,
	2018			2017			2016
Application of statutory income tax rate	$	8,671,562		$	12,231,838		$	10,219,573
State income taxes, net of federal tax benefit	(583,186		)	352,708			26,215
Income of Real Estate Investment Trust not subject to tax	(10,339,520		)	(11,975,853		)	(10,663,371		)
Tax reform impact	—			1,262,444			—
Other	(167,582		)	474,181			(46,837		)
Total income tax expense (benefit)	$	(2,418,726	)	$	2,345,318		$	(464,420	)

Total income taxes are computed by applying the federal statutory rate of 21 percent plus a blended state income tax rate. Corridor Public Holdings, Inc. and Corridor Private Holdings, Inc. had a blended state rate of approximately 5.53 percent, 3.78 percent and 3.78 percent for the years ended December 31, 2018, 2017 and 2016, respectively. CorEnergy BBWS, Inc. had a blended state income tax rate of approximately 5 percent for the year ended December 31, 2018 due to its operations in Missouri. CorEnergy BBWS, Inc. did not record a provision for state income taxes for the years ended December 31, 2017 and 2016 because it only operated in Wyoming, which does not have state income tax. Because Corridor MoGas, Inc. primarily only operates in the state of Missouri, a blended state income tax rate of 5 percent was used for the operation of the TRS for the years ended December 31, 2018, 2017 and 2016. Prior to its reorganization to a QRS at the end of 2017, Mowood Corridor, Inc. had a blended state income tax rate of 5 percent for the years ended December 31, 2017 and 2016. For the years ended December 31, 2018, 2017 and 2016, all of the income tax expense (benefit) presented above relates to the assets and activities held in the Company's TRSs. The components of income tax expense (benefit) include the following for the periods presented:

Components of Income Tax Expense (Benefit)
	For the Years Ended December 31,
	2018			2017			2016
Current tax expense (benefit)
Federal	$	(413,248	)	$	2,498,363		$	(321,720	)
State (net of federal tax benefit)	(172,138		)	333,295			8,613
Total current tax expense (benefit)	$	(585,386	)	$	2,831,658		$	(313,107	)
Deferred tax expense (benefit)
Federal	$	(1,422,292	)	$	(505,753	)	$	(168,915	)
State (net of federal tax benefit)	(411,048		)	19,413			17,602
Total deferred tax benefit	$	(1,833,340	)	$	(486,340	)	$	(151,313	)
Total income tax expense (benefit), net	$	(2,418,726	)	$	2,345,318		$	(464,420	)

As of December 31, 2017 and 2016, the TRSs had a cumulative net operating loss of $4.1 million and $3.0 million, respectively. For the year ended December 31, 2018, the TRSs incurred a net operating loss of approximately $17.1 million, resulting in a cumulative net operating loss of approximately $21.0 million as of December 31, 2018. The net operating loss generated during the year ended December 31, 2018 may be carried forward indefinitely, subject to limitation. Net operating losses generated for years prior to December 31, 2018 may be carried forward for 20 years. If not utilized, the net operating loss will expire as follows: $328 thousand, $176 thousand, $1.4 million and $2.0 million in the years ending December 31, 2034, 2035, 2036 and 2037, respectively. The amount of deferred tax asset for net operating losses as of December 31, 2018 includes amounts for the year ended December 31, 2018.

The aggregate cost of securities for federal income tax purposes and securities with unrealized appreciation and depreciation, were as follows:

Aggregate Cost of Securities for Income Tax Purposes
	December 31, 2018		December 31, 2017
Aggregate cost for federal income tax purposes	$	408,051	$	3,063,430
Gross unrealized appreciation	—		325,130
Gross unrealized depreciation	—		—
Net unrealized appreciation	$	—	$	325,130

The Company provides the following tax information to its common stockholders pertaining to the character of distributions paid during tax years 2018, 2017 and 2016. For a stockholder that received all distributions in cash during 2018, 71.3 percent will be

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treated as ordinary dividend income, none will be treated as return of capital and 28.7 percent will be treated as capital gain distributions. Of the ordinary dividend income, none will be treated as qualified dividend income for a non-corporate taxpayer; all of the ordinary dividend income may be taken into account on an individual's section 199A deduction, subject to the applicable holding period. Of the capital gain distribution, 13.4 percent is subject to a maximum 25 percent federal income tax rate and 15.3 percent is subject to a maximum 20 percent federal income tax rate. The per share characterization by quarter is reflected in the following tables:

2018 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Unrecaptured Section 1250 Gain		Section 199A Dividends
2/14/2018	2/13/2018	2/28/2018	$	0.7500	$	0.5346	$	—	$	0.2154	$	0.1007	$	0.5346
5/17/2018	5/16/2018	5/31/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
8/17/2018	8/16/2018	8/31/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
11/15/2018	11/14/2018	11/30/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
Total 2018 Distributions			$	3.0000	$	2.1384	$	—	$	0.8616	$	0.4028	$	2.1384

2017 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
2/13/2017	2/9/2017	2/28/2017	$	0.7500	$	0.5925	$	0.0785	$	—	$	0.1575
5/16/2017	5/12/2017	5/31/2017	0.7500		0.5925		0.0785		—		0.1575
8/17/2017	8/15/2017	8/31/2017	0.7500		0.5925		0.0785		—		0.1575
11/15/2017	11/14/2017	11/30/2017	0.7500		0.5925		0.0785		—		0.1575
Total 2017 Distributions			$	3.0000	$	2.3700	$	0.3140	$	—	$	0.6300

2016 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
02/12/2016	02/10/2016	02/29/2016	$	0.7500	$	0.2955	$	—	$	—	$	0.4545
05/13/2016	05/11/2016	05/31/2016	0.7500		0.2955		—		—		0.4545
08/17/2016	08/15/2016	08/31/2016	0.7500		0.2955		—		—		0.4545
11/15/2016	11/11/2016	11/30/2016	0.7500		0.2955		—		—		0.4545
Total 2016 Distributions			$	3.0000	$	1.1820	$	—	$	—	$	1.8180

The Company provides the following tax information to its preferred stockholders pertaining to the character of distributions paid during the 2018, 2017 and 2016 tax years. For a stockholder that received all distributions in cash during 2018, 71.3 percent will be treated as ordinary dividend income, none will be treated as return of capital and 28.7 percent will be treated as capital gain distributions. Of the ordinary dividend income, none will be treated as qualified dividend income for a non-corporate taxpayer; all of the ordinary dividend income may be taken into account on an individual's section 199A deduction, subject to the applicable holding period. Of the capital gain distribution, 13.4 percent is subject to a maximum 25 percent federal income tax rate and 15.3 percent is subject to a maximum 20 percent federal income tax rate. The per share characterization by quarter is reflected in the following tables:

2018 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Unrecaptured Section 1250 Gain		Section 199A Dividends
2/14/2018	2/13/2018	2/28/2018	$	0.4609	$	0.3285	$	—	$	0.1324	$	0.0619	$	0.3285
5/17/2018	5/16/2018	5/31/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
8/17/2018	8/16/2018	8/31/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
11/15/2018	11/14/2018	11/30/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
Total 2018 Distributions			$	1.8436	$	1.3140	$	—	$	0.5296	$	0.2476	$	1.3140

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2017 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
2/13/2017	2/9/2017	2/28/2017	$	0.4609	$	0.4609	$	0.0611	$	—	$	—
5/16/2017	5/12/2017	5/31/2017	0.4609		0.4609		0.0611		—		—
8/17/2017	8/15/2017	8/31/2017	0.4609		0.4609		0.0611		—		—
11/15/2017	11/14/2017	11/30/2017	0.4609		0.4609		0.0611		—		—
Total 2017 Distributions			$	1.8436	$	1.8436	$	0.2444	$	—	$	—

2016 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
02/12/2016	02/10/2016	02/29/2016	$	0.4609	$	0.4609	$	—	$	—	$	—
05/13/2016	05/11/2016	05/31/2016	0.4609		0.4609		—		—		—
08/17/2016	08/15/2016	08/31/2016	0.4609		0.4609		—		—		—
11/15/2016	11/11/2016	11/30/2016	0.4609		0.4609		—		—		—
Total 2016 Distributions			$	1.8436	$	1.8436	$	—	$	—	$	—

The Company elected, effective for the 2013 tax year, to be treated as a REIT for federal income tax purposes. The Company's REIT election, assuming continued compliance with the applicable tests, will continue in effect for subsequent tax years. The Company satisfied the annual income test and the quarterly asset tests necessary for us to qualify to be taxed as a REIT for 2018, 2017 and 2016. Distributions made during 2017 were treated as qualifying dividend income related to taxable dividends received from the Company's TRSs that were received and distributed in the same year.

7.PROPERTY AND EQUIPMENT

Property and equipment consist of the following:

Property and Equipment
	December 31, 2018			December 31, 2017
Land	$	580,000		$	580,000
Natural gas pipeline	124,306,175			124,303,315
Vehicles and trailers	696,164			650,634
Office equipment and computers	268,559			268,559
Gross property and equipment	$	125,850,898		$	125,802,508
Less: accumulated depreciation	(15,969,346		)	(12,643,636		)
Net property and equipment	$	109,881,552		$	113,158,872

Depreciation expense was $3.4 million for the years ended December 31, 2018, 2017 and 2016, respectively.

8.CONCENTRATIONS

The Company has customer concentrations through major tenants at its two significant leased properties as discussed fully in Note 3 ("Leased Properties And Leases"). In addition to these lease concentrations, contracted transportation revenues from the Company's subsidiary, MoGas, to its largest customer, Spire (formally Laclede Gas Company), represented approximately 6 percent, 11 percent and 12 percent of consolidated revenues for the years ended December 31, 2018, 2017 and 2016, respectively. The Company's contracted transportation revenues with Spire for the year ended December 31, 2018 were impacted by the adoption of ASC 606, which required the Company to record the contract with Spire on a straight-line basis and record a transition adjustment on January 1, 2018. Refer to Note 4 ("Transportation And Distribution Revenue") for additional details.

9.MANAGEMENT AGREEMENT

The Company has executed a Management Agreement with Corridor InfraTrust Management, LLC ("Corridor"), a related party. Under the Management Agreement, Corridor (i) presents the Company with suitable acquisition opportunities consistent with the investment policies and objectives of the Company, (ii) is responsible for the day-to-day operations of the Company and (iii) performs such services and activities relating to the assets and operations of the Company as may be appropriate. The Management

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Agreement, which does not have a specific term and will remain in place unless terminated by the Company or Corridor in accordance with its terms, does give a majority of the stockholders of the Company, or two-thirds of the independent directors, the ability to terminate the agreement for any reason on thirty (30) days' prior written notice, so long as that notice is delivered with a termination payment equal to three times the base management fee and incentive fee paid to the manager in the last four quarters.

The terms of the Management Agreement provide for a quarterly management fee to be paid to Corridor equal to 0.25 percent (1.00 percent annualized) of the value of the Company's Managed Assets as of the end of each quarter. "Managed Assets" means the total assets of the Company (including any securities receivables, other personal property or real property purchased with or attributable to any borrowed funds) minus (A) the initial invested value of all non-controlling interests, (B) the value of any hedged derivative assets, (C) any prepaid expenses and (D) all of the accrued liabilities other than (1) deferred taxes and (2) debt entered into for the purpose of leverage. For purposes of the definition of Managed Assets, the Company's securities portfolio will be valued at then current market value. For purposes of the definition of Managed Assets, other personal property and real property assets will include real and other personal property owned and the assets of the Company invested, directly or indirectly, in equity interests in or loans secured by real estate or personal property (including acquisition related costs and acquisition costs that may be allocated to intangibles or are unallocated), valued at the aggregate historical cost, before reserves for depreciation, amortization, impairment charges or bad debts or other similar noncash reserves.

The Management Agreement also provides for payment of a quarterly incentive fee of 10 percent of the increase in distributions paid over a distribution threshold equal to $0.625 per share per quarter, and requires that at least half of any incentive fees that are paid be reinvested in the Company's common stock. The foregoing description of the terms of the May 1, 2015 Management Agreement is qualified in its entirety by reference to the full terms of such agreement, which is incorporated by reference as an exhibit to this Report.

During the years ended December 31, 2017 and 2016 the Company and the Manager agreed to the following modifications to the fee arrangements described above:

• In light of the provisions for loan losses recognized by the Company on certain of its energy infrastructure financing investments (collectively, the "Underperforming Loans") during 2015 and the first quarter of 2016, the Manager voluntarily recommended, and the Company agreed, that effective on and after the Company's March 31, 2016 balance sheet date, solely for the purpose of computing the value of the Company's Managed Assets in calculating the quarterly management fee under the terms of the Management Agreement, that portion of the Management Fee attributable to the Company's investment in the Underperforming Loans shall be based on the estimated net realizable value of such loans, which shall not exceed the amount invested in the Underperforming Loans as of the end of the quarter for which the Management Fee is to be calculated.

• During the year ended December 31, 2016, the Manager voluntarily recommended, and the Company agreed, that the Manager would waive $88 thousand of the total $595 thousand incentive fee that would have otherwise been payable under the provisions of the Management Agreement with respect to dividends paid on the Company's common stock.

• During the year ended December 31, 2017, the Manager voluntarily recommended, and the Company agreed, that the Manager would waive $100 thousand of the total $595 thousand incentive fee that would otherwise be payable under the provisions of the Management Agreement with respect to dividends paid on the Company's common stock.

• In order to ensure equitable application of the quarterly management fee provisions of the Management Agreement for the acquisition of Prudential's minority limited partner interest in Pinedale LP, which closed on December 29, 2017, the Manager waived any incremental management fee due as of the end of the fourth quarter of 2017 based on the net impact of the Pinedale LP acquisition.

Fees incurred under the Management Agreement for the years ended December 31, 2018, 2017 and 2016 were $7.6 million, $7.2 million and $7.2 million, respectively, and are reported in the General and Administrative line item on the Consolidated Statements of Income.

The Company pays Corridor, as the Company's Administrator pursuant to an Administrative Agreement, an administrative fee equal to an annual rate of 0.04 percent of the value of the Company's Managed Assets, with a minimum annual fee of $30 thousand. Fees incurred under the Administrative Agreement for the years ended December 31, 2018, 2017 and 2016 were $280 thousand, $269 thousand and $266 thousand, respectively, and are reported in the General and Administrative line item on the Consolidated Statements of Income.

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10.FAIR VALUE

As of December 31, 2017, the Company's investments in Lightfoot and Joliet were its only remaining private company other equity securities. These other equity securities were also the only assets and liabilities measured at fair value on a recurring basis. Certain private equity investments were sold or disposed of by the end of 2018. Refer to the "Lightfoot" and "Joliet" sections below for additional details.

The following tables set forth the Company's assets and liabilities measured at fair value on a recurring basis, by input level within the fair value hierarchy, as of December 31, 2017:

	December 31, 2017
	Total		Fair Value
			Level 1		Level 2		Level 3
Assets:
Other equity securities	$	2,958,315	$	—	$	—	$	2,958,315
Total Assets	$	2,958,315	$	—	$	—	$	2,958,315

The changes for all Level 3 securities measured at fair value on a recurring basis using significant unobservable inputs for the years ended December 31, 2018 and 2017, are as follows:

Level 3 Rollforward
For the Year Ended 2018	Fair Value Beginning Balance		Acquisitions		Disposals			Total Realized and Unrealized Gains (Losses) Included in Net Income			Return of Capital Adjustments Impacting Cost Basis of Securities			Fair Value Ending Balance		Changes in Unrealized Gains Included In Net Income, Relating to Securities Still Held (1)
Other equity securities	$	2,958,315	$	—	$	(449,067	)	$	(1,845,309	)	$	(663,939	)	$	—	$	—
Total	$	2,958,315	$	—	$	(449,067	)	$	(1,845,309	)	$	(663,939	)	$	—	$	—
For the Year Ended 2017
Other equity securities	$	9,287,209	$	1,161,034	$	(8,752,201	)	$	1,531,827		$	(269,554	)	$	2,958,315	$	295,161
Total	$	9,287,209	$	1,161,034	$	(8,752,201	)	$	1,531,827		$	(269,554	)	$	2,958,315	$	295,161
(1) Located in Net realized and unrealized gain on other equity securities in the Consolidated Statements of Income

The Company utilizes the beginning of reporting period method for determining transfers between levels. There were no transfers between levels 1, 2 or 3 for the years ended December 31, 2018 and 2017.

Valuation Techniques and Unobservable Inputs

The Company's other equity securities, which represent securities issued by private companies, were classified as Level 3 assets and the Company elected to report at fair value under the fair value option. Significant judgment was required in selecting the assumptions used to determine the fair values of these investments.

Lightfoot

The Company's Lightfoot investment consisted of a 6.6 percent and 1.5 percent equity interest in Lightfoot LP and Lightfoot GP, respectively. As of December 31, 2017, Lightfoot's only material asset consisted of its remaining investment in Gulf LNG, a 1.5 billion cubic feet per day ("bcf/d") receiving, storage and regasification terminal in Pascagoula, Mississippi.

On December 21, 2017, Zenith closed its acquisition of Arc Logistics. Under the terms of the agreement, Lightfoot LP received $14.50 per common unit of Arc Logistics. Lightfoot LP additionally received $36.2 million for the sale of 5.52 percent of its interest in Gulf LNG to Zenith (the "Unconditional Interest"). In addition, Zenith was to purchase the remaining 4.16 percent of Lightfoot's Gulf LNG interest (the "Conditional Interest") for an additional $27.3 million upon a successful outcome (as defined) of the Gulf LNG arbitration with Eni USA, as discussed further below. Lightfoot GP received $94.5 million for 100 percent of the membership interests in Arc Logistics GP. Under the terms of the merger, at closing, Lightfoot LP and Lightfoot GP used a portion of their sale proceeds to purchase an approximate 13.5 percent interest in Joliet.

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Subsequent to closing of the transaction, the Company received $7.6 million in cash proceeds related to its pro rata portion of the sale proceeds of Lightfoot, including proceeds related to Arc Logistics common units, the Unconditional Interest in Gulf LNG and membership interests in Arc Logistics GP. Amounts received are net of approximately $1.2 million related to the Company's required reinvestment in Joliet.

On March 1, 2016, an affiliate of Gulf LNG received a Notice of Disagreement and Disputed Statements and a Notice of Arbitration from Eni USA, one of the two companies that had entered into a terminal use agreement for capacity of the liquefied natural gas facility owned by Gulf LNG and its subsidiaries. On June 29, 2018, the arbitration panel delivered its award, and the panel's ruling calls for the termination of the agreement and Eni USA's payment of compensation to Gulf LNG. On September 25, 2018, Gulf LNG filed a lawsuit against Eni USA in the Delaware Court of Chancery to enforce the award. Further, on September 28, 2018, Gulf LNG filed a lawsuit against Eni S.p.A. in the Supreme Court of the State of New York in New York County to enforce a guarantee agreement entered by Eni S.p.A. in connection with the terminal use agreement.

During the third quarter of 2018, the fair value of the Lightfoot investment was reduced to zero due to additional market information. In the fourth quarter of 2018, the Company received a distribution representing a return of capital totaling approximately $667 thousand due to the disposition of the remaining asset interest. The Company recognized a realized loss of $1.1 million for the year ended December 31, 2018. The loss is recorded in net realized and unrealized gain (loss) on other equity securities in the Consolidated Statements of Income.

Joliet

As of December 31, 2017, the Company owned a 0.6 percent interest in Joliet, which was acquired in conjunction with the terms of Zenith's acquisition of Arc Logistics discussed above.

On December 21, 2018, the Company sold its interest in Joliet, along with the Portland Terminal Facility, to Zenith Terminals for approximately $446 thousand. The sale resulted in a realized loss on other equity securities of approximately $715 thousand included in net realized and unrealized gain (loss) on other equity securities in the Consolidated Statements of Income for the year ended December 31, 2018.

The fair value of the Company's private company investments at December 31, 2017 was approximately $3.0 million, which was determined using recent transaction data and expected proceeds, discounted using a risk-free rate through the expected receipt date. Due to the inherent uncertainty of determining the fair value of investments that do not have a readily available market value, the fair value of the Company's investment may fluctuate from period to period. Additionally, the fair value of the Company's investment may differ from the values that would have been used had a ready market existed for such investment and may differ materially from the values that the Company may ultimately realize.

The following section describes the valuation methodologies used by the Company for estimating fair value for financial instruments not recorded at fair value, but fair value is included for disclosure purposes only, as required under disclosure guidance related to the fair value of financial instruments.

Cash and Cash Equivalents — The carrying value of cash, amounts due from banks, federal funds sold and securities purchased under resale agreements approximates fair value.

Financing Notes Receivable — The financing notes receivable are valued on a non-recurring basis. The financing notes receivable are reviewed for impairment when events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Financing Notes with carrying values that are not expected to be recovered through future cash flows are written-down to their estimated net realizable value. Estimates of realizable value are determined based on unobservable inputs, including estimates of future cash flow generation and value of collateral underlying the notes.

Secured Credit Facilities — The fair value of the Company's long-term variable-rate and fixed-rate debt under its secured credit facilities approximates carrying value.

Unsecured Convertible Senior Notes — The fair value of the unsecured convertible senior notes is estimated using quoted market prices.

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Carrying and Fair Value Amounts
	Level within Fair Value Hierarchy	December 31, 2018				December 31, 2017
		Carrying Amount (1)		Fair Value		Carrying Amount (1)		Fair Value
Financial Assets:
Cash and cash equivalents	Level 1	$	69,287,177	$	69,287,177	$	15,787,069	$	15,787,069
Financing notes receivable (Note 5)	Level 3	1,300,000		1,300,000		1,500,000		1,500,000
Financial Liabilities:
Secured credit facilities	Level 2	$	37,261,109	$	37,261,109	$	40,745,354	$	40,745,354
Unsecured convertible senior notes	Level 1	112,777,271		119,378,982		112,032,083		139,101,660
(1) The carrying value of debt balances are presented net of unamortized original issuance discount and debt issuance costs.

11.DEBT

The following is a summary of debt facilities and balances as of December 31, 2018 and 2017:

	Total Commitment  or Original Principal		Quarterly Principal Payments			December 31, 2018				December 31, 2017
					Maturity Date	Amount Outstanding		Interest Rate		Amount Outstanding		Interest Rate
CorEnergy Secured Credit Facility:
CorEnergy Revolver	$	160,000,000	$	—	7/28/2022	$	—	5.25	%	$	—	4.32	%
MoGas Revolver	1,000,000		—		7/28/2022	—		5.25	%	—		4.32	%
Omega Line of Credit	1,500,000		—		7/31/2019	—		6.50	%	—		5.57	%
Pinedale Secured Credit Facility:
Amended Pinedale Term Credit Facility	41,000,000		882,000		12/29/2022	37,472,000		6.50	%	41,000,000		6.50	%
7.00% Unsecured Convertible Senior Notes	115,000,000		—		6/15/2020	113,958,000		7.00	%	114,000,000		7.00	%
Total Debt						$	151,430,000			$	155,000,000
Less:
Unamortized deferred financing costs (1)						$	283,278			$	375,309
Unamortized discount on 7.00% Convertible Senior Notes						1,108,342				1,847,254
Long-term debt, net of deferred financing costs						$	150,038,380			$	152,777,437
Debt due within one year						$	3,528,000			$	3,528,000
(1) Unamortized deferred financing costs related to the Company's revolving credit facilities are included in Deferred Costs in the Assets section of the Consolidated Balance Sheets. Refer to the "Deferred Financing Costs" paragraph below.

CorEnergy Credit Facilities

On July 8, 2015, the Company amended and upsized its then current $93.0 million credit facility with Regions Bank (as lender and administrative agent for the other participating lenders) to provide borrowing commitments of $153.0 million, consisting of (i) an increase in the CorEnergy Revolver at the CorEnergy parent entity level to $105.0 million, (ii) a $45.0 million term loan at the CorEnergy parent entity level (the "CorEnergy Term Loan") and (iii) a $3.0 million revolving credit facility at the MoGas subsidiary entity level (the "MoGas Revolver" and, collectively with the upsized CorEnergy Revolver and the CorEnergy Term Loan, the "CorEnergy Credit Facility"). Upon closing the CorEnergy Credit Facility, CorEnergy drew $45.0 million on the CorEnergy Term Loan to pay off the balance on the CorEnergy Revolver that had been used in funding the GIGS acquisition in June 2015. The term note required quarterly principal payments of $900 thousand, which began on September 30, 2015. Quarterly principal payments were subsequently increased to $1.6 million in conjunction with the financing of the Pinedale Credit Facility, discussed further below.

On July 28, 2017, the Company entered into an amendment and restatement of the CorEnergy Credit Facility with Regions Bank (as lender and administrative agent for other participating lenders). The amended facility provides for borrowing commitments of up to $161.0 million, consisting of (i) $160.0 million on the CorEnergy Revolver, subject to borrowing base limitations, and (ii) $1.0 million on the MoGas Revolver, as detailed below. In connection with entering into the amended and restated facility on July 28, 2017, the Company used cash on hand and $10.0 million of borrowings under the amended facility to repay the $33.5 million outstanding balance on the CorEnergy Term Loan.

The amended facility has 5-year term maturing on July 28, 2022, and provides for a springing maturity on February 28, 2020, and thereafter, if the Company fails to meet certain liquidity requirements from the springing maturity date through the maturity of the Company's convertible notes on June 15, 2020. Borrowings under the credit facility will generally bear interest on the outstanding

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principal amount using a LIBOR pricing grid that is expected to equal a LIBOR rate plus an applicable margin of 2.75 percent to 3.75 percent, based on the Company's senior secured recourse leverage ratio. Total availability is subject to a borrowing base. The CorEnergy Credit Facility contains, among other restrictions, certain financial covenants including the maintenance of certain financial ratios, as well as default and cross-default provisions customary for transactions of this nature (with applicable customary grace periods).

The CorEnergy Credit Facility is secured by substantially all of the assets owned by the Company and its subsidiaries other than (i) the assets held by Mowood, LLC, Omega, Pinedale LP and Pinedale GP (the "Unrestricted Subs") and (ii) the equity investments in the Unrestricted Subs.

As of December 31, 2018, the Company was in compliance with all covenants of the CorEnergy Credit Facility, and the Company had approximately $122.7 million of availability.

MoGas Revolver

In conjunction with the MoGas Transaction, MoGas and United Property Systems, as co-borrowers, entered into a revolving credit agreement dated November 24, 2014 ("the MoGas Revolver") with certain lenders, including Regions Bank as agent for such lenders. Following subsequent amendments and restatements made on July 8, 2015 and July 28, 2017, in connection with the amendments and restatements of the CorEnergy Credit Facility discussed above, commitments under the MoGas Revolver were reduced from the original level of $3.0 million to a current total of $1.0 million.

The MoGas Revolver is secured by the assets held at MoGas and has a maturity date of July 28, 2022. Interest accrues under the MoGas Revolver at the same rate and pursuant to the same terms as it accrues under the CorEnergy Revolver. As of December 31, 2018, the co-borrowers were in compliance with all covenants, and there were no borrowings against the MoGas Revolver.

Mowood/Omega Revolver

On July 31, 2015, a $1.5 million revolving line of credit ("Mowood/Omega Revolver") was established with Regions Bank with a maturity date of July 31, 2016. Following annual extensions, the current maturity of the facility has been amended and extended to July 31, 2019. The Mowood/Omega Revolver is used by Omega for working capital and general business purposes and is guaranteed and secured by the assets of Omega. Interest accrues at LIBOR plus 4 percent and is payable monthly in arrears with no unused fee. There was no outstanding balance at December 31, 2018.

Amended Pinedale Term Credit Facility

On December 20, 2012, Pinedale LP closed on a $70.0 million secured term credit facility. Outstanding balances under the original facility generally accrued interest at a variable annual rate equal to LIBOR plus 3.25 percent. This credit facility was secured by the Pinedale LGS asset. Under the original agreement, Pinedale LP was obligated to pay all accrued interest monthly and was further obligated to make monthly principal payments, which began on March 7, 2014, in the amount of $294 thousand or 0.42 percent of the principal balance as of March 1, 2014. The credit facility remained in effect until December 31, 2015, with an option to extend through December 31, 2016. Although the Company elected not to extend the facility for an additional one-year period, it did amend the facility to extend the maturity date to March 30, 2016. During the extension period, the Company made principal payments of $3.2 million and the credit facility bore interest on the outstanding principal amount at LIBOR plus 4.25 percent.

On March 4, 2016, the Company obtained a consent from its lenders under the CorEnergy Credit Facility, which permitted the Company to utilize the CorEnergy Credit Facility to refinance the Company's pro rata share of the remaining balance of the Pinedale secured term credit facility. On March 30, 2016, the Company and Prudential (collectively, "the Refinancing Lenders"), refinanced the remaining $58.5 million principal balance of the $70.0 million credit facility (on a pro rata basis equal to their respective equity interests in Pinedale LP, with the Company's 81.05 percent share being approximately $47.4 million) and executed a series of agreements assigning the credit facility to the Refinancing Lenders, with CorEnergy Infrastructure Trust, Inc. as Agent for the Refinancing Lenders. The facility was further modified to extend the maturity date to March 30, 2021; to increase the LIBOR Rate to the greater of (i) 1.00 percent and (ii) the one-month LIBOR rate; and to increase the LIBOR Rate Spread to 7.00 percent per annum. The Company's portion of the debt and interest was eliminated in consolidation and Prudential's portion of the debt was shown as a related-party liability.

Pinedale LP automatically entered into a Cash Control Period (as defined in the credit facility) with the Refinancing Lenders upon the April 29, 2016 bankruptcy filing by Ultra Wyoming and its parent guarantor, Ultra Petroleum. During a Cash Control Period, the Company as Agent swept all funds for the repayment of accrued interest, scheduled principal payments and principal prepayments on the loans. Ultra Petroleum emerged from bankruptcy in April 2017, resulting in the end of the Cash Control Period and, in May 2017, Pinedale LP resumed distributions. For the years ended December 31, 2017 and 2016, pursuant to these additional

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cash sweep provisions, an additional $4.4 million and $9.1 million, respectively, was distributed (pro rata, based on ownership percentages) to the Refinancing Lenders as a reduction to the outstanding principal.

On December 29, 2017, Pinedale LP entered into the Amended Pinedale Term Credit Facility with Prudential and a group of lenders affiliated with Prudential as the sole lenders and Prudential serving as administrative agent. Under the terms of the Amended Term Credit Facility, Pinedale LP was provided with a 5-year $41.0 million term loan facility, bearing interest at a fixed rate of 6.5 percent, which matures on December 29, 2022. Principal payments of $294 thousand, plus accrued interest, are payable monthly. The Amended Pinedale Term Credit Facility was utilized to pay off the balance due to the Refinancing Lenders under the previously existing Pinedale LP credit facility.

Outstanding balances under the facility are secured by the Pinedale LGS assets. The Amended Pinedale Term Credit Facility contains, among other restrictions, specific financial covenants including the maintenance of certain financial coverage ratios and a minimum net worth requirement which, along with other provisions of the credit facility, limit cash dividends and loans by Pinedale LP to the Company. At December 31, 2018, the net assets of Pinedale LP were $137.0 million and Pinedale LP was in compliance with all of the financial covenants of the Amended Pinedale Term Credit Facility.

Deferred Financing Costs

A summary of deferred financing cost amortization expenses for the years ended December 31, 2018, 2017 and 2016 is as follows:

Deferred Financing Cost Amortization Expense (1)(2)
	For the Years Ended December 31,
	2018		2017		2016
CorEnergy Credit Facility	$	574,541	$	873,601	$	1,078,526
Amended Pinedale Term Credit Facility	52,728		392		156,330
Total Deferred Debt Cost Amortization	$	627,269	$	873,993	$	1,234,856
(1) Amortization of deferred debt issuance costs is included in interest expense in the Consolidated Statements of Income.
(2) For the amount of deferred debt costs amortization relating to the Convertible Notes included in the Consolidated Statements of Income, refer to the Convertible Note Interest Expense table below.

CorEnergy Credit Facilities

Prior to the July 28, 2017 credit facility amendment and restatement, previously existing deferred financing costs related to the CorEnergy Credit Facility were approximately $1.8 million, of which approximately $1.6 million continue to be deferred and amortized under the amended and restated facility. Additionally, the Company incurred approximately $1.3 million in new debt issuance costs which have been deferred and are being amortized over the term of the new facility. The total deferred financing costs of $2.9 million are being amortized on a straight-line basis over the 5-year term of the amended and restated CorEnergy Credit Facility. Approximately $234 thousand of existing deferred costs and new debt issuance costs were expensed as a loss on extinguishment of debt related to the amendment and restatement in the Consolidated Statements of Income for the year ended December 31, 2017.

Amended Pinedale Term Credit Facility

In connection with entering into the Amended Pinedale Term Credit Facility, Pinedale LP incurred approximately $367 thousand in new debt issuance costs, of which $264 thousand were deferred and are being amortized on a straight-line basis over the 5-year term of the Amended Pinedale Term Credit Facility. The remaining $103 thousand was expensed as a loss on extinguishment of debt in the Consolidated Statements of Income for the year ended December 31, 2017.

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Contractual Payments

The remaining contractual principal payments as of December 31, 2018 under the Amended Pinedale Term Credit Facility are as follows:

Year	Amended Pinedale Term Credit Facility
2019	$	3,528,000
2020	3,528,000
2021	3,528,000
2022	26,888,000
2023	—
Thereafter	—
Total	$	37,472,000

Convertible Debt

On June 29, 2015, the Company completed a public offering of $115.0 million aggregate principal amount of 7.00% Convertible Senior Notes Due 2020 (the "Convertible Notes"). The Convertible Notes mature on June 15, 2020 and bear interest at a rate of 7.0 percent per annum, payable semi-annually in arrears on June 15 and December 15 of each year, beginning on December 15, 2015.

Holders may convert their Convertible Notes into shares of the Company's common stock at their option until the close of business on the second scheduled trading day immediately preceding the maturity date. The initial conversion rate for the Convertible Notes will be 30.3030 shares of Common Stock per $1,000 principal amount of the Convertible Notes, equivalent to an initial conversion price of $33.00 per share of Common Stock. Such conversion rate will be subject to adjustment in certain events as specified in the Indenture. During the year ended December 31, 2018, certain holders elected to convert approximately $42 thousand of Convertible Notes for 1,271 shares of CorEnergy common stock.

The Convertible Notes currently may not be redeemed prior to the maturity date without the consent of the agent and lenders under the CorEnergy Credit Facility. However, upon the occurrence of a fundamental change (as defined in the Indenture), holders may require the Company to repurchase all or a portion of the Convertible Notes for cash at a price equal to 100 percent of the principal amount of the Convertible Notes to be purchased plus any accrued and unpaid interest, if any, to, but excluding, the applicable fundamental change repurchase date as prescribed in the Indenture. In addition, in certain circumstances the Company will increase the conversion rate for a holder that converts the Convertible Notes in connection with any of a specified set of corporate events, each of which is deemed to constitute a make whole adjustment event pursuant to the terms of the Indenture.

The Convertible Notes rank equal in right of payment to any other current and future unsecured obligations of the Company and senior in right of payment to any other current and future indebtedness of the Company that is contractually subordinated to the Convertible Notes. The Convertible Notes are structurally subordinated to all liabilities (including trade payables) of the Company's subsidiaries. The Convertible Notes are effectively junior to all of the Company's existing or future secured debt, to the extent of the value of the collateral securing such debt.

On May 23, 2016, the Company repurchased $1.0 million of its Convertible Notes on the open market. This resulted in the Company writing off a portion of the original underwriter's discount and deferred debt costs, as well as recognizing a gain on extinguishment of debt of $72 thousand which is included in interest expense in the Consolidated Statements of Income for the year ended December 31, 2016. As of December 31, 2018, the Company had approximately $114.0 million of face value of the Convertible Notes outstanding. Refer to Note 17 ("Subsequent Events")for information regarding the exchange of Convertible Notes for cash and common stock, with the requisite consent of the agent and lenders under the CorEnergy Credit Facility, subsequent to December 31, 2018.

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The following is a summary of the impact of Convertible Notes on interest expense for the years ended December 31, 2018, 2017 and 2016:

Convertible Note Interest Expense
	For the Years Ended December 31,
	2018		2017		2016
7.00% Convertible Notes	$	7,979,118	$	7,980,000	$	8,008,195
Discount Amortization	738,912		738,912		744,081
Deferred Debt Issuance Cost Amortization	48,276		48,276		48,566
Total	$	8,766,306	$	8,767,188	$	8,800,842

The Convertible Notes were initially issued with an underwriters' discount of $3.7 million which is being amortized over the life of the Convertible Notes. Additionally, the Company incurred approximately $241 thousand in debt issuance costs associated with the Convertible Notes which are being amortized over the life of the notes. Including the impact of the convertible debt discount and related deferred debt issuance costs, the effective interest rate on the Convertible Notes was approximately 7.7 percent for each of the years ended December 31, 2018, 2017 and 2016.

12.ASSET RETIREMENT OBLIGATION

A component of the consideration exchanged to purchase the GIGS assets in June 2015 was the assumption of the seller's asset retirement obligation ("ARO") associated with such assets. The ARO represents the estimated costs of decommissioning the GIGS pipelines and onshore oil receiving and separation facilities in Grand Isle, Louisiana at retirement. The Company recognized the ARO at its estimated fair value on the date of acquisition with a corresponding ARO asset capitalized as part of the carrying amount of the related long-lived assets to be depreciated over the assets' remaining useful lives.

The Company's tenant, EGC Tenant, has an ARO related to the platform which is currently attached to the GIGS pipelines. If in the future, EGC Tenant is unable to fulfill their obligation, the Company may be required to assume the liability for the related asset removal costs.

In periods subsequent to the initial measurement of an ARO, the Company recognizes changes in the liability resulting from (a) the passage of time through accretion expense and (b) revisions to either the timing or the amount of the estimate of undiscounted cash flows based on periodic revaluations. Future expected cash flows are based on subjective estimates and assumptions, which inherently include significant uncertainties which are beyond the Company's control. These assumptions represent Level 3 inputs in the fair value hierarchy. The Company has no assets that are legally restricted for purposes of settling asset retirement obligations.

In December 2018 and 2017, the Company revised its estimates to reflect a decrease in (i) marketplace rates for labor and other costs, (ii) for the expected timing of work and for (iii) recent decommissioning estimates. During the fourth quarter of 2018, the Company decommissioned a segment of the GIGS pipeline system. The Company incurred decommissioning costs of approximately $939 thousand compared to the estimated segment ARO liability of $628 thousand resulting in a loss on settlement of ARO of $311 thousand. The loss on settlement of ARO is recorded in general and administrative expenses in the Consolidated Statements of Income for the year ended December 31, 2018. For the year ended December 31, 2017, the change in estimate did not result in any charge to income.

The following table is a reconciliation of the asset retirement obligation as of December 31, 2018 and 2017:

Asset Retirement Obligation
	For the Years Ended December 31,
	2018			2017
Beginning asset retirement obligation	$	9,170,493		$	11,882,943
Liabilities assumed	—			—
ARO accretion expense	499,562			663,065
Liabilities settled	(628,300		)	—
Revision in cash flow estimates	(1,085,412		)	(3,375,515		)
Ending asset retirement obligation	$	7,956,343		$	9,170,493

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13.INTEREST RATE HEDGE SWAPS

Derivative Instruments and Hedging Activities

The Company has historically used interest rate swaps to add stability to interest expense and to manage its exposure to interest rate movements. In February 2013, the Company entered into two interest rate swap agreements associated with a portion of its variable rate debt under the $70.0 million Pinedale Credit Facility, as discussed further in Note 11 ("Debt"). The notional amount covered under these agreements totaled $52.5 million (split evenly between the two agreements). Under the terms of the interest rate swap agreements, the Company received a floating rate based on the one-month LIBOR and paid a fixed rate of 0.865%. Each of the swap agreements was set to expire in December 2017. The agreements were designated as cash flow hedges at inception and accordingly, the effective portion of the gain or loss on the swap was reported as a component of accumulated other comprehensive income ("AOCI") and was reclassified into interest expense when the interest rate swap transaction affected earnings. Any ineffective portion of the gain or loss was recognized immediately in interest expense.

On March 30, 2016, the Company restructured the Pinedale Credit Facility, as further discussed in Note 11 ("Debt"). In connection with the assignment of the Pinedale Credit Facility, the Company terminated one of the interest rate swap agreements with a notional amount of $26.3 million and the remaining interest rate swap with a notional amount of $26.3 million was de-designated from hedge accounting. The remaining derivative expired in December 2017.

The table below presents the effect of the Company's derivative financial instruments on the Consolidated Statements of Income and Comprehensive Income for the years ended December 31, 2017 and 2016 (note that the ineffective portion is not presented as it was inconsequential for all periods presented):

	For the Years Ended December 31,
Derivatives in Cash Flow Hedging Relationship	2017		2016
Amount of Loss on Derivatives Recognized in AOCI (Effective Portion)	$	—	$	(300,181	)
Amount of Loss on Derivatives Reclassified from AOCI (Effective Portion) Recognized in Net Income(1)	—		(50,964		)
Derivatives Not Designated as Hedging Instruments
Amount of Gain on Derivatives Recognized in Income(2)	$	25,842	$	73,204
(1) Included in "Interest Expense" on the face of the Consolidated Statements of Income and Comprehensive Income.
(2) The gains recognized in income on derivatives include changes in fair value for derivatives subsequent to de-designation from hedge accounting.

14.STOCKHOLDERS' EQUITY

PREFERRED STOCK

The Company's authorized preferred stock consists of 10.0 million shares having a par value of $0.001 per share. On January 27, 2015, the Company sold, in an underwritten public offering, 2,250,000 depositary shares, each representing 1/100th of a share of 7.375% Series A Cumulative Redeemable Preferred Stock ("Series A Preferred Stock"). Pursuant to this offering, the Company issued 22,500 whole shares of Series A Preferred Stock and received net cash proceeds of approximately $54.2 million.

On April 18, 2017, the Company closed a follow-on underwritten public offering of 2,800,000 depository shares, each representing 1/100th of a share of 7.375% Series A Preferred Stock, at a price of $25.00 per depository share. On May 10, 2017, the Company sold an additional 150,000 depository shares at a public offering price of $25.00 per depository share in connection with the underwriters' exercise of their over-allotment option to purchase additional shares. Total proceeds from the offering were approximately $71.2 million, after deducting underwriting discounts and other offering expenses. A portion of the proceeds from the offering were utilized to repay $44.0 million in outstanding borrowings under the CorEnergy Revolver. Following the offering, the Company had a total of 5,200,000 depository shares outstanding, or 52,000 whole shares.

The depositary shares pay an annual dividend of $1.84375 per share, equivalent to 7.375 percent of the $25.00 liquidation preference. The depositary shares may be redeemed on or after January 27, 2020, at the Company's option, in whole or in part, at the $25.00 liquidation preference plus all accrued and unpaid dividends to, but not including, the date of redemption. The depositary shares have no stated maturity, are not subject to any sinking fund or mandatory redemption and are not convertible into any other securities of the Company except in connection with certain changes of control. Holders of the depositary shares generally have no voting rights, except for limited voting rights if the Company fails to pay dividends for six or more quarters (whether or not consecutive) and in certain other circumstances. The depositary shares representing the Series A Preferred Stock trade on the NYSE under the ticker "CORRPrA."

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The Company's Board of Directors authorized a share repurchase program for the Company to buy up to $10.0 million of its depository shares of Series A Preferred Stock, which commenced August 6, 2018. Purchases may be made through the program through August 5, 2019. During 2018, the Company repurchased 177,773 depository shares for approximately $4.3 million in cash. As of December 31, 2018, the Company had a total of 5,022,227 depository shares outstanding, or approximately 50,222 whole shares, with an aggregate par value of $50.22.

See Note 17 ("Subsequent Events"), for further information regarding the declaration of a dividend on the Series A Preferred Stock and for details of Series A Preferred Stock repurchases subsequent to December 31, 2018.

COMMON STOCK

On December 31, 2015, the Company's Board of Directors authorized a share repurchase program for the Company to buy up to $10.0 million of its common stock. During 2016, the Company repurchased 90,613 shares for approximately $2.0 million in cash. Under the program, which expired December 31, 2016, the Company was authorized to repurchase shares from time to time through open market transactions, including through block purchases, privately negotiated transactions, or otherwise. There were no such repurchases in 2017 or 2018. As of December 31, 2018, the Company had 11,960,225 of common shares issued and outstanding. See Note 17 ("Subsequent Events"), for further information regarding the declaration of a dividend on the common stock.

SHELF REGISTRATION

On October 30, 2018, the Company filed a shelf registration statement with the SEC, pursuant to which it registered 1,000,000 shares of common stock for issuance under its dividend reinvestment plan. As of December 31, 2018, we have issued 10,927 shares of common stock under our dividend reinvestment plan pursuant to the shelf resulting in remaining availability of approximately 989,073 shares of common stock.

On November 9, 2018, the Company had a new shelf registration statement declared effective by the SEC replacing the Company's previously filed shelf registration statement, pursuant to which it may publicly offer additional debt or equity securities with an aggregate offering price of up to $600.0 million. As of December 31, 2018, the Company has not issued any securities under this new shelf registration statement, so total availability remains at $600.0 million.

15.EARNINGS PER SHARE

Basic earnings per share data is computed based on the weighted-average number of shares of common stock outstanding during the periods. Diluted EPS data is computed based on the weighted-average number of shares of common stock outstanding, including all potentially issuable shares of common stock. For the year ended December 31, 2018, the dilutive shares include 3,453,273 common shares outstanding from the if-converted method for the 7.00% Convertible Notes. Diluted EPS for the years ended December 31, 2017 and 2016 exclude the impact to income and to the potential number of shares outstanding from the conversion of the 7.00% Convertible Notes because such impact is antidilutive. If converted, the 7.00% Convertible Notes would result in an additional 3,454,545 common shares outstanding for the years ended December 31, 2017 and 2016.

Earnings Per Share
	For the Years Ended December 31,
	2018		2017		2016
Net income attributable to CorEnergy stockholders	$	43,711,876	$	32,602,790	$	29,663,200
Less: preferred dividend requirements(1)	9,548,377		7,953,988		4,148,437
Net income attributable to common stockholders	$	34,163,499	$	24,648,802	$	25,514,763
Weighted average shares - basic	11,935,021		11,900,516		11,901,985
Basic earnings per share	$	2.86	$	2.07	$	2.14
Net income attributable to common stockholders (from above)	$	34,163,499	$	24,648,802	$	25,514,763
Add: After tax effect of convertible interest	8,766,306		—		—
Income attributable for dilutive securities	$	42,929,805	$	24,648,802	$	25,514,763
Weighted average shares - diluted	15,389,180		11,900,516		11,901,985
Diluted earnings per share	$	2.79	$	2.07	$	2.14
(1) In connection with the repurchases of Series A Preferred Stock during the year ended December 31, 2018, preferred dividend requirements were reduced by $10,554 representing the discount in the repurchase price paid compared to the carrying amount derecognized.

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16.QUARTERLY FINANCIAL DATA (Unaudited)

	For the Fiscal 2018 Quarters Ended
	March 31			June 30			September 30			December 31
Revenue
Lease revenue	$	17,591,859		$	18,275,859		$	18,391,983		$	18,487,661
Transportation and distribution revenue	3,952,979			3,874,157			4,244,722			4,412,378
Total Revenue	21,544,838			22,150,016			22,636,705			22,900,039
Expenses
Transportation and distribution expenses	1,572,896			1,534,524			2,241,999			1,861,329
General and administrative	2,727,057			3,107,776			3,046,481			4,161,533
Depreciation, amortization and ARO accretion expense	6,289,330			6,290,082			6,289,459			6,078,582
Provision for loan (gain) loss	500,000			—			—			(536,867		)
Total Expenses	11,089,283			10,932,382			11,577,939			11,564,577
Operating Income	$	10,455,555		$	11,217,634		$	11,058,766		$	11,335,462
Other Income (Expense)
Net distributions and dividend income	$	3,951		$	55,714		$	5,627		$	41,503
Net realized and unrealized gain (loss) on other equity securities	13,966			(881,100		)	(930,147		)	(48,028		)
Interest expense	(3,210,590		)	(3,196,248		)	(3,183,589		)	(3,168,583		)
Gain on the sale of leased property, net	—			—			—			11,723,257
Total Other Income (Expense)	(3,192,673		)	(4,021,634		)	(4,108,109		)	8,548,149
Income before income taxes	7,262,882			7,196,000			6,950,657			19,883,611
Taxes
Current tax benefit	(35,549		)	(10,785		)	(8,393		)	(530,659		)
Deferred tax benefit	(409,277		)	(604,064		)	(738,274		)	(81,725		)
Income tax benefit, net	(444,826		)	(614,849		)	(746,667		)	(612,384		)
Net Income attributable to CorEnergy Stockholders	$	7,707,708		$	7,810,849		$	7,697,324		$	20,495,995
Preferred dividend requirements	2,396,875			2,396,875			2,396,875			2,357,752
Net Income attributable to Common Stockholders	$	5,310,833		$	5,413,974		$	5,300,449		$	18,138,243
Earnings Per Common Share:
Basic	$	0.45		$	0.45		$	0.44		$	1.52
Diluted	$	0.45		$	0.45		$	0.44		$	1.32

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	For the Fiscal 2017 Quarters Ended
	March 31			June 30			September 30			December 31
Revenue
Lease revenue	$	17,066,526		$	17,050,092		$	17,173,676		$	17,513,510
Transportation and distribution revenue	5,010,590			4,775,780			5,270,628			4,888,575
Total Revenue	22,077,116			21,825,872			22,444,304			22,402,085
Expenses
Transportation and distribution expenses	1,335,570			1,362,980			2,384,182			1,646,975
General and administrative	3,061,240			2,558,339			2,632,546			2,534,372
Depreciation, amortization and ARO accretion expense	6,005,908			6,005,995			6,017,664			6,018,143
Total Expenses	10,402,718			9,927,314			11,034,392			10,199,490
Operating Income	$	11,674,398		$	11,898,558		$	11,409,912		$	12,202,595
Other Income (Expense)
Net distributions and dividend income	$	43,462		$	221,440		$	213,040		$	202,149
Net realized and unrealized gain (loss) on other equity securities	(544,208		)	614,634			1,340,197			121,204
Interest expense	(3,454,397		)	(3,202,837		)	(2,928,036		)	(2,793,245		)
Loss on extinguishment of debt	—			—			(234,433		)	(102,500		)
Total Other Expense	(3,955,143		)	(2,366,763		)	(1,609,232		)	(2,572,392		)
Income before income taxes	7,719,255			9,531,795			9,800,680			9,630,203
Taxes
Current tax expense (benefit)	(33,760		)	57,651			65,131			2,742,636
Deferred tax expense (benefit)	(298,846		)	38,084			126,440			(352,018		)
Income tax expense (benefit), net	(332,606		)	95,735			191,571			2,390,618
Net Income	8,051,861			9,436,060			9,609,109			7,239,585
Less: Net Income attributable to non-controlling interest	382,383			435,888			431,825			483,730
Net Income attributable to CorEnergy Stockholders	$	7,669,478		$	9,000,172		$	9,177,284		$	6,755,855
Preferred dividend requirements	1,037,109			2,123,129			2,396,875			2,396,875
Net Income attributable to Common Stockholders	$	6,632,369		$	6,877,043		$	6,780,409		$	4,358,980
Earnings Per Common Share:
Basic	$	0.56		$	0.58		$	0.57		$	0.37
Diluted	$	0.56		$	0.58		$	0.57		$	0.37

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17.SUBSEQUENT EVENTS

The Company performed an evaluation of subsequent events through the date of the issuance of these financial statements and determined that no additional items require recognition or disclosure, except for the following:

Preferred Stock Repurchase

On January 9, 2019, the Company repurchased 2,500 depository shares of Series A Preferred Stock for approximately $61 thousand in cash. Subsequent to the repurchase, the Company had a total of 5,019,727 depository shares outstanding, or approximately 50,197 whole shares.

Convertible Note Exchange

On January 16, 2019, the Company agreed with three holders of its Convertible Notes, pursuant to privately negotiated agreements, to exchange $43.8 million face amount of such notes for an aggregate of 837,040 shares of the Company's common stock, par value $0.001 per share, plus aggregate cash consideration of $19.8 million. The Company's agent and lenders under the CorEnergy Credit Facility provided a consent for the convertible note exchange, subject to certain conditions. Subsequent to the exchange, the Company had approximately $70.2 million of face value of the Convertible Notes outstanding. The Company will record a loss on extinguishment of debt of approximately $5.0 million in the Consolidated Statements of Income for the first quarter of 2019.

Common Stock Dividend

On January 23, 2019, the Company's Board of Directors declared a 2018 fourth quarter dividend of $0.75 per share for CorEnergy common stock. The dividend was paid on February 28, 2019, to stockholders of record on February 14, 2019.

Preferred Stock Dividend

On January 23, 2019, the Company's Board of Directors also declared a dividend of $0.4609375 per depositary share for its 7.375% Series A Preferred Stock. The preferred stock dividend was paid on February 28, 2019, to stockholders of record on February 14, 2019.

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT

CorEnergy Infrastructure Trust, Inc.

CONDENSED BALANCE SHEETS	December 31, 2018		December 31, 2017
Assets
Leased property, net of accumulated depreciation of $1,112,218 and $927,838	$	3,681,438	$	3,865,818
Investments	415,674,601		479,840,250
Cash and cash equivalents	64,574,701		6,662,474
Due from subsidiary	10,549,719		7,302,678
Note receivable from subsidiary	81,000,000		83,250,000
Deferred costs, net of accumulated amortization of $712,182 and $226,342	1,769,585		2,255,425
Prepaid expenses and other assets	265,024		197,211
Total Assets	$	577,515,068	$	583,373,856
Liabilities and Equity
Unsecured convertible senior notes, net of discount and debt issuance costs of $1,180,729 and $1,967,917	112,777,271		112,032,083
Accounts payable and other accrued liabilities	1,075,045		987,881
Management fees payable	1,831,613		1,748,426
Due to affiliate	153,640		153,640
Total Liabilities	$	115,837,569	$	114,922,030
Equity
Series A Cumulative Redeemable Preferred Stock 7.375%, $125,555,675 and $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 50,222 and 52,000 issued and outstanding at December 31, 2018 and December 31, 2017, respectively	$	125,555,675	$	130,000,000
Capital stock, non-convertible, $0.001 par value; 11,960,225 and 11,915,830 shares issued and outstanding at December 31, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,960		11,916
Additional paid-in capital	326,962,163		338,439,910
Retained earnings	9,147,701		—
Total Equity	461,677,499		468,451,826
Total Liabilities and Equity	$	577,515,068	$	583,373,856
See accompanying Schedule I Notes to Condensed Financial Statements.

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - CorEnergy Infrastructure Trust, Inc. - Continued

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME	For the Years Ended December 31,
	2018			2017			2016
Revenue
Earnings from subsidiary	$	48,353,177		$	36,222,221		$	32,856,338
Total Revenue	48,353,177			36,222,221			32,856,338
Expenses
General and administrative	2,353,593			2,298,201			2,236,358
Depreciation expense	184,380			184,380			184,380
Amortization expense	5,316			5,316			5,316
Total Expenses	2,543,289			2,487,897			2,426,054
Operating Income	$	45,809,888		$	33,734,324		$	30,430,284
Other Income (Expense)
Net distributions and dividend income	$	56,827		$	96,866		$	12,963
Interest on loans to subsidiaries	7,903,104			11,549,344			11,705,465
Interest expense, net	(10,057,943		)	(11,451,944		)	(12,485,510		)
Loss on extinguishment of debt	—			(225,801		)	—
Total Other Expense	(2,098,012		)	(31,535		)	(767,082		)
Net Income	$	43,711,876		$	33,702,789		$	29,663,202
Other comprehensive income:
Changes in fair value of qualifying hedges	—			11,196			(201,993		)
Total Comprehensive Income	$	43,711,876		$	33,713,985		$	29,461,209
See accompanying Schedule I Notes to Condensed Financial Statements.

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - CorEnergy Infrastructure Trust, Inc. - Continued

CONDENSED STATEMENTS OF CASH FLOW	For the Years Ended December 31,
	2018			2017			2016
Net cash provided by (used in) operating activities	$	(6,257,124	)	$	1,661,123		$	(3,141,286	)
Investing Activities
Issuance of note to subsidiary	—			—			(47,414,250		)
Principal payments received from notes to subsidiaries	2,250,000			40,092,095			11,899,659
Investment in consolidated subsidiaries	(73,996		)	(33,900,000		)	—
Cash distributions from consolidated subsidiaries	110,140,459			46,774,111			39,139,897
Net cash provided by investing activities	$	112,316,463		$	52,966,206		$	3,625,306
Financing Activities
Debt financing costs	—			(1,360,241		)	(193,000		)
Net offering proceeds on Series A preferred stock	—			71,161,531			—
Repurchases of common stock	—			—			(2,041,851		)
Repurchases of convertible debt	—			—			(899,960		)
Repurchases of preferred stock debt	(4,275,553		)	—			—
Dividends paid on Series A preferred stock	(9,587,500		)	(8,227,734		)	(4,148,437		)
Dividends paid on common stock	(34,284,059		)	(34,731,892		)	(34,896,727		)
Advances on revolving line of credit	—			10,000,000			44,000,000
Payments on revolving line of credit	—			(54,000,000		)	—
Principal payments on term debt	—			(36,740,000		)	(6,460,000		)
Net cash used in financing activities	$	(48,147,112	)	$	(53,898,336	)	$	(4,639,975	)
Net Change in Cash and Cash Equivalents	$	57,912,227		$	728,993		$	(4,155,955	)
Cash and Cash Equivalents at beginning of period	6,662,474			5,933,481			10,089,436
Cash and Cash Equivalents at end of period	$	64,574,701		$	6,662,474		$	5,933,481
Supplemental Disclosure of Cash Flow Information
Interest Paid	$	8,794,086		$	10,080,764		$	11,335,654
Non-Cash Investing Activities
Conversion of note receivable from subsidiary to investments	$	—		$	4,902,495		$	—
Dissolution of investment in subsidiary upon liquidation	(73,996		)	—			—
Non-Cash Financing Activities
Common stock issued upon conversion of convertible notes	$	42,654		$	—		$	—
Reinvestment of distributions by common stockholders in additional common shares	1,509,830			962,308			815,889
See accompanying Schedule I Notes to Condensed Financial Statements.

NOTES TO SCHEDULE I CONDENSED FINANCIAL STATEMENTS

NOTE A - BASIS OF PRESENTATION

In the parent-company-only financial statements, the Company's investment in subsidiaries is stated at cost plus equity in undistributed earnings of subsidiaries since the date of acquisition. The parent-company-only financial statements should be read in conjunction with the Company's consolidated financial statements.

NOTE B - DIVIDENDS FROM SUBSIDIARIES

Cash dividends paid to CorEnergy Infrastructure Trust, Inc. from the Company's consolidated subsidiaries were $110.1 million, $46.8 million and $39.1 million for the years ended December 31, 2018, 2017 and 2016, respectively.

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SCHEDULE III - REAL ESTATE AND ACCUMULATED DEPRECIATION - CorEnergy Infrastructure Trust, Inc.

				Initial Cost to Company				Costs Capitalized Subsequent to Acquisition			Gross Amount Carried at Close of Period December 31, 2018
Description	Location	Encumbrances		Land		Building & Fixtures		Improvements / Adjustments (4)			Land		Building & Fixtures		Total		Accumulated Depreciation		Investment in Real Estate, net, at 12/31/18		Date Acquired	Life on which depreciation in latest income statement is computed
Pinedale LGS (1)(5)	Pinedale, WY	$	37,472,000	$	105,485,063	$	125,119,062	$	—		$	105,485,063	$	125,119,062	$	230,604,125	$	53,501,538	$	177,102,587	2012	26 years
United Property Systems (4)	St. Louis, MO	—		210,000		1,188,000		78,621			210,000		1,266,621		1,476,621		138,096		1,338,525		2014	40 years
Grand Isle Gathering System(2)(3)(4)	Gulf of Mexico	—		960,000		258,471,397		(6,143,693		)	960,000		252,327,704		253,287,704		33,514,461		219,773,243		2015	27 years
		$	37,472,000	$	106,655,063	$	384,778,459	$	(6,065,072	)	$	106,655,063	$	378,713,387	$	485,368,450	$	87,154,095	$	398,214,355
(1) In connection with the asset acquisition, CorEnergy and Pinedale LP incurred acquisition costs of $2,557,910, which are included in the total asset balance.
(2) In connection with the asset acquisition, Grand Isle Gathering System incurred acquisition costs of $1,931,396, which are included in the total asset balance.
(3) Initial costs associated with the GIGS asset include amounts capitalized related to an acquired asset retirement obligation (ARO). The negative subsequent adjustment relates to (i) downward revisions of the ARO based on periodic reevaluation as required under FASB ASC 410-20 and (ii) the settlement of a portion of the ARO when a segment of the GIGS pipeline system was decommissioned during the fourth quarter of 2018.
(4) These 2 properties serve as collateral under the CorEnergy Credit Facility. There are no amounts outstanding on the credit facility as of December 31, 2018.
(5) The amount outstanding for the Amended Pinedale Term Credit Facility is $37,472,000 as of December 31, 2018.

NOTES TO SCHEDULE III - CONSOLIDATED REAL ESTATE AND ACCUMULATED DEPRECIATION

Reconciliation of Real Estate and Accumulated Depreciation

	For the Years Ended December 31,
	2018			2017			2016
Investment in real estate:
Balance, beginning of year	$	538,112,220		$	541,478,086		$	543,095,478
Addition: Acquisitions and developments	3,599			9,649			65,371
Deduction: Dispositions and other(1)(2)	(52,747,369		)	(3,375,515		)	(1,682,763		)
Balance, end of year	$	485,368,450		$	538,112,220		$	541,478,086
Accumulated depreciation:
Balance, beginning of year	$	72,155,753		$	52,219,717		$	33,869,263
Addition: Depreciation	20,986,461			19,936,036			18,350,454
Deduction: Dispositions and other(2)	(5,988,119		)	—			—
Balance, end of year	$	87,154,095		$	72,155,753		$	52,219,717
(1) The Grand Isle Gathering System had a change in estimate related to the ARO in 2018, 2017 and 2016. Refer to Note 12 ("Asset Retirement Obligation") for further details.
(2) On December 21, 2018, the Company sold its Portland Terminal Facility with a net carrying value of $45.7 million (i.e. gross investment of $51.7 million less accumulated depreciation of $6.0 million). Refer to Note 3 ("Leased Properties and Leases") for further details.

The aggregate cost of the properties is approximately $4.2 million lower for federal income tax purposes at December 31, 2018. The tax basis of the properties is unaudited.

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SCHEDULE IV - MORTGAGE LOANS ON REAL ESTATE - CorEnergy Infrastructure Trust, Inc.

Description	Interest Rate	Final Maturity	Monthly Payment Amount		Prior Liens	Face Value		Carrying Amount of Mortgage		Principal Amount of Loans Subject to Delinquent Principal or Interest
First Mortgages
Billings, Dunn and McKenzie Counties, North Dakota (Morlock Well)	8.52%	6/15/2019	$	—	None	$	1,300,000	$	1,300,000	$	—
Total						$	1,300,000	$	1,300,000	$	—

NOTES TO SCHEDULE IV - CONSOLIDATED MORTGAGE LOANS ON REAL ESTATE

Reconciliation of Mortgage Loans on Real Estate

	For the Years Ended December 31,
	2018			2017		2016
Beginning balance	$	1,500,000		$	1,500,000	$	6,877,021
Additions:
New loans	—			—		100,000
Interest receivable(1)	—			—		(95,114		)
Total Additions	$	—		$	—	$	4,886
Deductions:
Principal repayments(2)	$	236,867		$	—	$	—
Foreclosures	—			—		1,857,000
Amortization of deferred costs	—			—		(2,025		)
Principal, Interest and Deferred Costs Write (Up) Down(2)(3)	(36,867		)	—		3,526,932
Total deductions	$	200,000		$	—	$	5,381,907
Ending balance	$	1,300,000		$	1,500,000	$	1,500,000
(1) In 2016, $100 thousand of interest receivable on the SWD Enterprises REIT note was converted to principal.
(2) In 2018, Four Wood Corridor and Compass SWD executed a $1.3 million loan agreement and Compass SWD paid approximately $237 thousand in cash for assets secured by the previous $1.5 million loans. As a result, SWD Enterprises was released from the terms of its loans, and the Company recognized a provision for loan gain of $37 thousand in the Consolidated Statements of Income. Refer to Note 5 ("Financing Notes Receivable") for further details.
(3) For 2016, the amount of provision for loan loss on the Consolidated Statements of Income also includes (a) $656 thousand of loan losses not related to mortgage loans and (b) $832 thousand of losses associated with the foreclosure and sale of Black Bison.

F-41

Table of Contents Index to Financial Statements Glossary of Defined Terms

ITEM 16. FORM 10-K SUMMARY

None.

CORENERGY INFRASTRUCTURE TRUST, INC.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.

CORENERGY INFRASTRUCTURE TRUST, INC.
	(Registrant)
By:	/s/ Rebecca M. Sandring
	Rebecca M. Sandring
	Chief Accounting Officer, Treasurer and Secretary (Principal Accounting and Principal Financial 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 and on the dates indicated.

SIGNATURE	TITLE	DATE
/s/ David J. Schulte	Chairman and Chief Executive Officer (Principal Executive Officer)	February 28, 2019
David J. Schulte
/s/ Rebecca M. Sandring	Chief Accounting Officer, Treasurer and Secretary (Principal Accounting and Principal Financial Officer)	February 28, 2019
Rebecca M. Sandring
/s/ Todd Banks	Director	February 28, 2019
Todd Banks
/s/ Barrett Brady	Director	February 28, 2019
Barrett Brady
/s/ Conrad S. Ciccotello	Director	February 28, 2019
Conrad S. Ciccotello
/s/ Catherine A. Lewis	Director	February 28, 2019
Catherine A. Lewis

F-42

EX-21.1

Exhibit 21.1

Subsidiaries of CorEnergy Infrastructure Trust, Inc.

As of December 31, 2018

Subsidiary	State of Incorporation or Formation
CorEnergy BBWS, Inc.	Delaware
CorEnergy Pipeline Company, LLC	Delaware
Corridor Bison, LLC	Delaware
Corridor Leeds Path West, Inc.	Delaware
Corridor MoGas, Inc.	Delaware
Corridor Private Holdings, Inc.	Delaware
Corridor Public Holdings, Inc.	Delaware
Four Wood Corridor, LLC	Delaware
Grand Isle Corridor, LP	Delaware
Grand Isle GP, Inc.	Delaware
Grand Isle LP, Inc.	Delaware
LCP Oregon Holdings, LLC	Delaware
MoGas Pipeline LLC	Delaware
Mowood, LLC	Delaware
Omega Gas Marketing, LLC	Delaware
Omega Pipeline Company, LLC	Delaware
Pinedale Corridor, LP	Delaware
Pinedale GP, Inc.	Delaware
Pinedale LP I, LLC	Delaware
United Property Systems, LLC	Delaware

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) Registration Statement (Form S-3 No. 333-198921) of CorEnergy Infrastructure Trust, Inc.,

(2) Registration Statement (Form S-8 No. 333-198799) pertaining to the CorEnergy Infrastructure Trust, Inc. Director Compensation Plan,

(3) Registration Statement (Form S-3 No. 333-228065) pertaining to the CorEnergy Infrastructure Trust, Inc. Dividend Reinvestment Plan, and

(4) Registration Statement (Form S-3 No. 333-228101) of CorEnergy Infrastructure Trust, Inc.

of our reports dated February 28, 2019, with respect to the consolidated financial statements of CorEnergy Infrastructure Trust, Inc., and the effectiveness of internal control over financial reporting of CorEnergy Infrastructure Trust, Inc. included in this Annual Report (Form 10-K) of CorEnergy Infrastructure Trust, Inc. for the year ended December 31, 2018.

/s/ Ernst & Young LLP

Kansas City, Missouri

February 28, 2019

EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, David J. Schulte, certify that:

1. I have reviewed this Annual Report on Form 10-K of CorEnergy Infrastructure Trust, Inc.;

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: February 28, 2019	/s/ David J. Schulte
	David J. Schulte
	Chief Executive Officer (Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, Rebecca M. Sandring, certify that:

1. I have reviewed this Annual Report on Form 10-K of CorEnergy Infrastructure Trust, Inc.;

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: February 28, 2019	/s/ Rebecca M. Sandring
	Rebecca M. Sandring
	Chief Accounting Officer, Treasurer and Secretary (Principal Accounting Officer and Principal Financial Officer)

EX-32.1

Exhibit 32.1

SECTION 906 CERTIFICATION

Pursuant to U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2001, the undersigned officers of CorEnergy Infrastructure Trust, Inc. (the “Company”), hereby certify that the Annual Report on Form 10-K for the period ended December 31, 2018, filed with the Securities and Exchange Commission on the date hereof (the “Report”), fully complies with the requirements of Section13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, as amended, and that the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ David J. Schulte

David J. Schulte

Chief Executive Officer (Principal Executive Officer)

Date: February 28, 2019

/s/ Rebecca M. Sandring

Rebecca M. Sandring

Chief Accounting Officer, Treasurer and Secretary (Principal Accounting Officer and Principal Financial Officer)

Date: February 28, 2019

The foregoing certification is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of this report. A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2018	Feb. 27, 2019	Jun. 29, 2018
Document and Entity Information [Abstract]
Entity Registrant Name	CorEnergy Infrastructure Trust, Inc.
Entity Central Index Key	0001347652
Document Type	10-K
Document Period End Date	Dec. 31, 2018
Amendment Flag	false
Entity Shell Company	false
Entity Emerging Growth Company	false
Entity Small Business	true
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 445,335,846
Entity Common Stock, Shares Outstanding		12,797,265

XML

Consolidated Balance Sheets - USD ($)	Dec. 31, 2018		Dec. 31, 2017
Assets
Leased property, net of accumulated depreciation of $87,154,095 and $72,155,753	$ 398,214,355		$ 465,956,467
Property and equipment, net of accumulated depreciation of $15,969,346 and $12,643,636	109,881,552		113,158,872
Financing notes and related accrued interest receivable, net of reserve of $600,000 and $4,100,000	1,300,000		1,500,000
Note receivable	5,000,000		0
Other equity securities, at fair value	0		2,958,315
Cash and cash equivalents	69,287,177		15,787,069
Deferred rent receivable	25,942,755		22,060,787
Accounts and other receivables	5,083,243		3,786,036
Deferred costs, net of accumulated amortization of $1,290,236 and $623,764	2,838,443		3,504,916
Prepaid expenses and other assets	668,584		742,154
Deferred tax asset, net	4,948,203		2,244,629
Goodwill	1,718,868		1,718,868
Total Assets	624,883,180		633,418,113
Liabilities and Equity
Secured credit facilities, net of debt issuance costs of $210,891 and $254,646	37,261,109		40,745,354
Unsecured convertible senior notes, net of discount and debt issuance costs of $1,180,729 and $1,967,917	112,777,271		112,032,083
Asset retirement obligation	7,956,343		9,170,493
Accounts payable and other accrued liabilities	3,493,490		2,333,782
Management fees payable	1,831,613		1,748,426
Income tax liability	0		2,204,626
Unearned revenue	6,552,049		3,397,717
Total Liabilities	169,871,875		171,632,481
Equity
Series A Cumulative Redeemable Preferred Stock 7.375%, $125,555,675 and $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 50,222 and 52,000 issued and outstanding at December 31, 2018 and December 31, 2017, respectively	125,555,675		130,000,000
Capital stock, non-convertible, $0.001 par value; 11,960,225 and $11,915,830 shares issued and outstanding at December 31, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,960		11,916
Additional paid-in capital	320,295,969		331,773,716
Retained earnings	9,147,701		0
Total Equity	455,011,305	[1]	461,785,632
Total Liabilities and Equity	$ 624,883,180		$ 633,418,113

[1] (2) The retained earnings balance at December 31, 2018 was generated due to the timing of quarterly dividends and quarterly net income. In the fourth quarter of 2018, net income was greater than dividends due to the gain on sale of leased property, net from the sale of the Portland Terminal Facility resulting in a retained earnings balance as of December 31, 2018.

XML

Consolidated Balance Sheets (Parenthetical) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Accumulated depreciation, leased property	$ 87,154,095	$ 72,155,753
Accumulated depreciation, property and equipment	15,969,346	12,643,636
Accumulated amortization, Deferred costs	1,290,236	623,764
Reserve for financing notes and related accrued interest receivable	$ 600,000	$ 4,100,000
Preferred stock, par value (in dollars per share)	$ 0.001
Preferred stock, authorized (in shares)	10,000,000
Preferred stock, outstanding (in shares)	50,222.27
Capital stock non-convertible, par value (in dollars per share)	$ 0.001	$ 0.001
Capital stock non-convertible, shares issued (in shares)	11,960,225	11,915,830
Capital stock non-convertible, shares outstanding (in shares)	11,960,225	11,915,830
Capital stock non-convertible, shares authorized (in shares)	100,000,000	100,000,000
Series A Cumulative Redeemable Preferred Stock
Preferred stock interest rate	7.375%	7.375%
Preferred Stock, Liquidation Preference	$ 125,555,675	$ 130,000,000
Preferred Stock, Liquidation Preference (in dollars per share)	$ 2,500	$ 2,500
Preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Preferred stock, authorized (in shares)	10,000,000	10,000,000
Preferred stock, issued (in shares)	50,222	52,000
Preferred stock, outstanding (in shares)	50,222	52,000
Convertible Debt
Net of discount and debt issuance costs	$ 1,180,729	$ 1,967,917
Deferred debt financing costs, net	241,000
Secured Debt
Deferred debt financing costs, net	$ 210,891	$ 254,646

XML

Consolidated Statements of Income and Comprehensive Income - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenue
Lease revenue	$ 72,747,362	$ 68,803,804	$ 67,994,130
Revenue	16,484,236
Total Revenue	89,231,598	88,749,377	89,250,586
Expenses
Transportation and distribution expenses	7,210,748	6,729,707	6,463,348
General and administrative	13,042,847	10,786,497	12,270,380
Depreciation, amortization and ARO accretion expense	24,947,453	24,047,710	22,522,871
Provision for loan (gain) loss	(36,867)	0	5,014,466
Total Expenses	45,164,181	41,563,914	46,271,065
Operating Income	44,067,417	47,185,463	42,979,521
Other Income (Expense)
Net distributions and dividend income	106,795	680,091	1,140,824
Net realized and unrealized gain (loss) on other equity securities	(1,845,309)	1,531,827	824,482
Interest expense	(12,759,010)	(12,378,514)	(14,417,839)
Gain on the sale of leased property, net	11,723,257	0	0
Loss on extinguishment of debt	0	(336,933)	0
Total Other Expense	(2,774,267)	(10,503,529)	(12,452,533)
Income before income taxes	41,293,150	36,681,934	30,526,988
Taxes
Current tax expense (benefit)	(585,386)	2,831,658	(313,107)
Deferred tax benefit	(1,833,340)	(486,340)	(151,313)
Income tax expense (benefit), net	(2,418,726)	2,345,318	(464,420)
Net Income	43,711,876	34,336,616	30,991,408
Less: Net Income attributable to non-controlling interest	0	1,733,826	1,328,208
Net Income attributable to CorEnergy Stockholders	43,711,876	32,602,790	29,663,200
Preferred dividend requirements	9,548,377	7,953,988	4,148,437
Net Income attributable to Common Stockholders	34,163,499	24,648,802	25,514,763
Net Income	43,711,876	34,336,616	30,991,408
Other comprehensive income (loss):
Changes in fair value of qualifying hedges / AOCI attributable to CorEnergy stockholders	0	11,196	(201,993)
Changes in fair value of qualifying hedges / AOCI attributable to non-controlling interest	0	2,617	(47,226)
Net Change in Other Comprehensive Income (Loss)	0	13,813	(249,219)
Total Comprehensive Income (Loss)	43,711,876	34,350,429	30,742,189
Less: Comprehensive income attributable to non-controlling interest	0	1,736,443	1,280,982
Comprehensive Income attributable to CorEnergy Stockholders	$ 43,711,876	$ 32,613,986	$ 29,461,207
Earnings Per Common Share:
Basic (in dollars per share)	$ 2.86	$ 2.07	$ 2.14
Diluted (in dollars per share)	$ 2.79	$ 2.07	$ 2.14
Weighted Average Shares of Common Stock Outstanding:
Basic (in shares)	11,935,021	11,900,516	11,901,985
Diluted (in shares)	15,389,180	11,900,516	11,901,985
Dividends declared per share (in dollars per share)	$ 3.000	$ 3.000	$ 3.000
Transportation and distribution revenue
Revenue
Revenue	$ 16,484,236	$ 19,945,573	$ 21,094,112
Financing revenue
Revenue
Revenue	$ 0	$ 0	$ 162,344

XML

Consolidated Statements of Equity - USD ($)		Total	Capital Stock		Preferred Stock	Additional Paid-in Capital	Accumulated Other Comprehensive Income (Loss)	Retained Earnings	Non-Controlling Interest	Series A Cumulative Redeemable Preferred Stock	Series A Cumulative Redeemable Preferred Stock Preferred Stock	Series A Cumulative Redeemable Preferred Stock Additional Paid-in Capital
Beginning balance, (in shares) at Dec. 31, 2015			11,939,697
Beginning balance at Dec. 31, 2015		$ 444,194,306	$ 11,940		$ 56,250,000	$ 361,581,507	$ 190,797	$ 0	$ 26,160,062
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		30,991,408						29,663,200	1,328,208
Net change in cash flow hedges		(249,219)					(201,993)		(47,226)
Total Comprehensive Income (Loss)		30,742,189					(201,993)	29,663,200	1,280,982
Repurchase of stock (in shares)			(90,613)
Repurchase of stock		(2,041,851)	$ (91)			(2,041,760)
Series A preferred stock dividends		(4,148,437)						(4,148,437)
Common stock dividends		(35,712,616)				(10,197,853)		(25,514,763)
Common stock issued under director's compensation plan (in shares)			2,551
Common stock issued under director's compensation plan		60,000	$ 2			59,998
Reinvestment of dividends paid to common stockholders (in shares)			34,581
Reinvestment of dividends paid to common stockholders		815,889	$ 35			815,854
Ending balance at Dec. 31, 2016		433,909,480	$ 11,886		56,250,000	350,217,746	(11,196)	0	27,441,044
Ending balance, (in shares) at Dec. 31, 2016			11,886,216
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income		34,336,616						32,602,790	1,733,826
Net change in cash flow hedges		13,813
Amortization related to de-designated cash flow hedges		13,813					11,196		2,617
Total Comprehensive Income (Loss)		34,350,429					11,196	32,602,790	1,736,443
Issuance of Series A cumulative redeemable preferred stock, 7.375% - redemption value										$ 71,161,531	$ 73,750,000	$ (2,588,469)
Series A preferred stock dividends		(8,227,734)				(727,001)		(7,500,733)
Common stock dividends		(35,694,200)				(10,592,143)		(25,102,057)
Common stock issued under director's compensation plan (in shares)			1,979
Common stock issued under director's compensation plan		67,500	$ 2			67,498
Distributions to Non-controlling interest		(1,833,650)							(1,833,650)
Purchase of Non-controlling interest		(32,910,032)				(5,566,195)			(27,343,837)
Reinvestment of dividends paid to common stockholders (in shares)			27,635
Reinvestment of dividends paid to common stockholders		962,308	$ 28			962,280
Ending balance at Dec. 31, 2017		$ 461,785,632	$ 11,916		130,000,000	331,773,716	0	0	0
Ending balance, (in shares) at Dec. 31, 2017		11,915,830	11,915,830
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cumulative transition adjustment upon the adoption of ASC 606, net of tax		$ (2,449,245)				(2,449,245)
Net income		43,711,876						43,711,876	0
Net change in cash flow hedges		0
Total Comprehensive Income (Loss)		43,711,876
Repurchase of stock	[1]	(4,275,553)			(4,444,325)	158,218		10,554
Series A preferred stock dividends		(9,587,500)						(9,587,500)
Common stock dividends		(35,793,889)				(10,806,660)		(24,987,229)
Common stock issued under director's compensation plan (in shares)			1,807
Common stock issued under director's compensation plan		67,500	$ 2			67,498
Common stock issued upon conversion of convertible notes (in shares)			1,271
Common stock issued upon conversion of convertible notes		42,654	$ 1			42,653
Reinvestment of dividends paid to common stockholders (in shares)			41,317
Reinvestment of dividends paid to common stockholders		1,509,830	$ 41			1,509,789
Ending balance at Dec. 31, 2018	[2]	$ 455,011,305	$ 11,960		$ 125,555,675	$ 320,295,969	$ 0	$ 9,147,701	$ 0
Ending balance, (in shares) at Dec. 31, 2018		11,960,225	11,960,225	[2]

[1] (1) In connection with the repurchases of Series A Preferred Stock during 2018, the deduction to preferred dividends of $10,554 represents the discount in the repurchase price paid compared to the carrying amount derecognized.

[2] (2) The retained earnings balance at December 31, 2018 was generated due to the timing of quarterly dividends and quarterly net income. In the fourth quarter of 2018, net income was greater than dividends due to the gain on sale of leased property, net from the sale of the Portland Terminal Facility resulting in a retained earnings balance as of December 31, 2018.

XML

Consolidated Statements of Equity (Parenthetical) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Decrease in preferred dividends	$ 10,554
Series A Cumulative Redeemable Preferred Stock
Preferred stock interest rate	7.375%	7.375%

XML

Consolidated Statements of Cash Flow - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Activities
Net Income	$ 43,711,876	$ 34,336,616	$ 30,991,408
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income tax, net	(1,845,710)	(486,340)	(151,313)
Depreciation, amortization and ARO accretion	26,361,907	25,708,891	24,548,350
Gain on sale of leased property	(11,723,257)	0	0
Provision for loan (gain) loss	(36,867)	0	5,014,466
Loss on extinguishment of debt	0	336,933	0
Non-cash settlement of accounts payable	0	(221,609)	0
(Gain) loss on sale of equipment	(8,416)	4,203	0
Gain on repurchase of convertible debt	0	0	(71,702)
Net distributions and dividend income, including recharacterization of income	0	148,649	(117,004)
Net realized and unrealized (gain) loss on other equity securities	1,845,309	(1,531,827)	(781,153)
Unrealized gain on derivative contract	0	0	(75,591)
Settlement of derivative contract	0	0	(95,319)
Loss on settlement of asset retirement obligation	310,941	0	0
Common stock issued under directors compensation plan	67,500	67,500	60,000
Changes in assets and liabilities:
Increase in deferred rent receivables	(7,038,848)	(7,184,005)	(8,360,036)
(Increase) decrease in accounts and other receivables	(1,297,207)	752,848	(174,390)
Decrease in financing note accrued interest receivable	0	0	95,114
(Increase) decrease in prepaid expenses and other assets	73,505	(16,717)	329,735
Increase (decrease) in management fee payable	83,187	13,402	(28,723)
Increase (decrease) in accounts payable and other accrued liabilities	476,223	(225,961)	(231,151)
Increase (decrease) in income tax liability	(2,204,626)	2,204,626	0
Increase (decrease) in unearned revenue	(152,777)	2,884,362	155,961
Net cash provided by operating activities	48,622,740	56,791,571	51,108,652
Investing Activities
Proceeds from the sale of leased property	55,553,975	0	0
Proceeds from sale of other equity securities	449,067	7,591,166	0
Proceeds from assets and liabilities held for sale	0	0	644,934
Purchases of property and equipment, net	(105,357)	(116,595)	(191,926)
Proceeds from asset foreclosure and sale	17,999	0	223,451
Principal payment on financing note receivable	236,867	0	0
Increase in financing notes receivable	0	0	(202,000)
Return of capital on distributions received	663,939	120,906	4,631
Net cash provided by investing activities	56,816,490	7,595,477	479,090
Financing Activities
Debt financing costs	(264,010)	(1,462,741)	(193,000)
Net offering proceeds on Series A preferred stock	0	71,161,531	0
Repurchases of common stock	0	0	(2,041,851)
Repurchases of convertible debt	0	0	(899,960)
Repurchases of Series A preferred stock	(4,275,553)	0	0
Dividends paid on Series A preferred stock	(9,587,500)	(8,227,734)	(4,148,437)
Dividends paid on common stock	(34,284,059)	(34,731,892)	(34,896,727)
Distributions to non-controlling interest	0	(1,833,650)	0
Advances on revolving line of credit	0	10,000,000	44,000,000
Payments on revolving line of credit	0	(54,000,000)	0
Proceeds from term debt	0	41,000,000	0
Principal payments on secured credit facilities	(3,528,000)	(45,600,577)	(60,131,423)
Purchase of non-controlling interest	0	(32,800,000)	0
Net cash used in financing activities	(51,939,122)	(56,495,063)	(58,311,398)
Net Change in Cash and Cash Equivalents	53,500,108	7,891,985	(6,723,656)
Cash and Cash Equivalents at beginning of period	15,787,069	7,895,084	14,618,740
Cash and Cash Equivalents at end of period	69,287,177	15,787,069	7,895,084
Supplemental Disclosure of Cash Flow Information
Interest paid	11,200,835	10,780,150	12,900,901
Income taxes paid (net of refunds)	2,136,563	199,772	37,736
Non-Cash Investing Activities
Note receivable in consideration of the sale of leased property	5,000,000	0	0
Investment in other equity securities	0	(1,161,034)	0
Change in accounts and other receivables	0	0	(450,000)
Net change in Assets Held for Sale, Property and equipment, Prepaid expenses and other assets, Accounts payable and other accrued liabilities and Liabilities held for sale	0	0	(1,776,549)
Non-Cash Financing Activities
Change in accounts payable and accrued expenses related to debt financing costs	(255,037)	255,037	0
Reinvestment of distributions by common stockholders in additional common shares	1,509,830	962,308	815,889
Common stock issued upon conversion of convertible notes	$ 42,654	$ 0	$ 0

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Introduction and Basis of Presentation

12 Months Ended

Dec. 31, 2018

Organization, Consolidation and Presentation of Financial Statements [Abstract]

INTRODUCTION AND BASIS OF PRESENTATION

INTRODUCTION AND BASIS OF PRESENTATION

Introduction

CorEnergy Infrastructure Trust, Inc. (referred to as "CorEnergy" or "the Company"), was organized as a Maryland corporation and commenced operations on December 8, 2005. The Company's common shares are listed on the New York Stock Exchange ("NYSE") under the symbol "CORR" and its depositary shares representing Series A Preferred Stock are listed on the NYSE under the symbol "CORR PrA".

The Company is primarily focused on acquiring and financing real estate assets within the U.S. energy infrastructure sector and concurrently entering into long-term triple-net participating leases with energy companies. The Company also may provide other types of capital, including loans secured by energy infrastructure assets. Targeted assets include pipelines, storage tanks, transmission lines, and gathering systems, among others. These sale-leaseback or real property mortgage transactions provide the energy company with a source of capital that is an alternative to other sources such as corporate borrowing, bond offerings, or equity offerings. Many of the Company's leases contain participation features in the financial performance or value of the underlying infrastructure real property asset. The triple-net lease structure requires that the tenant pay all operating expenses of the business conducted by the tenant, including real estate taxes, insurance, utilities, and expenses of maintaining the asset in good working order. CorEnergy considers its investments in these energy infrastructure assets to be a single business segment and reports them accordingly in its financial statements.

Basis of Presentation

The accompanying consolidated financial statements include CorEnergy accounts and the accounts of its wholly-owned subsidiaries and have been prepared in accordance with U.S. generally accepted accounting principles ("GAAP") set forth in the Accounting Standards Codification ("ASC"), as published by the Financial Accounting Standards Board ("FASB"), and with the Securities and Exchange Commission ("SEC") instructions to Form 10-K. The accompanying consolidated financial statements reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the Company's financial position, results of operations and cash flows for the periods presented. There were no adjustments that, in the opinion of management, were not of a normal and recurring nature. All intercompany transactions and balances have been eliminated in consolidation, and the Company's net earnings have been reduced by the portion of net earnings attributable to non-controlling interests, when applicable.

The FASB issued ASU 2015-02 Consolidations (Topic 810) - Amendments to the Consolidation Analysis ("ASU 2015-02"), which amended previous consolidation guidance, including introducing a separate consolidation analysis specific to limited partnerships and other similar entities. Under this analysis, limited partnerships and other similar entities are considered a variable interest entity ("VIE") unless the limited partners hold substantive kick-out rights or participating rights. Management determined that Pinedale LP and Grand Isle Corridor LP are VIEs under the amended guidance because the limited partners of both partnerships lack both substantive kick-out rights and participating rights. As such, management evaluated the qualitative criteria under FASB ASC Topic 810 in conjunction with ASU 2015-02 to make a determination whether these partnerships should be consolidated in the Company's financial statements. ASC Topic 810-10 requires the primary beneficiary of a variable interest entity's activities to consolidate the VIE. The primary beneficiary is identified as the enterprise that has a) the power to direct the activities of the VIE that most significantly impact the entity's economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. The standard requires an ongoing analysis to determine whether the variable interest gives rise to a controlling financial interest in the VIE. Based on the general partners' roles and rights as afforded by the partnership agreements and its exposure to losses and benefits of each of the partnerships through its significant limited partner interests, management determined that CorEnergy is the primary beneficiary of both Pinedale LP and Grand Isle Corridor LP. Based upon this evaluation and the Company's 100 percent ownership interest in Pinedale LP (2018) and Grand Isle Corridor LP (2016-2018) and the majority ownership interest in Pinedale LP (2016-2017) of the limited partnership interests, the consolidated financial statements presented include full consolidation with respect to both of the partnerships.

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Significant Accounting Policies

12 Months Ended

Dec. 31, 2018

Accounting Policies [Abstract]

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES

A. Use of Estimates – The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

B. Leased Property – The Company includes assets subject to lease arrangements within leased property, net of accumulated depreciation, in the Consolidated Balance Sheets. Lease payments received are reflected in lease revenue on the Consolidated Statements of Income, net of amortization of any off-market adjustments. Costs in connection with the creation and execution of a lease are capitalized and amortized over the lease term. See Note 3 ("Leased Properties And Leases") for further discussion.

C. Property and Equipment – Property and equipment are stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful life of the asset. Expenditures for repairs and maintenance are charged to operations as incurred, and improvements, which extend the useful lives of assets, are capitalized and depreciated over the remaining estimated useful life of the asset. The Company initially records long-lived assets at their purchase price plus any direct acquisition costs, unless the transaction is accounted for as a business combination, in which case the acquisition costs are expensed as incurred. If the transaction is accounted for as a business combination, the Company allocates the purchase price to the acquired tangible and intangible assets and liabilities based on their estimated fair values.

D. Long-Lived Asset Impairment – The Company's long-lived assets consist primarily of a subsea midstream pipeline system, liquids gathering system and natural gas pipelines that have been obtained through asset acquisitions and a business combination. Management continually monitors its business, the business environment and performance of its operations to determine if an event has occurred that indicates that the carrying value of a long-lived asset may be impaired. When a triggering event occurs, which is a determination that involves judgment, management utilizes cash flow projections to assess its ability to recover the carrying value of its assets based on the Company's long-lived assets' ability to generate future cash flows on an undiscounted basis. This differs from the evaluation of goodwill, for which the recoverability assessment utilizes fair value estimates that include discounted cash flows in the estimation process and accordingly any goodwill impairment recognized may not be indicative of a similar impairment of the related underlying long-lived assets.

Management's projected cash flows of long-lived assets are primarily based on contractual cash flows relating to existing leases that extend many years into the future. If those cash flow projections indicate that the long-lived asset's carrying value is not recoverable, management records an impairment charge for the excess of carrying value of the asset over its fair value. The estimate of fair value considers a number of factors, including the potential value that would be received if the asset were sold, discount rates and projected cash flows. Due to the imprecise nature of these projections and assumptions, actual results can differ from management's estimates. There were no impairments of long-lived assets recorded during the years ended December 31, 2018, 2017 or 2016.

E. Financing Notes Receivable – Financing notes receivable are presented at face value plus accrued interest receivable and deferred loan origination costs and net of related direct loan origination income. Each quarter the Company reviews its financing notes receivable to determine if the balances are realizable based on factors affecting the collectability of those balances. Factors may include credit quality, timeliness of required periodic payments, past due status and management discussions with obligors. The Company evaluates the collectability of both interest and principal of each of its loans to determine if an allowance is needed. An allowance will be recorded when based on current information and events, the Company determines it is probable that it will be unable to collect all amounts due according to the existing contractual terms. If the Company does determine an allowance is necessary, the amount deemed uncollectable is expensed in the period of determination. An insignificant delay or shortfall in the amount of payments does not necessarily result in the recording of an allowance. Generally, when interest and/or principal payments on a loan become past due, or if the Company does not otherwise expect the borrower to be able to service its debt and other obligations, the Company will place the loan on non-accrual status and will typically cease recognizing financing revenue on that loan until all principal and interest have been brought current. Interest income recognition is resumed if and when the previously reserved-for financing notes become contractually current and performance has been demonstrated. Payments received subsequent to the recording of an allowance will be recorded as a reduction to principal. During the years ended December 31, 2018, 2017 and 2016, the Company recorded provisions for loan (gain) loss of approximately $(37) thousand, $0 and 5.0 million, respectively. The Company's financing notes receivable are discussed more fully in Note 5 ("Financing Notes Receivable").

F. Investment Securities – The Company's investments in securities are classified as other equity securities and represent interests in private companies which the Company has elected to report at fair value under the fair value option. These investments are subject to restrictions on resale, have no established trading market and are valued on a quarterly basis. Because of the inherent uncertainty of valuation, the fair values of such investments, which are determined in accordance with procedures approved by the Company's Board of Directors, may differ materially from the values that would have been used had a ready market existed for the investments.

The Company determines fair value to be the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Company has determined the principal market, or the market in which the Company exits its private portfolio investments with the greatest volume and level of activity, to be the private secondary market. Typically, private companies are bought and sold based on multiples of EBITDA, cash flows, net income, revenues, or in limited cases, book value.

For private company investments, value is often realized through a liquidity event. Therefore, the value of the company as a whole (enterprise value) at the reporting date often provides the best evidence of the value of the investment and is the initial step for valuing the Company's privately issued securities. For any one company, enterprise value may best be expressed as a range of fair values, from which a single estimate of fair value will be derived. In determining the enterprise value of a portfolio company, an analysis is prepared consisting of traditional valuation methodologies including market and income approaches. The Company considers some or all of the traditional valuation methods based on the individual circumstances of the portfolio company in order to derive its estimate of enterprise value.

The fair value of investments in private portfolio companies is determined based on various factors, including enterprise value, observable market transactions, such as recent offers to purchase a company, recent transactions involving the purchase or sale of the equity securities of the company, or other liquidation events. The determined equity values may be discounted when the Company has a minority position, or is subject to restrictions on resale, has specific concerns about the receptivity of the capital markets to a specific company at a certain time, or other comparable factors exist.

G. Fair Value Measurements – FASB ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. Various inputs are used in determining the fair value of the Company's assets and liabilities. These inputs are summarized in the three broad levels listed below:

• Level 1 - quoted prices in active markets for identical investments

• Level 2 - other significant observable inputs (including quoted prices for similar investments, market corroborated inputs, etc.)

• Level 3 - significant unobservable inputs (including the Company's own assumptions in determining the fair value of investments)

See Note 10 ("Fair Value") for further discussion of the Company's fair value measurements.

H. Cash and Cash Equivalents – The Company maintains cash balances at financial institutions in amounts that regularly exceed FDIC insured limits. The Company's cash equivalents are comprised of short-term, liquid money market instruments.

I. Accounts and other receivables – Accounts receivable are presented at face value net of an allowance for doubtful accounts within accounts and other receivables on the balance sheet. Accounts are considered past due based on the terms of sale with the customers. The Company reviews accounts for collectability based on an analysis of specific outstanding receivables, current economic conditions and past collection experience. For the years ended December 31, 2018 and 2017, the Company determined that an allowance for doubtful accounts was not necessary.

J. Deferred rent receivables – Lease receivables are determined according to the terms of the lease agreements entered into by the Company and its lessees, as discussed within Note 3 ("Leased Properties And Leases"). Lease receivables primarily represent timing differences between straight-line revenue recognition and contractual lease receipts. As of December 31, 2018, lease payments by the Company's tenants have remained timely and without lapse.

K. Goodwill – Goodwill represents the excess of the amount paid for the MoGas business over the fair value of the net identifiable assets acquired. To comply with ASC 350, Intangibles - Goodwill and Other ("ASC 350"), the Company performs an impairment test for goodwill annually, or more frequently in the event that a triggering event has occurred. December 31st is the Company's annual testing date associated with its MoGas reporting unit.

In January 2017, the FASB issued ASU 2017-04, Simplifying the Test for Goodwill Impairment, which simplifies how an entity is required to test goodwill for impairment by eliminating step two from the goodwill impairment test. Effective January 1, 2017, the Company elected to early adopt this standard.

In accordance with ASC 350, a company may elect to perform a qualitative assessment to determine whether the quantitative impairment test is required. If the company elects to perform a qualitative assessment, the quantitative impairment test is required only if the conclusion is that it is more likely than not that the reporting unit's fair value is less than its carrying amount. If a company bypasses the qualitative assessment, the quantitative goodwill impairment test should be followed in step one.

Step one compares the fair value of the reporting unit to its carrying value to identify and measure any potential impairment. The reporting unit fair value is based upon consideration of various valuation methodologies, one of which is projecting future cash flows discounted at rates commensurate with the risks involved ("Discounted Cash Flow" or "DCF"). Assumptions used in a DCF require the exercise of significant judgment, including judgment about appropriate discount rates and terminal values, growth rates and the amount and timing of expected future cash flows. Forecasted cash flows require management to make judgments and assumptions, including estimates of future volumes and rates. Declines in volumes or rates from those forecasted, or other changes in assumptions, may result in a change in management's estimate and result in an impairment.

The Company elected to perform a qualitative goodwill impairment assessment for the years ended December 31, 2018 and 2017. In performing the qualitative assessment, the Company analyzed the key drivers and other external factors that impact the business in order to determine if any significant events, transactions or other factors had occurred or are expected to occur that would impair earnings or competitiveness, therefore impairing the fair value of the MoGas reporting unit. After assessing the totality of events and circumstances, it was determined that it was not more likely than not that the fair value of the MoGas reporting unit was less than the carrying value, and so it was not necessary to perform the quantitative step one valuation. Key drivers that were considered in the qualitative evaluation of the MoGas reporting unit included: general economic conditions, continued recovery of the energy markets, natural gas pricing, input costs, liquidity and capital resources and customer outlook. Additionally, the Company considered the quantitative impairment analysis performed as of December 31, 2016, including potential updates to key valuation assumptions, in determining that it was not more likely than not that goodwill was impaired for the current year assessment.

L. Debt Discount and Debt Issuance Costs – Costs incurred for the issuance of new debt are capitalized and amortized into interest expense over the debt term. Issuance costs related to long-term debt are recorded as a direct deduction from the carrying amount of that debt liability, net of accumulated amortization. Issuance costs related to line-of-credit arrangements however, are presented as an asset instead of a direct deduction from the carrying amount of the debt. In accordance with ASC 470, Debt ("ASC 470"), the Company recorded its Convertible Senior Notes at the aggregate principal amount, less discount. The Company is amortizing the debt discount over the life of the convertible notes as additional non-cash interest expense utilizing the effective interest method. Refer to Note 11 ("Debt") for additional information.

M. Asset Retirement Obligations – The Company follows ASC 410-20, Asset Retirement Obligations, which requires that an asset retirement obligation ("ARO") associated with the retirement of a long-lived asset be recognized as a liability in the period in which it is incurred and becomes determinable, with an offsetting increase in the carrying amount of the associated asset. The Company recognized an existing ARO in conjunction with the acquisition of the GIGS in June 2015.

The Company measures changes in the ARO liability due to passage of time by applying an interest method of allocation to the amount of the liability at the beginning of the period. The increase in the carrying amount of the liability is recognized as an expense classified as an operating item in the Consolidated Statements of Income, hereinafter referred to as ARO accretion expense. The Company periodically reassesses the timing and amount of cash flows anticipated associated with the ARO and adjusts the fair value of the liability accordingly under the guidance in ASC 410-20.

The fair value of the obligation at the acquisition date was capitalized as part of the carrying amount of the related long-lived assets and is being depreciated over the asset's remaining useful life. The useful lives of most pipeline gathering systems are primarily derived from available supply resources and ultimate consumption of those resources by end users. Adjustments to the ARO resulting from reassessments of the timing and amount of cash flows will result in changes to the retirement costs capitalized as part of the carrying amount of the asset.

Upon decommissioning of the ARO or a portion thereof, the Company reduces the fair value of the liability and recognizes a (gain) loss on settlement of ARO as an operating item in the Consolidated Statements of Income for the difference between the liability and actual decommissioning costs incurred.

Refer to Note 12 ("Asset Retirement Obligation") for additional information.

N. Revenue Recognition – In May 2014, the FASB issued ASU No. 2014-09 Revenue from Contracts with Customers ("ASU 2014-09" or "ASC 606"), which became effective for all public entities on January 1, 2018. ASC 606 supersedes previously existing revenue recognition standards with a single model unless those contracts are within the scope of other standards (e.g. leases). The model requires an entity to recognize as revenue the amount of consideration to which it expects to be entitled for the transfer of promised goods or services to customers. A substantial portion of the Company's revenue consists of rental income from leasing arrangements, which is specifically excluded from ASC 606. However, the Company's transportation and distribution revenue is within the scope of the new guidance. The Company adopted ASC 606 effective on January 1, 2018 using the modified retrospective method. The Company elected to apply the guidance only to open contracts as of the effective date. The Company recognized the cumulative effect of applying the new standard as an adjustment to the opening balance of stockholders' equity. The comparative information has not been restated and continues to be reported under accounting standards in effect for those periods. Refer to Note 4 ("Transportation And Distribution Revenue") for further discussion of the transition impact and related disclosures under ASC 606.

Specific recognition policies for the Company's revenue items are as follows:

• Lease revenue – Base rent related to the Company's leased property is recognized on a straight-line basis over the term of the lease when collectability is reasonably assured. Participating rent is recognized when it is earned, based on the achievement of specified performance criteria. Rental payments received in advance are classified as unearned revenue and included as a liability within the Consolidated Balance Sheets. Unearned revenue is amortized ratably over the lease period as revenue recognition criteria are met. Rental payments received in arrears are accrued and classified as deferred rent receivable and included in assets within the Consolidated Balance Sheets.

• Transportation and distribution revenue – The Company's contracts related to transportation and distribution revenue are primarily comprised of a mix of natural gas supply, transportation and distribution performance obligations, as well as limited performance obligations related to system maintenance and expansion. Transportation revenues are recognized by MoGas and distribution revenues are recognized by Omega and Omega Gas Marketing, LLC.

◦ Under the Company's natural gas supply, transportation and distribution performance obligations, the customer simultaneously receives and consumes the benefit of the services as natural gas is delivered. Therefore, the transaction price is allocated proportionally over the series of identical performance obligations with each contract. The transaction price is calculated based on (i) index price, plus a contractual markup in the case of natural gas supply agreements (considered variable due to fluctuations in the index), (ii) FERC regulated rates or negotiated rates in the case of transportation agreements and (iii) contracted amounts (with annual CPI escalators) in the case of the Company's distribution agreement. Based on the nature of the agreements, revenue for all but one of the Company's natural gas supply, transportation and distribution performance obligations is recognized on a right to invoice basis as the performance obligations are met, which represents what the Company expects to receive in consideration and is representative of value delivered to the customer. The Company has a contract with one customer, Spire, that has fixed pricing which varies over the contract term. For this specific contract, the transaction price has been allocated ratably over the contractual performance obligation beginning in 2018 with the adoption of ASC 606. All invoicing is done in the month following service, with payment typically due a month from invoice date.

◦ The Company's contracts also contain performance obligations related to system maintenance and expansion, which are completed on an as-needed basis. The work performed is specific and tailored to the customer's needs and there are no alternative uses for the services provided. Therefore, as the work is being completed, control is transferring to the customer. These services are billed at the Company's cost, plus an agreed upon margin, and the Company has an enforceable right to payment for services provided. The Company invoices for this service on a monthly basis according to an agreed upon billing schedule. Revenue is recognized on an input method, based on the actual cost of a service as a measure of performance obligations satisfaction, which the Company determined to be the method which faithfully depicts the transfer of services. Differences between the amounts invoiced and revenue recognized under the input method are reflected as an asset or liability on the Consolidated Balance Sheets. Any differences are typically expected to be recognized within a year.

◦ Beginning February 1, 2016, due to changes that commenced under a new contract with the Department of Defense ("DOD"), gas sales and cost of gas sales are presented on a net basis in the transportation and distribution revenue line. The Company continues to present the gas sales and cost of gas sales on a net basis upon adoption of ASC 606.

• Financing revenue – Historically, financing notes receivable have been considered a core product offering and therefore the related income is presented as a component of operating income. For increasing rate loans, base interest income is recorded ratably over the life of the loan, using the effective interest rate. The net amount of deferred loan origination income and costs are amortized on a straight-line basis over the life of the loan and reported as an adjustment to yield in financing revenue. Participating financing revenues are recorded when specific performance criteria have been met.

O. Transportation and distribution expense –Included here are both MoGas' costs of operating and maintaining the natural gas transmission line and Omega's costs of operating and maintaining the natural gas distribution system, including any necessary expansion of the distribution system. These costs are incurred both internally and externally. The internal costs relate to system control, pipeline operations, maintenance, insurance and taxes. Other internal costs include payroll for employees associated with gas control, field employees and management. The external costs consist of professional services such as audit and accounting, legal and regulatory and engineering.

Historically, Omega's amounts paid for gas and propane delivered to customers were presented as cost of sales. Beginning February 1, 2016, under a new contract with the DOD, amounts paid by Omega for gas and propane are netted against sales and are presented in the transportation and distribution revenue line. See paragraph (N) above.

P. Other Income Recognition –Specific policies for the Company's other income items are as follows:

• Net distributions and dividend income from investments – Distributions and dividends from investments are recorded on their ex-dates and are reflected as other income within the accompanying Consolidated Statements of Income. Distributions received from the Company's investments are generally characterized as ordinary income, capital gains and distributions received from investment securities. The portion characterized as return of capital is paid by the Company's investees from their cash flow from operations. The Company records investment income, capital gains and distributions received from investment securities based on estimates made at the time such distributions are received. Such estimates are based on information available from each company and other industry sources. These estimates may subsequently be revised based on information received from the entities after their tax reporting periods are concluded, as the actual character of these distributions is not known until after the fiscal year end of the Company.

• Net realized and unrealized gain (loss) from investments – Securities transactions are accounted for on the date the securities are purchased or sold. Realized gains and losses are reported on an identified cost basis. The Company records investment income and return of capital based on estimates made at the time such distributions are received. Such estimates are based on information available from the portfolio company and other industry sources. These estimates may subsequently be revised based on information received from the portfolio company after their tax reporting periods are concluded, as the actual character of these distributions are not known until after the Company's fiscal year end.

Q. Asset Acquisition Expenses – Costs incurred in connection with the research of real property acquisitions not accounted for as business combinations are expensed until it is determined that the acquisition of the real property is probable. Upon such determination, costs incurred in connection with the acquisition of the property are capitalized as described in paragraph (C) above. Deferred costs related to an acquisition that the Company has determined, based on management's judgment, not to pursue are expensed in the period in which such determination is made. Costs incurred in connection with a business combination are expensed as incurred.

R. Offering Costs – Offering costs related to the issuance of common or preferred stock are charged to additional paid-in capital when the stock is issued.

S. Derivative Instruments and Hedging Activities – The Company has used forward swap contracts primarily to reduce exposure to changes in interest rates on a portion of its variable-rate debt and to provide a cash flow hedge. In accordance with FASB ASC 815, Derivatives and Hedging ("ASC 815"), these derivative contracts have been recorded on the balance sheet at fair value. Historically, these derivative instruments have been designated as hedges for accounting purposes. The measurement of the cash flow hedge ineffectiveness has historically been recognized in earnings, when applicable. The effective portion of the gain or loss on qualifying swaps has been reported in accumulated other comprehensive income ("AOCI"), in accordance with ASC 815. For swaps de-designated as cash flow hedges, changes in fair value of the swaps have been fully recognized in earnings. See Note 13 ("Interest Rate Hedge Swaps") for further discussion.

T. Earnings Per Share – Basic earnings per share ("EPS") is computed using the weighted average number of common shares outstanding during the period. Diluted EPS is computed using the weighted average number of common and dilutive common equivalent shares outstanding during the period except for periods of net loss for which no common share equivalents are included because their effect would be anti-dilutive. Dilutive common equivalent shares consist of shares issuable upon conversion of the Convertible Notes calculated using the if-converted method.

U. Federal and State Income Taxation – In 2013 the Company qualified for REIT status, and in March 2014 elected (effective as of January 1, 2013), to be treated as a REIT for federal income tax purposes. Because certain of its assets may not produce REIT-qualifying income or be treated as interests in real property, those assets are held in wholly-owned TRSs in order to limit the potential that such assets and income could prevent the Company from qualifying as a REIT.

As a REIT, the Company holds and operates certain of its assets through one or more wholly-owned TRSs. The Company's use of TRSs enables it to continue to engage in certain businesses while complying with REIT qualification requirements and also allows it to retain income generated by these businesses for reinvestment without the requirement of distributing those earnings. In the future, the Company may elect to reorganize and transfer certain assets or operations from its TRSs to the Company or other subsidiaries, including qualified REIT subsidiaries.

The Company's other equity securities are limited partnerships or limited liability companies which are treated as partnerships for federal and state income tax purposes. As a limited partner, the Company reports its allocable share of taxable income in computing its own taxable income. To the extent held by a TRS, the TRS's tax expense or benefit is included in the Consolidated Statements of Income based on the component of income or gains and losses to which such expense or benefit relates. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. A valuation allowance is recognized if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized. It is expected that for the year ended December 31, 2018, and future periods, any deferred tax liability or asset generated will be related entirely to the assets and activities of the Company's TRSs.

If the Company ceased to qualify as a REIT, the Company, as a C corporation, would be obligated to pay federal and state income tax on its taxable income.

V. Recent Accounting Pronouncements – In February 2016, the FASB issued ASU 2016-02, Leases ("ASU 2016-02" or "ASC 842"), which amends the existing accounting standards for lease accounting, including requiring lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. ASU 2016-02 is effective for fiscal years and interim periods beginning after December 15, 2018, with early adoption permitted. At adoption, the standard will be applied using a modified retrospective approach. Alternatively, ASU 2018-11, Leases (Topic 842) Targeted Improvements, allows the Company to initially apply the new lease standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings and to continue to apply legacy guidance in ASC 840, Leases, including its disclosures requirements, in the comparative periods presented in the year of adoption. The Company has substantially completed its evaluation of the impact of the standard on its consolidated financial statements and related disclosures and expects that it will record a right of use asset and lease liability of less than $100 thousand on January 1, 2019 for its lessee operating leases.

The Company also concluded that Omega's long-term contract with the DOD to provide natural gas distribution to Fort Leonard Wood through Omega's pipeline distribution system on the military post meets the definition of a lease under ASC 842. Omega is the lessor in the contract and the lease is expected to be classified as an operating lease. The Company noted the non-lease component is the predominant component in the lease, and the timing and pattern of transfer of the lease component and the associated non-lease components are the same. Therefore, the Company expects to elect a practical expedient that allows lessors to not separate lease and related non-lease components if the non-lease components otherwise would be accounted for in accordance with the revenue standard under ASC 606. With the expected election of this practical expedient, the Company is expected to account for the DOD contract under the revenue standard, which is consistent with the Company's current accounting for the contract.

In August 2018, the FASB issued ASU 2018-13, Changes to the Disclosure Requirements for Fair Value Measurement ("ASU 2018-13"), which modifies the disclosure requirements on fair value measurements. The amendments add disclosure requirements for the changes in unrealized gains and losses for the period that are held in other comprehensive income for recurring Level 3 fair value measurements as well as disclosure requirements for the range and weighted average of significant observable inputs used to develop Level 3 fair value measurements. The amendments also clarify that the measurement uncertainty disclosure is to communicate information about the uncertainty in measurement as of the reporting date. ASU 2018-13 is effective for annual reporting periods, and interim periods within those annual periods, beginning after December 15, 2019. Management does not expect the adoption of this standard to have a material impact on the Company's consolidated financial statements.

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Leased Properties and Leases

12 Months Ended

Dec. 31, 2018

Leases [Abstract]

LEASED PROPERTIES AND LEASES

LEASED PROPERTIES AND LEASES

As of December 31, 2018, the Company had two significant leases following the sale of the Portland Terminal Facility and termination of Portland Lease Agreement on December 21, 2018. The properties, located in Wyoming, Louisiana and the Gulf of Mexico, are leased on a triple-net basis to major tenants, described in the table below. These major tenants are responsible for the payment of all taxes, maintenance, repairs, insurance and other operating expenses relating to the leased properties. The long-term, triple-net leases generally have an initial term of 11 to 15 years with options for renewals. Lease payments are scheduled to increase at varying intervals during the initial term of the leases. The following table summarizes the significant leased properties, major tenants and lease terms:

Summary of Leased Properties, Major Tenants and Lease Terms
Property	Grand Isle Gathering System	Pinedale LGS
Location	Gulf of Mexico/Louisiana	Pinedale, WY
Tenant	Energy XXI GIGS Services, LLC	Ultra Wyoming LGS, LLC
Asset Description	Approximately 153 miles of offshore pipeline with total capacity of 120 thousand Bbls/d, including a 16-acre onshore terminal and saltwater disposal system.	Approximately 150 miles of pipelines and four central storage facilities.
Date Acquired	June 2015	December 2012
Initial Lease Term	11 years	15 years
Renewal Option	Equal to the lesser of 9-years or 75 percent of the remaining useful life	5-year terms
Current Monthly Rent Payments	7/1/17 - 6/30/18: $2,854,667 7/1/18 - 6/30/19: $2,860,917	$1,776,772(1)
Estimated Useful Life	27 years	26 years
(1) Monthly rent payments increased to $1,812,307 beginning January 1, 2019.

The future contracted minimum rental receipts for all leases as of December 31, 2018, are as follows:

Future Minimum Lease Receipts
Year Ending December 31,	Amount
2019	$	58,347,190
2020	65,383,190
2021	71,345,190
2022	70,322,690
2023	67,274,690
Thereafter	193,639,760
Total	$	526,312,710

The table below displays the Company's individually significant leases as a percentage of total leased properties and total lease revenues for the periods presented:

	As a Percentage of (1)
	Leased Properties				Lease Revenues
	As of December 31,				For the Years Ended December 31,
	2018		2017		2018		2017		2016
Pinedale LGS (2)	44.5	%	39.9	%	35.2	%	31.2	%	30.4	%
Grand Isle Gathering System	55.2	%	49.7	%	55.9	%	59.1	%	59.8	%
Portland Terminal Facility (3)	—	%	10.1	%	8.8	%	9.6	%	9.7	%
(1) Insignificant leases are not presented; thus percentages may not sum to 100%.
(2) Pinedale LGS lease revenues include variable rent of $4.3 million and $587 thousand for the years ended December 31, 2018 and 2017, respectively.
(3) On December 21, 2018, the Portland Terminal Facility was sold to Zenith Terminals, terminating the Portland Lease Agreement. Refer to "Sale of the Portland Terminal Facility" section below.

The following table reflects the depreciation and amortization included in the accompanying Consolidated Statements of Income associated with the Company's leases and leased properties:

	For the Years Ended December 31,
	2018		2017		2016
Depreciation Expense
GIGS	$	10,836,590	$	9,754,596	$	8,605,506
Pinedale	8,869,440		8,869,440		8,869,440
Portland Terminal Facility (1)	1,243,769		1,275,660		843,084
United Property Systems	36,662		36,298		32,424
Total Depreciation Expense	$	20,986,461	$	19,935,994	$	18,350,454
Amortization Expense - Deferred Lease Costs
GIGS	$	30,564	$	30,564	$	30,564
Pinedale	61,368		61,368		61,368
Total Amortization Expense - Deferred Lease Costs	$	91,932	$	91,932	$	91,932
ARO Accretion Expense
GIGS	$	499,562	$	663,065	$	726,664
Total ARO Accretion Expense	$	499,562	$	663,065	$	726,664
(1) On December 21, 2018, the Portland Terminal Facility was sold to Zenith Terminals, terminating the Portland Lease Agreement. Refer to "Sale of the Portland Terminal Facility" section below.

The following table reflects the deferred costs that are included in the accompanying Consolidated Balance Sheets associated with the Company's leased properties:

	December 31, 2018		December 31, 2017
Net Deferred Lease Costs
GIGS	$	229,319	$	259,883
Pinedale	550,349		611,717
Total Deferred Lease Costs, net	$	779,668	$	871,600

TENANT INFORMATION

Substantially all of the lease tenants' financial results are driven by exploiting naturally occurring oil and natural gas hydrocarbon deposits beneath the Earth's surface. As a result, the tenants' financial results are highly dependent on the performance of the oil and natural gas industry, which is highly competitive and subject to volatility. During the terms of the leases, management monitors credit quality of its tenants by reviewing their published credit ratings, if available, reviewing publicly available financial statements, or reviewing financial or other operating statements, monitoring news reports regarding the tenants and their respective businesses and monitoring the timeliness of lease payments and the performance of other financial covenants under their leases.

Ultra Petroleum

On March 14, 2017, the bankruptcy court issued an order confirming its plan of reorganization and on April 12, 2017, UPL emerged from bankruptcy. UPL is currently subject to the reporting requirements under the Exchange Act and is required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. Its SEC filings can be found at www.sec.gov. Its stock is trading on the NASDAQ under the symbol UPL. The Company makes no representation as to the accuracy or completeness of the audited and unaudited financial statements of UPL but has no reason to doubt the accuracy or completeness of such information. In addition, UPL has no duty, contractual or otherwise, to advise the Company of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. None of the information in the public reports of UPL that are filed with the SEC is incorporated by reference into, or in any way form, a part of this filing.

Energy Gulf Coast/Cox Oil

The Company believes the terms of the Grand Isle Lease Agreement require copies of certain financial statement information be provided that the Company is required to file pursuant to SEC Regulation S-X, as described in Section 2340 of the SEC Financial Reporting Manual. Prior to October 29, 2018, EGC was subject to the reporting requirements of the Exchange Act and was required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. So long as EGC remained a public reporting company, the Grand Isle Lease Agreement provided this requirement was fulfilled by EGC making its financial statements and reports publicly available through the SEC’s EDGAR system, in lieu of delivering such information directly to the Company. On October 18, 2018, EGC was acquired by an affiliate of privately-held Cox Oil. Upon the filing by EGC of a Form 15 with the SEC on October 29, 2018, EGC's SEC reporting obligations were suspended and it ceased to file such reports.

As EGC's financial information is no longer publicly available, the Company is engaged in discussions with Cox Oil/EGC concerning satisfaction of its obligations under the Grand Isle Lease Agreement to provide the required information to the Company for inclusion in its SEC reports. To date, Cox Oil has not yet fulfilled these obligations. It is the Company's intention to enforce the obligations of EGC to provide the financial statement information that the Company believes are required under the terms of the Grand Isle Lease Agreement. The Company expects to file the financial statement information that is required by Regulation S-X by amendment to this Annual Report on Form 10-K once such information is made available in accordance with the terms of the lease.

EGC's SEC filings prior to October 29, 2018 can be found at www.sec.gov. The Company makes no representation as to the accuracy or completeness of the audited and unaudited financial statements of EGC but has no reason to doubt the accuracy or completeness of such information. In addition, EGC has no duty, contractual or otherwise, to advise the Company of any events that might have occurred subsequent to the date of such financial statements which could affect the significance or accuracy of such information. None of the information in the public reports of EGC that are filed with the SEC is incorporated by reference into, or in any way form, a part of this filing.

Sale of the Portland Terminal Facility

On December 21, 2018, the Company entered into a Purchase and Sale Agreement with Zenith Energy Terminals Holdings, LLC ("Zenith Terminals"), the Company's tenant under the Portland Lease Agreement, to sell the Portland Terminal Facility and remaining interest in the Joliet Terminal ("Joliet") for an aggregate consideration of $61.0 million, net of transaction costs. Of the negotiated sale price of $61.0 million, approximately $56.0 million was paid in cash at closing, with the balance of $5.0 million in a promissory note, which was paid on January 7, 2019. The Company would be entitled to receive certain additional consideration, under a formula prescribed in the Agreement, in the event Zenith sells, or enters into a definitive agreement to sell, the Portland Terminal Facility to a third party for a price greater than $60.0 million within six months following December 21, 2018. The sale of the Portland Terminal Facility effectively terminated the Portland Lease Agreement, dated January 14, 2014, between the Company and Zenith Terminals.

The consideration was allocated to the Portland Terminal Facility ($60.6 million) and Joliet ($0.4 million) based on fair value information utilized in negotiating the transaction. As of December 21, 2018, the Portland Terminal Facility had a carrying value of $45.7 million. The sale of the Portland Terminal Facility resulted in a gain on sale of leased asset of approximately $11.7 million, net of deferred rent receivable of approximately $3.2 million. Prior to the sale of the Joliet interest, the equity interest was valued at its transacted value of $1.2 million from the required reinvestment during the Arc Logistics merger with Zenith in December 2017. The sale of the Joliet interest resulted in a realized loss on other equity securities of approximately $715 thousand. Both the gain on sale of leased asset, net and the realized loss on other equity securities are included as items in other income (expense) in the Consolidated Statements of Income for the year ended December 31, 2018. Refer to Note 10 ("Fair Value") for additional information on the sale of the interest in Joliet.

Acquisition of Pinedale LGS Non-Controlling Interest

On December 29, 2017, Pinedale LP I, a wholly-owned subsidiary of the Company, purchased Prudential's 18.95 percent non-controlling equity interest in Pinedale LP for considerations of approximately $32.9 million. The carrying value of Prudential's non-controlling interest at the transaction date was $27.3 million. As the transaction resulted in an increase in the Company's interest in Pinedale LP, but not a change in control, the purchase was accounted for as an equity transaction. The difference between the fair value of the purchase consideration and the carrying value of the non-controlling interest of $5.6 million was recognized in additional paid-in-capital and attributable to the Company. Upon closing the transaction, the Company indirectly owns 100 percent of Pinedale LP through its wholly-owned subsidiaries Pinedale GP and Pinedale LP I and there is no longer a noncontrolling interest in the Company's consolidated financial statements.

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Transportation and Distribution Revenue

12 Months Ended

Dec. 31, 2018

Revenue from Contract with Customer [Abstract]

Transportation and Distribution Revenue

TRANSPORTATION AND DISTRIBUTION REVENUE

The Company's contracts related to transportation and distribution revenue are primarily comprised of a mix of natural gas supply, transportation and distribution performance obligations, as well as limited performance obligations related to system maintenance and expansion. Refer to Note 2 ("Significant Accounting Policies") for additional details on the Company's revenue recognition guidance under ASC 606.

The table below summarizes the Company's contract asset and contract liability balances related to its transportation and distribution revenue contracts as of December 31, 2018:

	Contract Asset(1)			Contract Liability(2)
Beginning Balance January 1, 2018	$	328,033		$	—
Cumulative Transition Adjustment Upon Adoption of ASC 606	—			3,307,109
Unrecognized Performance Obligations	(836,628		)	3,307,109
Recognized Performance Obligations	689,174			(91,864		)
Ending Balance December 31, 2018	$	180,579		$	6,522,354
(1) The contract asset balance is included in prepaid expenses and other assets in the Consolidated Balance Sheets.
(2) The contract liability balance is included in unearned revenue in the Consolidated Balance Sheets.

Based on a downward revision of the rate during the Company's long-term natural gas transportation contract with Spire, ASC 606 requires the Company to record the contractual transaction price, and therefore aggregate revenue, from the contract ratably over the term of the contract. Accordingly, on January 1, 2018, the Company recorded a cumulative adjustment to recognize a contract liability of approximately $3.3 million, and a corresponding reduction to beginning equity (net of deferred tax impact). The adjustment reflects the difference in amounts previously recognized as invoiced, versus cumulative revenues earned under the contract on a straight-line basis in accordance with ASC 606, as of the date of adoption. The contract liability continued to accumulate additional unrecognized performance obligations at a rate of approximately $992 thousand per quarter until the contractual rate decrease took effect in November 2018. Following the rate decline, recognized performance obligations exceeded amounts invoiced and the contract liability will decline at a rate of approximately $138 thousand per quarter through the end of the contract in October 2030. As of December 31, 2018, the revenue allocated to the remaining performance obligation under this contract is approximately $63.5 million.

The following is a breakout of the Company's transportation and distribution revenue for the years ended December 31, 2018, 2017 and 2016:

	For the Years Ended December 31,
	2018		2017		2016
Natural gas transportation contracts	64.3	%	71.5	%	67.6	%
Natural gas distribution contracts	26.8	%	20.4	%	19.0	%

In accordance with ASC 606 transition disclosure requirements, the cumulative effect of changes made to the Consolidated Balance Sheet as of January 1, 2018 for the adoption of ASC 606 were as follows:

Balance Sheet	Balance at December 31, 2017		Adjustments Due to ASC 606			Balance at January 1, 2018
Assets
Deferred Tax Asset	$	2,244,629	$	857,864		$	3,102,493
Liabilities
Unearned revenue	3,397,717		3,307,109			6,704,826
Equity
Additional paid in capital	331,773,716		(2,449,245		)	329,324,471

The tables below disclose the impact of adoption on the Consolidated Balance Sheet and Consolidated Statement of Income as of and for the year ended December 31, 2018:

	As of December 31, 2018
Balance Sheet	As Reported		Balances Without Adoption of ASC 606		Effect of Change Higher/(Lower)
Assets
Deferred Tax Asset	$	4,948,203	$	3,256,304	$	1,691,899
Liabilities
Unearned revenue	6,552,049		29,695		6,522,354
Equity
Additional paid in capital	320,295,969		325,126,424		(4,830,455		)

	For the Year Ended December 31, 2018
Statement of Income	As Reported			Balances Without Adoption of ASC 606			Effect of Change Higher/(Lower)
Revenues
Transportation and distribution revenue	$	16,484,236		$	19,699,481		$	(3,215,245	)
Taxes
Deferred tax benefit	(1,833,340		)	(999,305		)	(834,035		)

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Financing Notes Receivable

12 Months Ended

Dec. 31, 2018

Receivables [Abstract]

FINANCING NOTES RECEIVABLE

FINANCING NOTES RECEIVABLE

Four Wood Financing Note Receivable

On December 31, 2014, a subsidiary of the Company, Four Wood Corridor, LLC ("Four Wood Corridor"), entered into a Loan Agreement with SWD Enterprises, LLC ("SWD Enterprises"), a wholly-owned subsidiary of Four Wood Energy, pursuant to which Four Wood Corridor made a loan to SWD Enterprises for $4.0 million (the "REIT Loan"). Concurrently, the Company's TRS, Corridor Private entered into a TRS Loan Agreement with SWD Enterprises, pursuant to which Corridor Private made a loan to SWD Enterprises for $1.0 million (the "TRS Loan"). The proceeds of the REIT Loan and the TRS Loan were used by SWD Enterprises and its affiliates to finance the acquisition of real and personal property that provides saltwater disposal services for the oil and natural gas industry, and to pay related expenses. For the REIT Loan from Four Wood Corridor, interest initially accrued on the outstanding principal at an annual base rate of 12 percent. For the TRS Loan from Corridor Private, interest initially accrued on the outstanding principal at an annual base rate of 13 percent. The base rates of both loans were to increase by 2 percent of the current base rate per year. The REIT Loan and the TRS Loan are secured by the real property and equipment held by SWD Enterprises and the outstanding equity in SWD Enterprises and its affiliates. The REIT Loan and the TRS Loan are also guaranteed by all affiliates of SWD Enterprises.

As a result of the decreased economic activity by SWD Enterprises, the Company recorded a provision for loan loss with respect to the SWD loans. The Consolidated Statement of Income for the year ended December 31, 2016 reflects a provision for loan loss of $3.5 million, which includes $71 thousand of deferred origination income and $98 thousand of interest accrued under the original loan agreements. The loans were placed on non-accrual status during the first quarter of 2016. During the first quarter of 2018, the Company recorded an additional provision for loan loss on the SWD loans of $500 thousand. Prior to the sale of the real property and equipment securing the loans to a new third-party debtor in the fourth quarter of 2018 as discussed further below, the balance of the SWD loans was valued based on the enterprise value of SWD Enterprises, the collateral value supporting the loans, at $1.0 million during 2018 and $1.5 million as of December 31, 2017, respectively.

On December 12, 2018, Four Wood Corridor granted SWD Enterprises approval to sell the assets securing the REIT Loan and the TRS Loan, as described above, to Compass SWD, LLC ("Compass SWD") in exchange for Compass SWD executing a new loan agreement with Four Wood Corridor for $1.3 million (the "Compass REIT Loan") and approximately $237 thousand in cash consideration, net of costs facilitating the close. The Compass REIT Loan is scheduled to mature on June 15, 2019 and interest is accrued on the outstanding principal at an annual rate of LIBOR plus 6 percent. As of December 31, 2018, the Compass REIT Loan is valued at $1.3 million. As a result of the transaction, SWD Enterprises was released from the terms of the REIT Loan and the TRS Loan, and the Company recognized a provision for loan gain of $37 thousand in the Consolidated Statements of Income for the year ended December 31, 2018.

Black Bison Financing Notes

During 2014, the Company's wholly-owned subsidiaries, Corridor Bison and CorEnergy BBWS, entered into loan agreements with Black Bison Water Services, LLC ("Black Bison WS") totaling $12.0 million and $3.3 million, respectively (the "Black Bison WS Loan" and the "TRS Loan" and, together the "Black Bison Loans"). The purpose of the loans was to finance the acquisition and development of real property to provide water sourcing, water disposal, or water treating and recycling services for the oil and natural gas industry. The Black Bison Loans were set to mature on March 31, 2024, and were set to amortize by quarterly payments beginning on March 31, 2015. The Loans were secured by the real property and equipment held by Black Bison WS and the outstanding equity in Black Bison WS and its affiliates. The Black Bison Loans were also guaranteed by all affiliates of Black Bison WS and further secured by all assets of those guarantors.

Due to reduced drilling activity in the Black Bison area of operations, Black Bison WS requested, and the Company granted, certain temporary forbearance waivers in June 2015 and August 2015 that had the effect of excusing the borrower from full performance under the terms of the Black Bison Loans while such waivers were in effect. None of the granted forbearance agreements were deemed to be concessions. As a result of the continued inability of the borrower to perform under the terms of these loans, even as temporarily modified by the waivers, effective December 31, 2015, the Company recorded a provision for loan loss with respect to the Black Bison Loans of $13.8 million.

On February 29, 2016, the Company foreclosed on 100 percent of the equity of BB Intermediate, the borrower of the Black Bison financing notes, as well as all of the other collateral securing the Black Bison Loans. The foreclosure was accepted in satisfaction of the $2.0 million total outstanding loan balance. On June 16, 2016, the Company entered into an asset sale agreement with Expedition Water Solutions for the sale of specified disposal wells and related equipment as outlined in the sale agreement. Consideration received by the company included $748 thousand cash, net of fees, and the future right to royalty payments, which was recorded at its fair value of $450 thousand. The rights to future cash payments are tied to the future volumes of water disposed of in each of the wells sold. The Company did not record any financing revenue related to the Black Bison Loans for the year ended December 31, 2016 or any subsequent period. These notes were considered by the Company to be on non-accrual status and were reflected as such in the financial statements. For the year ended December 31, 2016, the Company recorded $832 thousand in provision for loan loss related to the Black Bison Loans.

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Income Taxes

12 Months Ended

Dec. 31, 2018

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

Deferred income taxes reflect the net tax effect of temporary differences between the carrying amount of assets and liabilities for financial reporting and tax purposes. Components of the Company's deferred tax assets and liabilities as of December 31, 2018 and 2017, are as follows:

Deferred Tax Assets and Liabilities
	December 31, 2018			December 31, 2017
Deferred Tax Assets:
Deferred contract revenue	$	1,691,899		$	—
Net operating loss carryforwards	5,424,671			957,719
Loan loss provision	263,508			247,814
Basis reduction of investment in partnerships	—			261,549
Other	95,695			2,965,321
Sub-total	$	7,475,773		$	4,432,403
Deferred Tax Liabilities:
Net unrealized gain on investment securities	$	—		$	(342,669	)
Cost recovery of leased and fixed assets	(2,508,547		)	(1,845,105		)
Other	(19,023		)	—
Sub-total	$	(2,527,570	)	$	(2,187,774	)
Total net deferred tax asset	$	4,948,203		$	2,244,629

As of December 31, 2018, the total deferred tax assets and liabilities presented above relate to the Company's TRSs. The Company recognizes the tax benefits of uncertain tax positions only when the position is "more likely than not" to be sustained upon examination by the tax authorities based on the technical merits of the tax position. The Company's policy is to record interest and penalties on uncertain tax positions as part of tax expense. Tax years subsequent to the year ended December 31, 2014, remain open to examination by federal and state tax authorities.

The Tax Cuts and Jobs Act (the "2017 Tax Act") was enacted on December 22, 2017. The 2017 Tax Act reduced the US federal corporate tax rate from 35 percent to 21 percent. The 2017 Tax Act also repealed the alternative minimum tax for corporations. In December 2018, the Company completed its accounting for the tax effects of enactment of the 2017 Tax Act as allowed under SEC Staff Accounting Bulletin 118. The Company remeasured deferred tax assets and liabilities based on the updated rates at which they are expected to reverse in the future, which resulted in a $1.3 million transition adjustment that reduced net deferred tax assets. One of the Company's TRSs qualifies for the regulated utility and real property business exceptions under the new proposed treasury regulations for Section 163(j). Therefore, previously disqualified interest from years prior to 2018 was deducted and resulted in a reclassification from other deferred tax assets to deferred tax assets for net operating loss carryforwards during the year ended December 31, 2018. Refer to additional discussion of the Company's net operating loss carryforwards below. The Company will continue to assess the impact of new tax legislation, as well as any future regulations and updates provided by the tax authorities.

Total income tax expense (benefit) differs from the amount computed by applying the federal statutory income tax rate of 21 percent for the year ended December 31, 2018 and 35 percent for the years ended December 31, 2017 and 2016, to income or loss from operations and other income and expense for the years presented, as follows:

Income Tax Expense (Benefit)
	For the Years Ended December 31,
	2018			2017			2016
Application of statutory income tax rate	$	8,671,562		$	12,231,838		$	10,219,573
State income taxes, net of federal tax benefit	(583,186		)	352,708			26,215
Income of Real Estate Investment Trust not subject to tax	(10,339,520		)	(11,975,853		)	(10,663,371		)
Tax reform impact	—			1,262,444			—
Other	(167,582		)	474,181			(46,837		)
Total income tax expense (benefit)	$	(2,418,726	)	$	2,345,318		$	(464,420	)

Total income taxes are computed by applying the federal statutory rate of 21 percent plus a blended state income tax rate. Corridor Public Holdings, Inc. and Corridor Private Holdings, Inc. had a blended state rate of approximately 5.53 percent, 3.78 percent and 3.78 percent for the years ended December 31, 2018, 2017 and 2016, respectively. CorEnergy BBWS, Inc. had a blended state income tax rate of approximately 5 percent for the year ended December 31, 2018 due to its operations in Missouri. CorEnergy BBWS, Inc. did not record a provision for state income taxes for the years ended December 31, 2017 and 2016 because it only operated in Wyoming, which does not have state income tax. Because Corridor MoGas, Inc. primarily only operates in the state of Missouri, a blended state income tax rate of 5 percent was used for the operation of the TRS for the years ended December 31, 2018, 2017 and 2016. Prior to its reorganization to a QRS at the end of 2017, Mowood Corridor, Inc. had a blended state income tax rate of 5 percent for the years ended December 31, 2017 and 2016. For the years ended December 31, 2018, 2017 and 2016, all of the income tax expense (benefit) presented above relates to the assets and activities held in the Company's TRSs. The components of income tax expense (benefit) include the following for the periods presented:

Components of Income Tax Expense (Benefit)
	For the Years Ended December 31,
	2018			2017			2016
Current tax expense (benefit)
Federal	$	(413,248	)	$	2,498,363		$	(321,720	)
State (net of federal tax benefit)	(172,138		)	333,295			8,613
Total current tax expense (benefit)	$	(585,386	)	$	2,831,658		$	(313,107	)
Deferred tax expense (benefit)
Federal	$	(1,422,292	)	$	(505,753	)	$	(168,915	)
State (net of federal tax benefit)	(411,048		)	19,413			17,602
Total deferred tax benefit	$	(1,833,340	)	$	(486,340	)	$	(151,313	)
Total income tax expense (benefit), net	$	(2,418,726	)	$	2,345,318		$	(464,420	)

As of December 31, 2017 and 2016, the TRSs had a cumulative net operating loss of $4.1 million and $3.0 million, respectively. For the year ended December 31, 2018, the TRSs incurred a net operating loss of approximately $17.1 million, resulting in a cumulative net operating loss of approximately $21.0 million as of December 31, 2018. The net operating loss generated during the year ended December 31, 2018 may be carried forward indefinitely, subject to limitation. Net operating losses generated for years prior to December 31, 2018 may be carried forward for 20 years. If not utilized, the net operating loss will expire as follows: $328 thousand, $176 thousand, $1.4 million and $2.0 million in the years ending December 31, 2034, 2035, 2036 and 2037, respectively. The amount of deferred tax asset for net operating losses as of December 31, 2018 includes amounts for the year ended December 31, 2018.

The aggregate cost of securities for federal income tax purposes and securities with unrealized appreciation and depreciation, were as follows:

Aggregate Cost of Securities for Income Tax Purposes
	December 31, 2018		December 31, 2017
Aggregate cost for federal income tax purposes	$	408,051	$	3,063,430
Gross unrealized appreciation	—		325,130
Gross unrealized depreciation	—		—
Net unrealized appreciation	$	—	$	325,130

The Company provides the following tax information to its common stockholders pertaining to the character of distributions paid during tax years 2018, 2017 and 2016. For a stockholder that received all distributions in cash during 2018, 71.3 percent will be treated as ordinary dividend income, none will be treated as return of capital and 28.7 percent will be treated as capital gain distributions. Of the ordinary dividend income, none will be treated as qualified dividend income for a non-corporate taxpayer; all of the ordinary dividend income may be taken into account on an individual's section 199A deduction, subject to the applicable holding period. Of the capital gain distribution, 13.4 percent is subject to a maximum 25 percent federal income tax rate and 15.3 percent is subject to a maximum 20 percent federal income tax rate. The per share characterization by quarter is reflected in the following tables:

2018 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Unrecaptured Section 1250 Gain		Section 199A Dividends
2/14/2018	2/13/2018	2/28/2018	$	0.7500	$	0.5346	$	—	$	0.2154	$	0.1007	$	0.5346
5/17/2018	5/16/2018	5/31/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
8/17/2018	8/16/2018	8/31/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
11/15/2018	11/14/2018	11/30/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
Total 2018 Distributions			$	3.0000	$	2.1384	$	—	$	0.8616	$	0.4028	$	2.1384

2017 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
2/13/2017	2/9/2017	2/28/2017	$	0.7500	$	0.5925	$	0.0785	$	—	$	0.1575
5/16/2017	5/12/2017	5/31/2017	0.7500		0.5925		0.0785		—		0.1575
8/17/2017	8/15/2017	8/31/2017	0.7500		0.5925		0.0785		—		0.1575
11/15/2017	11/14/2017	11/30/2017	0.7500		0.5925		0.0785		—		0.1575
Total 2017 Distributions			$	3.0000	$	2.3700	$	0.3140	$	—	$	0.6300

2016 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
02/12/2016	02/10/2016	02/29/2016	$	0.7500	$	0.2955	$	—	$	—	$	0.4545
05/13/2016	05/11/2016	05/31/2016	0.7500		0.2955		—		—		0.4545
08/17/2016	08/15/2016	08/31/2016	0.7500		0.2955		—		—		0.4545
11/15/2016	11/11/2016	11/30/2016	0.7500		0.2955		—		—		0.4545
Total 2016 Distributions			$	3.0000	$	1.1820	$	—	$	—	$	1.8180

The Company provides the following tax information to its preferred stockholders pertaining to the character of distributions paid during the 2018, 2017 and 2016 tax years. For a stockholder that received all distributions in cash during 2018, 71.3 percent will be treated as ordinary dividend income, none will be treated as return of capital and 28.7 percent will be treated as capital gain distributions. Of the ordinary dividend income, none will be treated as qualified dividend income for a non-corporate taxpayer; all of the ordinary dividend income may be taken into account on an individual's section 199A deduction, subject to the applicable holding period. Of the capital gain distribution, 13.4 percent is subject to a maximum 25 percent federal income tax rate and 15.3 percent is subject to a maximum 20 percent federal income tax rate. The per share characterization by quarter is reflected in the following tables:

2018 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Unrecaptured Section 1250 Gain		Section 199A Dividends
2/14/2018	2/13/2018	2/28/2018	$	0.4609	$	0.3285	$	—	$	0.1324	$	0.0619	$	0.3285
5/17/2018	5/16/2018	5/31/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
8/17/2018	8/16/2018	8/31/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
11/15/2018	11/14/2018	11/30/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
Total 2018 Distributions			$	1.8436	$	1.3140	$	—	$	0.5296	$	0.2476	$	1.3140

2017 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
2/13/2017	2/9/2017	2/28/2017	$	0.4609	$	0.4609	$	0.0611	$	—	$	—
5/16/2017	5/12/2017	5/31/2017	0.4609		0.4609		0.0611		—		—
8/17/2017	8/15/2017	8/31/2017	0.4609		0.4609		0.0611		—		—
11/15/2017	11/14/2017	11/30/2017	0.4609		0.4609		0.0611		—		—
Total 2017 Distributions			$	1.8436	$	1.8436	$	0.2444	$	—	$	—

2016 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
02/12/2016	02/10/2016	02/29/2016	$	0.4609	$	0.4609	$	—	$	—	$	—
05/13/2016	05/11/2016	05/31/2016	0.4609		0.4609		—		—		—
08/17/2016	08/15/2016	08/31/2016	0.4609		0.4609		—		—		—
11/15/2016	11/11/2016	11/30/2016	0.4609		0.4609		—		—		—
Total 2016 Distributions			$	1.8436	$	1.8436	$	—	$	—	$	—

The Company elected, effective for the 2013 tax year, to be treated as a REIT for federal income tax purposes. The Company's REIT election, assuming continued compliance with the applicable tests, will continue in effect for subsequent tax years. The Company satisfied the annual income test and the quarterly asset tests necessary for us to qualify to be taxed as a REIT for 2018, 2017 and 2016. Distributions made during 2017 were treated as qualifying dividend income related to taxable dividends received from the Company's TRSs that were received and distributed in the same year.

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Property and Equipment

12 Months Ended

Dec. 31, 2018

Property, Plant and Equipment [Abstract]

PROPERTY AND EQUIPMENT

PROPERTY AND EQUIPMENT

Property and equipment consist of the following:

Property and Equipment
	December 31, 2018			December 31, 2017
Land	$	580,000		$	580,000
Natural gas pipeline	124,306,175			124,303,315
Vehicles and trailers	696,164			650,634
Office equipment and computers	268,559			268,559
Gross property and equipment	$	125,850,898		$	125,802,508
Less: accumulated depreciation	(15,969,346		)	(12,643,636		)
Net property and equipment	$	109,881,552		$	113,158,872

Depreciation expense was $3.4 million for the years ended December 31, 2018, 2017 and 2016, respectively.

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Concentrations

12 Months Ended

Dec. 31, 2018

Risks and Uncertainties [Abstract]

Concentrations

CONCENTRATIONS

The Company has customer concentrations through major tenants at its two significant leased properties as discussed fully in Note 3 ("Leased Properties And Leases"). In addition to these lease concentrations, contracted transportation revenues from the Company's subsidiary, MoGas, to its largest customer, Spire (formally Laclede Gas Company), represented approximately 6 percent, 11 percent and 12 percent of consolidated revenues for the years ended December 31, 2018, 2017 and 2016, respectively. The Company's contracted transportation revenues with Spire for the year ended December 31, 2018 were impacted by the adoption of ASC 606, which required the Company to record the contract with Spire on a straight-line basis and record a transition adjustment on January 1, 2018. Refer to Note 4 ("Transportation And Distribution Revenue") for additional details.

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Management Agreement

12 Months Ended

Dec. 31, 2018

Agreements [Abstract]

MANAGEMENT AGREEMENT

MANAGEMENT AGREEMENT

The Company has executed a Management Agreement with Corridor InfraTrust Management, LLC ("Corridor"), a related party. Under the Management Agreement, Corridor (i) presents the Company with suitable acquisition opportunities consistent with the investment policies and objectives of the Company, (ii) is responsible for the day-to-day operations of the Company and (iii) performs such services and activities relating to the assets and operations of the Company as may be appropriate. The Management Agreement, which does not have a specific term and will remain in place unless terminated by the Company or Corridor in accordance with its terms, does give a majority of the stockholders of the Company, or two-thirds of the independent directors, the ability to terminate the agreement for any reason on thirty (30) days' prior written notice, so long as that notice is delivered with a termination payment equal to three times the base management fee and incentive fee paid to the manager in the last four quarters.

The terms of the Management Agreement provide for a quarterly management fee to be paid to Corridor equal to 0.25 percent (1.00 percent annualized) of the value of the Company's Managed Assets as of the end of each quarter. "Managed Assets" means the total assets of the Company (including any securities receivables, other personal property or real property purchased with or attributable to any borrowed funds) minus (A) the initial invested value of all non-controlling interests, (B) the value of any hedged derivative assets, (C) any prepaid expenses and (D) all of the accrued liabilities other than (1) deferred taxes and (2) debt entered into for the purpose of leverage. For purposes of the definition of Managed Assets, the Company's securities portfolio will be valued at then current market value. For purposes of the definition of Managed Assets, other personal property and real property assets will include real and other personal property owned and the assets of the Company invested, directly or indirectly, in equity interests in or loans secured by real estate or personal property (including acquisition related costs and acquisition costs that may be allocated to intangibles or are unallocated), valued at the aggregate historical cost, before reserves for depreciation, amortization, impairment charges or bad debts or other similar noncash reserves.

The Management Agreement also provides for payment of a quarterly incentive fee of 10 percent of the increase in distributions paid over a distribution threshold equal to $0.625 per share per quarter, and requires that at least half of any incentive fees that are paid be reinvested in the Company's common stock. The foregoing description of the terms of the May 1, 2015 Management Agreement is qualified in its entirety by reference to the full terms of such agreement, which is incorporated by reference as an exhibit to this Report.

During the years ended December 31, 2017 and 2016 the Company and the Manager agreed to the following modifications to the fee arrangements described above:

• In light of the provisions for loan losses recognized by the Company on certain of its energy infrastructure financing investments (collectively, the "Underperforming Loans") during 2015 and the first quarter of 2016, the Manager voluntarily recommended, and the Company agreed, that effective on and after the Company's March 31, 2016 balance sheet date, solely for the purpose of computing the value of the Company's Managed Assets in calculating the quarterly management fee under the terms of the Management Agreement, that portion of the Management Fee attributable to the Company's investment in the Underperforming Loans shall be based on the estimated net realizable value of such loans, which shall not exceed the amount invested in the Underperforming Loans as of the end of the quarter for which the Management Fee is to be calculated.

• During the year ended December 31, 2016, the Manager voluntarily recommended, and the Company agreed, that the Manager would waive $88 thousand of the total $595 thousand incentive fee that would have otherwise been payable under the provisions of the Management Agreement with respect to dividends paid on the Company's common stock.

• During the year ended December 31, 2017, the Manager voluntarily recommended, and the Company agreed, that the Manager would waive $100 thousand of the total $595 thousand incentive fee that would otherwise be payable under the provisions of the Management Agreement with respect to dividends paid on the Company's common stock.

• In order to ensure equitable application of the quarterly management fee provisions of the Management Agreement for the acquisition of Prudential's minority limited partner interest in Pinedale LP, which closed on December 29, 2017, the Manager waived any incremental management fee due as of the end of the fourth quarter of 2017 based on the net impact of the Pinedale LP acquisition.

Fees incurred under the Management Agreement for the years ended December 31, 2018, 2017 and 2016 were $7.6 million, $7.2 million and $7.2 million, respectively, and are reported in the General and Administrative line item on the Consolidated Statements of Income.

The Company pays Corridor, as the Company's Administrator pursuant to an Administrative Agreement, an administrative fee equal to an annual rate of 0.04 percent of the value of the Company's Managed Assets, with a minimum annual fee of $30 thousand. Fees incurred under the Administrative Agreement for the years ended December 31, 2018, 2017 and 2016 were $280 thousand, $269 thousand and $266 thousand, respectively, and are reported in the General and Administrative line item on the Consolidated Statements of Income.

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Fair Value

12 Months Ended

Dec. 31, 2018

Fair Value Disclosures [Abstract]

FAIR VALUE

FAIR VALUE

As of December 31, 2017, the Company's investments in Lightfoot and Joliet were its only remaining private company other equity securities. These other equity securities were also the only assets and liabilities measured at fair value on a recurring basis. Certain private equity investments were sold or disposed of by the end of 2018. Refer to the "Lightfoot" and "Joliet" sections below for additional details.

The following tables set forth the Company's assets and liabilities measured at fair value on a recurring basis, by input level within the fair value hierarchy, as of December 31, 2017:

	December 31, 2017
	Total		Fair Value
			Level 1		Level 2		Level 3
Assets:
Other equity securities	$	2,958,315	$	—	$	—	$	2,958,315
Total Assets	$	2,958,315	$	—	$	—	$	2,958,315

The changes for all Level 3 securities measured at fair value on a recurring basis using significant unobservable inputs for the years ended December 31, 2018 and 2017, are as follows:

Level 3 Rollforward
For the Year Ended 2018	Fair Value Beginning Balance		Acquisitions		Disposals			Total Realized and Unrealized Gains (Losses) Included in Net Income			Return of Capital Adjustments Impacting Cost Basis of Securities			Fair Value Ending Balance		Changes in Unrealized Gains Included In Net Income, Relating to Securities Still Held (1)
Other equity securities	$	2,958,315	$	—	$	(449,067	)	$	(1,845,309	)	$	(663,939	)	$	—	$	—
Total	$	2,958,315	$	—	$	(449,067	)	$	(1,845,309	)	$	(663,939	)	$	—	$	—
For the Year Ended 2017
Other equity securities	$	9,287,209	$	1,161,034	$	(8,752,201	)	$	1,531,827		$	(269,554	)	$	2,958,315	$	295,161
Total	$	9,287,209	$	1,161,034	$	(8,752,201	)	$	1,531,827		$	(269,554	)	$	2,958,315	$	295,161
(1) Located in Net realized and unrealized gain on other equity securities in the Consolidated Statements of Income

The Company utilizes the beginning of reporting period method for determining transfers between levels. There were no transfers between levels 1, 2 or 3 for the years ended December 31, 2018 and 2017.

Valuation Techniques and Unobservable Inputs

The Company's other equity securities, which represent securities issued by private companies, were classified as Level 3 assets and the Company elected to report at fair value under the fair value option. Significant judgment was required in selecting the assumptions used to determine the fair values of these investments.

Lightfoot

The Company's Lightfoot investment consisted of a 6.6 percent and 1.5 percent equity interest in Lightfoot LP and Lightfoot GP, respectively. As of December 31, 2017, Lightfoot's only material asset consisted of its remaining investment in Gulf LNG, a 1.5 billion cubic feet per day ("bcf/d") receiving, storage and regasification terminal in Pascagoula, Mississippi.

On December 21, 2017, Zenith closed its acquisition of Arc Logistics. Under the terms of the agreement, Lightfoot LP received $14.50 per common unit of Arc Logistics. Lightfoot LP additionally received $36.2 million for the sale of 5.52 percent of its interest in Gulf LNG to Zenith (the "Unconditional Interest"). In addition, Zenith was to purchase the remaining 4.16 percent of Lightfoot's Gulf LNG interest (the "Conditional Interest") for an additional $27.3 million upon a successful outcome (as defined) of the Gulf LNG arbitration with Eni USA, as discussed further below. Lightfoot GP received $94.5 million for 100 percent of the membership interests in Arc Logistics GP. Under the terms of the merger, at closing, Lightfoot LP and Lightfoot GP used a portion of their sale proceeds to purchase an approximate 13.5 percent interest in Joliet.

Subsequent to closing of the transaction, the Company received $7.6 million in cash proceeds related to its pro rata portion of the sale proceeds of Lightfoot, including proceeds related to Arc Logistics common units, the Unconditional Interest in Gulf LNG and membership interests in Arc Logistics GP. Amounts received are net of approximately $1.2 million related to the Company's required reinvestment in Joliet.

On March 1, 2016, an affiliate of Gulf LNG received a Notice of Disagreement and Disputed Statements and a Notice of Arbitration from Eni USA, one of the two companies that had entered into a terminal use agreement for capacity of the liquefied natural gas facility owned by Gulf LNG and its subsidiaries. On June 29, 2018, the arbitration panel delivered its award, and the panel's ruling calls for the termination of the agreement and Eni USA's payment of compensation to Gulf LNG. On September 25, 2018, Gulf LNG filed a lawsuit against Eni USA in the Delaware Court of Chancery to enforce the award. Further, on September 28, 2018, Gulf LNG filed a lawsuit against Eni S.p.A. in the Supreme Court of the State of New York in New York County to enforce a guarantee agreement entered by Eni S.p.A. in connection with the terminal use agreement.

During the third quarter of 2018, the fair value of the Lightfoot investment was reduced to zero due to additional market information. In the fourth quarter of 2018, the Company received a distribution representing a return of capital totaling approximately $667 thousand due to the disposition of the remaining asset interest. The Company recognized a realized loss of $1.1 million for the year ended December 31, 2018. The loss is recorded in net realized and unrealized gain (loss) on other equity securities in the Consolidated Statements of Income.

Joliet

As of December 31, 2017, the Company owned a 0.6 percent interest in Joliet, which was acquired in conjunction with the terms of Zenith's acquisition of Arc Logistics discussed above.

On December 21, 2018, the Company sold its interest in Joliet, along with the Portland Terminal Facility, to Zenith Terminals for approximately $446 thousand. The sale resulted in a realized loss on other equity securities of approximately $715 thousand included in net realized and unrealized gain (loss) on other equity securities in the Consolidated Statements of Income for the year ended December 31, 2018.

The fair value of the Company's private company investments at December 31, 2017 was approximately $3.0 million, which was determined using recent transaction data and expected proceeds, discounted using a risk-free rate through the expected receipt date. Due to the inherent uncertainty of determining the fair value of investments that do not have a readily available market value, the fair value of the Company's investment may fluctuate from period to period. Additionally, the fair value of the Company's investment may differ from the values that would have been used had a ready market existed for such investment and may differ materially from the values that the Company may ultimately realize.

The following section describes the valuation methodologies used by the Company for estimating fair value for financial instruments not recorded at fair value, but fair value is included for disclosure purposes only, as required under disclosure guidance related to the fair value of financial instruments.

Cash and Cash Equivalents — The carrying value of cash, amounts due from banks, federal funds sold and securities purchased under resale agreements approximates fair value.

Financing Notes Receivable — The financing notes receivable are valued on a non-recurring basis. The financing notes receivable are reviewed for impairment when events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Financing Notes with carrying values that are not expected to be recovered through future cash flows are written-down to their estimated net realizable value. Estimates of realizable value are determined based on unobservable inputs, including estimates of future cash flow generation and value of collateral underlying the notes.

Secured Credit Facilities — The fair value of the Company's long-term variable-rate and fixed-rate debt under its secured credit facilities approximates carrying value.

Unsecured Convertible Senior Notes — The fair value of the unsecured convertible senior notes is estimated using quoted market prices.

Carrying and Fair Value Amounts
	Level within Fair Value Hierarchy	December 31, 2018				December 31, 2017
		Carrying Amount (1)		Fair Value		Carrying Amount (1)		Fair Value
Financial Assets:
Cash and cash equivalents	Level 1	$	69,287,177	$	69,287,177	$	15,787,069	$	15,787,069
Financing notes receivable (Note 5)	Level 3	1,300,000		1,300,000		1,500,000		1,500,000
Financial Liabilities:
Secured credit facilities	Level 2	$	37,261,109	$	37,261,109	$	40,745,354	$	40,745,354
Unsecured convertible senior notes	Level 1	112,777,271		119,378,982		112,032,083		139,101,660
(1) The carrying value of debt balances are presented net of unamortized original issuance discount and debt issuance costs.

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Debt

12 Months Ended

Dec. 31, 2018

Debt Disclosure [Abstract]

DEBT

DEBT

The following is a summary of debt facilities and balances as of December 31, 2018 and 2017:

	Total Commitment  or Original Principal		Quarterly Principal Payments			December 31, 2018				December 31, 2017
					Maturity Date	Amount Outstanding		Interest Rate		Amount Outstanding		Interest Rate
CorEnergy Secured Credit Facility:
CorEnergy Revolver	$	160,000,000	$	—	7/28/2022	$	—	5.25	%	$	—	4.32	%
MoGas Revolver	1,000,000		—		7/28/2022	—		5.25	%	—		4.32	%
Omega Line of Credit	1,500,000		—		7/31/2019	—		6.50	%	—		5.57	%
Pinedale Secured Credit Facility:
Amended Pinedale Term Credit Facility	41,000,000		882,000		12/29/2022	37,472,000		6.50	%	41,000,000		6.50	%
7.00% Unsecured Convertible Senior Notes	115,000,000		—		6/15/2020	113,958,000		7.00	%	114,000,000		7.00	%
Total Debt						$	151,430,000			$	155,000,000
Less:
Unamortized deferred financing costs (1)						$	283,278			$	375,309
Unamortized discount on 7.00% Convertible Senior Notes						1,108,342				1,847,254
Long-term debt, net of deferred financing costs						$	150,038,380			$	152,777,437
Debt due within one year						$	3,528,000			$	3,528,000
(1) Unamortized deferred financing costs related to the Company's revolving credit facilities are included in Deferred Costs in the Assets section of the Consolidated Balance Sheets. Refer to the "Deferred Financing Costs" paragraph below.

CorEnergy Credit Facilities

On July 8, 2015, the Company amended and upsized its then current $93.0 million credit facility with Regions Bank (as lender and administrative agent for the other participating lenders) to provide borrowing commitments of $153.0 million, consisting of (i) an increase in the CorEnergy Revolver at the CorEnergy parent entity level to $105.0 million, (ii) a $45.0 million term loan at the CorEnergy parent entity level (the "CorEnergy Term Loan") and (iii) a $3.0 million revolving credit facility at the MoGas subsidiary entity level (the "MoGas Revolver" and, collectively with the upsized CorEnergy Revolver and the CorEnergy Term Loan, the "CorEnergy Credit Facility"). Upon closing the CorEnergy Credit Facility, CorEnergy drew $45.0 million on the CorEnergy Term Loan to pay off the balance on the CorEnergy Revolver that had been used in funding the GIGS acquisition in June 2015. The term note required quarterly principal payments of $900 thousand, which began on September 30, 2015. Quarterly principal payments were subsequently increased to $1.6 million in conjunction with the financing of the Pinedale Credit Facility, discussed further below.

On July 28, 2017, the Company entered into an amendment and restatement of the CorEnergy Credit Facility with Regions Bank (as lender and administrative agent for other participating lenders). The amended facility provides for borrowing commitments of up to $161.0 million, consisting of (i) $160.0 million on the CorEnergy Revolver, subject to borrowing base limitations, and (ii) $1.0 million on the MoGas Revolver, as detailed below. In connection with entering into the amended and restated facility on July 28, 2017, the Company used cash on hand and $10.0 million of borrowings under the amended facility to repay the $33.5 million outstanding balance on the CorEnergy Term Loan.

The amended facility has 5-year term maturing on July 28, 2022, and provides for a springing maturity on February 28, 2020, and thereafter, if the Company fails to meet certain liquidity requirements from the springing maturity date through the maturity of the Company's convertible notes on June 15, 2020. Borrowings under the credit facility will generally bear interest on the outstanding principal amount using a LIBOR pricing grid that is expected to equal a LIBOR rate plus an applicable margin of 2.75 percent to 3.75 percent, based on the Company's senior secured recourse leverage ratio. Total availability is subject to a borrowing base. The CorEnergy Credit Facility contains, among other restrictions, certain financial covenants including the maintenance of certain financial ratios, as well as default and cross-default provisions customary for transactions of this nature (with applicable customary grace periods).

The CorEnergy Credit Facility is secured by substantially all of the assets owned by the Company and its subsidiaries other than (i) the assets held by Mowood, LLC, Omega, Pinedale LP and Pinedale GP (the "Unrestricted Subs") and (ii) the equity investments in the Unrestricted Subs.

As of December 31, 2018, the Company was in compliance with all covenants of the CorEnergy Credit Facility, and the Company had approximately $122.7 million of availability.

MoGas Revolver

In conjunction with the MoGas Transaction, MoGas and United Property Systems, as co-borrowers, entered into a revolving credit agreement dated November 24, 2014 ("the MoGas Revolver") with certain lenders, including Regions Bank as agent for such lenders. Following subsequent amendments and restatements made on July 8, 2015 and July 28, 2017, in connection with the amendments and restatements of the CorEnergy Credit Facility discussed above, commitments under the MoGas Revolver were reduced from the original level of $3.0 million to a current total of $1.0 million.

The MoGas Revolver is secured by the assets held at MoGas and has a maturity date of July 28, 2022. Interest accrues under the MoGas Revolver at the same rate and pursuant to the same terms as it accrues under the CorEnergy Revolver. As of December 31, 2018, the co-borrowers were in compliance with all covenants, and there were no borrowings against the MoGas Revolver.

Mowood/Omega Revolver

On July 31, 2015, a $1.5 million revolving line of credit ("Mowood/Omega Revolver") was established with Regions Bank with a maturity date of July 31, 2016. Following annual extensions, the current maturity of the facility has been amended and extended to July 31, 2019. The Mowood/Omega Revolver is used by Omega for working capital and general business purposes and is guaranteed and secured by the assets of Omega. Interest accrues at LIBOR plus 4 percent and is payable monthly in arrears with no unused fee. There was no outstanding balance at December 31, 2018.

Amended Pinedale Term Credit Facility

On December 20, 2012, Pinedale LP closed on a $70.0 million secured term credit facility. Outstanding balances under the original facility generally accrued interest at a variable annual rate equal to LIBOR plus 3.25 percent. This credit facility was secured by the Pinedale LGS asset. Under the original agreement, Pinedale LP was obligated to pay all accrued interest monthly and was further obligated to make monthly principal payments, which began on March 7, 2014, in the amount of $294 thousand or 0.42 percent of the principal balance as of March 1, 2014. The credit facility remained in effect until December 31, 2015, with an option to extend through December 31, 2016. Although the Company elected not to extend the facility for an additional one-year period, it did amend the facility to extend the maturity date to March 30, 2016. During the extension period, the Company made principal payments of $3.2 million and the credit facility bore interest on the outstanding principal amount at LIBOR plus 4.25 percent.

On March 4, 2016, the Company obtained a consent from its lenders under the CorEnergy Credit Facility, which permitted the Company to utilize the CorEnergy Credit Facility to refinance the Company's pro rata share of the remaining balance of the Pinedale secured term credit facility. On March 30, 2016, the Company and Prudential (collectively, "the Refinancing Lenders"), refinanced the remaining $58.5 million principal balance of the $70.0 million credit facility (on a pro rata basis equal to their respective equity interests in Pinedale LP, with the Company's 81.05 percent share being approximately $47.4 million) and executed a series of agreements assigning the credit facility to the Refinancing Lenders, with CorEnergy Infrastructure Trust, Inc. as Agent for the Refinancing Lenders. The facility was further modified to extend the maturity date to March 30, 2021; to increase the LIBOR Rate to the greater of (i) 1.00 percent and (ii) the one-month LIBOR rate; and to increase the LIBOR Rate Spread to 7.00 percent per annum. The Company's portion of the debt and interest was eliminated in consolidation and Prudential's portion of the debt was shown as a related-party liability.

Pinedale LP automatically entered into a Cash Control Period (as defined in the credit facility) with the Refinancing Lenders upon the April 29, 2016 bankruptcy filing by Ultra Wyoming and its parent guarantor, Ultra Petroleum. During a Cash Control Period, the Company as Agent swept all funds for the repayment of accrued interest, scheduled principal payments and principal prepayments on the loans. Ultra Petroleum emerged from bankruptcy in April 2017, resulting in the end of the Cash Control Period and, in May 2017, Pinedale LP resumed distributions. For the years ended December 31, 2017 and 2016, pursuant to these additional cash sweep provisions, an additional $4.4 million and $9.1 million, respectively, was distributed (pro rata, based on ownership percentages) to the Refinancing Lenders as a reduction to the outstanding principal.

On December 29, 2017, Pinedale LP entered into the Amended Pinedale Term Credit Facility with Prudential and a group of lenders affiliated with Prudential as the sole lenders and Prudential serving as administrative agent. Under the terms of the Amended Term Credit Facility, Pinedale LP was provided with a 5-year $41.0 million term loan facility, bearing interest at a fixed rate of 6.5 percent, which matures on December 29, 2022. Principal payments of $294 thousand, plus accrued interest, are payable monthly. The Amended Pinedale Term Credit Facility was utilized to pay off the balance due to the Refinancing Lenders under the previously existing Pinedale LP credit facility.

Outstanding balances under the facility are secured by the Pinedale LGS assets. The Amended Pinedale Term Credit Facility contains, among other restrictions, specific financial covenants including the maintenance of certain financial coverage ratios and a minimum net worth requirement which, along with other provisions of the credit facility, limit cash dividends and loans by Pinedale LP to the Company. At December 31, 2018, the net assets of Pinedale LP were $137.0 million and Pinedale LP was in compliance with all of the financial covenants of the Amended Pinedale Term Credit Facility.

Deferred Financing Costs

A summary of deferred financing cost amortization expenses for the years ended December 31, 2018, 2017 and 2016 is as follows:

Deferred Financing Cost Amortization Expense (1)(2)
	For the Years Ended December 31,
	2018		2017		2016
CorEnergy Credit Facility	$	574,541	$	873,601	$	1,078,526
Amended Pinedale Term Credit Facility	52,728		392		156,330
Total Deferred Debt Cost Amortization	$	627,269	$	873,993	$	1,234,856
(1) Amortization of deferred debt issuance costs is included in interest expense in the Consolidated Statements of Income.
(2) For the amount of deferred debt costs amortization relating to the Convertible Notes included in the Consolidated Statements of Income, refer to the Convertible Note Interest Expense table below.

CorEnergy Credit Facilities

Prior to the July 28, 2017 credit facility amendment and restatement, previously existing deferred financing costs related to the CorEnergy Credit Facility were approximately $1.8 million, of which approximately $1.6 million continue to be deferred and amortized under the amended and restated facility. Additionally, the Company incurred approximately $1.3 million in new debt issuance costs which have been deferred and are being amortized over the term of the new facility. The total deferred financing costs of $2.9 million are being amortized on a straight-line basis over the 5-year term of the amended and restated CorEnergy Credit Facility. Approximately $234 thousand of existing deferred costs and new debt issuance costs were expensed as a loss on extinguishment of debt related to the amendment and restatement in the Consolidated Statements of Income for the year ended December 31, 2017.

Amended Pinedale Term Credit Facility

In connection with entering into the Amended Pinedale Term Credit Facility, Pinedale LP incurred approximately $367 thousand in new debt issuance costs, of which $264 thousand were deferred and are being amortized on a straight-line basis over the 5-year term of the Amended Pinedale Term Credit Facility. The remaining $103 thousand was expensed as a loss on extinguishment of debt in the Consolidated Statements of Income for the year ended December 31, 2017.

Contractual Payments

The remaining contractual principal payments as of December 31, 2018 under the Amended Pinedale Term Credit Facility are as follows:

Year	Amended Pinedale Term Credit Facility
2019	$	3,528,000
2020	3,528,000
2021	3,528,000
2022	26,888,000
2023	—
Thereafter	—
Total	$	37,472,000

Convertible Debt

On June 29, 2015, the Company completed a public offering of $115.0 million aggregate principal amount of 7.00% Convertible Senior Notes Due 2020 (the "Convertible Notes"). The Convertible Notes mature on June 15, 2020 and bear interest at a rate of 7.0 percent per annum, payable semi-annually in arrears on June 15 and December 15 of each year, beginning on December 15, 2015.

Holders may convert their Convertible Notes into shares of the Company's common stock at their option until the close of business on the second scheduled trading day immediately preceding the maturity date. The initial conversion rate for the Convertible Notes will be 30.3030 shares of Common Stock per $1,000 principal amount of the Convertible Notes, equivalent to an initial conversion price of $33.00 per share of Common Stock. Such conversion rate will be subject to adjustment in certain events as specified in the Indenture. During the year ended December 31, 2018, certain holders elected to convert approximately $42 thousand of Convertible Notes for 1,271 shares of CorEnergy common stock.

The Convertible Notes currently may not be redeemed prior to the maturity date without the consent of the agent and lenders under the CorEnergy Credit Facility. However, upon the occurrence of a fundamental change (as defined in the Indenture), holders may require the Company to repurchase all or a portion of the Convertible Notes for cash at a price equal to 100 percent of the principal amount of the Convertible Notes to be purchased plus any accrued and unpaid interest, if any, to, but excluding, the applicable fundamental change repurchase date as prescribed in the Indenture. In addition, in certain circumstances the Company will increase the conversion rate for a holder that converts the Convertible Notes in connection with any of a specified set of corporate events, each of which is deemed to constitute a make whole adjustment event pursuant to the terms of the Indenture.

The Convertible Notes rank equal in right of payment to any other current and future unsecured obligations of the Company and senior in right of payment to any other current and future indebtedness of the Company that is contractually subordinated to the Convertible Notes. The Convertible Notes are structurally subordinated to all liabilities (including trade payables) of the Company's subsidiaries. The Convertible Notes are effectively junior to all of the Company's existing or future secured debt, to the extent of the value of the collateral securing such debt.

On May 23, 2016, the Company repurchased $1.0 million of its Convertible Notes on the open market. This resulted in the Company writing off a portion of the original underwriter's discount and deferred debt costs, as well as recognizing a gain on extinguishment of debt of $72 thousand which is included in interest expense in the Consolidated Statements of Income for the year ended December 31, 2016. As of December 31, 2018, the Company had approximately $114.0 million of face value of the Convertible Notes outstanding. Refer to Note 17 ("Subsequent Events")for information regarding the exchange of Convertible Notes for cash and common stock, with the requisite consent of the agent and lenders under the CorEnergy Credit Facility, subsequent to December 31, 2018.

The following is a summary of the impact of Convertible Notes on interest expense for the years ended December 31, 2018, 2017 and 2016:

Convertible Note Interest Expense
	For the Years Ended December 31,
	2018		2017		2016
7.00% Convertible Notes	$	7,979,118	$	7,980,000	$	8,008,195
Discount Amortization	738,912		738,912		744,081
Deferred Debt Issuance Cost Amortization	48,276		48,276		48,566
Total	$	8,766,306	$	8,767,188	$	8,800,842

The Convertible Notes were initially issued with an underwriters' discount of $3.7 million which is being amortized over the life of the Convertible Notes. Additionally, the Company incurred approximately $241 thousand in debt issuance costs associated with the Convertible Notes which are being amortized over the life of the notes. Including the impact of the convertible debt discount and related deferred debt issuance costs, the effective interest rate on the Convertible Notes was approximately 7.7 percent for each of the years ended December 31, 2018, 2017 and 2016.

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Asset Retirement Obligation

12 Months Ended

Dec. 31, 2018

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligation

ASSET RETIREMENT OBLIGATION

A component of the consideration exchanged to purchase the GIGS assets in June 2015 was the assumption of the seller's asset retirement obligation ("ARO") associated with such assets. The ARO represents the estimated costs of decommissioning the GIGS pipelines and onshore oil receiving and separation facilities in Grand Isle, Louisiana at retirement. The Company recognized the ARO at its estimated fair value on the date of acquisition with a corresponding ARO asset capitalized as part of the carrying amount of the related long-lived assets to be depreciated over the assets' remaining useful lives.

The Company's tenant, EGC Tenant, has an ARO related to the platform which is currently attached to the GIGS pipelines. If in the future, EGC Tenant is unable to fulfill their obligation, the Company may be required to assume the liability for the related asset removal costs.

In periods subsequent to the initial measurement of an ARO, the Company recognizes changes in the liability resulting from (a) the passage of time through accretion expense and (b) revisions to either the timing or the amount of the estimate of undiscounted cash flows based on periodic revaluations. Future expected cash flows are based on subjective estimates and assumptions, which inherently include significant uncertainties which are beyond the Company's control. These assumptions represent Level 3 inputs in the fair value hierarchy. The Company has no assets that are legally restricted for purposes of settling asset retirement obligations.

In December 2018 and 2017, the Company revised its estimates to reflect a decrease in (i) marketplace rates for labor and other costs, (ii) for the expected timing of work and for (iii) recent decommissioning estimates. During the fourth quarter of 2018, the Company decommissioned a segment of the GIGS pipeline system. The Company incurred decommissioning costs of approximately $939 thousand compared to the estimated segment ARO liability of $628 thousand resulting in a loss on settlement of ARO of $311 thousand. The loss on settlement of ARO is recorded in general and administrative expenses in the Consolidated Statements of Income for the year ended December 31, 2018. For the year ended December 31, 2017, the change in estimate did not result in any charge to income.

The following table is a reconciliation of the asset retirement obligation as of December 31, 2018 and 2017:

Asset Retirement Obligation
	For the Years Ended December 31,
	2018			2017
Beginning asset retirement obligation	$	9,170,493		$	11,882,943
Liabilities assumed	—			—
ARO accretion expense	499,562			663,065
Liabilities settled	(628,300		)	—
Revision in cash flow estimates	(1,085,412		)	(3,375,515		)
Ending asset retirement obligation	$	7,956,343		$	9,170,493

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Interest Rate Hedge Swaps

12 Months Ended

Dec. 31, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Interest Rate Hedge Swaps

13.INTEREST RATE HEDGE SWAPS

Derivative Instruments and Hedging Activities

The Company has historically used interest rate swaps to add stability to interest expense and to manage its exposure to interest rate movements. In February 2013, the Company entered into two interest rate swap agreements associated with a portion of its variable rate debt under the $70.0 million Pinedale Credit Facility, as discussed further in Note 11 ("Debt"). The notional amount covered under these agreements totaled $52.5 million (split evenly between the two agreements). Under the terms of the interest rate swap agreements, the Company received a floating rate based on the one-month LIBOR and paid a fixed rate of 0.865%. Each of the swap agreements was set to expire in December 2017. The agreements were designated as cash flow hedges at inception and accordingly, the effective portion of the gain or loss on the swap was reported as a component of accumulated other comprehensive income ("AOCI") and was reclassified into interest expense when the interest rate swap transaction affected earnings. Any ineffective portion of the gain or loss was recognized immediately in interest expense.

On March 30, 2016, the Company restructured the Pinedale Credit Facility, as further discussed in Note 11 ("Debt"). In connection with the assignment of the Pinedale Credit Facility, the Company terminated one of the interest rate swap agreements with a notional amount of $26.3 million and the remaining interest rate swap with a notional amount of $26.3 million was de-designated from hedge accounting. The remaining derivative expired in December 2017.

The table below presents the effect of the Company's derivative financial instruments on the Consolidated Statements of Income and Comprehensive Income for the years ended December 31, 2017 and 2016 (note that the ineffective portion is not presented as it was inconsequential for all periods presented):

	For the Years Ended December 31,
Derivatives in Cash Flow Hedging Relationship	2017		2016
Amount of Loss on Derivatives Recognized in AOCI (Effective Portion)	$	—	$	(300,181	)
Amount of Loss on Derivatives Reclassified from AOCI (Effective Portion) Recognized in Net Income(1)	—		(50,964		)
Derivatives Not Designated as Hedging Instruments
Amount of Gain on Derivatives Recognized in Income(2)	$	25,842	$	73,204
(1) Included in "Interest Expense" on the face of the Consolidated Statements of Income and Comprehensive Income.
(2) The gains recognized in income on derivatives include changes in fair value for derivatives subsequent to de-designation from hedge accounting.

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Stockholder's Equity

12 Months Ended

Dec. 31, 2018

Equity [Abstract]

STOCKHOLDER'S EQUITY

STOCKHOLDERS' EQUITY

PREFERRED STOCK

The Company's authorized preferred stock consists of 10.0 million shares having a par value of $0.001 per share. On January 27, 2015, the Company sold, in an underwritten public offering, 2,250,000 depositary shares, each representing 1/100th of a share of 7.375% Series A Cumulative Redeemable Preferred Stock ("Series A Preferred Stock"). Pursuant to this offering, the Company issued 22,500 whole shares of Series A Preferred Stock and received net cash proceeds of approximately $54.2 million.

On April 18, 2017, the Company closed a follow-on underwritten public offering of 2,800,000 depository shares, each representing 1/100th of a share of 7.375% Series A Preferred Stock, at a price of $25.00 per depository share. On May 10, 2017, the Company sold an additional 150,000 depository shares at a public offering price of $25.00 per depository share in connection with the underwriters' exercise of their over-allotment option to purchase additional shares. Total proceeds from the offering were approximately $71.2 million, after deducting underwriting discounts and other offering expenses. A portion of the proceeds from the offering were utilized to repay $44.0 million in outstanding borrowings under the CorEnergy Revolver. Following the offering, the Company had a total of 5,200,000 depository shares outstanding, or 52,000 whole shares.

The depositary shares pay an annual dividend of $1.84375 per share, equivalent to 7.375 percent of the $25.00 liquidation preference. The depositary shares may be redeemed on or after January 27, 2020, at the Company's option, in whole or in part, at the $25.00 liquidation preference plus all accrued and unpaid dividends to, but not including, the date of redemption. The depositary shares have no stated maturity, are not subject to any sinking fund or mandatory redemption and are not convertible into any other securities of the Company except in connection with certain changes of control. Holders of the depositary shares generally have no voting rights, except for limited voting rights if the Company fails to pay dividends for six or more quarters (whether or not consecutive) and in certain other circumstances. The depositary shares representing the Series A Preferred Stock trade on the NYSE under the ticker "CORRPrA."

The Company's Board of Directors authorized a share repurchase program for the Company to buy up to $10.0 million of its depository shares of Series A Preferred Stock, which commenced August 6, 2018. Purchases may be made through the program through August 5, 2019. During 2018, the Company repurchased 177,773 depository shares for approximately $4.3 million in cash. As of December 31, 2018, the Company had a total of 5,022,227 depository shares outstanding, or approximately 50,222 whole shares, with an aggregate par value of $50.22.

See Note 17 ("Subsequent Events"), for further information regarding the declaration of a dividend on the Series A Preferred Stock and for details of Series A Preferred Stock repurchases subsequent to December 31, 2018.

COMMON STOCK

On December 31, 2015, the Company's Board of Directors authorized a share repurchase program for the Company to buy up to $10.0 million of its common stock. During 2016, the Company repurchased 90,613 shares for approximately $2.0 million in cash. Under the program, which expired December 31, 2016, the Company was authorized to repurchase shares from time to time through open market transactions, including through block purchases, privately negotiated transactions, or otherwise. There were no such repurchases in 2017 or 2018. As of December 31, 2018, the Company had 11,960,225 of common shares issued and outstanding. See Note 17 ("Subsequent Events"), for further information regarding the declaration of a dividend on the common stock.

SHELF REGISTRATION

On October 30, 2018, the Company filed a shelf registration statement with the SEC, pursuant to which it registered 1,000,000 shares of common stock for issuance under its dividend reinvestment plan. As of December 31, 2018, we have issued 10,927 shares of common stock under our dividend reinvestment plan pursuant to the shelf resulting in remaining availability of approximately 989,073 shares of common stock.

On November 9, 2018, the Company had a new shelf registration statement declared effective by the SEC replacing the Company's previously filed shelf registration statement, pursuant to which it may publicly offer additional debt or equity securities with an aggregate offering price of up to $600.0 million. As of December 31, 2018, the Company has not issued any securities under this new shelf registration statement, so total availability remains at $600.0 million.

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Earnings Per Share

12 Months Ended

Dec. 31, 2018

Earnings Per Share [Abstract]

EARNINGS PER SHARE

EARNINGS PER SHARE

Basic earnings per share data is computed based on the weighted-average number of shares of common stock outstanding during the periods. Diluted EPS data is computed based on the weighted-average number of shares of common stock outstanding, including all potentially issuable shares of common stock. For the year ended December 31, 2018, the dilutive shares include 3,453,273 common shares outstanding from the if-converted method for the 7.00% Convertible Notes. Diluted EPS for the years ended December 31, 2017 and 2016 exclude the impact to income and to the potential number of shares outstanding from the conversion of the 7.00% Convertible Notes because such impact is antidilutive. If converted, the 7.00% Convertible Notes would result in an additional 3,454,545 common shares outstanding for the years ended December 31, 2017 and 2016.

Earnings Per Share
	For the Years Ended December 31,
	2018		2017		2016
Net income attributable to CorEnergy stockholders	$	43,711,876	$	32,602,790	$	29,663,200
Less: preferred dividend requirements(1)	9,548,377		7,953,988		4,148,437
Net income attributable to common stockholders	$	34,163,499	$	24,648,802	$	25,514,763
Weighted average shares - basic	11,935,021		11,900,516		11,901,985
Basic earnings per share	$	2.86	$	2.07	$	2.14
Net income attributable to common stockholders (from above)	$	34,163,499	$	24,648,802	$	25,514,763
Add: After tax effect of convertible interest	8,766,306		—		—
Income attributable for dilutive securities	$	42,929,805	$	24,648,802	$	25,514,763
Weighted average shares - diluted	15,389,180		11,900,516		11,901,985
Diluted earnings per share	$	2.79	$	2.07	$	2.14
(1) In connection with the repurchases of Series A Preferred Stock during the year ended December 31, 2018, preferred dividend requirements were reduced by $10,554 representing the discount in the repurchase price paid compared to the carrying amount derecognized.

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Quarterly Financial Data (Unaudited)

12 Months Ended

Dec. 31, 2018

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Data (Unaudited)

QUARTERLY FINANCIAL DATA (Unaudited)

	For the Fiscal 2018 Quarters Ended
	March 31			June 30			September 30			December 31
Revenue
Lease revenue	$	17,591,859		$	18,275,859		$	18,391,983		$	18,487,661
Transportation and distribution revenue	3,952,979			3,874,157			4,244,722			4,412,378
Total Revenue	21,544,838			22,150,016			22,636,705			22,900,039
Expenses
Transportation and distribution expenses	1,572,896			1,534,524			2,241,999			1,861,329
General and administrative	2,727,057			3,107,776			3,046,481			4,161,533
Depreciation, amortization and ARO accretion expense	6,289,330			6,290,082			6,289,459			6,078,582
Provision for loan (gain) loss	500,000			—			—			(536,867		)
Total Expenses	11,089,283			10,932,382			11,577,939			11,564,577
Operating Income	$	10,455,555		$	11,217,634		$	11,058,766		$	11,335,462
Other Income (Expense)
Net distributions and dividend income	$	3,951		$	55,714		$	5,627		$	41,503
Net realized and unrealized gain (loss) on other equity securities	13,966			(881,100		)	(930,147		)	(48,028		)
Interest expense	(3,210,590		)	(3,196,248		)	(3,183,589		)	(3,168,583		)
Gain on the sale of leased property, net	—			—			—			11,723,257
Total Other Income (Expense)	(3,192,673		)	(4,021,634		)	(4,108,109		)	8,548,149
Income before income taxes	7,262,882			7,196,000			6,950,657			19,883,611
Taxes
Current tax benefit	(35,549		)	(10,785		)	(8,393		)	(530,659		)
Deferred tax benefit	(409,277		)	(604,064		)	(738,274		)	(81,725		)
Income tax benefit, net	(444,826		)	(614,849		)	(746,667		)	(612,384		)
Net Income attributable to CorEnergy Stockholders	$	7,707,708		$	7,810,849		$	7,697,324		$	20,495,995
Preferred dividend requirements	2,396,875			2,396,875			2,396,875			2,357,752
Net Income attributable to Common Stockholders	$	5,310,833		$	5,413,974		$	5,300,449		$	18,138,243
Earnings Per Common Share:
Basic	$	0.45		$	0.45		$	0.44		$	1.52
Diluted	$	0.45		$	0.45		$	0.44		$	1.32

	For the Fiscal 2017 Quarters Ended
	March 31			June 30			September 30			December 31
Revenue
Lease revenue	$	17,066,526		$	17,050,092		$	17,173,676		$	17,513,510
Transportation and distribution revenue	5,010,590			4,775,780			5,270,628			4,888,575
Total Revenue	22,077,116			21,825,872			22,444,304			22,402,085
Expenses
Transportation and distribution expenses	1,335,570			1,362,980			2,384,182			1,646,975
General and administrative	3,061,240			2,558,339			2,632,546			2,534,372
Depreciation, amortization and ARO accretion expense	6,005,908			6,005,995			6,017,664			6,018,143
Total Expenses	10,402,718			9,927,314			11,034,392			10,199,490
Operating Income	$	11,674,398		$	11,898,558		$	11,409,912		$	12,202,595
Other Income (Expense)
Net distributions and dividend income	$	43,462		$	221,440		$	213,040		$	202,149
Net realized and unrealized gain (loss) on other equity securities	(544,208		)	614,634			1,340,197			121,204
Interest expense	(3,454,397		)	(3,202,837		)	(2,928,036		)	(2,793,245		)
Loss on extinguishment of debt	—			—			(234,433		)	(102,500		)
Total Other Expense	(3,955,143		)	(2,366,763		)	(1,609,232		)	(2,572,392		)
Income before income taxes	7,719,255			9,531,795			9,800,680			9,630,203
Taxes
Current tax expense (benefit)	(33,760		)	57,651			65,131			2,742,636
Deferred tax expense (benefit)	(298,846		)	38,084			126,440			(352,018		)
Income tax expense (benefit), net	(332,606		)	95,735			191,571			2,390,618
Net Income	8,051,861			9,436,060			9,609,109			7,239,585
Less: Net Income attributable to non-controlling interest	382,383			435,888			431,825			483,730
Net Income attributable to CorEnergy Stockholders	$	7,669,478		$	9,000,172		$	9,177,284		$	6,755,855
Preferred dividend requirements	1,037,109			2,123,129			2,396,875			2,396,875
Net Income attributable to Common Stockholders	$	6,632,369		$	6,877,043		$	6,780,409		$	4,358,980
Earnings Per Common Share:
Basic	$	0.56		$	0.58		$	0.57		$	0.37
Diluted	$	0.56		$	0.58		$	0.57		$	0.37

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Subsequent Events

12 Months Ended

Dec. 31, 2018

Subsequent Events [Abstract]

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS

The Company performed an evaluation of subsequent events through the date of the issuance of these financial statements and determined that no additional items require recognition or disclosure, except for the following:

Preferred Stock Repurchase

On January 9, 2019, the Company repurchased 2,500 depository shares of Series A Preferred Stock for approximately $61 thousand in cash. Subsequent to the repurchase, the Company had a total of 5,019,727 depository shares outstanding, or approximately 50,197 whole shares.

Convertible Note Exchange

On January 16, 2019, the Company agreed with three holders of its Convertible Notes, pursuant to privately negotiated agreements, to exchange $43.8 million face amount of such notes for an aggregate of 837,040 shares of the Company's common stock, par value $0.001 per share, plus aggregate cash consideration of $19.8 million. The Company's agent and lenders under the CorEnergy Credit Facility provided a consent for the convertible note exchange, subject to certain conditions. Subsequent to the exchange, the Company had approximately $70.2 million of face value of the Convertible Notes outstanding. The Company will record a loss on extinguishment of debt of approximately $5.0 million in the Consolidated Statements of Income for the first quarter of 2019.

Common Stock Dividend

On January 23, 2019, the Company's Board of Directors declared a 2018 fourth quarter dividend of $0.75 per share for CorEnergy common stock. The dividend was paid on February 28, 2019, to stockholders of record on February 14, 2019.

Preferred Stock Dividend

On January 23, 2019, the Company's Board of Directors also declared a dividend of $0.4609375 per depositary share for its 7.375% Series A Preferred Stock. The preferred stock dividend was paid on February 28, 2019, to stockholders of record on February 14, 2019.

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT

12 Months Ended

Dec. 31, 2018

Condensed Financial Information Disclosure [Abstract]

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT

CorEnergy Infrastructure Trust, Inc.

CONDENSED BALANCE SHEETS	December 31, 2018		December 31, 2017
Assets
Leased property, net of accumulated depreciation of $1,112,218 and $927,838	$	3,681,438	$	3,865,818
Investments	415,674,601		479,840,250
Cash and cash equivalents	64,574,701		6,662,474
Due from subsidiary	10,549,719		7,302,678
Note receivable from subsidiary	81,000,000		83,250,000
Deferred costs, net of accumulated amortization of $712,182 and $226,342	1,769,585		2,255,425
Prepaid expenses and other assets	265,024		197,211
Total Assets	$	577,515,068	$	583,373,856
Liabilities and Equity
Unsecured convertible senior notes, net of discount and debt issuance costs of $1,180,729 and $1,967,917	112,777,271		112,032,083
Accounts payable and other accrued liabilities	1,075,045		987,881
Management fees payable	1,831,613		1,748,426
Due to affiliate	153,640		153,640
Total Liabilities	$	115,837,569	$	114,922,030
Equity
Series A Cumulative Redeemable Preferred Stock 7.375%, $125,555,675 and $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 50,222 and 52,000 issued and outstanding at December 31, 2018 and December 31, 2017, respectively	$	125,555,675	$	130,000,000
Capital stock, non-convertible, $0.001 par value; 11,960,225 and 11,915,830 shares issued and outstanding at December 31, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,960		11,916
Additional paid-in capital	326,962,163		338,439,910
Retained earnings	9,147,701		—
Total Equity	461,677,499		468,451,826
Total Liabilities and Equity	$	577,515,068	$	583,373,856
See accompanying Schedule I Notes to Condensed Financial Statements.

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - CorEnergy Infrastructure Trust, Inc. - Continued

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME	For the Years Ended December 31,
	2018			2017			2016
Revenue
Earnings from subsidiary	$	48,353,177		$	36,222,221		$	32,856,338
Total Revenue	48,353,177			36,222,221			32,856,338
Expenses
General and administrative	2,353,593			2,298,201			2,236,358
Depreciation expense	184,380			184,380			184,380
Amortization expense	5,316			5,316			5,316
Total Expenses	2,543,289			2,487,897			2,426,054
Operating Income	$	45,809,888		$	33,734,324		$	30,430,284
Other Income (Expense)
Net distributions and dividend income	$	56,827		$	96,866		$	12,963
Interest on loans to subsidiaries	7,903,104			11,549,344			11,705,465
Interest expense, net	(10,057,943		)	(11,451,944		)	(12,485,510		)
Loss on extinguishment of debt	—			(225,801		)	—
Total Other Expense	(2,098,012		)	(31,535		)	(767,082		)
Net Income	$	43,711,876		$	33,702,789		$	29,663,202
Other comprehensive income:
Changes in fair value of qualifying hedges	—			11,196			(201,993		)
Total Comprehensive Income	$	43,711,876		$	33,713,985		$	29,461,209
See accompanying Schedule I Notes to Condensed Financial Statements.

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - CorEnergy Infrastructure Trust, Inc. - Continued

CONDENSED STATEMENTS OF CASH FLOW	For the Years Ended December 31,
	2018			2017			2016
Net cash provided by (used in) operating activities	$	(6,257,124	)	$	1,661,123		$	(3,141,286	)
Investing Activities
Issuance of note to subsidiary	—			—			(47,414,250		)
Principal payments received from notes to subsidiaries	2,250,000			40,092,095			11,899,659
Investment in consolidated subsidiaries	(73,996		)	(33,900,000		)	—
Cash distributions from consolidated subsidiaries	110,140,459			46,774,111			39,139,897
Net cash provided by investing activities	$	112,316,463		$	52,966,206		$	3,625,306
Financing Activities
Debt financing costs	—			(1,360,241		)	(193,000		)
Net offering proceeds on Series A preferred stock	—			71,161,531			—
Repurchases of common stock	—			—			(2,041,851		)
Repurchases of convertible debt	—			—			(899,960		)
Repurchases of preferred stock debt	(4,275,553		)	—			—
Dividends paid on Series A preferred stock	(9,587,500		)	(8,227,734		)	(4,148,437		)
Dividends paid on common stock	(34,284,059		)	(34,731,892		)	(34,896,727		)
Advances on revolving line of credit	—			10,000,000			44,000,000
Payments on revolving line of credit	—			(54,000,000		)	—
Principal payments on term debt	—			(36,740,000		)	(6,460,000		)
Net cash used in financing activities	$	(48,147,112	)	$	(53,898,336	)	$	(4,639,975	)
Net Change in Cash and Cash Equivalents	$	57,912,227		$	728,993		$	(4,155,955	)
Cash and Cash Equivalents at beginning of period	6,662,474			5,933,481			10,089,436
Cash and Cash Equivalents at end of period	$	64,574,701		$	6,662,474		$	5,933,481
Supplemental Disclosure of Cash Flow Information
Interest Paid	$	8,794,086		$	10,080,764		$	11,335,654
Non-Cash Investing Activities
Conversion of note receivable from subsidiary to investments	$	—		$	4,902,495		$	—
Dissolution of investment in subsidiary upon liquidation	(73,996		)	—			—
Non-Cash Financing Activities
Common stock issued upon conversion of convertible notes	$	42,654		$	—		$	—
Reinvestment of distributions by common stockholders in additional common shares	1,509,830			962,308			815,889
See accompanying Schedule I Notes to Condensed Financial Statements.

NOTES TO SCHEDULE I CONDENSED FINANCIAL STATEMENTS

NOTE A - BASIS OF PRESENTATION

In the parent-company-only financial statements, the Company's investment in subsidiaries is stated at cost plus equity in undistributed earnings of subsidiaries since the date of acquisition. The parent-company-only financial statements should be read in conjunction with the Company's consolidated financial statements.

NOTE B - DIVIDENDS FROM SUBSIDIARIES

Cash dividends paid to CorEnergy Infrastructure Trust, Inc. from the Company's consolidated subsidiaries were $110.1 million, $46.8 million and $39.1 million for the years ended December 31, 2018, 2017 and 2016, respectively.

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SCHEDULE III - REAL ESTATE AND ACCUMULATED DEPRECIATION

12 Months Ended

Dec. 31, 2018

SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation Disclosure [Abstract]

SCHEDULE III - REAL ESTATE AND ACCUMULATED DEPRECIATION

SCHEDULE III - REAL ESTATE AND ACCUMULATED DEPRECIATION - CorEnergy Infrastructure Trust, Inc.

				Initial Cost to Company				Costs Capitalized Subsequent to Acquisition			Gross Amount Carried at Close of Period December 31, 2018
Description	Location	Encumbrances		Land		Building & Fixtures		Improvements / Adjustments (4)			Land		Building & Fixtures		Total		Accumulated Depreciation		Investment in Real Estate, net, at 12/31/18		Date Acquired	Life on which depreciation in latest income statement is computed
Pinedale LGS (1)(5)	Pinedale, WY	$	37,472,000	$	105,485,063	$	125,119,062	$	—		$	105,485,063	$	125,119,062	$	230,604,125	$	53,501,538	$	177,102,587	2012	26 years
United Property Systems (4)	St. Louis, MO	—		210,000		1,188,000		78,621			210,000		1,266,621		1,476,621		138,096		1,338,525		2014	40 years
Grand Isle Gathering System(2)(3)(4)	Gulf of Mexico	—		960,000		258,471,397		(6,143,693		)	960,000		252,327,704		253,287,704		33,514,461		219,773,243		2015	27 years
		$	37,472,000	$	106,655,063	$	384,778,459	$	(6,065,072	)	$	106,655,063	$	378,713,387	$	485,368,450	$	87,154,095	$	398,214,355
(1) In connection with the asset acquisition, CorEnergy and Pinedale LP incurred acquisition costs of $2,557,910, which are included in the total asset balance.
(2) In connection with the asset acquisition, Grand Isle Gathering System incurred acquisition costs of $1,931,396, which are included in the total asset balance.
(3) Initial costs associated with the GIGS asset include amounts capitalized related to an acquired asset retirement obligation (ARO). The negative subsequent adjustment relates to (i) downward revisions of the ARO based on periodic reevaluation as required under FASB ASC 410-20 and (ii) the settlement of a portion of the ARO when a segment of the GIGS pipeline system was decommissioned during the fourth quarter of 2018.
(4) These 2 properties serve as collateral under the CorEnergy Credit Facility. There are no amounts outstanding on the credit facility as of December 31, 2018.
(5) The amount outstanding for the Amended Pinedale Term Credit Facility is $37,472,000 as of December 31, 2018.

NOTES TO SCHEDULE III - CONSOLIDATED REAL ESTATE AND ACCUMULATED DEPRECIATION

Reconciliation of Real Estate and Accumulated Depreciation

	For the Years Ended December 31,
	2018			2017			2016
Investment in real estate:
Balance, beginning of year	$	538,112,220		$	541,478,086		$	543,095,478
Addition: Acquisitions and developments	3,599			9,649			65,371
Deduction: Dispositions and other(1)(2)	(52,747,369		)	(3,375,515		)	(1,682,763		)
Balance, end of year	$	485,368,450		$	538,112,220		$	541,478,086
Accumulated depreciation:
Balance, beginning of year	$	72,155,753		$	52,219,717		$	33,869,263
Addition: Depreciation	20,986,461			19,936,036			18,350,454
Deduction: Dispositions and other(2)	(5,988,119		)	—			—
Balance, end of year	$	87,154,095		$	72,155,753		$	52,219,717
(1) The Grand Isle Gathering System had a change in estimate related to the ARO in 2018, 2017 and 2016. Refer to Note 12 ("Asset Retirement Obligation") for further details.
(2) On December 21, 2018, the Company sold its Portland Terminal Facility with a net carrying value of $45.7 million (i.e. gross investment of $51.7 million less accumulated depreciation of $6.0 million). Refer to Note 3 ("Leased Properties and Leases") for further details.

The aggregate cost of the properties is approximately $4.2 million lower for federal income tax purposes at December 31, 2018. The tax basis of the properties is unaudited.

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SCHEDULE IV - MORTGAGE LOANS ON REAL ESTATE

12 Months Ended

Dec. 31, 2018

SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Abstract]

SCHEDULE IV - MORTGAGE LOANS ON REAL ESTATE

SCHEDULE IV - MORTGAGE LOANS ON REAL ESTATE - CorEnergy Infrastructure Trust, Inc.

Description	Interest Rate	Final Maturity	Monthly Payment Amount		Prior Liens	Face Value		Carrying Amount of Mortgage		Principal Amount of Loans Subject to Delinquent Principal or Interest
First Mortgages
Billings, Dunn and McKenzie Counties, North Dakota (Morlock Well)	8.52%	6/15/2019	$	—	None	$	1,300,000	$	1,300,000	$	—
Total						$	1,300,000	$	1,300,000	$	—

NOTES TO SCHEDULE IV - CONSOLIDATED MORTGAGE LOANS ON REAL ESTATE

Reconciliation of Mortgage Loans on Real Estate

	For the Years Ended December 31,
	2018			2017		2016
Beginning balance	$	1,500,000		$	1,500,000	$	6,877,021
Additions:
New loans	—			—		100,000
Interest receivable(1)	—			—		(95,114		)
Total Additions	$	—		$	—	$	4,886
Deductions:
Principal repayments(2)	$	236,867		$	—	$	—
Foreclosures	—			—		1,857,000
Amortization of deferred costs	—			—		(2,025		)
Principal, Interest and Deferred Costs Write (Up) Down(2)(3)	(36,867		)	—		3,526,932
Total deductions	$	200,000		$	—	$	5,381,907
Ending balance	$	1,300,000		$	1,500,000	$	1,500,000
(1) In 2016, $100 thousand of interest receivable on the SWD Enterprises REIT note was converted to principal.
(2) In 2018, Four Wood Corridor and Compass SWD executed a $1.3 million loan agreement and Compass SWD paid approximately $237 thousand in cash for assets secured by the previous $1.5 million loans. As a result, SWD Enterprises was released from the terms of its loans, and the Company recognized a provision for loan gain of $37 thousand in the Consolidated Statements of Income. Refer to Note 5 ("Financing Notes Receivable") for further details.
(3) For 2016, the amount of provision for loan loss on the Consolidated Statements of Income also includes (a) $656 thousand of loan losses not related to mortgage loans and (b) $832 thousand of losses associated with the foreclosure and sale of Black Bison.

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Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2018

Accounting Policies [Abstract]

Basis of Presentation and Use of Estimates

Basis of Presentation

The accompanying consolidated financial statements include CorEnergy accounts and the accounts of its wholly-owned subsidiaries and have been prepared in accordance with U.S. generally accepted accounting principles ("GAAP") set forth in the Accounting Standards Codification ("ASC"), as published by the Financial Accounting Standards Board ("FASB"), and with the Securities and Exchange Commission ("SEC") instructions to Form 10-K. The accompanying consolidated financial statements reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the Company's financial position, results of operations and cash flows for the periods presented. There were no adjustments that, in the opinion of management, were not of a normal and recurring nature. All intercompany transactions and balances have been eliminated in consolidation, and the Company's net earnings have been reduced by the portion of net earnings attributable to non-controlling interests, when applicable.

The FASB issued ASU 2015-02 Consolidations (Topic 810) - Amendments to the Consolidation Analysis ("ASU 2015-02"), which amended previous consolidation guidance, including introducing a separate consolidation analysis specific to limited partnerships and other similar entities. Under this analysis, limited partnerships and other similar entities are considered a variable interest entity ("VIE") unless the limited partners hold substantive kick-out rights or participating rights. Management determined that Pinedale LP and Grand Isle Corridor LP are VIEs under the amended guidance because the limited partners of both partnerships lack both substantive kick-out rights and participating rights. As such, management evaluated the qualitative criteria under FASB ASC Topic 810 in conjunction with ASU 2015-02 to make a determination whether these partnerships should be consolidated in the Company's financial statements. ASC Topic 810-10 requires the primary beneficiary of a variable interest entity's activities to consolidate the VIE. The primary beneficiary is identified as the enterprise that has a) the power to direct the activities of the VIE that most significantly impact the entity's economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. The standard requires an ongoing analysis to determine whether the variable interest gives rise to a controlling financial interest in the VIE. Based on the general partners' roles and rights as afforded by the partnership agreements and its exposure to losses and benefits of each of the partnerships through its significant limited partner interests, management determined that CorEnergy is the primary beneficiary of both Pinedale LP and Grand Isle Corridor LP. Based upon this evaluation and the Company's 100 percent ownership interest in Pinedale LP (2018) and Grand Isle Corridor LP (2016-2018) and the majority ownership interest in Pinedale LP (2016-2017) of the limited partnership interests, the consolidated financial statements presented include full consolidation with respect to both of the partnerships.

Use of Estimates

Use of Estimates – The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Leased Property

Leased Property – The Company includes assets subject to lease arrangements within leased property, net of accumulated depreciation, in the Consolidated Balance Sheets. Lease payments received are reflected in lease revenue on the Consolidated Statements of Income, net of amortization of any off-market adjustments. Costs in connection with the creation and execution of a lease are capitalized and amortized over the lease term. See Note 3 ("Leased Properties And Leases") for further discussion.

Property and Equipment

Property and Equipment – Property and equipment are stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful life of the asset. Expenditures for repairs and maintenance are charged to operations as incurred, and improvements, which extend the useful lives of assets, are capitalized and depreciated over the remaining estimated useful life of the asset. The Company initially records long-lived assets at their purchase price plus any direct acquisition costs, unless the transaction is accounted for as a business combination, in which case the acquisition costs are expensed as incurred. If the transaction is accounted for as a business combination, the Company allocates the purchase price to the acquired tangible and intangible assets and liabilities based on their estimated fair values.

Long-Lived Asset Impairment

Long-Lived Asset Impairment – The Company's long-lived assets consist primarily of a subsea midstream pipeline system, liquids gathering system and natural gas pipelines that have been obtained through asset acquisitions and a business combination. Management continually monitors its business, the business environment and performance of its operations to determine if an event has occurred that indicates that the carrying value of a long-lived asset may be impaired. When a triggering event occurs, which is a determination that involves judgment, management utilizes cash flow projections to assess its ability to recover the carrying value of its assets based on the Company's long-lived assets' ability to generate future cash flows on an undiscounted basis. This differs from the evaluation of goodwill, for which the recoverability assessment utilizes fair value estimates that include discounted cash flows in the estimation process and accordingly any goodwill impairment recognized may not be indicative of a similar impairment of the related underlying long-lived assets.

Management's projected cash flows of long-lived assets are primarily based on contractual cash flows relating to existing leases that extend many years into the future. If those cash flow projections indicate that the long-lived asset's carrying value is not recoverable, management records an impairment charge for the excess of carrying value of the asset over its fair value. The estimate of fair value considers a number of factors, including the potential value that would be received if the asset were sold, discount rates and projected cash flows. Due to the imprecise nature of these projections and assumptions, actual results can differ from management's estimates. There were no impairments of long-lived assets recorded during the years ended December 31, 2018, 2017 or 2016.

Financing Notes Receivable

Financing Notes Receivable – Financing notes receivable are presented at face value plus accrued interest receivable and deferred loan origination costs and net of related direct loan origination income. Each quarter the Company reviews its financing notes receivable to determine if the balances are realizable based on factors affecting the collectability of those balances. Factors may include credit quality, timeliness of required periodic payments, past due status and management discussions with obligors. The Company evaluates the collectability of both interest and principal of each of its loans to determine if an allowance is needed. An allowance will be recorded when based on current information and events, the Company determines it is probable that it will be unable to collect all amounts due according to the existing contractual terms. If the Company does determine an allowance is necessary, the amount deemed uncollectable is expensed in the period of determination. An insignificant delay or shortfall in the amount of payments does not necessarily result in the recording of an allowance. Generally, when interest and/or principal payments on a loan become past due, or if the Company does not otherwise expect the borrower to be able to service its debt and other obligations, the Company will place the loan on non-accrual status and will typically cease recognizing financing revenue on that loan until all principal and interest have been brought current. Interest income recognition is resumed if and when the previously reserved-for financing notes become contractually current and performance has been demonstrated. Payments received subsequent to the recording of an allowance will be recorded as a reduction to principal.

Investment Securities

Investment Securities – The Company's investments in securities are classified as other equity securities and represent interests in private companies which the Company has elected to report at fair value under the fair value option. These investments are subject to restrictions on resale, have no established trading market and are valued on a quarterly basis. Because of the inherent uncertainty of valuation, the fair values of such investments, which are determined in accordance with procedures approved by the Company's Board of Directors, may differ materially from the values that would have been used had a ready market existed for the investments.

The Company determines fair value to be the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Company has determined the principal market, or the market in which the Company exits its private portfolio investments with the greatest volume and level of activity, to be the private secondary market. Typically, private companies are bought and sold based on multiples of EBITDA, cash flows, net income, revenues, or in limited cases, book value.

For private company investments, value is often realized through a liquidity event. Therefore, the value of the company as a whole (enterprise value) at the reporting date often provides the best evidence of the value of the investment and is the initial step for valuing the Company's privately issued securities. For any one company, enterprise value may best be expressed as a range of fair values, from which a single estimate of fair value will be derived. In determining the enterprise value of a portfolio company, an analysis is prepared consisting of traditional valuation methodologies including market and income approaches. The Company considers some or all of the traditional valuation methods based on the individual circumstances of the portfolio company in order to derive its estimate of enterprise value.

The fair value of investments in private portfolio companies is determined based on various factors, including enterprise value, observable market transactions, such as recent offers to purchase a company, recent transactions involving the purchase or sale of the equity securities of the company, or other liquidation events. The determined equity values may be discounted when the Company has a minority position, or is subject to restrictions on resale, has specific concerns about the receptivity of the capital markets to a specific company at a certain time, or other comparable factors exist.

Fair Value Measurements

Fair Value Measurements – FASB ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. Various inputs are used in determining the fair value of the Company's assets and liabilities. These inputs are summarized in the three broad levels listed below:

• Level 1 - quoted prices in active markets for identical investments

• Level 2 - other significant observable inputs (including quoted prices for similar investments, market corroborated inputs, etc.)

• Level 3 - significant unobservable inputs (including the Company's own assumptions in determining the fair value of investments)

See Note 10 ("Fair Value") for further discussion of the Company's fair value measurements.

Cash and Cash Equivalents

Cash and Cash Equivalents – The Company maintains cash balances at financial institutions in amounts that regularly exceed FDIC insured limits. The Company's cash equivalents are comprised of short-term, liquid money market instruments.

Accounts and other receivables/Deferred rent receivables

Accounts and other receivables – Accounts receivable are presented at face value net of an allowance for doubtful accounts within accounts and other receivables on the balance sheet. Accounts are considered past due based on the terms of sale with the customers. The Company reviews accounts for collectability based on an analysis of specific outstanding receivables, current economic conditions and past collection experience. For the years ended December 31, 2018 and 2017, the Company determined that an allowance for doubtful accounts was not necessary.

J. Deferred rent receivables – Lease receivables are determined according to the terms of the lease agreements entered into by the Company and its lessees, as discussed within Note 3 ("Leased Properties And Leases"). Lease receivables primarily represent timing differences between straight-line revenue recognition and contractual lease receipts. As of December 31, 2018, lease payments by the Company's tenants have remained timely and without lapse.

Goodwill

Goodwill – Goodwill represents the excess of the amount paid for the MoGas business over the fair value of the net identifiable assets acquired. To comply with ASC 350, Intangibles - Goodwill and Other ("ASC 350"), the Company performs an impairment test for goodwill annually, or more frequently in the event that a triggering event has occurred. December 31st is the Company's annual testing date associated with its MoGas reporting unit.

In January 2017, the FASB issued ASU 2017-04, Simplifying the Test for Goodwill Impairment, which simplifies how an entity is required to test goodwill for impairment by eliminating step two from the goodwill impairment test. Effective January 1, 2017, the Company elected to early adopt this standard.

In accordance with ASC 350, a company may elect to perform a qualitative assessment to determine whether the quantitative impairment test is required. If the company elects to perform a qualitative assessment, the quantitative impairment test is required only if the conclusion is that it is more likely than not that the reporting unit's fair value is less than its carrying amount. If a company bypasses the qualitative assessment, the quantitative goodwill impairment test should be followed in step one.

Step one compares the fair value of the reporting unit to its carrying value to identify and measure any potential impairment. The reporting unit fair value is based upon consideration of various valuation methodologies, one of which is projecting future cash flows discounted at rates commensurate with the risks involved ("Discounted Cash Flow" or "DCF"). Assumptions used in a DCF require the exercise of significant judgment, including judgment about appropriate discount rates and terminal values, growth rates and the amount and timing of expected future cash flows. Forecasted cash flows require management to make judgments and assumptions, including estimates of future volumes and rates. Declines in volumes or rates from those forecasted, or other changes in assumptions, may result in a change in management's estimate and result in an impairment.

The Company elected to perform a qualitative goodwill impairment assessment for the years ended December 31, 2018 and 2017. In performing the qualitative assessment, the Company analyzed the key drivers and other external factors that impact the business in order to determine if any significant events, transactions or other factors had occurred or are expected to occur that would impair earnings or competitiveness, therefore impairing the fair value of the MoGas reporting unit. After assessing the totality of events and circumstances, it was determined that it was not more likely than not that the fair value of the MoGas reporting unit was less than the carrying value, and so it was not necessary to perform the quantitative step one valuation. Key drivers that were considered in the qualitative evaluation of the MoGas reporting unit included: general economic conditions, continued recovery of the energy markets, natural gas pricing, input costs, liquidity and capital resources and customer outlook. Additionally, the Company considered the quantitative impairment analysis performed as of December 31, 2016, including potential updates to key valuation assumptions, in determining that it was not more likely than not that goodwill was impaired for the current year assessment.

Debt Discount and Debt Issuance Costs

Debt Discount and Debt Issuance Costs – Costs incurred for the issuance of new debt are capitalized and amortized into interest expense over the debt term. Issuance costs related to long-term debt are recorded as a direct deduction from the carrying amount of that debt liability, net of accumulated amortization. Issuance costs related to line-of-credit arrangements however, are presented as an asset instead of a direct deduction from the carrying amount of the debt. In accordance with ASC 470, Debt ("ASC 470"), the Company recorded its Convertible Senior Notes at the aggregate principal amount, less discount. The Company is amortizing the debt discount over the life of the convertible notes as additional non-cash interest expense utilizing the effective interest method. Refer to Note 11 ("Debt") for additional information.

Asset Retirement Obligations

Asset Retirement Obligations – The Company follows ASC 410-20, Asset Retirement Obligations, which requires that an asset retirement obligation ("ARO") associated with the retirement of a long-lived asset be recognized as a liability in the period in which it is incurred and becomes determinable, with an offsetting increase in the carrying amount of the associated asset. The Company recognized an existing ARO in conjunction with the acquisition of the GIGS in June 2015.

The Company measures changes in the ARO liability due to passage of time by applying an interest method of allocation to the amount of the liability at the beginning of the period. The increase in the carrying amount of the liability is recognized as an expense classified as an operating item in the Consolidated Statements of Income, hereinafter referred to as ARO accretion expense. The Company periodically reassesses the timing and amount of cash flows anticipated associated with the ARO and adjusts the fair value of the liability accordingly under the guidance in ASC 410-20.

The fair value of the obligation at the acquisition date was capitalized as part of the carrying amount of the related long-lived assets and is being depreciated over the asset's remaining useful life. The useful lives of most pipeline gathering systems are primarily derived from available supply resources and ultimate consumption of those resources by end users. Adjustments to the ARO resulting from reassessments of the timing and amount of cash flows will result in changes to the retirement costs capitalized as part of the carrying amount of the asset.

Upon decommissioning of the ARO or a portion thereof, the Company reduces the fair value of the liability and recognizes a (gain) loss on settlement of ARO as an operating item in the Consolidated Statements of Income for the difference between the liability and actual decommissioning costs incurred.

Refer to Note 12 ("Asset Retirement Obligation") for additional information.

Revenue Recognition

Revenue Recognition – In May 2014, the FASB issued ASU No. 2014-09 Revenue from Contracts with Customers ("ASU 2014-09" or "ASC 606"), which became effective for all public entities on January 1, 2018. ASC 606 supersedes previously existing revenue recognition standards with a single model unless those contracts are within the scope of other standards (e.g. leases). The model requires an entity to recognize as revenue the amount of consideration to which it expects to be entitled for the transfer of promised goods or services to customers. A substantial portion of the Company's revenue consists of rental income from leasing arrangements, which is specifically excluded from ASC 606. However, the Company's transportation and distribution revenue is within the scope of the new guidance. The Company adopted ASC 606 effective on January 1, 2018 using the modified retrospective method. The Company elected to apply the guidance only to open contracts as of the effective date. The Company recognized the cumulative effect of applying the new standard as an adjustment to the opening balance of stockholders' equity. The comparative information has not been restated and continues to be reported under accounting standards in effect for those periods. Refer to Note 4 ("Transportation And Distribution Revenue") for further discussion of the transition impact and related disclosures under ASC 606.

Specific recognition policies for the Company's revenue items are as follows:

• Lease revenue – Base rent related to the Company's leased property is recognized on a straight-line basis over the term of the lease when collectability is reasonably assured. Participating rent is recognized when it is earned, based on the achievement of specified performance criteria. Rental payments received in advance are classified as unearned revenue and included as a liability within the Consolidated Balance Sheets. Unearned revenue is amortized ratably over the lease period as revenue recognition criteria are met. Rental payments received in arrears are accrued and classified as deferred rent receivable and included in assets within the Consolidated Balance Sheets.

• Transportation and distribution revenue – The Company's contracts related to transportation and distribution revenue are primarily comprised of a mix of natural gas supply, transportation and distribution performance obligations, as well as limited performance obligations related to system maintenance and expansion. Transportation revenues are recognized by MoGas and distribution revenues are recognized by Omega and Omega Gas Marketing, LLC.

◦ Under the Company's natural gas supply, transportation and distribution performance obligations, the customer simultaneously receives and consumes the benefit of the services as natural gas is delivered. Therefore, the transaction price is allocated proportionally over the series of identical performance obligations with each contract. The transaction price is calculated based on (i) index price, plus a contractual markup in the case of natural gas supply agreements (considered variable due to fluctuations in the index), (ii) FERC regulated rates or negotiated rates in the case of transportation agreements and (iii) contracted amounts (with annual CPI escalators) in the case of the Company's distribution agreement. Based on the nature of the agreements, revenue for all but one of the Company's natural gas supply, transportation and distribution performance obligations is recognized on a right to invoice basis as the performance obligations are met, which represents what the Company expects to receive in consideration and is representative of value delivered to the customer. The Company has a contract with one customer, Spire, that has fixed pricing which varies over the contract term. For this specific contract, the transaction price has been allocated ratably over the contractual performance obligation beginning in 2018 with the adoption of ASC 606. All invoicing is done in the month following service, with payment typically due a month from invoice date.

◦ The Company's contracts also contain performance obligations related to system maintenance and expansion, which are completed on an as-needed basis. The work performed is specific and tailored to the customer's needs and there are no alternative uses for the services provided. Therefore, as the work is being completed, control is transferring to the customer. These services are billed at the Company's cost, plus an agreed upon margin, and the Company has an enforceable right to payment for services provided. The Company invoices for this service on a monthly basis according to an agreed upon billing schedule. Revenue is recognized on an input method, based on the actual cost of a service as a measure of performance obligations satisfaction, which the Company determined to be the method which faithfully depicts the transfer of services. Differences between the amounts invoiced and revenue recognized under the input method are reflected as an asset or liability on the Consolidated Balance Sheets. Any differences are typically expected to be recognized within a year.

◦ Beginning February 1, 2016, due to changes that commenced under a new contract with the Department of Defense ("DOD"), gas sales and cost of gas sales are presented on a net basis in the transportation and distribution revenue line. The Company continues to present the gas sales and cost of gas sales on a net basis upon adoption of ASC 606.

• Financing revenue – Historically, financing notes receivable have been considered a core product offering and therefore the related income is presented as a component of operating income. For increasing rate loans, base interest income is recorded ratably over the life of the loan, using the effective interest rate. The net amount of deferred loan origination income and costs are amortized on a straight-line basis over the life of the loan and reported as an adjustment to yield in financing revenue. Participating financing revenues are recorded when specific performance criteria have been met.

Transportation and distribution expense

Transportation and distribution expense –Included here are both MoGas' costs of operating and maintaining the natural gas transmission line and Omega's costs of operating and maintaining the natural gas distribution system, including any necessary expansion of the distribution system. These costs are incurred both internally and externally. The internal costs relate to system control, pipeline operations, maintenance, insurance and taxes. Other internal costs include payroll for employees associated with gas control, field employees and management. The external costs consist of professional services such as audit and accounting, legal and regulatory and engineering.

Historically, Omega's amounts paid for gas and propane delivered to customers were presented as cost of sales. Beginning February 1, 2016, under a new contract with the DOD, amounts paid by Omega for gas and propane are netted against sales and are presented in the transportation and distribution revenue line. See paragraph (N) above.

Other Income Recognition

Other Income Recognition –Specific policies for the Company's other income items are as follows:

• Net distributions and dividend income from investments – Distributions and dividends from investments are recorded on their ex-dates and are reflected as other income within the accompanying Consolidated Statements of Income. Distributions received from the Company's investments are generally characterized as ordinary income, capital gains and distributions received from investment securities. The portion characterized as return of capital is paid by the Company's investees from their cash flow from operations. The Company records investment income, capital gains and distributions received from investment securities based on estimates made at the time such distributions are received. Such estimates are based on information available from each company and other industry sources. These estimates may subsequently be revised based on information received from the entities after their tax reporting periods are concluded, as the actual character of these distributions is not known until after the fiscal year end of the Company.

• Net realized and unrealized gain (loss) from investments – Securities transactions are accounted for on the date the securities are purchased or sold. Realized gains and losses are reported on an identified cost basis. The Company records investment income and return of capital based on estimates made at the time such distributions are received. Such estimates are based on information available from the portfolio company and other industry sources. These estimates may subsequently be revised based on information received from the portfolio company after their tax reporting periods are concluded, as the actual character of these distributions are not known until after the Company's fiscal year end.

Asset Acquisition Expenses

Asset Acquisition Expenses – Costs incurred in connection with the research of real property acquisitions not accounted for as business combinations are expensed until it is determined that the acquisition of the real property is probable. Upon such determination, costs incurred in connection with the acquisition of the property are capitalized as described in paragraph (C) above. Deferred costs related to an acquisition that the Company has determined, based on management's judgment, not to pursue are expensed in the period in which such determination is made. Costs incurred in connection with a business combination are expensed as incurred.

Offering Costs

Offering Costs – Offering costs related to the issuance of common or preferred stock are charged to additional paid-in capital when the stock is issued.

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities – The Company has used forward swap contracts primarily to reduce exposure to changes in interest rates on a portion of its variable-rate debt and to provide a cash flow hedge. In accordance with FASB ASC 815, Derivatives and Hedging ("ASC 815"), these derivative contracts have been recorded on the balance sheet at fair value. Historically, these derivative instruments have been designated as hedges for accounting purposes. The measurement of the cash flow hedge ineffectiveness has historically been recognized in earnings, when applicable. The effective portion of the gain or loss on qualifying swaps has been reported in accumulated other comprehensive income ("AOCI"), in accordance with ASC 815. For swaps de-designated as cash flow hedges, changes in fair value of the swaps have been fully recognized in earnings. See Note 13 ("Interest Rate Hedge Swaps") for further discussion.

Earnings Per Share

Earnings Per Share – Basic earnings per share ("EPS") is computed using the weighted average number of common shares outstanding during the period. Diluted EPS is computed using the weighted average number of common and dilutive common equivalent shares outstanding during the period except for periods of net loss for which no common share equivalents are included because their effect would be anti-dilutive. Dilutive common equivalent shares consist of shares issuable upon conversion of the Convertible Notes calculated using the if-converted method.

Federal and State Income Taxation

Federal and State Income Taxation – In 2013 the Company qualified for REIT status, and in March 2014 elected (effective as of January 1, 2013), to be treated as a REIT for federal income tax purposes. Because certain of its assets may not produce REIT-qualifying income or be treated as interests in real property, those assets are held in wholly-owned TRSs in order to limit the potential that such assets and income could prevent the Company from qualifying as a REIT.

As a REIT, the Company holds and operates certain of its assets through one or more wholly-owned TRSs. The Company's use of TRSs enables it to continue to engage in certain businesses while complying with REIT qualification requirements and also allows it to retain income generated by these businesses for reinvestment without the requirement of distributing those earnings. In the future, the Company may elect to reorganize and transfer certain assets or operations from its TRSs to the Company or other subsidiaries, including qualified REIT subsidiaries.

The Company's other equity securities are limited partnerships or limited liability companies which are treated as partnerships for federal and state income tax purposes. As a limited partner, the Company reports its allocable share of taxable income in computing its own taxable income. To the extent held by a TRS, the TRS's tax expense or benefit is included in the Consolidated Statements of Income based on the component of income or gains and losses to which such expense or benefit relates. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. A valuation allowance is recognized if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized. It is expected that for the year ended December 31, 2018, and future periods, any deferred tax liability or asset generated will be related entirely to the assets and activities of the Company's TRSs.

If the Company ceased to qualify as a REIT, the Company, as a C corporation, would be obligated to pay federal and state income tax on its taxable income.

Recent Accounting Pronouncements

Recent Accounting Pronouncements – In February 2016, the FASB issued ASU 2016-02, Leases ("ASU 2016-02" or "ASC 842"), which amends the existing accounting standards for lease accounting, including requiring lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. ASU 2016-02 is effective for fiscal years and interim periods beginning after December 15, 2018, with early adoption permitted. At adoption, the standard will be applied using a modified retrospective approach. Alternatively, ASU 2018-11, Leases (Topic 842) Targeted Improvements, allows the Company to initially apply the new lease standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings and to continue to apply legacy guidance in ASC 840, Leases, including its disclosures requirements, in the comparative periods presented in the year of adoption. The Company has substantially completed its evaluation of the impact of the standard on its consolidated financial statements and related disclosures and expects that it will record a right of use asset and lease liability of less than $100 thousand on January 1, 2019 for its lessee operating leases.

The Company also concluded that Omega's long-term contract with the DOD to provide natural gas distribution to Fort Leonard Wood through Omega's pipeline distribution system on the military post meets the definition of a lease under ASC 842. Omega is the lessor in the contract and the lease is expected to be classified as an operating lease. The Company noted the non-lease component is the predominant component in the lease, and the timing and pattern of transfer of the lease component and the associated non-lease components are the same. Therefore, the Company expects to elect a practical expedient that allows lessors to not separate lease and related non-lease components if the non-lease components otherwise would be accounted for in accordance with the revenue standard under ASC 606. With the expected election of this practical expedient, the Company is expected to account for the DOD contract under the revenue standard, which is consistent with the Company's current accounting for the contract.

In August 2018, the FASB issued ASU 2018-13, Changes to the Disclosure Requirements for Fair Value Measurement ("ASU 2018-13"), which modifies the disclosure requirements on fair value measurements. The amendments add disclosure requirements for the changes in unrealized gains and losses for the period that are held in other comprehensive income for recurring Level 3 fair value measurements as well as disclosure requirements for the range and weighted average of significant observable inputs used to develop Level 3 fair value measurements. The amendments also clarify that the measurement uncertainty disclosure is to communicate information about the uncertainty in measurement as of the reporting date. ASU 2018-13 is effective for annual reporting periods, and interim periods within those annual periods, beginning after December 15, 2019. Management does not expect the adoption of this standard to have a material impact on the Company's consolidated financial statements.

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Leased Properties and Leases (Tables)

12 Months Ended

Dec. 31, 2018

Leases [Abstract]

Significant leased properties, major tenants and lease terms

The following table summarizes the significant leased properties, major tenants and lease terms:

Summary of Leased Properties, Major Tenants and Lease Terms
Property	Grand Isle Gathering System	Pinedale LGS
Location	Gulf of Mexico/Louisiana	Pinedale, WY
Tenant	Energy XXI GIGS Services, LLC	Ultra Wyoming LGS, LLC
Asset Description	Approximately 153 miles of offshore pipeline with total capacity of 120 thousand Bbls/d, including a 16-acre onshore terminal and saltwater disposal system.	Approximately 150 miles of pipelines and four central storage facilities.
Date Acquired	June 2015	December 2012
Initial Lease Term	11 years	15 years
Renewal Option	Equal to the lesser of 9-years or 75 percent of the remaining useful life	5-year terms
Current Monthly Rent Payments	7/1/17 - 6/30/18: $2,854,667 7/1/18 - 6/30/19: $2,860,917	$1,776,772(1)
Estimated Useful Life	27 years	26 years
(1) Monthly rent payments increased to $1,812,307 beginning January 1, 2019.

Schedule of future minimum lease receipts

The future contracted minimum rental receipts for all leases as of December 31, 2018, are as follows:

Future Minimum Lease Receipts
Year Ending December 31,	Amount
2019	$	58,347,190
2020	65,383,190
2021	71,345,190
2022	70,322,690
2023	67,274,690
Thereafter	193,639,760
Total	$	526,312,710

Schedule of Significant Leases

The table below displays the Company's individually significant leases as a percentage of total leased properties and total lease revenues for the periods presented:

	As a Percentage of (1)
	Leased Properties				Lease Revenues
	As of December 31,				For the Years Ended December 31,
	2018		2017		2018		2017		2016
Pinedale LGS (2)	44.5	%	39.9	%	35.2	%	31.2	%	30.4	%
Grand Isle Gathering System	55.2	%	49.7	%	55.9	%	59.1	%	59.8	%
Portland Terminal Facility (3)	—	%	10.1	%	8.8	%	9.6	%	9.7	%
(1) Insignificant leases are not presented; thus percentages may not sum to 100%.
(2) Pinedale LGS lease revenues include variable rent of $4.3 million and $587 thousand for the years ended December 31, 2018 and 2017, respectively.
(3) On December 21, 2018, the Portland Terminal Facility was sold to Zenith Terminals, terminating the Portland Lease Agreement. Refer to "Sale of the Portland Terminal Facility" section below.

Schedule of Depreciation, Amortization and Accretion

The following table reflects the depreciation and amortization included in the accompanying Consolidated Statements of Income associated with the Company's leases and leased properties:

	For the Years Ended December 31,
	2018		2017		2016
Depreciation Expense
GIGS	$	10,836,590	$	9,754,596	$	8,605,506
Pinedale	8,869,440		8,869,440		8,869,440
Portland Terminal Facility (1)	1,243,769		1,275,660		843,084
United Property Systems	36,662		36,298		32,424
Total Depreciation Expense	$	20,986,461	$	19,935,994	$	18,350,454
Amortization Expense - Deferred Lease Costs
GIGS	$	30,564	$	30,564	$	30,564
Pinedale	61,368		61,368		61,368
Total Amortization Expense - Deferred Lease Costs	$	91,932	$	91,932	$	91,932
ARO Accretion Expense
GIGS	$	499,562	$	663,065	$	726,664
Total ARO Accretion Expense	$	499,562	$	663,065	$	726,664
(1) On December 21, 2018, the Portland Terminal Facility was sold to Zenith Terminals, terminating the Portland Lease Agreement. Refer to "Sale of the Portland Terminal Facility" section below.

Schedule of Deferred Lease Costs

The following table reflects the deferred costs that are included in the accompanying Consolidated Balance Sheets associated with the Company's leased properties:

	December 31, 2018		December 31, 2017
Net Deferred Lease Costs
GIGS	$	229,319	$	259,883
Pinedale	550,349		611,717
Total Deferred Lease Costs, net	$	779,668	$	871,600

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Transportation and Distribution Revenue (Tables)

12 Months Ended

Dec. 31, 2018

Revenue from Contract with Customer [Abstract]

Contract with Customer, Asset and Liability

The table below summarizes the Company's contract asset and contract liability balances related to its transportation and distribution revenue contracts as of December 31, 2018:

	Contract Asset(1)			Contract Liability(2)
Beginning Balance January 1, 2018	$	328,033		$	—
Cumulative Transition Adjustment Upon Adoption of ASC 606	—			3,307,109
Unrecognized Performance Obligations	(836,628		)	3,307,109
Recognized Performance Obligations	689,174			(91,864		)
Ending Balance December 31, 2018	$	180,579		$	6,522,354
(1) The contract asset balance is included in prepaid expenses and other assets in the Consolidated Balance Sheets.
(2) The contract liability balance is included in unearned revenue in the Consolidated Balance Sheets.

Schedules of Concentration of Risk

The following is a breakout of the Company's transportation and distribution revenue for the years ended December 31, 2018, 2017 and 2016:

	For the Years Ended December 31,
	2018		2017		2016
Natural gas transportation contracts	64.3	%	71.5	%	67.6	%
Natural gas distribution contracts	26.8	%	20.4	%	19.0	%

Schedule of New Accounting Pronouncements and Changes in Accounting Principles

In accordance with ASC 606 transition disclosure requirements, the cumulative effect of changes made to the Consolidated Balance Sheet as of January 1, 2018 for the adoption of ASC 606 were as follows:

Balance Sheet	Balance at December 31, 2017		Adjustments Due to ASC 606			Balance at January 1, 2018
Assets
Deferred Tax Asset	$	2,244,629	$	857,864		$	3,102,493
Liabilities
Unearned revenue	3,397,717		3,307,109			6,704,826
Equity
Additional paid in capital	331,773,716		(2,449,245		)	329,324,471

The tables below disclose the impact of adoption on the Consolidated Balance Sheet and Consolidated Statement of Income as of and for the year ended December 31, 2018:

	As of December 31, 2018
Balance Sheet	As Reported		Balances Without Adoption of ASC 606		Effect of Change Higher/(Lower)
Assets
Deferred Tax Asset	$	4,948,203	$	3,256,304	$	1,691,899
Liabilities
Unearned revenue	6,552,049		29,695		6,522,354
Equity
Additional paid in capital	320,295,969		325,126,424		(4,830,455		)

	For the Year Ended December 31, 2018
Statement of Income	As Reported			Balances Without Adoption of ASC 606			Effect of Change Higher/(Lower)
Revenues
Transportation and distribution revenue	$	16,484,236		$	19,699,481		$	(3,215,245	)
Taxes
Deferred tax benefit	(1,833,340		)	(999,305		)	(834,035		)

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2018

Income Tax Disclosure [Abstract]

Components of deferred tax assets and liabilities

Components of the Company's deferred tax assets and liabilities as of December 31, 2018 and 2017, are as follows:

Deferred Tax Assets and Liabilities
	December 31, 2018			December 31, 2017
Deferred Tax Assets:
Deferred contract revenue	$	1,691,899		$	—
Net operating loss carryforwards	5,424,671			957,719
Loan loss provision	263,508			247,814
Basis reduction of investment in partnerships	—			261,549
Other	95,695			2,965,321
Sub-total	$	7,475,773		$	4,432,403
Deferred Tax Liabilities:
Net unrealized gain on investment securities	$	—		$	(342,669	)
Cost recovery of leased and fixed assets	(2,508,547		)	(1,845,105		)
Other	(19,023		)	—
Sub-total	$	(2,527,570	)	$	(2,187,774	)
Total net deferred tax asset	$	4,948,203		$	2,244,629

Total income tax expense

Total income tax expense (benefit) differs from the amount computed by applying the federal statutory income tax rate of 21 percent for the year ended December 31, 2018 and 35 percent for the years ended December 31, 2017 and 2016, to income or loss from operations and other income and expense for the years presented, as follows:

Income Tax Expense (Benefit)
	For the Years Ended December 31,
	2018			2017			2016
Application of statutory income tax rate	$	8,671,562		$	12,231,838		$	10,219,573
State income taxes, net of federal tax benefit	(583,186		)	352,708			26,215
Income of Real Estate Investment Trust not subject to tax	(10,339,520		)	(11,975,853		)	(10,663,371		)
Tax reform impact	—			1,262,444			—
Other	(167,582		)	474,181			(46,837		)
Total income tax expense (benefit)	$	(2,418,726	)	$	2,345,318		$	(464,420	)

Components of income tax expense

The components of income tax expense (benefit) include the following for the periods presented:

Components of Income Tax Expense (Benefit)
	For the Years Ended December 31,
	2018			2017			2016
Current tax expense (benefit)
Federal	$	(413,248	)	$	2,498,363		$	(321,720	)
State (net of federal tax benefit)	(172,138		)	333,295			8,613
Total current tax expense (benefit)	$	(585,386	)	$	2,831,658		$	(313,107	)
Deferred tax expense (benefit)
Federal	$	(1,422,292	)	$	(505,753	)	$	(168,915	)
State (net of federal tax benefit)	(411,048		)	19,413			17,602
Total deferred tax benefit	$	(1,833,340	)	$	(486,340	)	$	(151,313	)
Total income tax expense (benefit), net	$	(2,418,726	)	$	2,345,318		$	(464,420	)

Aggregate cost of securities for federal income tax purposes and securities with unrealized appreciation and depreciation

The aggregate cost of securities for federal income tax purposes and securities with unrealized appreciation and depreciation, were as follows:

Aggregate Cost of Securities for Income Tax Purposes
	December 31, 2018		December 31, 2017
Aggregate cost for federal income tax purposes	$	408,051	$	3,063,430
Gross unrealized appreciation	—		325,130
Gross unrealized depreciation	—		—
Net unrealized appreciation	$	—	$	325,130

Dividends declared and paid

The per share characterization by quarter is reflected in the following tables:

2018 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Unrecaptured Section 1250 Gain		Section 199A Dividends
2/14/2018	2/13/2018	2/28/2018	$	0.4609	$	0.3285	$	—	$	0.1324	$	0.0619	$	0.3285
5/17/2018	5/16/2018	5/31/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
8/17/2018	8/16/2018	8/31/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
11/15/2018	11/14/2018	11/30/2018	0.4609		0.3285		—		0.1324		0.0619		0.3285
Total 2018 Distributions			$	1.8436	$	1.3140	$	—	$	0.5296	$	0.2476	$	1.3140

2017 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
2/13/2017	2/9/2017	2/28/2017	$	0.4609	$	0.4609	$	0.0611	$	—	$	—
5/16/2017	5/12/2017	5/31/2017	0.4609		0.4609		0.0611		—		—
8/17/2017	8/15/2017	8/31/2017	0.4609		0.4609		0.0611		—		—
11/15/2017	11/14/2017	11/30/2017	0.4609		0.4609		0.0611		—		—
Total 2017 Distributions			$	1.8436	$	1.8436	$	0.2444	$	—	$	—

2016 Preferred Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
02/12/2016	02/10/2016	02/29/2016	$	0.4609	$	0.4609	$	—	$	—	$	—
05/13/2016	05/11/2016	05/31/2016	0.4609		0.4609		—		—		—
08/17/2016	08/15/2016	08/31/2016	0.4609		0.4609		—		—		—
11/15/2016	11/11/2016	11/30/2016	0.4609		0.4609		—		—		—
Total 2016 Distributions			$	1.8436	$	1.8436	$	—	$	—	$	—

The per share characterization by quarter is reflected in the following tables:

2018 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Unrecaptured Section 1250 Gain		Section 199A Dividends
2/14/2018	2/13/2018	2/28/2018	$	0.7500	$	0.5346	$	—	$	0.2154	$	0.1007	$	0.5346
5/17/2018	5/16/2018	5/31/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
8/17/2018	8/16/2018	8/31/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
11/15/2018	11/14/2018	11/30/2018	0.7500		0.5346		—		0.2154		0.1007		0.5346
Total 2018 Distributions			$	3.0000	$	2.1384	$	—	$	0.8616	$	0.4028	$	2.1384

2017 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
2/13/2017	2/9/2017	2/28/2017	$	0.7500	$	0.5925	$	0.0785	$	—	$	0.1575
5/16/2017	5/12/2017	5/31/2017	0.7500		0.5925		0.0785		—		0.1575
8/17/2017	8/15/2017	8/31/2017	0.7500		0.5925		0.0785		—		0.1575
11/15/2017	11/14/2017	11/30/2017	0.7500		0.5925		0.0785		—		0.1575
Total 2017 Distributions			$	3.0000	$	2.3700	$	0.3140	$	—	$	0.6300

2016 Common Stock Tax Information
Record Date	Ex-Dividend Date	Payable Date	Total Distribution per Share		Total Ordinary Dividends		Qualified Dividends		Capital Gain Distributions		Nondividend Distributions
02/12/2016	02/10/2016	02/29/2016	$	0.7500	$	0.2955	$	—	$	—	$	0.4545
05/13/2016	05/11/2016	05/31/2016	0.7500		0.2955		—		—		0.4545
08/17/2016	08/15/2016	08/31/2016	0.7500		0.2955		—		—		0.4545
11/15/2016	11/11/2016	11/30/2016	0.7500		0.2955		—		—		0.4545
Total 2016 Distributions			$	3.0000	$	1.1820	$	—	$	—	$	1.8180

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Property and Equipment (Tables)

12 Months Ended

Dec. 31, 2018

Property, Plant and Equipment [Abstract]

Property and Equipment

Property and equipment consist of the following:

Property and Equipment
	December 31, 2018			December 31, 2017
Land	$	580,000		$	580,000
Natural gas pipeline	124,306,175			124,303,315
Vehicles and trailers	696,164			650,634
Office equipment and computers	268,559			268,559
Gross property and equipment	$	125,850,898		$	125,802,508
Less: accumulated depreciation	(15,969,346		)	(12,643,636		)
Net property and equipment	$	109,881,552		$	113,158,872

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Fair Value (Tables)

12 Months Ended

Dec. 31, 2018

Fair Value Disclosures [Abstract]

Assets and liabilities measured on a recurring basis

The following tables set forth the Company's assets and liabilities measured at fair value on a recurring basis, by input level within the fair value hierarchy, as of December 31, 2017:

	December 31, 2017
	Total		Fair Value
			Level 1		Level 2		Level 3
Assets:
Other equity securities	$	2,958,315	$	—	$	—	$	2,958,315
Total Assets	$	2,958,315	$	—	$	—	$	2,958,315

The changes for all Level 3 assets measured at fair value on a recurring basis using significant unobservable inputs

The changes for all Level 3 securities measured at fair value on a recurring basis using significant unobservable inputs for the years ended December 31, 2018 and 2017, are as follows:

Level 3 Rollforward
For the Year Ended 2018	Fair Value Beginning Balance		Acquisitions		Disposals			Total Realized and Unrealized Gains (Losses) Included in Net Income			Return of Capital Adjustments Impacting Cost Basis of Securities			Fair Value Ending Balance		Changes in Unrealized Gains Included In Net Income, Relating to Securities Still Held (1)
Other equity securities	$	2,958,315	$	—	$	(449,067	)	$	(1,845,309	)	$	(663,939	)	$	—	$	—
Total	$	2,958,315	$	—	$	(449,067	)	$	(1,845,309	)	$	(663,939	)	$	—	$	—
For the Year Ended 2017
Other equity securities	$	9,287,209	$	1,161,034	$	(8,752,201	)	$	1,531,827		$	(269,554	)	$	2,958,315	$	295,161
Total	$	9,287,209	$	1,161,034	$	(8,752,201	)	$	1,531,827		$	(269,554	)	$	2,958,315	$	295,161
(1) Located in Net realized and unrealized gain on other equity securities in the Consolidated Statements of Income

Carrying and Fair Value Amounts

Carrying and Fair Value Amounts
	Level within Fair Value Hierarchy	December 31, 2018				December 31, 2017
		Carrying Amount (1)		Fair Value		Carrying Amount (1)		Fair Value
Financial Assets:
Cash and cash equivalents	Level 1	$	69,287,177	$	69,287,177	$	15,787,069	$	15,787,069
Financing notes receivable (Note 5)	Level 3	1,300,000		1,300,000		1,500,000		1,500,000
Financial Liabilities:
Secured credit facilities	Level 2	$	37,261,109	$	37,261,109	$	40,745,354	$	40,745,354
Unsecured convertible senior notes	Level 1	112,777,271		119,378,982		112,032,083		139,101,660
(1) The carrying value of debt balances are presented net of unamortized original issuance discount and debt issuance costs.

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Debt (Tables)

12 Months Ended

Dec. 31, 2018

Debt Disclosure [Abstract]

Schedule of Debt

The following is a summary of debt facilities and balances as of December 31, 2018 and 2017:

	Total Commitment  or Original Principal		Quarterly Principal Payments			December 31, 2018				December 31, 2017
					Maturity Date	Amount Outstanding		Interest Rate		Amount Outstanding		Interest Rate
CorEnergy Secured Credit Facility:
CorEnergy Revolver	$	160,000,000	$	—	7/28/2022	$	—	5.25	%	$	—	4.32	%
MoGas Revolver	1,000,000		—		7/28/2022	—		5.25	%	—		4.32	%
Omega Line of Credit	1,500,000		—		7/31/2019	—		6.50	%	—		5.57	%
Pinedale Secured Credit Facility:
Amended Pinedale Term Credit Facility	41,000,000		882,000		12/29/2022	37,472,000		6.50	%	41,000,000		6.50	%
7.00% Unsecured Convertible Senior Notes	115,000,000		—		6/15/2020	113,958,000		7.00	%	114,000,000		7.00	%
Total Debt						$	151,430,000			$	155,000,000
Less:
Unamortized deferred financing costs (1)						$	283,278			$	375,309
Unamortized discount on 7.00% Convertible Senior Notes						1,108,342				1,847,254
Long-term debt, net of deferred financing costs						$	150,038,380			$	152,777,437
Debt due within one year						$	3,528,000			$	3,528,000
(1) Unamortized deferred financing costs related to the Company's revolving credit facilities are included in Deferred Costs in the Assets section of the Consolidated Balance Sheets. Refer to the "Deferred Financing Costs" paragraph below.

A summary of deferred financing cost amortization expenses for the years ended December 31, 2018, 2017 and 2016 is as follows:

Deferred Financing Cost Amortization Expense (1)(2)
	For the Years Ended December 31,
	2018		2017		2016
CorEnergy Credit Facility	$	574,541	$	873,601	$	1,078,526
Amended Pinedale Term Credit Facility	52,728		392		156,330
Total Deferred Debt Cost Amortization	$	627,269	$	873,993	$	1,234,856
(1) Amortization of deferred debt issuance costs is included in interest expense in the Consolidated Statements of Income.
(2) For the amount of deferred debt costs amortization relating to the Convertible Notes included in the Consolidated Statements of Income, refer to the Convertible Note Interest Expense table below.

Schedule of Maturities of Long-term Debt

The remaining contractual principal payments as of December 31, 2018 under the Amended Pinedale Term Credit Facility are as follows:

Year	Amended Pinedale Term Credit Facility
2019	$	3,528,000
2020	3,528,000
2021	3,528,000
2022	26,888,000
2023	—
Thereafter	—
Total	$	37,472,000

Components of convertible debt

The following is a summary of the impact of Convertible Notes on interest expense for the years ended December 31, 2018, 2017 and 2016:

Convertible Note Interest Expense
	For the Years Ended December 31,
	2018		2017		2016
7.00% Convertible Notes	$	7,979,118	$	7,980,000	$	8,008,195
Discount Amortization	738,912		738,912		744,081
Deferred Debt Issuance Cost Amortization	48,276		48,276		48,566
Total	$	8,766,306	$	8,767,188	$	8,800,842

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Asset Retirement Obligation (Tables)

12 Months Ended

Dec. 31, 2018

Asset Retirement Obligation Disclosure [Abstract]

Schedule of asset retirement obligations

The following table is a reconciliation of the asset retirement obligation as of December 31, 2018 and 2017:

Asset Retirement Obligation
	For the Years Ended December 31,
	2018			2017
Beginning asset retirement obligation	$	9,170,493		$	11,882,943
Liabilities assumed	—			—
ARO accretion expense	499,562			663,065
Liabilities settled	(628,300		)	—
Revision in cash flow estimates	(1,085,412		)	(3,375,515		)
Ending asset retirement obligation	$	7,956,343		$	9,170,493

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Interest Rate Hedge Swaps (Tables)

12 Months Ended

Dec. 31, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of gain (loss) on derivative instruments

The table below presents the effect of the Company's derivative financial instruments on the Consolidated Statements of Income and Comprehensive Income for the years ended December 31, 2017 and 2016 (note that the ineffective portion is not presented as it was inconsequential for all periods presented):

	For the Years Ended December 31,
Derivatives in Cash Flow Hedging Relationship	2017		2016
Amount of Loss on Derivatives Recognized in AOCI (Effective Portion)	$	—	$	(300,181	)
Amount of Loss on Derivatives Reclassified from AOCI (Effective Portion) Recognized in Net Income(1)	—		(50,964		)
Derivatives Not Designated as Hedging Instruments
Amount of Gain on Derivatives Recognized in Income(2)	$	25,842	$	73,204
(1) Included in "Interest Expense" on the face of the Consolidated Statements of Income and Comprehensive Income.
(2) The gains recognized in income on derivatives include changes in fair value for derivatives subsequent to de-designation from hedge accounting.

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Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2018

Earnings Per Share [Abstract]

Computation of basic and diluted earnings per share

Earnings Per Share
	For the Years Ended December 31,
	2018		2017		2016
Net income attributable to CorEnergy stockholders	$	43,711,876	$	32,602,790	$	29,663,200
Less: preferred dividend requirements(1)	9,548,377		7,953,988		4,148,437
Net income attributable to common stockholders	$	34,163,499	$	24,648,802	$	25,514,763
Weighted average shares - basic	11,935,021		11,900,516		11,901,985
Basic earnings per share	$	2.86	$	2.07	$	2.14
Net income attributable to common stockholders (from above)	$	34,163,499	$	24,648,802	$	25,514,763
Add: After tax effect of convertible interest	8,766,306		—		—
Income attributable for dilutive securities	$	42,929,805	$	24,648,802	$	25,514,763
Weighted average shares - diluted	15,389,180		11,900,516		11,901,985
Diluted earnings per share	$	2.79	$	2.07	$	2.14
(1) In connection with the repurchases of Series A Preferred Stock during the year ended December 31, 2018, preferred dividend requirements were reduced by $10,554 representing the discount in the repurchase price paid compared to the carrying amount derecognized.

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Quarterly Financial Data (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2018

Quarterly Financial Information Disclosure [Abstract]

Schedule of Quarterly Financial Information

	For the Fiscal 2018 Quarters Ended
	March 31			June 30			September 30			December 31
Revenue
Lease revenue	$	17,591,859		$	18,275,859		$	18,391,983		$	18,487,661
Transportation and distribution revenue	3,952,979			3,874,157			4,244,722			4,412,378
Total Revenue	21,544,838			22,150,016			22,636,705			22,900,039
Expenses
Transportation and distribution expenses	1,572,896			1,534,524			2,241,999			1,861,329
General and administrative	2,727,057			3,107,776			3,046,481			4,161,533
Depreciation, amortization and ARO accretion expense	6,289,330			6,290,082			6,289,459			6,078,582
Provision for loan (gain) loss	500,000			—			—			(536,867		)
Total Expenses	11,089,283			10,932,382			11,577,939			11,564,577
Operating Income	$	10,455,555		$	11,217,634		$	11,058,766		$	11,335,462
Other Income (Expense)
Net distributions and dividend income	$	3,951		$	55,714		$	5,627		$	41,503
Net realized and unrealized gain (loss) on other equity securities	13,966			(881,100		)	(930,147		)	(48,028		)
Interest expense	(3,210,590		)	(3,196,248		)	(3,183,589		)	(3,168,583		)
Gain on the sale of leased property, net	—			—			—			11,723,257
Total Other Income (Expense)	(3,192,673		)	(4,021,634		)	(4,108,109		)	8,548,149
Income before income taxes	7,262,882			7,196,000			6,950,657			19,883,611
Taxes
Current tax benefit	(35,549		)	(10,785		)	(8,393		)	(530,659		)
Deferred tax benefit	(409,277		)	(604,064		)	(738,274		)	(81,725		)
Income tax benefit, net	(444,826		)	(614,849		)	(746,667		)	(612,384		)
Net Income attributable to CorEnergy Stockholders	$	7,707,708		$	7,810,849		$	7,697,324		$	20,495,995
Preferred dividend requirements	2,396,875			2,396,875			2,396,875			2,357,752
Net Income attributable to Common Stockholders	$	5,310,833		$	5,413,974		$	5,300,449		$	18,138,243
Earnings Per Common Share:
Basic	$	0.45		$	0.45		$	0.44		$	1.52
Diluted	$	0.45		$	0.45		$	0.44		$	1.32

	For the Fiscal 2017 Quarters Ended
	March 31			June 30			September 30			December 31
Revenue
Lease revenue	$	17,066,526		$	17,050,092		$	17,173,676		$	17,513,510
Transportation and distribution revenue	5,010,590			4,775,780			5,270,628			4,888,575
Total Revenue	22,077,116			21,825,872			22,444,304			22,402,085
Expenses
Transportation and distribution expenses	1,335,570			1,362,980			2,384,182			1,646,975
General and administrative	3,061,240			2,558,339			2,632,546			2,534,372
Depreciation, amortization and ARO accretion expense	6,005,908			6,005,995			6,017,664			6,018,143
Total Expenses	10,402,718			9,927,314			11,034,392			10,199,490
Operating Income	$	11,674,398		$	11,898,558		$	11,409,912		$	12,202,595
Other Income (Expense)
Net distributions and dividend income	$	43,462		$	221,440		$	213,040		$	202,149
Net realized and unrealized gain (loss) on other equity securities	(544,208		)	614,634			1,340,197			121,204
Interest expense	(3,454,397		)	(3,202,837		)	(2,928,036		)	(2,793,245		)
Loss on extinguishment of debt	—			—			(234,433		)	(102,500		)
Total Other Expense	(3,955,143		)	(2,366,763		)	(1,609,232		)	(2,572,392		)
Income before income taxes	7,719,255			9,531,795			9,800,680			9,630,203
Taxes
Current tax expense (benefit)	(33,760		)	57,651			65,131			2,742,636
Deferred tax expense (benefit)	(298,846		)	38,084			126,440			(352,018		)
Income tax expense (benefit), net	(332,606		)	95,735			191,571			2,390,618
Net Income	8,051,861			9,436,060			9,609,109			7,239,585
Less: Net Income attributable to non-controlling interest	382,383			435,888			431,825			483,730
Net Income attributable to CorEnergy Stockholders	$	7,669,478		$	9,000,172		$	9,177,284		$	6,755,855
Preferred dividend requirements	1,037,109			2,123,129			2,396,875			2,396,875
Net Income attributable to Common Stockholders	$	6,632,369		$	6,877,043		$	6,780,409		$	4,358,980
Earnings Per Common Share:
Basic	$	0.56		$	0.58		$	0.57		$	0.37
Diluted	$	0.56		$	0.58		$	0.57		$	0.37

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Introduction and Basis of Presentation - Narrative (Details)	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Pinedale LP
Schedule of Equity Method Investments [Line Items]
Equity interest percentage	100.00%
Grand Isle Corridor LP
Schedule of Equity Method Investments [Line Items]
Equity interest percentage	100.00%	100.00%	100.00%

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Significant Accounting Policies (Details) - USD ($)	3 Months Ended				12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Provision for loan (gain) loss	$ (536,867)	$ 0	$ 0	$ 500,000	$ (36,867)	$ 0	$ 5,014,466
Subsequent event | ASU 2016-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
ROU asset								$ 100,000
Lease liability								$ 100,000

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Leased Properties and Leases - Leased Properties (Details) bbl / d in Thousands		12 Months Ended
	Jan. 01, 2019 USD ($)	Dec. 31, 2018 USD ($) a bbl / d facility leased_property mi
Sale Leaseback Transaction [Line Items]
Number of significant leased properties | leased_property		2
Grand Isle Gathering System
Sale Leaseback Transaction [Line Items]
Initial term		11 years
Renewal term		9 years
Renewal Term, percentage of remaining useful life		75.00%
Length of offshore pipeline (in miles) | mi		153
Pipeline capacity (in bbl/day) | bbl / d		120
Number of acres in the onshore terminal and saltwater disposal system (in acres) | a		16
Current Monthly Rent Payments		$ 2,854,667
Expected future monthly rent payments		$ 2,860,917
Estimated Useful Life		27 years
Pinedale LGS
Sale Leaseback Transaction [Line Items]
Initial term		15 years
Renewal term		5 years
Length of offshore pipeline (in miles) | mi		150
Number of storage facilities | facility		4
Current Monthly Rent Payments		$ 1,776,772
Estimated Useful Life		26 years
Minimum
Sale Leaseback Transaction [Line Items]
Initial term		11 years
Maximum
Sale Leaseback Transaction [Line Items]
Initial term		15 years
Forecast | Pinedale LGS
Sale Leaseback Transaction [Line Items]
Current Monthly Rent Payments	$ 1,812,307

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Leased Properties and Leases - Future Minimum Lease Receipts (Details)	Dec. 31, 2018 USD ($)
Leases [Abstract]
2019	$ 58,347,190
2020	65,383,190
2021	71,345,190
2022	70,322,690
2023	67,274,690
Thereafter	193,639,760
Total	$ 526,312,710

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Leased Properties and Leases - Significant Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Pinedale LGS
Operating Leased Assets [Line Items]
Percentage of total leased properties	44.50%	39.90%
Percentage of leased property revenue	35.20%	31.20%	30.40%
Variable rent	$ 4,300	$ 587
Grand Isle Gathering System
Operating Leased Assets [Line Items]
Percentage of total leased properties	55.20%	49.70%
Percentage of leased property revenue	55.90%	59.10%	59.80%
Portland Terminal Facility
Operating Leased Assets [Line Items]
Percentage of total leased properties	0.00%	10.10%
Percentage of leased property revenue	8.80%	9.60%	9.70%

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Leased Properties and Leases - Amortization, Depreciation Expense, Accretion Expense (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Sale Leaseback Transaction [Line Items]
Depreciation Expense	$ 3,400,000	$ 3,400,000	$ 3,400,000
ARO Accretion Expense	499,562	663,065
All Properties [Member]
Sale Leaseback Transaction [Line Items]
Depreciation Expense	20,986,461	19,935,994	18,350,454
Amortization Expense - Deferred Lease Costs	91,932	91,932	91,932
ARO Accretion Expense	499,562	663,065	726,664
Net Deferred Lease Costs	779,668	871,600
GIGS
Sale Leaseback Transaction [Line Items]
Depreciation Expense	10,836,590	9,754,596	8,605,506
Amortization Expense - Deferred Lease Costs	30,564	30,564	30,564
ARO Accretion Expense	499,562	663,065	726,664
Net Deferred Lease Costs	229,319	259,883
Pinedale LGS
Sale Leaseback Transaction [Line Items]
Depreciation Expense	8,869,440	8,869,440	8,869,440
Amortization Expense - Deferred Lease Costs	61,368	61,368	61,368
Net Deferred Lease Costs	550,349	611,717
Portland Terminal Facility
Sale Leaseback Transaction [Line Items]
Depreciation Expense	1,243,769	1,275,660	843,084
United Property Systems
Sale Leaseback Transaction [Line Items]
Depreciation Expense	$ 36,662	$ 36,298	$ 32,424

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Leased Properties and Leases - Sale of the Portland Terminal Facility (Details) - USD ($)		3 Months Ended				12 Months Ended
	Dec. 21, 2018	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from the sale of leased property						$ 55,553,975	$ 0	$ 0
Gain on sale of leased property		$ 11,723,257	$ 0	$ 0	$ 0	11,723,257	0	$ 0
Deferred rent receivable		25,942,755				25,942,755	22,060,787
Joliet Terminal
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Investments							$ 1,200,000
Realized loss on sale of investment	$ 715,000
Disposed of by Sale, Not Discontinued Operations | Zenith Energy Terminals Holdings | Portland Terminal Facility and Joliet Terminal
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal consideration	61,000,000
Proceeds from the sale of leased property	56,000,000
Note receivable	5,000,000
Disposed of by Sale, Not Discontinued Operations | Zenith Energy Terminals Holdings | Portland Terminal Facility
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal consideration	60,600,000
Disposal consideration if sold to third party within 6 months, more than	60,000,000
Gain on sale of leased property						11,700,000
Deferred rent receivable		$ 3,200,000				$ 3,200,000
Disposed of by Sale, Not Discontinued Operations | Zenith Energy Terminals Holdings | Joliet Terminal
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal consideration	400,000
Portland Terminal Facility
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Property investment	$ 45,700,000

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Leased Properties and Leases - Pinedale LGS Acquisition (Details) - USD ($) $ in Millions	Dec. 29, 2017	Dec. 31, 2018
Pinedale LP
Noncontrolling Interest [Line Items]
Difference in fair value of purchase consideration and carrying amount		$ 5.6
Controlling economic interest	100.00%
Pinedale LP | Pinedale LP I
Noncontrolling Interest [Line Items]
Purchase price	$ 32.9
Pinedale LGS | Limited Partner | Prudential
Noncontrolling Interest [Line Items]
Ownership percentage	18.95%
Noncontrolling economic interest	$ 27.3

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Transportation and Distribution Revenue - Contract Assets and Liabilities (Details) - USD ($)		11 Months Ended	12 Months Ended
	Jan. 01, 2018	Nov. 30, 2018	Dec. 31, 2018
Change In Contract With Customer, Asset [Roll Forward]
Beginning Balance	$ 328,033	$ 328,033	$ 328,033
Cumulative Transition Adjustment Upon Adoption of ASC 606			0
Unrecognized Performance Obligations			(836,628)
Recognized Performance Obligations			689,174
Ending Balance			180,579
Change In Contract With Customer, Liability [Roll Forward]
Beginning Balance	0	0	0
Cumulative Transition Adjustment Upon Adoption of ASC 606	$ 3,300,000		3,307,109
Unrecognized Performance Obligations		$ 992,000	3,307,109
Recognized Performance Obligations			(91,864)
Ending Balance			$ 6,522,354

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Transportation and Distribution Revenue - Additional Information (Details) - USD ($)		11 Months Ended	12 Months Ended			143 Months Ended
	Jan. 01, 2018	Nov. 30, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Oct. 31, 2030
Concentration Risk [Line Items]
Cumulative Transition Adjustment Upon Adoption of ASC 606	$ 3,300,000		$ 3,307,109
Unrecognized performance obligations		$ 992,000	3,307,109
Remaining performance obligation			$ 63,500,000
Natural gas transportation contracts | Product and services | Revenue
Concentration Risk [Line Items]
Concentration percentage			64.30%	71.50%	67.60%
Natural gas distribution contracts | Product and services | Revenue
Concentration Risk [Line Items]
Concentration percentage			26.80%	20.40%	19.00%
Forecast
Concentration Risk [Line Items]
Recognized performance obligations quarterly						$ 138,000

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Transportation and Distribution Revenue - Balance Sheet and Income Statement (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 01, 2018
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Deferred Tax Asset	$ 4,948,203				$ 2,244,629				$ 4,948,203	$ 2,244,629		$ 3,102,493
Unearned revenue	6,552,049				3,397,717				6,552,049	3,397,717		6,704,826
Additional paid-in capital	320,295,969				331,773,716				320,295,969	331,773,716		329,324,471
Transportation and distribution revenue									16,484,236
Deferred tax benefit	(81,725)	$ (738,274)	$ (604,064)	$ (409,277)	(352,018)	$ 126,440	$ 38,084	$ (298,846)	(1,833,340)	(486,340)	$ (151,313)
Balances Without Adoption of ASC 606
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Deferred Tax Asset					2,244,629					2,244,629
Unearned revenue					3,397,717					3,397,717
Additional paid-in capital					$ 331,773,716					$ 331,773,716
Balances Without Adoption of ASC 606 | ASU 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Deferred Tax Asset	3,256,304								3,256,304
Unearned revenue	29,695								29,695
Additional paid-in capital	325,126,424								325,126,424
Transportation and distribution revenue									19,699,481
Deferred tax benefit									(999,305)
Effect of Change Higher/(Lower) | ASU 2014-09
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Deferred Tax Asset	1,691,899								1,691,899			857,864
Unearned revenue	6,522,354								6,522,354			3,307,109
Additional paid-in capital	$ (4,830,455)								(4,830,455)			$ (2,449,245)
Transportation and distribution revenue									(3,215,245)
Deferred tax benefit									$ (834,035)

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Financing Notes Receivable - Four Wood Financing Note Receivable (Details) - USD ($)			3 Months Ended				12 Months Ended
	Dec. 12, 2018	Dec. 31, 2014	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 11, 2018
Accounts, Notes, Loans and Financing Receivable [Line Items]
Provision for loan (gain) loss			$ (536,867)	$ 0	$ 0	$ 500,000	$ (36,867)	$ 0	$ 5,014,466
Cash consideration	$ 237,000						17,999	0	223,451
SWD Enterprises
Accounts, Notes, Loans and Financing Receivable [Line Items]
Maximum borrowing capacity								1,500,000
Provision for loan (gain) loss						$ 500,000	(37,000)		3,500,000
Deferred origination costs									71,000
Interest accrued									$ 98,000
Compass REIT Loan
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing receivable	1,300,000		$ 1,300,000				$ 1,300,000
Maximum borrowing capacity	$ 1,300,000
Line of Credit
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing receivable		$ 4,000,000
Basis spread on variable rate		2.00%
Line of Credit | REIT Loan
Accounts, Notes, Loans and Financing Receivable [Line Items]
Interest Rate		12.00%
Line of Credit | TRS Loan
Accounts, Notes, Loans and Financing Receivable [Line Items]
Interest Rate		13.00%
Long-term Debt | Subsidiaries
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing receivable		$ 1,000,000
SWD Enterprises | REIT Loan
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing receivable								$ 1,500,000		$ 1,000,000
LIBOR | Compass REIT Loan
Accounts, Notes, Loans and Financing Receivable [Line Items]
Basis spread on variable rate	6.00%

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Financing Notes Receivable - Black Bison Financing Notes (Details) - USD ($)			3 Months Ended				12 Months Ended
	Dec. 12, 2018	Jun. 16, 2016	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Feb. 29, 2016	Dec. 31, 2014
Accounts, Notes, Loans and Financing Receivable [Line Items]
Provision for loan (gain) loss			$ (536,867)	$ 0	$ 0	$ 500,000	$ (36,867)	$ 0	$ 5,014,466
Proceeds from asset foreclosure and sale	$ 237,000						$ 17,999	$ 0	223,451
Black Bison Water Services LLC | Long-term Debt
Accounts, Notes, Loans and Financing Receivable [Line Items]
Maximum borrowing capacity												$ 12,000,000
Subsidiaries | Black Bison Water Services LLC | Long-term Debt
Accounts, Notes, Loans and Financing Receivable [Line Items]
Maximum borrowing capacity												$ 3,300,000
Loans Agreement | Subsidiaries
Accounts, Notes, Loans and Financing Receivable [Line Items]
Provision for loan (gain) loss										$ 13,800,000
Outstanding loan balance											$ 2,000,000
BB Intermediate
Accounts, Notes, Loans and Financing Receivable [Line Items]
Provision for loan (gain) loss									$ 832,000
Equity interest percentage											100.00%
Wells and Related Equipment and Facilities | Expedition Water Solutions
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds from asset foreclosure and sale		$ 748,000
Fair value of future royalty payments		$ 450,000

XML

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Deferred Tax Assets:
Deferred contract revenue	$ 1,691,899	$ 0
Net operating loss carryforwards	5,424,671	957,719
Loan loss provision	263,508	247,814
Basis reduction of investment in partnerships	0	261,549
Other	95,695	2,965,321
Sub-total	7,475,773	4,432,403
Deferred Tax Liabilities:
Net unrealized gain on investment securities	0	(342,669)
Cost recovery of leased and fixed assets	(2,508,547)	(1,845,105)
Other	(19,023)	0
Sub-total	(2,527,570)	(2,187,774)
Total net deferred tax asset	$ 4,948,203	$ 2,244,629

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Income Taxes - Additional Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Contingency [Line Items]
Adjustment which reduced net deferred tax assets		$ 1,300
Federal statutory income tax rate	21.00%	35.00%	35.00%
Net operating loss for federal income tax purposes	$ 21,000
NOL expiring in 2034 if not utilized	328
NOL expiring in 2035 if not utilized	176
NOL expiring in 2036 if not utilized	1,400
NOL expiring in 2037 if not utilized	2,000
Subsidiaries
Income Tax Contingency [Line Items]
Net operating loss for federal income tax purposes	$ 17,100	$ 4,100	$ 3,000
State | Corridor Public Holdings, Inc. And Corridor Private Holdings, Inc.
Income Tax Contingency [Line Items]
Blended state tax rate	5.53%	3.78%	3.78%
State | Missouri | CorEnergy BBWS, Inc
Income Tax Contingency [Line Items]
Blended state tax rate	5.00%
State | Missouri | Corridor MoGas
Income Tax Contingency [Line Items]
Blended state tax rate	5.00%	5.00%	5.00%
State | Missouri | Mowood Corridor
Income Tax Contingency [Line Items]
Blended state tax rate		5.00%	5.00%

XML

Income Taxes - Income Tax Benefit (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Federal statutory income tax rate									21.00%	35.00%	35.00%
Total income tax expense (benefit) differs from the amount computed by applying the federal statutory income tax rates net investment income and net realized and unrealized gains on investments
Application of statutory income tax rate									$ 8,671,562	$ 12,231,838	$ 10,219,573
State income taxes, net of federal tax benefit									(583,186)	352,708	26,215
Income of Real Estate Investment Trust not subject to tax									(10,339,520)	(11,975,853)	(10,663,371)
Tax reform impact									0	1,262,444	0
Other									(167,582)	474,181	(46,837)
Income tax expense (benefit), net	$ (612,384)	$ (746,667)	$ (614,849)	$ (444,826)	$ 2,390,618	$ 191,571	$ 95,735	$ (332,606)	$ (2,418,726)	$ 2,345,318	$ (464,420)

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Income Taxes - Components of Income Tax Benefit (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current tax expense (benefit)
Federal									$ (413,248)	$ 2,498,363	$ (321,720)
State (net of federal tax benefit)									(172,138)	333,295	8,613
Total current tax expense (benefit)	$ (530,659)	$ (8,393)	$ (10,785)	$ (35,549)	$ 2,742,636	$ 65,131	$ 57,651	$ (33,760)	(585,386)	2,831,658	(313,107)
Deferred tax expense (benefit)
Federal									(1,422,292)	(505,753)	(168,915)
State (net of federal tax benefit)									(411,048)	19,413	17,602
Total deferred tax benefit	(81,725)	(738,274)	(604,064)	(409,277)	(352,018)	126,440	38,084	(298,846)	(1,833,340)	(486,340)	(151,313)
Income tax expense (benefit), net	$ (612,384)	$ (746,667)	$ (614,849)	$ (444,826)	$ 2,390,618	$ 191,571	$ 95,735	$ (332,606)	$ (2,418,726)	$ 2,345,318	$ (464,420)

XML

Income Taxes - Aggregate Cost of Securities for Income Tax Purposes (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Aggregate cost of securities for federal income tax purposes and securities with unrealized appreciation and depreciation
Aggregate cost for federal income tax purposes	$ 408,051	$ 3,063,430
Gross unrealized appreciation	0	325,130
Gross unrealized depreciation	0	0
Net unrealized appreciation	$ 0	$ 325,130

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Income Taxes - Common and Preferred Stock Distribution (Details) - $ / shares	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	$ 3.000	$ 3.000	$ 3.000
Total Distribution per Share
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	3.0000	3.0000	3.0000
Preferred Stock, Dividends declared per share (in dollars per share)	1.8436	1.8436	1.8436
Total Ordinary Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	2.1384	2.3700	1.1820
Preferred Stock, Dividends declared per share (in dollars per share)	1.3140	1.8436	1.8436
Qualified Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.0000	0.3140	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.0000	0.2444	0.0000
Capital Gain Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.8616	0.0000	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.5296	0.0000	0.0000
Unrecaptured Section 1250 Gain
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.4028
Preferred Stock, Dividends declared per share (in dollars per share)	0.2476
Section 199A Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	2.1384
Preferred Stock, Dividends declared per share (in dollars per share)	1.3140
Nondividend Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)		0.6300	1.8180
Preferred Stock, Dividends declared per share (in dollars per share)		0.0000	0.0000
Installment One | Total Distribution per Share
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.7500	0.7500	0.7500
Preferred Stock, Dividends declared per share (in dollars per share)	0.4609	0.4609	0.4609
Installment One | Total Ordinary Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346	0.5925	0.2955
Preferred Stock, Dividends declared per share (in dollars per share)	0.3285	0.4609	0.4609
Installment One | Qualified Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.0000	0.0785	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.0000	0.0611	0.0000
Installment One | Capital Gain Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.2154	0.0000	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.1324	0.0000	0.0000
Installment One | Unrecaptured Section 1250 Gain
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.1007
Preferred Stock, Dividends declared per share (in dollars per share)	0.0619
Installment One | Section 199A Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346
Preferred Stock, Dividends declared per share (in dollars per share)	0.3285
Installment One | Nondividend Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)		0.1575	0.4545
Preferred Stock, Dividends declared per share (in dollars per share)		0.0000	0.0000
Installment Two | Total Distribution per Share
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.7500	0.7500	0.7500
Preferred Stock, Dividends declared per share (in dollars per share)	0.4609	0.4609	0.4609
Installment Two | Total Ordinary Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346	0.5925	0.2955
Preferred Stock, Dividends declared per share (in dollars per share)	0.3285	0.4609	0.4609
Installment Two | Qualified Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.0000	0.0785	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.0000	0.0611	0.0000
Installment Two | Capital Gain Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.2154	0.0000	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.1324	0.0000	0.0000
Installment Two | Unrecaptured Section 1250 Gain
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.1007
Preferred Stock, Dividends declared per share (in dollars per share)	0.0619
Installment Two | Section 199A Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346
Preferred Stock, Dividends declared per share (in dollars per share)	0.3285
Installment Two | Nondividend Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)		0.1575	0.4545
Preferred Stock, Dividends declared per share (in dollars per share)		0.0000	0.0000
Installment Three | Total Distribution per Share
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.7500	0.7500	0.7500
Preferred Stock, Dividends declared per share (in dollars per share)	0.4609	0.4609	0.4609
Installment Three | Total Ordinary Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346	0.5925	0.2955
Preferred Stock, Dividends declared per share (in dollars per share)	0.3285	0.4609	0.4609
Installment Three | Qualified Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.0000	0.0785	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.0000	0.0611	0.0000
Installment Three | Capital Gain Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.2154	0.0000	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.1324	0.0000	0.0000
Installment Three | Unrecaptured Section 1250 Gain
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.1007
Preferred Stock, Dividends declared per share (in dollars per share)	0.0619
Installment Three | Section 199A Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346
Preferred Stock, Dividends declared per share (in dollars per share)	0.3285
Installment Three | Nondividend Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)		0.1575	0.4545
Preferred Stock, Dividends declared per share (in dollars per share)		0.0000	0.0000
Installment Four | Total Distribution per Share
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.7500	0.7500	0.7500
Preferred Stock, Dividends declared per share (in dollars per share)	0.4609	0.4609	0.4609
Installment Four | Total Ordinary Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346	0.5925	0.2955
Preferred Stock, Dividends declared per share (in dollars per share)	0.3285	0.4609	0.4609
Installment Four | Qualified Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.0000	0.0785	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.0000	0.0611	0.0000
Installment Four | Capital Gain Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.2154	0.0000	0.0000
Preferred Stock, Dividends declared per share (in dollars per share)	0.1324	0.0000	0.0000
Installment Four | Unrecaptured Section 1250 Gain
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.1007
Preferred Stock, Dividends declared per share (in dollars per share)	0.0619
Installment Four | Section 199A Dividends
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)	0.5346
Preferred Stock, Dividends declared per share (in dollars per share)	$ 0.3285
Installment Four | Nondividend Distributions
Dividends Payable [Line Items]
Common Stock, Dividends declared per share (in dollars per share)		0.1575	0.4545
Preferred Stock, Dividends declared per share (in dollars per share)		$ 0.0000	$ 0.0000
Capital Stock
Dividends Payable [Line Items]
Ordinary income dividend percentage	71.30%
Return of capital percentage	0.00%
Capital gain percentage	28.70%
Qualified dividend income percentage	0.00%
Capital gain, percentage subject to maximum 25 percent tax rate	13.40%
Capital gain, percentage subject to maximum 20 percent tax rate	15.30%
Preferred Stock
Dividends Payable [Line Items]
Ordinary income dividend percentage	71.30%
Return of capital percentage	0.00%
Capital gain percentage	28.70%
Qualified dividend income percentage	0.00%
Capital gain, percentage subject to maximum 25 percent tax rate	13.40%
Capital gain, percentage subject to maximum 20 percent tax rate	15.30%

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Property and Equipment (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Component of property and equipment
Gross property and equipment	$ 125,850,898	$ 125,802,508
Less: accumulated depreciation	(15,969,346)	(12,643,636)
Net property and equipment	109,881,552	113,158,872
Depreciation Expense	3,400,000	3,400,000	$ 3,400,000
Land
Component of property and equipment
Gross property and equipment	580,000	580,000
Natural gas pipeline
Component of property and equipment
Gross property and equipment	124,306,175	124,303,315
Vehicles and trailers
Component of property and equipment
Gross property and equipment	696,164	650,634
Office equipment and computers
Component of property and equipment
Gross property and equipment	$ 268,559	$ 268,559

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Concentrations (Details) - leased_property	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Concentration Risk [Line Items]
Number of significant leased properties	2
Revenue from Contract with Customer | Customer Concentration Risk
Concentration Risk [Line Items]
Percentage of revenues	6.00%	11.00%	12.00%

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Management Agreement (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Management Agreement [Line Items]
Percentage of directors to reach majority	0.6667%
Number of days prior to written notice to terminate	30 days
Percentage of fees of the last 4 quarters	300.00%
Corridor Infra Trust Management
Management Agreement [Line Items]
Quarterly management fee percentage	0.25%
Annual management fee percentage	1.00%
Quarterly incentive fee percentage in relation to distribution threshold	10.00%
Distribution threshold (in dollars per share)	$ 0.625
General and Administrative Expense | Corridor Infra Trust Management
Management Agreement [Line Items]
Management Fee	$ 7,600	$ 7,200	$ 7,200
Administrative Fee	$ 280	269	266
New Management Agreement
Management Agreement [Line Items]
Incentive fees waived		100	88
Incentive Fee		$ 595	$ 595
Administrative Agreement
Management Agreement [Line Items]
Annual rate percentage of managed assets	0.04%
Minimum annual fee	$ 30

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Fair Value - Assets and Liabilities Measured on a Recurring Basis (Details) - Recurring	Dec. 31, 2017 USD ($)
Assets:
Other equity securities	$ 2,958,315
Total Assets	2,958,315
Level 1
Assets:
Other equity securities	0
Total Assets	0
Level 2
Assets:
Other equity securities	0
Total Assets	0
Level 3
Assets:
Other equity securities	2,958,315
Total Assets	$ 2,958,315

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Fair Value - Changes in Level 3 Securities (Details) - Level 3 - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value Beginning Balance	$ 2,958,315	$ 9,287,209
Acquisitions	0	1,161,034
Disposals	(449,067)	(8,752,201)
Total Realized and Unrealized Gains (Losses) Included in Net Income	(1,845,309)	1,531,827
Return of Capital Adjustments Impacting Cost Basis of Securities	(663,939)	(269,554)
Fair Value Ending Balance	0	2,958,315
Changes in Unrealized Gains Included In Net Income, Relating to Securities Still Held	0	295,161
Other equity securities
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value Beginning Balance	2,958,315	9,287,209
Acquisitions	0	1,161,034
Disposals	(449,067)	(8,752,201)
Total Realized and Unrealized Gains (Losses) Included in Net Income	(1,845,309)	1,531,827
Return of Capital Adjustments Impacting Cost Basis of Securities	(663,939)	(269,554)
Fair Value Ending Balance	0	2,958,315
Changes in Unrealized Gains Included In Net Income, Relating to Securities Still Held	$ 0	$ 295,161

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Fair Value - Additional Information (Details) $ / shares in Units, $ in Thousands, Bcf / d in Billions		12 Months Ended
	Dec. 21, 2017 USD ($) $ / shares	Dec. 31, 2018 USD ($)	Dec. 31, 2017 Bcf / d
Schedule of Equity Method Investments [Line Items]
Proceeds from sale of interest	$ 7,600
Lightfoot Capital Partners LP
Schedule of Equity Method Investments [Line Items]
Equity interest percentage		6.60%	6.60%
Lightfoot GP
Schedule of Equity Method Investments [Line Items]
Equity interest percentage		1.50%	1.50%
Lightfoot Capital Partners LP | Gulf LNG
Schedule of Equity Method Investments [Line Items]
Receiving and regasification terminal, volume per day (bcf/d) | Bcf / d			1.5
Arc Terminal Joliet Holdings
Schedule of Equity Method Investments [Line Items]
Required reinvestment	$ 1,200
Gulf LNG | Zenith
Schedule of Equity Method Investments [Line Items]
Interest acquired	4.16%
Payments to acquire	$ 27,300
Arc Terminal Joliet Holdings | Lightfoot LP and Lightfoot GP
Schedule of Equity Method Investments [Line Items]
Interest acquired	13.50%
Arc Logistics GP | Lightfoot GP
Schedule of Equity Method Investments [Line Items]
Equity issued (in dollars per unit) | $ / shares	$ 14.50
Proceeds from sale of interest	$ 94,500
Percentage of interest sold	100.00%
Gulf LNG | Lightfoot GP
Schedule of Equity Method Investments [Line Items]
Proceeds from sale of interest	$ 36,200	$ 667
Percentage of interest sold	5.52%
Realized loss on sale of investment		$ 1,100

XML

Fair Value - Joliet (Details) - USD ($)	Dec. 21, 2018	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other equity securities, at fair value		$ 0	$ 2,958,315
Zenith Terminal Joliet Holdings
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity interest percentage			0.60%
Sale of investment	$ 446,000

XML

Fair Value - Carrying and Fair Value Amounts (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Carrying Amount | Level 1
Financial Assets:
Cash and cash equivalents	$ 69,287,177	$ 15,787,069
Financial Liabilities:
Unsecured convertible senior notes	112,777,271	112,032,083
Carrying Amount | Level 2
Financial Liabilities:
Long-term debt	37,261,109	40,745,354
Carrying Amount | Level 3
Financial Assets:
Financing notes receivable	1,300,000	1,500,000
Fair Value | Level 1
Financial Assets:
Cash and cash equivalents	69,287,177	15,787,069
Financial Liabilities:
Unsecured convertible senior notes	119,378,982	139,101,660
Fair Value | Level 2
Financial Liabilities:
Long-term debt	37,261,109	40,745,354
Fair Value | Level 3
Financial Assets:
Financing notes receivable	$ 1,300,000	$ 1,500,000

XML

Debt - Schedule of Debt (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Jul. 08, 2015	Jul. 07, 2015	Jun. 29, 2015	Nov. 24, 2014
Debt Instrument [Line Items]
Amount Outstanding	$ 151,430,000	$ 155,000,000
Total	150,038,380	152,777,437
Debt due within one year	3,528,000	3,528,000
7.00% Unsecured Convertible Senior Notes
Debt Instrument [Line Items]
Unamortized discount	1,108,342	1,847,254
Line of Credit
Debt Instrument [Line Items]
Total Commitment or Original Principal			$ 153,000,000
Line of Credit | Revolving Credit Facility
Debt Instrument [Line Items]
Total Commitment or Original Principal			$ 105,000,000	$ 93,000,000
Line of Credit | Revolving Credit Facility | CorEnergy Revolver
Debt Instrument [Line Items]
Total Commitment or Original Principal	160,000,000
Quarterly Principal Payments	0
Amount Outstanding	$ 0	$ 0
Interest Rate, effective	5.25%	4.32%
Line of Credit | Revolving Credit Facility | MoGas Revolver
Debt Instrument [Line Items]
Total Commitment or Original Principal	$ 1,000,000					$ 3,000,000.0
Quarterly Principal Payments	0
Amount Outstanding	$ 0	$ 0
Interest Rate, effective	5.25%	4.32%
Line of Credit | Revolving Credit Facility | Omega Line of Credit
Debt Instrument [Line Items]
Total Commitment or Original Principal	$ 1,500,000
Quarterly Principal Payments	0
Amount Outstanding	$ 0	$ 0
Interest Rate, effective	6.50%	5.57%
Secured Debt
Debt Instrument [Line Items]
Deferred debt financing costs, net	$ 210,891	$ 254,646
Total	37,472,000
Secured Debt | Amended Pinedale Term Credit Facility
Debt Instrument [Line Items]
Total	37,472,000
Secured Debt | Term Loan | Amended Pinedale Term Credit Facility
Debt Instrument [Line Items]
Total Commitment or Original Principal	41,000,000
Quarterly Principal Payments	882,000
Amount Outstanding	$ 37,472,000	$ 41,000,000
Interest Rate, fixed	6.50%	6.50%
Convertible Debt
Debt Instrument [Line Items]
Deferred debt financing costs, net	$ 241,000
Unamortized discount	3,700,000
Convertible Debt | 7.00% Unsecured Convertible Senior Notes
Debt Instrument [Line Items]
Total Commitment or Original Principal	115,000,000				$ 115,000,000.0
Quarterly Principal Payments	0
Amount Outstanding	$ 113,958,000	$ 114,000,000
Interest Rate, fixed	7.00%	7.00%			7.00%
Convertible Debt and Line of Credit
Debt Instrument [Line Items]
Deferred debt financing costs, net	$ 283,278	$ 375,309

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Debt - CorEnergy Credit Facilities (Details) - USD ($)			12 Months Ended
	Jul. 28, 2017	Jul. 08, 2015	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jul. 07, 2015	Nov. 24, 2014
Line of Credit Facility [Line Items]
Borrowed against the revolver			$ 0	$ 10,000,000	$ 44,000,000
Long-term debt outstanding			150,038,380	152,777,437
Parent Company
Line of Credit Facility [Line Items]
Borrowed against the revolver			0	$ 10,000,000	$ 44,000,000
Line of Credit
Line of Credit Facility [Line Items]
Face amount		$ 153,000,000
Line of Credit | Revolving Credit Facility
Line of Credit Facility [Line Items]
Face amount		105,000,000				$ 93,000,000
Monthly principal periodic payment		900,000	1,600,000
Line of Credit | Amended and Restated CorEnergy Credit Facility
Line of Credit Facility [Line Items]
Face amount	$ 161,000,000
Borrowed against the revolver	$ 10,000,000
Debt instrument term	5 years
Remaining borrowing capacity			122,700,000
Line of Credit | Subsidiaries | Revolving Credit Facility
Line of Credit Facility [Line Items]
Face amount		3,000,000
Line of Credit | Parent Company | Term Loan
Line of Credit Facility [Line Items]
Face amount		$ 45,000,000
Line of Credit | Minimum | LIBOR | Amended and Restated CorEnergy Credit Facility
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.75%
Line of Credit | Maximum | LIBOR | Amended and Restated CorEnergy Credit Facility
Line of Credit Facility [Line Items]
Basis spread on variable rate	3.75%
CorEnergy Revolver | Line of Credit | Revolving Credit Facility
Line of Credit Facility [Line Items]
Face amount			160,000,000
Extinguishment of debt			44,000,000
CorEnergy Revolver | Line of Credit | Amended and Restated CorEnergy Credit Facility
Line of Credit Facility [Line Items]
Face amount	$ 160,000,000
MoGas Revolver | Line of Credit | Revolving Credit Facility
Line of Credit Facility [Line Items]
Face amount			1,000,000				$ 3,000,000.0
MoGas Revolver | Line of Credit | Amended and Restated CorEnergy Credit Facility
Line of Credit Facility [Line Items]
Face amount	1,000,000
Remaining borrowing capacity	1,000,000
Long-term debt outstanding			$ 0
CorEnergy Term Loan | Line of Credit | Revolving Credit Facility
Line of Credit Facility [Line Items]
Extinguishment of debt	$ 33,500,000

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Debt - Mowood/Omega Revolver/Pinedale Credit Facility (Details) - USD ($)							3 Months Ended	12 Months Ended
	Dec. 29, 2017	Mar. 30, 2016	Jul. 31, 2015	Jul. 08, 2015	Mar. 07, 2014	Dec. 20, 2012	Mar. 31, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jul. 07, 2015
Debt Instrument [Line Items]
Long-term debt outstanding								$ 150,038,380	$ 152,777,437
Secured credit facilities, net								37,261,109	40,745,354
Cash sweep provision distribution									4,400,000	$ 9,100,000
Total assets								624,883,180	$ 633,418,113
Line of Credit
Debt Instrument [Line Items]
Face amount				$ 153,000,000
Secured Debt
Debt Instrument [Line Items]
Long-term debt outstanding								37,472,000
Revolving Credit Facility | Line of Credit
Debt Instrument [Line Items]
Monthly principal periodic payment				900,000				1,600,000
Face amount				$ 105,000,000							$ 93,000,000
Revolving Credit Facility | Line of Credit | Mowood/Omega Revolver
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 1,500,000.0
Basis spread on variable rate			4.00%
Long-term debt outstanding								0
Pinedale LP | Secured Term Credit Facility | Secured Debt
Debt Instrument [Line Items]
Maximum borrowing capacity						$ 70,000,000
Basis spread on variable rate		1.00%
Monthly principal periodic payment					$ 294,000
Required principle payment as percentage of outstanding amount, beginning in year two					0.42%
Extension option, term						1 year
Periodic payment through extension period							$ 3,200,000
Secured credit facilities, net		$ 58,500,000
Pinedale LP | Secured Term Credit Facility | Secured Debt | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate						3.25%	4.25%
Pinedale LP | Secured Term Credit Facility | Secured Debt | LIBOR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate		7.00%
Pinedale LP | Amended Pinedale Term Credit Facility
Debt Instrument [Line Items]
Monthly principal periodic payment	$ 294,000
Debt instrument term	5 years
Face amount	$ 41,000,000.0
Coupon rate percentage	6.50%
Pinedale LGS
Debt Instrument [Line Items]
Total assets								$ 137,000,000
Pinedale LGS | General Partner | Pinedale GP
Debt Instrument [Line Items]
Controlling economic interest							81.05%
Value of economic interest		$ 47,400,000

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Debt - Amortization of Deferred Financing Costs (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Line of Credit | CorEnergy Credit Facility
Debt Instrument [Line Items]
Deferred debt issuance amortization		$ 1,600,000
Interest Expense | Line of Credit
Debt Instrument [Line Items]
Deferred debt issuance amortization	$ 627,269	873,993	$ 1,234,856
Interest Expense | Line of Credit | CorEnergy Credit Facility
Debt Instrument [Line Items]
Deferred debt issuance amortization	574,541	873,601	1,078,526
Interest Expense | Secured Debt | Amended Pinedale Term Credit Facility
Debt Instrument [Line Items]
Deferred debt issuance amortization	$ 52,728	$ 392	$ 156,330

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Debt - CorEnergy Credit Facilities/Amended Pinedale Term Credit Facility (Details) - USD ($)			3 Months Ended				12 Months Ended
	Dec. 29, 2017	Jul. 28, 2017	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Loss on extinguishment of debt			$ 102,500	$ 234,433	$ 0	$ 0	$ 0	$ 336,933	$ 0
Amended Pinedale Term Credit Facility
Line of Credit Facility [Line Items]
Loss on extinguishment of debt								103,000
Amended Pinedale Term Credit Facility | Pinedale LP
Line of Credit Facility [Line Items]
Deferred debt financing costs, net	$ 367,000
Deferred debt issuance amortization	$ 264,000
Debt instrument term	5 years
Line of Credit | CorEnergy Credit Facility
Line of Credit Facility [Line Items]
Deferred debt financing costs, net		$ 1,800,000	$ 1,300,000					1,300,000
Deferred debt issuance amortization								1,600,000
Line of Credit | Amended and Restated CorEnergy Credit Facility
Line of Credit Facility [Line Items]
Deferred debt issuance amortization								2,900,000
Debt instrument term		5 years
Loss on extinguishment of debt								$ 234,000

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Debt - Long Term Debt Maturities (Details) - USD ($)	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Total	$ 150,038,380	$ 152,777,437
Secured Debt
Debt Instrument [Line Items]
2019	3,528,000
2020	3,528,000
2021	3,528,000
2022	26,888,000
2023	0
Thereafter	0
Total	$ 37,472,000

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Debt - Convertible Debt Information (Details) - USD ($)			3 Months Ended				12 Months Ended
	May 23, 2016	Jun. 29, 2015	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Shares issued (in shares)							1,271
Principal amount							$ 42,000
Repurchases of convertible debt	$ 1,000,000						0	$ 0	$ 899,960
Gain on extinguishment of debt			$ (102,500)	$ (234,433)	$ 0	$ 0	0	(336,933)	$ 0
Convertible Senior Notes Due 2020
Debt Instrument [Line Items]
Amount of underwriter's discount			$ 1,847,254				1,108,342	1,847,254
Convertible Debt
Debt Instrument [Line Items]
Gain on extinguishment of debt								$ 72,000
Amount of underwriter's discount							3,700,000
Deferred debt financing costs, net							$ 241,000
Effective percentage							7.70%	7.70%	7.70%
Convertible Debt | Convertible Senior Notes Due 2020
Debt Instrument [Line Items]
Face amount		$ 115,000,000.0					$ 115,000,000
Interest Rate		7.00%	7.00%				7.00%	7.00%
Shares issued (in shares)		30.3030
Principal amount		$ 1,000
Conversion price (in dollars per share)		$ 33.00
Percentage of principal amount redeemed		100.00%
Convertible debt outstanding							$ 114,000,000

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Debt - Convertible Debt (Details) - Convertible Debt - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jun. 29, 2015
Debt Instrument [Line Items]
Interest expense	$ 8,766,306	$ 8,767,188	$ 8,800,842
Discount amortization	738,912	738,912	744,081
Deferred debt issuance amortization	48,276	48,276	48,566
Convertible Senior Notes Due 2020
Debt Instrument [Line Items]
Interest expense	$ 7,979,118	$ 7,980,000	$ 8,008,195
Interest Rate	7.00%	7.00%		7.00%

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Asset Retirement Obligation (Details) - USD ($)	3 Months Ended	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Decommissioning costs incurred	$ 939,000	$ 939,000
Estimated segment ARO liability	628,000	628,000
Loss on settlement of asset retirement obligation	311,000	310,941	$ 0	$ 0
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning asset retirement obligation		9,170,493	11,882,943
Liabilities assumed		0	0
ARO accretion expense		499,562	663,065
Liabilities settled		(628,300)	0
Revision in cash flow estimates		(1,085,412)	(3,375,515)
Ending asset retirement obligation	$ 7,956,343	$ 7,956,343	$ 9,170,493	$ 11,882,943

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Interest Rate Hedge Swaps - Additional Information (Details)	Mar. 31, 2016 USD ($) Instrument	Feb. 28, 2013 USD ($) Instrument
Interest Rate Swap
Derivative [Line Items]
Number of derivative agreements | Instrument		2
Notional amount	$ 26,300,000	$ 52,500,000
Fixed interest rate		0.865%
Number of instruments terminated | Instrument	1
Notional amount terminated	$ 26,300,000
Secured Debt
Derivative [Line Items]
Maximum borrowing capacity		$ 70,000,000

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Interest Rate Hedge Swaps - Derivative Financial Instruments (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Derivatives in Cash Flow Hedging Relationship
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (Loss) Gain on Derivatives Recognized in AOCI (Effective Portion)	$ 0	$ (300,181)
Amount of Loss on Derivatives Reclassified from AOCI (Effective Portion) Recognized in Net Income	0	(50,964)
Derivatives Not Designated as Hedging Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (Loss) Gain on Derivatives Recognized in AOCI (Effective Portion)	$ 25,842	$ 73,204

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Stockholder's Equity - Preferred Stock (Details) - USD ($)				12 Months Ended
	May 10, 2017	Apr. 18, 2017	Jan. 27, 2015	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Aug. 06, 2018
Class of Stock [Line Items]
Preferred stock, authorized (in shares)				10,000,000
Preferred stock, par value (in dollars per share)				$ 0.001
Repurchases of preferred stock				$ 4,275,553	$ 0	$ 0
Preferred stock, outstanding (in shares)				50,222.27
Series A Cumulative Redeemable Preferred Stock
Class of Stock [Line Items]
Preferred stock, authorized (in shares)				10,000,000	10,000,000
Preferred stock, par value (in dollars per share)				$ 0.001	$ 0.001
Preferred stock interest rate				7.375%	7.375%
Preferred stock, issued (in shares)			22,500	50,222	52,000
Net offering proceeds			$ (54,200,000)
Preferred Stock, Liquidation Preference (in dollars per share)				$ 2,500	$ 2,500
Preferred stock, outstanding (in shares)				50,222	52,000
Depositary Shares
Class of Stock [Line Items]
Preferred stock, par value (in dollars per share)				$ 50.222
Percent equivalent of preferred shares				1.00%
Dividends (in dollars per share)				$ 1.84375
Preferred Stock, Liquidation Preference (in dollars per share)				$ 25.00
Authorized amount of shares to be repurchased							$ 10,000,000
Repurchase of stock (in shares)				177,773
Repurchases of preferred stock				$ 4,300,000
Preferred stock, outstanding (in shares)				5,022,227
Preferred Stock | Series A Cumulative Redeemable Preferred Stock
Class of Stock [Line Items]
Preferred stock interest rate			7.375%	7.375%
Underwritten Public Offering | Depositary Shares
Class of Stock [Line Items]
Shares sold in offering (in shares)	150,000	2,800,000	2,250,000
Sale of stock (in dollars per share)	$ 25.00	$ 25.00
Proceeds from sale of stock				$ 71,200,000
Shares outstanding				5,200,000
Underwritten Public Offering | Preferred Stock
Class of Stock [Line Items]
Shares outstanding				52,000
Line of Credit | Revolving Credit Facility | CorEnergy Revolver
Class of Stock [Line Items]
Extinguishment of debt				$ 44,000,000

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Stockholder's Equity - Common Stock (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Class of Stock [Line Items]
Repurchases of common stock	$ 0	$ 0	$ 2,041,851
Capital stock non-convertible, shares issued (in shares)	11,960,225	11,915,830
Capital Stock
Class of Stock [Line Items]
Authorized amount of shares to be repurchased				$ 10,000,000
Repurchase of common stock (in shares)			90,613
Repurchases of common stock			$ 2,000,000

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Stockholder's Equity - Shelf Registration (Details) - USD ($)	Dec. 31, 2018	Oct. 30, 2018	Nov. 09, 2018
Class of Stock [Line Items]
Aggregate offering price of shelf registration			$ 600,000,000
Current availability	$ 600,000,000
Dividend Reinvestment Plan
Class of Stock [Line Items]
Reinvestment of distributions to stockholders (in shares)	10,927	1,000,000
Remaining availability (in shares)	989,073

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Earnings Per Share (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jun. 29, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income attributable to CorEnergy stockholders	$ 20,495,995	$ 7,697,324	$ 7,810,849	$ 7,707,708	$ 6,755,855	$ 9,177,284	$ 9,000,172	$ 7,669,478	$ 43,711,876	$ 32,602,790	$ 29,663,200
Less: preferred dividend requirements	2,357,752	2,396,875	2,396,875	2,396,875	2,396,875	2,396,875	2,123,129	1,037,109	9,548,377	7,953,988	4,148,437
Net Income attributable to Common Stockholders	$ 18,138,243	$ 5,300,449	$ 5,413,974	$ 5,310,833	$ 4,358,980	$ 6,780,409	$ 6,877,043	$ 6,632,369	$ 34,163,499	$ 24,648,802	$ 25,514,763
Weighted average shares - basic (in shares)									11,935,021	11,900,516	11,901,985
Basic earnings per share (in dollars per share)	$ 1.52	$ 0.44	$ 0.45	$ 0.45	$ 0.37	$ 0.57	$ 0.58	$ 0.56	$ 2.86	$ 2.07	$ 2.14
Net income attributable to common stockholders (from above)	$ 18,138,243	$ 5,300,449	$ 5,413,974	$ 5,310,833	$ 4,358,980	$ 6,780,409	$ 6,877,043	$ 6,632,369	$ 34,163,499	$ 24,648,802	$ 25,514,763
Add: After tax effect of convertible interest									8,766,306	0	0
Income attributable for dilutive securities									$ 42,929,805	$ 24,648,802	$ 25,514,763
Weighted average shares - diluted (in shares)									15,389,180	11,900,516	11,901,985
Diluted earnings per share (in dollars per share)	$ 1.32	$ 0.44	$ 0.45	$ 0.45	$ 0.37	$ 0.57	$ 0.58	$ 0.56	$ 2.79	$ 2.07	$ 2.14
Decrease in preferred dividends									$ 10,554
Convertible Debt | Convertible Senior Notes Due 2020
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Coupon rate percentage	7.00%				7.00%				7.00%	7.00%		7.00%
Shares issued upon conversion (in shares)	3,453,273				3,454,545				3,453,273	3,454,545	3,454,545

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Quarterly Financial Data (Unaudited) (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenue
Lease revenue	$ 18,487,661	$ 18,391,983	$ 18,275,859	$ 17,591,859	$ 17,513,510	$ 17,173,676	$ 17,050,092	$ 17,066,526	$ 72,747,362	$ 68,803,804	$ 67,994,130
Revenue									16,484,236
Total Revenue	22,900,039	22,636,705	22,150,016	21,544,838	22,402,085	22,444,304	21,825,872	22,077,116	89,231,598	88,749,377	89,250,586
Expenses
Transportation and distribution expenses	1,861,329	2,241,999	1,534,524	1,572,896	1,646,975	2,384,182	1,362,980	1,335,570	7,210,748	6,729,707	6,463,348
General and administrative	4,161,533	3,046,481	3,107,776	2,727,057	2,534,372	2,632,546	2,558,339	3,061,240	13,042,847	10,786,497	12,270,380
Depreciation, amortization and ARO accretion expense	6,078,582	6,289,459	6,290,082	6,289,330	6,018,143	6,017,664	6,005,995	6,005,908	24,947,453	24,047,710	22,522,871
Provision for loan (gain) loss	(536,867)	0	0	500,000					(36,867)	0	5,014,466
Total Expenses	11,564,577	11,577,939	10,932,382	11,089,283	10,199,490	11,034,392	9,927,314	10,402,718	45,164,181	41,563,914	46,271,065
Operating Income	11,335,462	11,058,766	11,217,634	10,455,555	12,202,595	11,409,912	11,898,558	11,674,398	44,067,417	47,185,463	42,979,521
Other Income (Expense)
Net distributions and dividend income	41,503	5,627	55,714	3,951	202,149	213,040	221,440	43,462	106,795	680,091	1,140,824
Net realized and unrealized gain (loss) on other equity securities	(48,028)	(930,147)	(881,100)	13,966	121,204	1,340,197	614,634	(544,208)	(1,845,309)	1,531,827	824,482
Interest expense	(3,168,583)	(3,183,589)	(3,196,248)	(3,210,590)	(2,793,245)	(2,928,036)	(3,202,837)	(3,454,397)	(12,759,010)	(12,378,514)	(14,417,839)
Gain on the sale of leased property, net	11,723,257	0	0	0					11,723,257	0	0
Loss on extinguishment of debt					(102,500)	(234,433)	0	0	0	(336,933)	0
Total Other Expense	8,548,149	(4,108,109)	(4,021,634)	(3,192,673)	(2,572,392)	(1,609,232)	(2,366,763)	(3,955,143)	(2,774,267)	(10,503,529)	(12,452,533)
Income before income taxes	19,883,611	6,950,657	7,196,000	7,262,882	9,630,203	9,800,680	9,531,795	7,719,255	41,293,150	36,681,934	30,526,988
Taxes
Current tax expense (benefit)	(530,659)	(8,393)	(10,785)	(35,549)	2,742,636	65,131	57,651	(33,760)	(585,386)	2,831,658	(313,107)
Deferred tax expense (benefit)	(81,725)	(738,274)	(604,064)	(409,277)	(352,018)	126,440	38,084	(298,846)	(1,833,340)	(486,340)	(151,313)
Income tax expense (benefit), net	(612,384)	(746,667)	(614,849)	(444,826)	2,390,618	191,571	95,735	(332,606)	(2,418,726)	2,345,318	(464,420)
Net Income					7,239,585	9,609,109	9,436,060	8,051,861	43,711,876	34,336,616	30,991,408
Less: Net Income attributable to non-controlling interest					483,730	431,825	435,888	382,383	0	1,733,826	1,328,208
Net Income attributable to CorEnergy Stockholders	20,495,995	7,697,324	7,810,849	7,707,708	6,755,855	9,177,284	9,000,172	7,669,478	43,711,876	32,602,790	29,663,200
Preferred dividend requirements	2,357,752	2,396,875	2,396,875	2,396,875	2,396,875	2,396,875	2,123,129	1,037,109	9,548,377	7,953,988	4,148,437
Net Income attributable to Common Stockholders	$ 18,138,243	$ 5,300,449	$ 5,413,974	$ 5,310,833	$ 4,358,980	$ 6,780,409	$ 6,877,043	$ 6,632,369	$ 34,163,499	$ 24,648,802	$ 25,514,763
Earnings Per Common Share:
Basic (in dollars per share)	$ 1.52	$ 0.44	$ 0.45	$ 0.45	$ 0.37	$ 0.57	$ 0.58	$ 0.56	$ 2.86	$ 2.07	$ 2.14
Diluted (in dollars per share)	$ 1.32	$ 0.44	$ 0.45	$ 0.45	$ 0.37	$ 0.57	$ 0.58	$ 0.56	$ 2.79	$ 2.07	$ 2.14
Transportation and distribution revenue
Revenue
Revenue	$ 4,412,378	$ 4,244,722	$ 3,874,157	$ 3,952,979	$ 4,888,575	$ 5,270,628	$ 4,775,780	$ 5,010,590	$ 16,484,236	$ 19,945,573	$ 21,094,112

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Subsequent Events (Details) - USD ($)						3 Months Ended					12 Months Ended
	Jan. 23, 2019	Jan. 16, 2019	Jan. 09, 2019	May 23, 2016	Jan. 27, 2015	Mar. 31, 2019	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Subsequent Event [Line Items]
Repurchases of preferred stock											$ 4,275,553	$ 0	$ 0
Preferred stock, outstanding (in shares)											50,222.27
Face amount											$ 42,000
Shares issued (in shares)											1,271
Common stock, par value (in dollars per share)							$ 0.001				$ 0.001	$ 0.001
Repurchases of convertible debt				$ 1,000,000							$ 0	$ 0	899,960
Loss on extinguishment of debt							$ 102,500	$ 234,433	$ 0	$ 0	$ 0	$ 336,933	$ 0
Dividends declared per share (in dollars per share)											$ 3.000	$ 3.000	$ 3.000
Subsequent event
Subsequent Event [Line Items]
Face amount		$ 43,800,000
Shares issued (in shares)		837,040
Repurchases of convertible debt		$ 19,800,000
Convertible debt outstanding		$ 70,200,000
Capital Stock
Subsequent Event [Line Items]
Repurchase of stock (in shares)													90,613
Capital Stock | Subsequent event
Subsequent Event [Line Items]
Dividends declared per share (in dollars per share)	$ 0.750
Depositary Shares
Subsequent Event [Line Items]
Repurchase of stock (in shares)											177,773
Repurchases of preferred stock											$ 4,300,000
Preferred stock, outstanding (in shares)											5,022,227
Series A Cumulative Redeemable Preferred Stock
Subsequent Event [Line Items]
Preferred stock, outstanding (in shares)							52,000				50,222	52,000
Coupon rate percentage											7.375%	7.375%
Series A Cumulative Redeemable Preferred Stock | Depositary Shares | Subsequent event
Subsequent Event [Line Items]
Repurchase of stock (in shares)			2,500
Repurchases of preferred stock			$ 61,000
Preferred stock, outstanding (in shares)			5,019,727
Depositary stock, dividends declared per share (in dollars per share)	$ 0.4609375
Series A Cumulative Redeemable Preferred Stock | Preferred Stock
Subsequent Event [Line Items]
Coupon rate percentage					7.375%						7.375%
Series A Cumulative Redeemable Preferred Stock | Preferred Stock | Subsequent event
Subsequent Event [Line Items]
Preferred stock, outstanding (in shares)			50,197.27
Forecast
Subsequent Event [Line Items]
Loss on extinguishment of debt						$ 5,000,000

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - Balance Sheet (Details) - USD ($)	Dec. 31, 2018	Jan. 01, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Assets
Leased property, net of accumulated depreciation of $1,112,218 and $927,838	$ 398,214,355		$ 465,956,467
Cash and cash equivalents	69,287,177		15,787,069	$ 7,895,084	$ 14,618,740
Deferred costs, net of accumulated amortization of $712,182 and $226,342	2,838,443		3,504,916
Prepaid expenses and other assets	668,584		742,154
Total Assets	624,883,180		633,418,113
Liabilities and Equity
Unsecured convertible senior notes, net of discount and debt issuance costs of $1,180,729 and $1,967,917	112,777,271		112,032,083
Accounts payable and other accrued liabilities	3,493,490		2,333,782
Management fees payable	1,831,613		1,748,426
Total Liabilities	169,871,875		171,632,481
Equity
Series A Cumulative Redeemable Preferred Stock 7.375%, $125,555,675 and $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 50,222 and 52,000 issued and outstanding at December 31, 2018 and December 31, 2017, respectively	125,555,675		130,000,000
Capital stock, non-convertible, $0.001 par value; 11,960,225 and $11,915,830 shares issued and outstanding at December 31, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,960		11,916
Additional paid-in capital	320,295,969	$ 329,324,471	331,773,716
Retained earnings	9,147,701		0
Total Liabilities and Equity	624,883,180		633,418,113
Parent Company
Assets
Leased property, net of accumulated depreciation of $1,112,218 and $927,838	3,681,438		3,865,818
Investments	415,674,601		479,840,250
Cash and cash equivalents	64,574,701		6,662,474	$ 5,933,481	$ 10,089,436
Due from subsidiary	10,549,719		7,302,678
Note receivable from subsidiary	81,000,000		83,250,000
Deferred costs, net of accumulated amortization of $712,182 and $226,342	1,769,585		2,255,425
Prepaid expenses and other assets	265,024		197,211
Total Assets	577,515,068		583,373,856
Liabilities and Equity
Unsecured convertible senior notes, net of discount and debt issuance costs of $1,180,729 and $1,967,917	112,777,271		112,032,083
Accounts payable and other accrued liabilities	1,075,045		987,881
Management fees payable	1,831,613		1,748,426
Due to affiliate	153,640		153,640
Total Liabilities	115,837,569		114,922,030
Equity
Series A Cumulative Redeemable Preferred Stock 7.375%, $125,555,675 and $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 50,222 and 52,000 issued and outstanding at December 31, 2018 and December 31, 2017, respectively	125,555,675		130,000,000
Capital stock, non-convertible, $0.001 par value; 11,960,225 and $11,915,830 shares issued and outstanding at December 31, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,960		11,916
Additional paid-in capital	326,962,163		338,439,910
Retained earnings	9,147,701		0
Total Equity	461,677,499		468,451,826
Total Liabilities and Equity	$ 577,515,068		$ 583,373,856

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - Balance Sheet Parenthetical (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Jan. 27, 2015
Condensed Balance Sheet Statements, Captions [Line Items]
Accumulated depreciation, leased property	$ 87,154,095	$ 72,155,753
Accumulated amortization, Deferred costs	$ 1,290,236	$ 623,764
Preferred stock, par value (in dollars per share)	$ 0.001
Preferred Stock, Shares Authorized	10,000,000
Preferred stock, outstanding (in shares)	50,222.27
Capital stock non-convertible, par value (in dollars per share)	$ 0.001	$ 0.001
Capital stock non-convertible, shares issued (in shares)	11,960,225	11,915,830
Capital stock non-convertible, shares outstanding	11,960,225	11,915,830
Capital stock non-convertible, shares authorized	100,000,000	100,000,000
Convertible Debt
Condensed Balance Sheet Statements, Captions [Line Items]
Net of discount and debt issuance costs	$ 1,180,729	$ 1,967,917
Series A Cumulative Redeemable Preferred Stock
Condensed Balance Sheet Statements, Captions [Line Items]
Preferred stock interest rate	7.375%	7.375%
Preferred Stock, Liquidation Preference	$ 125,555,675	$ 130,000,000
Preferred Stock, Liquidation Preference (in dollars per share)	$ 2,500	$ 2,500
Preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Preferred Stock, Shares Authorized	10,000,000	10,000,000
Preferred Stock, Shares Issued	50,222	52,000	22,500
Preferred stock, outstanding (in shares)	50,222	52,000
Parent Company
Condensed Balance Sheet Statements, Captions [Line Items]
Accumulated depreciation, leased property	$ 1,112,218	$ 927,838
Accumulated amortization, Deferred costs	$ 712,182	$ 226,342
Capital stock non-convertible, par value (in dollars per share)	$ 0.001	$ 0.001
Capital stock non-convertible, shares issued (in shares)	11,960,225	11,915,830
Capital stock non-convertible, shares outstanding	11,960,225	11,915,830
Capital stock non-convertible, shares authorized	100,000,000	100,000,000
Parent Company | Convertible Debt
Condensed Balance Sheet Statements, Captions [Line Items]
Net of discount and debt issuance costs	$ 1,180,729	$ 1,967,917
Parent Company | Series A Cumulative Redeemable Preferred Stock
Condensed Balance Sheet Statements, Captions [Line Items]
Preferred stock interest rate	7.375%
Preferred Stock, Liquidation Preference	$ 125,555,675	$ 130,000,000
Preferred Stock, Liquidation Preference (in dollars per share)	$ 2,500	$ 2,500
Preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Preferred Stock, Shares Authorized	10,000,000	10,000,000
Preferred Stock, Shares Issued	50,222	52,000
Preferred stock, outstanding (in shares)	50,222	52,000

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - Income and Comprehensive Income (Details) - USD ($)	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Revenue
Total Revenue	$ 22,900,039	$ 22,636,705	$ 22,150,016	$ 21,544,838	$ 22,402,085	$ 22,444,304	$ 21,825,872	$ 22,077,116	$ 89,231,598	$ 88,749,377	$ 89,250,586
Expenses
General and administrative	4,161,533	3,046,481	3,107,776	2,727,057	2,534,372	2,632,546	2,558,339	3,061,240	13,042,847	10,786,497	12,270,380
Depreciation expense									3,400,000	3,400,000	3,400,000
Total Expenses	11,564,577	11,577,939	10,932,382	11,089,283	10,199,490	11,034,392	9,927,314	10,402,718	45,164,181	41,563,914	46,271,065
Operating Income	11,335,462	11,058,766	11,217,634	10,455,555	12,202,595	11,409,912	11,898,558	11,674,398	44,067,417	47,185,463	42,979,521
Other Income (Expense)
Net distributions and dividend income	41,503	5,627	55,714	3,951	202,149	213,040	221,440	43,462	106,795	680,091	1,140,824
Loss on extinguishment of debt					(102,500)	(234,433)	0	0	0	(336,933)	0
Total Other Expense	8,548,149	(4,108,109)	(4,021,634)	(3,192,673)	(2,572,392)	(1,609,232)	(2,366,763)	(3,955,143)	(2,774,267)	(10,503,529)	(12,452,533)
Net Income attributable to CorEnergy Stockholders	$ 20,495,995	$ 7,697,324	$ 7,810,849	$ 7,707,708	$ 6,755,855	$ 9,177,284	$ 9,000,172	$ 7,669,478	43,711,876	32,602,790	29,663,200
Changes in fair value of qualifying hedges									0	11,196	(201,993)
Net Change in Other Comprehensive Income (Loss)									0	13,813	(249,219)
Parent Company
Revenue
Earnings from subsidiary									48,353,177	36,222,221	32,856,338
Total Revenue									48,353,177	36,222,221	32,856,338
Expenses
General and administrative									2,353,593	2,298,201	2,236,358
Depreciation expense									184,380	184,380	184,380
Amortization expense									5,316	5,316	5,316
Total Expenses									2,543,289	2,487,897	2,426,054
Operating Income									45,809,888	33,734,324	30,430,284
Other Income (Expense)
Net distributions and dividend income									56,827	96,866	12,963
Interest on loans to subsidiaries									7,903,104	11,549,344	11,705,465
Interest expense, net									(10,057,943)	(11,451,944)	(12,485,510)
Loss on extinguishment of debt									0	(225,801)	0
Total Other Expense									(2,098,012)	(31,535)	(767,082)
Net Income attributable to CorEnergy Stockholders									43,711,876	33,702,789	29,663,202
Changes in fair value of qualifying hedges									0	11,196	(201,993)
Net Change in Other Comprehensive Income (Loss)									$ 43,711,876	$ 33,713,985	$ 29,461,209

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - Cash Flows (Details) - USD ($)			12 Months Ended
	Dec. 12, 2018	May 23, 2016	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities			$ 48,622,740	$ 56,791,571	$ 51,108,652
Investing Activities
Issuance of note to subsidiary			0	0	(202,000)
Principal payments received from notes to subsidiaries	$ 237,000		236,867	0	0
Net cash provided by investing activities			56,816,490	7,595,477	479,090
Financing Activities
Debt financing costs			(264,010)	(1,462,741)	(193,000)
Net offering proceeds on Series A preferred stock			0	71,161,531	0
Repurchases of common stock			0	0	(2,041,851)
Repurchases of convertible debt		$ (1,000,000)	0	0	(899,960)
Repurchases of Series A preferred stock			(4,275,553)	0	0
Dividends paid on Series A preferred stock			(9,587,500)	(8,227,734)	(4,148,437)
Dividends paid on common stock			(34,284,059)	(34,731,892)	(34,896,727)
Advances on revolving line of credit			0	10,000,000	44,000,000
Payments on revolving line of credit			0	(54,000,000)	0
Principal payments on term debt			(3,528,000)	(45,600,577)	(60,131,423)
Net cash used in financing activities			(51,939,122)	(56,495,063)	(58,311,398)
Net Change in Cash and Cash Equivalents			53,500,108	7,891,985	(6,723,656)
Cash and Cash Equivalents at beginning of period			15,787,069	7,895,084	14,618,740
Cash and Cash Equivalents at end of period			69,287,177	15,787,069	7,895,084
Supplemental Disclosure of Cash Flow Information
Interest Paid			11,200,835	10,780,150	12,900,901
Non-Cash Investing Activities
Conversion of note receivable from subsidiary to investments			42,000
Non-Cash Financing Activities
Common stock issued upon conversion of convertible notes			42,654	0	0
Reinvestment of distributions by common stockholders in additional common shares			1,509,830	962,308	815,889
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities			(6,257,124)	1,661,123	(3,141,286)
Investing Activities
Issuance of note to subsidiary			0	0	(47,414,250)
Principal payments received from notes to subsidiaries			2,250,000	40,092,095	11,899,659
Investment in consolidated subsidiaries			(73,996)	(33,900,000)	0
Cash distributions from consolidated subsidiaries			110,140,459	46,774,111	39,139,897
Net cash provided by investing activities			112,316,463	52,966,206	3,625,306
Financing Activities
Debt financing costs			0	(1,360,241)	(193,000)
Net offering proceeds on Series A preferred stock			0	71,161,531	0
Repurchases of common stock			0	0	(2,041,851)
Repurchases of convertible debt			0	0	(899,960)
Repurchases of Series A preferred stock			(4,275,553)	0	0
Dividends paid on Series A preferred stock			(9,587,500)	(8,227,734)	(4,148,437)
Dividends paid on common stock			(34,284,059)	(34,731,892)	(34,896,727)
Advances on revolving line of credit			0	10,000,000	44,000,000
Payments on revolving line of credit			0	(54,000,000)	0
Principal payments on term debt			0	(36,740,000)	(6,460,000)
Net cash used in financing activities			(48,147,112)	(53,898,336)	(4,639,975)
Net Change in Cash and Cash Equivalents			57,912,227	728,993	(4,155,955)
Cash and Cash Equivalents at beginning of period			6,662,474	5,933,481	10,089,436
Cash and Cash Equivalents at end of period			64,574,701	6,662,474	5,933,481
Supplemental Disclosure of Cash Flow Information
Interest Paid			8,794,086	10,080,764	11,335,654
Non-Cash Investing Activities
Conversion of note receivable from subsidiary to investments			0	4,902,495	0
Dissolution of investment in subsidiary upon liquidation			(73,996)	0	0
Non-Cash Financing Activities
Common stock issued upon conversion of convertible notes			42,654	0	0
Reinvestment of distributions by common stockholders in additional common shares			$ 1,509,830	$ 962,308	$ 815,889

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SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF REGISTRANT - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Parent Company
Condensed Financial Statements, Captions [Line Items]
Cash dividends paid	$ 110,140,459	$ 46,774,111	$ 39,139,897

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SCHEDULE III - REAL ESTATE AND ACCUMULATED DEPRECIATION (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	$ 37,472,000
Initial Cost to Company, Land	106,655,063
Initial Cost to Company, Building & Fixtures	384,778,459
Cost Capitalized Subsequent to Acquisition, Improvements	(6,065,072)
Gross Amount Carried at Close of Period, Land	106,655,063
Gross Amount Carried at Close of Period, Building & Fixtures	378,713,387
Gross Amount Carried at Close of Period, Total	485,368,450	$ 538,112,220	$ 541,478,086	$ 543,095,478
Accumulated Depreciation	87,154,095	$ 72,155,753	$ 52,219,717	$ 33,869,263
Investment in Real Estate, net	398,214,355
Pinedale LGS
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	37,472,000
Initial Cost to Company, Land	105,485,063
Initial Cost to Company, Building & Fixtures	125,119,062
Cost Capitalized Subsequent to Acquisition, Improvements	0
Gross Amount Carried at Close of Period, Land	105,485,063
Gross Amount Carried at Close of Period, Building & Fixtures	125,119,062
Gross Amount Carried at Close of Period, Total	230,604,125
Accumulated Depreciation	53,501,538
Investment in Real Estate, net	$ 177,102,587
Life on which depreciation in latest income statement is computed	26 years
United Property Systems
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	$ 0
Initial Cost to Company, Land	210,000
Initial Cost to Company, Building & Fixtures	1,188,000
Cost Capitalized Subsequent to Acquisition, Improvements	78,621
Gross Amount Carried at Close of Period, Land	210,000
Gross Amount Carried at Close of Period, Building & Fixtures	1,266,621
Gross Amount Carried at Close of Period, Total	1,476,621
Accumulated Depreciation	138,096
Investment in Real Estate, net	$ 1,338,525
Life on which depreciation in latest income statement is computed	40 years
Grand Isle Gathering System
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	$ 0
Initial Cost to Company, Land	960,000
Initial Cost to Company, Building & Fixtures	258,471,397
Cost Capitalized Subsequent to Acquisition, Improvements	(6,143,693)
Gross Amount Carried at Close of Period, Land	960,000
Gross Amount Carried at Close of Period, Building & Fixtures	252,327,704
Gross Amount Carried at Close of Period, Total	253,287,704
Accumulated Depreciation	33,514,461
Investment in Real Estate, net	$ 219,773,243
Life on which depreciation in latest income statement is computed	27 years

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SCHEDULE III - REAL ESTATE AND ACCUMULATED DEPRECIATION - Additional Information (Details)	12 Months Ended
	Dec. 31, 2018 USD ($) property	Dec. 21, 2018 USD ($)	Dec. 31, 2017 USD ($)
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Long-term debt outstanding	$ 150,038,380		$ 152,777,437
Property investment, accumualated depreciation	87,154,095		$ 72,155,753
Federal income tax basis	4,200,000
Pinedale LGS
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Acquisition costs	2,557,910
Portland Terminal Facility
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Property investment		$ 45,700,000
Property investment, gross		51,700,000
Property investment, accumualated depreciation		$ 6,000,000
Grand Isle Gathering System
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Acquisition costs	$ 1,931,396
Line of Credit | CorEnergy Credit Facility
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Number of properties serving as collateral | property	2
Long-term debt outstanding	$ 0
Secured Debt
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Long-term debt outstanding	37,472,000
Secured Debt | Amended Pinedale Term Credit Facility
SEC Schedule, 12-28, Real Estate Companies, Investment in Real Estate and Accumulated Depreciation [Line Items]
Long-term debt outstanding	$ 37,472,000

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SCHEDULE III - REAL ESTATE AND ACCUMULATED DEPRECIATION - Reconciliation of Real Estate (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Investment in real estate:
Balance, beginning of year	$ 538,112,220	$ 541,478,086	$ 543,095,478
Addition: Acquisitions and developments	3,599	9,649	65,371
Deduction: Dispositions and other	(52,747,369)	(3,375,515)	(1,682,763)
Balance, end of year	485,368,450	538,112,220	541,478,086
Accumulated depreciation:
Balance, beginning of year	72,155,753	52,219,717	33,869,263
Addition: Depreciation	20,986,461	19,936,036	18,350,454
Deduction: Dispositions and other	(5,988,119)	0	0
Balance, end of year	$ 87,154,095	$ 72,155,753	$ 52,219,717

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SCHEDULE IV - MORTGAGE LOANS ON REAL ESTATE - Mortgage Loans On Real Estate (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Face Value	$ 1,300,000
Carrying Amount of Mortgage	1,300,000	$ 1,500,000	$ 1,500,000	$ 6,877,021
Principal Amount of Loans Subject to Delinquent Principal or Interest	$ 0
Billings, Dunn and McKenzie Counties, North Dakota (Morlock Well) | First Mortgages
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Interest Rate	8.52%
Monthly Payment Amount	$ 0
Face Value	1,300,000
Carrying Amount of Mortgage	1,300,000
Principal Amount of Loans Subject to Delinquent Principal or Interest	$ 0

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SCHEDULE IV - MORTGAGE LOANS ON REAL ESTATE - Reconciliation of Mortgage Loans (Details) - USD ($)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
SEC Schedule, 12-29, Real Estate Companies, Investment in Movement in Mortgage Loans on Real Estate [Roll Forward]
Beginning balance	$ 1,500,000	$ 1,500,000	$ 6,877,021
Additions:
New loans	0	0	100,000
Interest receivable	0	0	(95,114)
Total Additions	0	0	4,886
Deductions:
Principal repayments	236,867	0	0
Foreclosures	0	0	1,857,000
Amortization of deferred costs	0	0	(2,025)
Principal, Interest and Deferred Costs Write Down	(36,867)	0	3,526,932
Total deductions	200,000	0	5,381,907
Ending balance	$ 1,300,000	$ 1,500,000	$ 1,500,000

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SCHEDULE IV - MORTGAGE LOANS ON REAL ESTATE - Additional Information (Details) - USD ($)		3 Months Ended				12 Months Ended
	Dec. 12, 2018	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Principal payment on financing note receivable	$ 237,000					$ 236,867	$ 0	$ 0
Provision for loan (gain) loss		$ 536,867	$ 0	$ 0	$ (500,000)	36,867	0	(5,014,466)
Not Related Mortgage Loans
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Provision for loan (gain) loss								(656,000)
Foreclosure and Sale of Black Bison
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Provision for loan (gain) loss								(832,000)
SWD Enterprise REIT Note
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Interest receivable converted to principal								100,000
Compass REIT Loan
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Maximum borrowing capacity	$ 1,300,000
SWD Enterprises
SEC Schedule, 12-29, Real Estate Companies, Investment in Mortgage Loans on Real Estate [Line Items]
Maximum borrowing capacity							$ 1,500,000
Provision for loan (gain) loss					$ (500,000)	$ 37,000		$ (3,500,000)