UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

___________________________________________

FORM 10-Q

 ___________________________________________

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

For the quarterly period ended June 30, 2018

OR

o 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

_________________________________________________________

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)

n/a

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

___________________________________________

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  x    No   o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).     Yes  x    Noo

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. (Check one):

Large accelerated filer	o	Accelerated filer	x
Non-accelerated filer	o (Do not check if a smaller reporting company)	Smaller reporting company	o
		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   o   No  x

As of August 1, 2018, the registrant had 11,934,575 common shares outstanding.

CorEnergy Infrastructure Trust, Inc.

FORM 10-Q

FOR THE QUARTER ENDED JUNE 30, 2018

TABLE OF CONTENTS

____________________________________________________________________________________________

				Page No.
Glossary of Defined Terms				4
Forward-Looking Statements				7
PART I		FINANCIAL INFORMATION		9
	Item 1.	Financial Statements (unaudited)		9
		Consolidated Balance Sheets		9
		Consolidated Statements of Income and Comprehensive Income		10
		Consolidated Statement of Equity		11
		Consolidated Statements of Cash Flows		12
		Notes to Consolidated Financial Statements		13
		1.	Introduction and Basis of Presentation	13
		2.	Recent Accounting Pronouncements	13
		3.	Leased Properties and Leases	14
		4.	Transportation and Distribution Revenue	16
		5.	Financing Notes Receivable	18
		6.	Income Taxes	19
		7.	Property and Equipment	20
		8.	Management Agreement	20
		9.	Fair Value	20
		10.	Debt	23
		11.	Stockholders' Equity	25
		12.	Earnings Per Share	26
		13.	Subsequent Events	26
	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		27
	Item 3.	Quantitative and Qualitative Disclosures about Market Risk		41
	Item 4.	Controls and Procedures		41
PART II.		OTHER INFORMATION		42
	Item 1.	Legal Proceedings		42
	Item 1A.	Risk Factors		42
	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		42
	Item 3.	Defaults Upon Senior Securities		42
	Item 4.	Mine Safety Disclosures		42
	Item 5.	Other Information		42
	Item 6.	Exhibits		42
Signatures				43

This Report on Form 10-Q ("Report") should be read in its entirety. No one section of the Report deals with all aspects of the subject matter. It should be read in conjunction with the consolidated financial statements, related notes, and with the Management's Discussion & Analysis ("MD&A") included within, as well as provided in the Annual Report on Form 10-K, for the year ended December 31, 2017.

2

The consolidated unaudited financial statements have been prepared in accordance with generally accepted accounting principles for interim financial information, the instructions to Form 10-Q, and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and notes required by generally accepted accounting principles for complete financial statements. In the opinion of Management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the three and six months ended June 30, 2018 are not necessarily indicative of the results that may be expected for the year ended December 31, 2018 or for any other interim or annual period. For further information, refer to the consolidated financial statements and footnotes thereto included in the CorEnergy Infrastructure Trust, Inc. Annual Report on Form 10-K, for the year ended December 31, 2017.

3

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.

Arc Logistics: Arc Logistics Partners LP, a wholly-owned subsidiary of Zenith Energy U.S., LP.

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.

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

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

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 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.

CPI: Consumer Price Index.

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

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. Throughout this document, references to EGC will refer to both the pre- and post-bankruptcy entities.

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.

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.

4

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

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.

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

Management Agreement: an 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, an indirect wholly-owned subsidiary of CorEnergy and the holding company of Omega Pipeline Company, LLC.

Mowood/Omega Revolver: a $1.5 million 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.

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

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 noncontrolling equity interest in Pinedale LGS from Prudential on December 29, 2017.

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 is triple-net leased to Zenith Terminals.

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

Prudential: the Prudential Insurance Company of America.

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 52,000 shares represented by 5,200,000 depositary shares, each representing 1/100th of a whole share of Series A Preferred.

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

5

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

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.

Zenith: Zenith Energy U.S., LP.

Zenith Terminals: Zenith Energy Terminal 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

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

Certain statements included or incorporated by reference in this Quarterly Report on Form 10-Q 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," "goals," "objectives," "targets," "predicts," "plans," "seeks," or similar expressions.

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. You should also understand that it is not possible to predict or identify all such factors and should not consider the following list to be a complete statement of all potential risks and uncertainties. Factors that could cause our actual results to differ materially from the results contemplated by such forward-looking statements include:

• the ability of our tenants and borrowers to make payments under their respective leases and mortgage loans, our reliance on certain major tenants under single tenant leases and our ability to re-lease properties;

• changes in economic and business conditions in the energy infrastructure sector where our investments are concentrated, including the financial condition of our tenants or borrowers and general economic conditions in the particular sectors of the energy industry served by each of our infrastructure assets;

• the inherent risks associated with owning real estate, including real estate market conditions, governing laws and regulations, including potential liabilities related to environmental matters, and the relative illiquidity of real estate investments;

• risks associated with the bankruptcy or default of any of our tenants or borrowers, including the exercise of the rights and remedies of bankrupt entities;

• the impact of laws and governmental regulations applicable to certain of our infrastructure assets, including additional costs imposed on our business or other adverse impacts as a result of any unfavorable changes in such laws or regulations;

• the potential impact of greenhouse gas regulation and climate change on our or our tenants' business, financial condition and results of operations;

• the loss of any member of our management team;

• our continued ability to access the debt and equity markets;

• our ability to successfully implement our selective acquisition strategy;

• our ability to obtain suitable tenants for our properties;

• our ability to refinance amounts outstanding under our credit facilities and our convertible notes at maturity on terms favorable to us;

• changes in interest rates under our current credit facilities and under any additional variable rate debt arrangements that we may enter into in the future;

• our ability to comply with certain debt covenants;

• dependence by us and our tenants on key customers for significant revenues, and the risk of defaults by any such tenants or customers;

• the risk of adverse impacts to our results of operations if the tenant exercises its early lease termination or lease buy-out options at our Portland Terminal Facility;

• our or our tenants' ability to secure adequate insurance and risk of potential uninsured losses, including from natural disasters;

• the continued availability of third-party pipelines, railroads or other facilities interconnected with certain of our infrastructure assets;

• risks associated with owning, operating or financing properties for which the tenants', mortgagors' or our operations may be impacted by extreme weather patterns and other natural phenomena;

• our ability to sell properties at an attractive price;

• market conditions and related price volatility affecting our debt and equity securities;

• competitive and regulatory pressures on the revenues of our interstate natural gas transmission business;

• changes in federal or state tax rules or regulations that could have adverse tax consequences;

• declines in the market value of our investment securities;

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Table of Contents Glossary of Defined Terms

• our ability to maintain internal controls and processes to ensure all transactions are accounted for properly, all relevant disclosures and filings are timely made in accordance with all rules and regulations, and any potential fraud or embezzlement is thwarted or detected;

• changes in federal income tax regulations (and applicable interpretations thereof), or in the composition or performance of our assets, that could impact our ability to continue to qualify as a real estate investment trust for federal income tax purposes; and

• risks related to potential terrorist attacks, acts of cyber-terrorism, or similar disruptions that could disrupt access to our information technology systems or result in other significant damage to our business and properties, some of which may not be covered by insurance and all of which could adversely impact distributions to our stockholders.

Forward-looking statements speak only as of the date on which they are made. While we may update these statements from time to time, we are not required to do so other than pursuant to applicable laws. For a further discussion of these and other factors that could impact our future results and performance, see Part I, Item 1A, "Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2017, filed with the SEC on February 28, 2018, and Part II, Item 1A, "Risk Factors", in this Report.

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Table of Contents Glossary of Defined Terms

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED BALANCE SHEETS

	June 30, 2018		December 31, 2017
Assets	(Unaudited)
Leased property, net of accumulated depreciation of $82,749,089 and $72,155,753	$	455,363,130	$	465,956,467
Property and equipment, net of accumulated depreciation of $14,312,665 and $12,643,636	111,514,726		113,158,872
Financing notes and related accrued interest receivable, net of reserve of $4,600,000 and $4,100,000	1,000,000		1,500,000
Other equity securities, at fair value	2,091,181		2,958,315
Cash and cash equivalents	14,175,860		15,787,069
Deferred rent receivable	25,769,989		22,060,787
Accounts and other receivables	3,373,602		3,786,036
Deferred costs, net of accumulated amortization of $956,999 and $623,764	3,171,680		3,504,916
Prepaid expenses and other assets	1,068,526		742,154
Deferred tax asset, net	4,115,834		2,244,629
Goodwill	1,718,868		1,718,868
Total Assets	$	623,363,396	$	633,418,113
Liabilities and Equity
Secured credit facilities, net of debt issuance costs of $237,302 and $254,646	$	38,998,698	$	40,745,354
Unsecured convertible senior notes, net of discount and debt issuance costs of $1,574,323 and $1,967,917	112,425,677		112,032,083
Asset retirement obligation	9,426,350		9,170,493
Accounts payable and other accrued liabilities	2,512,598		2,333,782
Management fees payable	1,814,105		1,748,426
Income tax liability	36,971		2,204,626
Unearned revenue	5,321,069		3,397,717
Total Liabilities	$	170,535,468	$	171,632,481
Equity
Series A Cumulative Redeemable Preferred Stock 7.375%, $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 52,000 issued and outstanding at June 30, 2018 and December 31, 2017	$	130,000,000	$	130,000,000
Capital stock, non-convertible, $0.001 par value; 11,933,774 and 11,915,830 shares issued and outstanding at June 30, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,934		11,916
Additional paid-in capital	322,815,994		331,773,716
Total Equity	452,827,928		461,785,632
Total Liabilities and Equity	$	623,363,396	$	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 (Unaudited)

	For the Three Months Ended						For the Six Months Ended
	June 30, 2018			June 30, 2017			June 30, 2018			June 30, 2017
Revenue
Lease revenue	$	18,275,859		$	17,050,092		$	35,867,718		$	34,116,618
Transportation and distribution revenue	3,874,157			4,775,780			7,827,136			9,786,370
Total Revenue	22,150,016			21,825,872			43,694,854			43,902,988
Expenses
Transportation and distribution expenses	1,534,524			1,362,980			3,107,420			2,698,550
General and administrative	3,107,776			2,558,339			5,834,833			5,619,579
Depreciation, amortization and ARO accretion expense	6,290,082			6,005,995			12,579,412			12,011,903
Provision for loan losses	—			—			500,000			—
Total Expenses	10,932,382			9,927,314			22,021,665			20,330,032
Operating Income	$	11,217,634		$	11,898,558		$	21,673,189		$	23,572,956
Other Income (Expense)
Net distributions and dividend income	$	55,714		$	221,440		$	59,665		$	264,902
Net realized and unrealized gain (loss) on other equity securities	(881,100		)	614,634			(867,134		)	70,426
Interest expense	(3,196,248		)	(3,202,837		)	(6,406,838		)	(6,657,234		)
Total Other Expense	(4,021,634		)	(2,366,763		)	(7,214,307		)	(6,321,906		)
Income before income taxes	7,196,000			9,531,795			14,458,882			17,251,050
Taxes
Current tax expense (benefit)	(10,785		)	57,651			(46,334		)	23,891
Deferred tax expense (benefit)	(604,064		)	38,084			(1,013,341		)	(260,762		)
Income tax expense (benefit), net	(614,849		)	95,735			(1,059,675		)	(236,871		)
Net Income	7,810,849			9,436,060			15,518,557			17,487,921
Less: Net Income attributable to non-controlling interest	—			435,888			—			818,271
Net Income attributable to CorEnergy Stockholders	$	7,810,849		$	9,000,172		$	15,518,557		$	16,669,650
Preferred dividend requirements	2,396,875			2,123,129			4,793,750			3,160,238
Net Income attributable to Common Stockholders	$	5,413,974		$	6,877,043		$	10,724,807		$	13,509,412
Net Income	$	7,810,849		$	9,436,060		$	15,518,557		$	17,487,921
Other comprehensive income:
Changes in fair value of qualifying hedges / AOCI attributable to CorEnergy stockholders	—			3,006			—			5,978
Changes in fair value of qualifying hedges / AOCI attributable to non-controlling interest	—			702			—			1,396
Net Change in Other Comprehensive Income	$	—		$	3,708		$	—		$	7,374
Total Comprehensive Income	7,810,849			9,439,768			15,518,557			17,495,295
Less: Comprehensive income attributable to non-controlling interest	—			436,590			—			819,667
Comprehensive Income attributable to CorEnergy Stockholders	$	7,810,849		$	9,003,178		$	15,518,557		$	16,675,628
Earnings Per Common Share:
Basic	$	0.45		$	0.58		$	0.90		$	1.14
Diluted	$	0.45		$	0.58		$	0.90		$	1.14
Weighted Average Shares of Common Stock Outstanding:
Basic	11,928,297			11,896,616			11,923,627			11,892,670
Diluted	11,928,297			11,896,616			11,923,627			11,892,670
Dividends declared per share	$	0.750		$	0.750		$	1.500		$	1.500
See accompanying Notes to Consolidated Financial Statements.

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Table of Contents Glossary of Defined Terms

CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENT OF EQUITY

	Capital Stock			Preferred Stock		Additional Paid-in Capital			Retained Earnings			Total
	Shares	Amount		Amount
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	—	—		—		—			15,518,557			15,518,557
Series A preferred stock dividends	—	—		—		—			(4,793,750		)	(4,793,750		)
Common stock dividends	—	—		—		(7,156,178		)	(10,724,807		)	(17,880,985		)
Common stock issued under director's compensation plan	1,006	1		—		37,499			—			37,500
Reinvestment of dividends paid to common stockholders	16,938	17		—		610,202			—			610,219
Balance at June 30, 2018 (Unaudited)	11,933,774	$	11,934	$	130,000,000	$	322,815,994		$	—		$	452,827,928
See accompanying Notes to Consolidated Financial Statements.

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CorEnergy Infrastructure Trust, Inc.

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	For the Six Months Ended
	June 30, 2018			June 30, 2017
Operating Activities
Net Income	$	15,518,557		$	17,487,921
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income tax, net	(1,013,341		)	(260,762		)
Depreciation, amortization and ARO accretion	13,286,595			12,949,644
Provision for loan losses	500,000			—
Non-cash settlement of accounts payable	—			(171,609		)
Gain on sale of equipment	(3,724		)	—
Net distributions and dividend income, including recharacterization of income	—			148,649
Net realized and unrealized (gain) loss on other equity securities	867,134			(70,426		)
Unrealized gain on derivative contract	—			(16,453		)
Common stock issued under directors' compensation plan	37,500			30,000
Changes in assets and liabilities:
Increase in deferred rent receivable	(3,709,202		)	(3,588,136		)
Decrease in accounts and other receivables	412,434			1,162,548
(Increase) decrease in prepaid expenses and other assets	(326,372		)	134,023
Increase in management fee payable	65,679			10,301
Increase (decrease) in accounts payable and other accrued liabilities	433,853			(53,621		)
Decrease in current income tax liability	(2,167,655		)	—
Increase (decrease) in unearned revenue	(1,383,757		)	29,695
Net cash provided by operating activities	$	22,517,701		$	27,791,774
Investing Activities
Purchases of property and equipment	(47,883		)	(13,745		)
Proceeds from sale of property and equipment	11,499			—
Return of capital on distributions received	—			61,828
Net cash (used in) provided by investing activities	$	(36,384	)	$	48,083
Financing Activities
Debt financing costs	(264,010		)	(2,512		)
Net offering proceeds on Series A preferred stock	—			71,170,611
Dividends paid on Series A preferred stock	(4,793,750		)	(3,433,984		)
Dividends paid on common stock	(17,270,766		)	(17,318,618		)
Distributions to non-controlling interest	—			(480,488		)
Payments on revolving line of credit	—			(44,000,000		)
Principal payments on secured credit facilities	(1,764,000		)	(4,389,261		)
Net cash (used in) provided by financing activities	$	(24,092,526	)	$	1,545,748
Net Change in Cash and Cash Equivalents	$	(1,611,209	)	$	29,385,605
Cash and Cash Equivalents at beginning of period	15,787,069			7,895,084
Cash and Cash Equivalents at end of period	$	14,175,860		$	37,280,689
Supplemental Disclosure of Cash Flow Information
Interest paid	$	5,546,660		$	5,777,328
Income taxes paid (net of refunds)	2,121,321			132,202
Non-Cash Financing Activities
Change in accounts payable and accrued expenses related to debt financing costs	$	(255,037	)	$	—
Reinvestment of distributions by common stockholders in additional common shares	610,219			516,565
See accompanying Notes to Consolidated Financial Statements.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

June 30, 2018

1.INTRODUCTION AND BASIS OF PRESENTATION

Introduction

CorEnergy Infrastructure Trust, Inc. ("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 GAAP set forth in the ASC, as published by the FASB, and with the SEC instructions to Form 10-Q, and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. 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. However, 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 of the limited partnership interest in both Pinedale LP and Grand Isle Corridor LP, the consolidated financial statements presented include full consolidation with respect to both of the partnerships.

Operating results for the three and six months ended June 30, 2018 are not necessarily indicative of the results that may be expected for the year ending December 31, 2018 or any other interim or annual period. These consolidated financial statements and Management's Discussion and Analysis of the Financial Condition and Results of Operations should be read in conjunction with CorEnergy's Annual Report on Form 10-K, for the year ended December 31, 2017, filed with the SEC on February 28, 2018 (the "2017 CorEnergy 10-K").

2.RECENT ACCOUNTING PRONOUNCEMENTS

In May 2014, the FASB issued ASU 2014-09 "Revenue from Contracts with Customers" ("ASU 2014-09" or "ASC 606"), which became effective for all public entities on January 1, 2018, if not adopted early. 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

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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 our transportation and distribution revenue recognition policy, transition impact and related disclosures under ASC 606.

In February 2016, the FASB issued ASU 2016-02 "Leases" ("ASU 2016-02"), 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. Management is in the process of evaluating the impact of the standard on its consolidated financial statements and related disclosures. As part of its assessment work, the Company has formed an implementation team, completed training on the new lease standard and is undertaking a review of its contracts.

In June 2016, the FASB issued ASU 2016-13 "Financial Instruments - Credit Losses" ("ASU 2016-13"), which introduces an approach based on expected losses to estimate credit losses on certain types of financial instruments. The new model, referred to as the current expected credit losses ("CECL model"), will apply to financial assets subject to credit losses and measured at amortized cost, and certain off-balance sheet credit exposures. ASU 2016-13 is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early application of the guidance will be permitted for all entities for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Management is currently evaluating the impact that adopting the new standard will have on the Company's consolidated financial statements but believes that, unless the Company acquires any additional financing receivables, the impact would not be material.

3.LEASED PROPERTIES AND LEASES

As of June 30, 2018, the Company had three significant leased properties located in Oregon, Wyoming, Louisiana, and the Gulf of Mexico, which 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 terms 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	Portland Terminal Facility
Location	Gulf of Mexico/Louisiana	Pinedale, WY	Portland, OR
Tenant	Energy XXI GIGS Services, LLC	Ultra Wyoming LGS, LLC	Zenith Energy Terminals Holdings 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.	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.
Date Acquired	June 2015	December 2012	January 2014
Initial Lease Term	11 years	15 years	15 years(1)
Renewal Option	Equal to the lesser of 9-years or 75 percent of the remaining useful life	5-year terms	5-year terms
Current Monthly Rent Payments	7/1/2017 - 6/30/2018: $2,854,667 7/1/2018 - 6/30/2019: $2,860,917	$1,776,772	$513,355
Initial Estimated Useful Life	27 years	26 years	30 years
(1) The lessee of the Portland Terminal Facility has a purchase option on the facility, which it can exercise with 90-days notice, as well as lease termination options on the fifth and tenth anniversaries of the lease. If exercised, the purchase option and termination options are subject to additional payment provisions and termination fees prescribed under the lease.

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The future contracted minimum rental receipts for all leases as of June 30, 2018, are as follows:

Future Minimum Lease Receipts (1)
Years Ending December 31,	Amount
2018	$	30,919,514
2019	64,103,462
2020	71,264,921
2021	77,445,396
2022	76,553,434
Thereafter	302,242,184
Total	$	622,528,911
(1) Future minimum lease receipts include base rents for the Portland Terminal Facility through its initial 15-year term.

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
					For the Three Months Ended				For the Six Months Ended
	June 30, 2018		December 31, 2017		June 30, 2018		June 30, 2017		June 30, 2018		June 30, 2017
Pinedale LGS(2)	39.9	%	39.9	%	35.3	%	30.6	%	34.1	%	30.6	%
Grand Isle Gathering System	49.7	%	49.7	%	55.6	%	59.6	%	56.7	%	59.6	%
Portland Terminal Facility	10.2	%	10.1	%	9.0	%	9.6	%	9.1	%	9.7	%
(1) Insignificant leases are not presented; thus percentages may not sum to 100%.
(2) Pinedale LGS lease revenues include variable rent of $1.1 million and $1.5 million for the three and six months ended June 30, 2018, respectively.

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 Three Months Ended				For the Six Months Ended
	June 30, 2018		June 30, 2017		June 30, 2018		June 30, 2017
Depreciation Expense
GIGS	$	2,751,272	$	2,438,649	$	5,502,544	$	4,877,298
Pinedale	2,217,360		2,217,360		4,434,720		4,434,720
Portland Terminal Facility	318,915		318,915		637,830		637,830
United Property Systems	9,120		9,060		18,242		18,119
Total Depreciation Expense	$	5,296,667	$	4,983,984	$	10,593,336	$	9,967,967
Amortization Expense - Deferred Lease Costs
GIGS	$	7,641	$	7,641	$	15,282	$	15,282
Pinedale	15,342		15,342		30,684		30,684
Total Amortization Expense - Deferred Lease Costs	$	22,983	$	22,983	$	45,966	$	45,966
ARO Accretion Expense
GIGS	$	127,928	$	160,629	$	255,856	$	321,258
Total ARO Accretion Expense	$	127,928	$	160,629	$	255,856	$	321,258

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

	June 30, 2018		December 31, 2017
Net Deferred Lease Costs
GIGS	$	244,601	$	259,883
Pinedale	581,033		611,717
Total Deferred Lease Costs, net	$	825,634	$	871,600

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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 the 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

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

EGC 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. Its SEC filings can be found at www.sec.gov. Effective March 21, 2018, EGC changed its NASDAQ ticker symbol from EXXI to EGC. 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. Upon closure of the previously announced acquisition of EGC by an affiliate of the privately-held Cox Oil, expected in the third quarter of 2018, EGC will no longer be subject to the filing and reporting requirements of the SEC.

Zenith

Currently our tenant, Zenith Terminals, has a number of different actions available to it under the Portland Lease Agreement, which include (i) continuing with the current terminal lease, (ii) exercising its buy-out option on the terminal or (iii) terminating the lease at its fifth or tenth anniversaries, subject to the termination provisions in the lease. The Company has entered into amendments with Zenith which have extended the notice period for the fifth anniversary termination option through September 1, 2018. The Company has not received notice with respect to either a buy-out or termination option election and, to date, the terminal lease continues to operate in the same manner as prior to the merger.

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. 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 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, as discussed further below. All invoicing is done in the month following service, with payment typically due a month from invoice date.

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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 will continue to accumulate additional unrecognized performance obligations at a rate of approximately $992 thousand per quarter until the contractual rate decrease takes effect in November 2018. Following the rate decline, recognized performance obligations will exceed amounts invoiced and the contract liability is expected to decline at a rate of approximately $138 thousand per quarter through the end of the contract in October 2030. As of June 30, 2018, the revenue allocated to the remaining performance obligation under this contract is approximately $66.2 million.

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 Sheet. Any differences are generally expected to be recognized within a year.

The table below summarizes the Company's contract asset and contract liability balances related to its transportation and distribution revenue contracts as of June 30, 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	(418,314		)	1,984,266
Recognized Performance Obligations	111,656			—
Ending Balance June 30, 2018	$	21,375		$	5,291,375
(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.

The following is a breakout of the Company's transportation and distribution revenue for the three and six months ended June 30, 2018 and 2017:

	For the Three Months Ended				For the Six Months Ended
	June 30, 2018		June 30, 2017		June 30, 2018		June 30, 2017
Natural gas transportation contracts	66.1	%	74.1	%	66.3	%	72.9	%
Natural gas distribution contracts	27.2	%	21.4	%	26.8	%	20.7	%

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

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The tables below disclose the impact of adoption on the Consolidated Balance Sheet and Consolidated Statement of Income as of and for the period ended June 30, 2018:

	As of June 30, 2018
Balance Sheet	As Reported		Balances Without Adoption of ASC 606		Effect of Change Higher/(Lower)
Assets
Deferred Tax Asset	$	4,115,834	$	2,743,252	$	1,372,582
Liabilities
Unearned revenue	5,321,069		29,694		5,291,375
Equity
Additional paid in capital	322,815,994		326,734,786		(3,918,792		)

	For the Three Months Ended June 30, 2018									For the Six Months Ended June 30, 2018
Statement of Income	As Reported			Balances Without Adoption of ASC 606			Effect of Change Higher/(Lower)			As Reported			Balances Without Adoption of ASC 606			Effect of Change Higher/(Lower)
Revenues
Transportation and distribution revenue	$	3,874,157		$	4,866,290		$	(992,133	)	$	7,827,136		$	9,811,402		$	(1,984,266	)
Taxes
Deferred tax benefit	(604,064		)	(346,705		)	(257,359		)	(1,013,341		)	(498,622		)	(514,719		)

5.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 management otherwise does not 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 generally 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.

Four Wood Financing Note Receivable

As a result of decreased economic activity by SWD, the Company recorded a provision for loan loss with respect to the SWD Loans and 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. The balance of the loans has been valued based on the enterprise value of SWD, the collateral supporting the loans, at $1.0 million and $1.5 million as of June 30, 2018 and December 31, 2017, respectively.

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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 June 30, 2018 and December 31, 2017, are as follows:

Deferred Tax Assets and Liabilities
	June 30, 2018			December 31, 2017
Deferred Tax Assets:
Deferred contract revenue	$	1,372,582		$	—
Net operating loss carryforwards	1,602,683			957,719
Loan loss provision	263,508			247,814
Basis reduction of investment in partnerships	233,158			261,549
Other loss carryforwards	2,965,320			2,965,321
Sub-total	$	6,437,251		$	4,432,403
Deferred Tax Liabilities:
Net unrealized gain on investment securities	$	(134,317	)	$	(342,669	)
Cost recovery of leased and fixed assets	(2,177,589		)	(1,845,105		)
Basis reduction in tax goodwill	(9,511		)	—
Sub-total	$	(2,321,417	)	$	(2,187,774	)
Total net deferred tax asset	$	4,115,834		$	2,244,629

As of June 30, 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, 2013 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 reduces the US federal corporate tax rate from 35 percent to 21 percent. The 2017 Tax Act also repealed the alternative minimum tax for corporations. The Company has completed its provisional accounting for the tax effects of enactment of the 2017 Tax Act. Due to the timing and complexities of the new legislation, the SEC has issued Staff Accounting Bulletin 118, which allows for the recognition of provisional amounts during a measurement period similar to the measurement period used when accounting for business combinations. The Company remeasured deferred tax assets and liabilities based on the updated rates at which they are expected to reverse in the future, in the table above, which resulted in a $1.3 million transition adjustment that reduced net deferred tax assets at December 31, 2017. The Company will continue to assess the impact of the new tax legislation, as well as any future regulations and updates, and will record any additional impacts as identified during the measurement period, if necessary.

Total income tax expense (benefit) differs from the amount computed by applying the federal statutory income tax rate of 21 percent for the three and six months ended June 30, 2018 and 35 percent for the three and six months ended June 30, 2017 to income from operations and other income and expense for the periods presented, as follows:

Income Tax Expense (Benefit)
	For the Three Months Ended						For the Six Months Ended
	June 30, 2018			June 30, 2017			June 30, 2018			June 30, 2017
Application of statutory income tax rate	$	1,511,160		$	3,158,922		$	3,036,365		$	5,726,827
State income taxes, net of federal tax expense (benefit)	(121,069		)	3,786			(265,019		)	(31,651		)
Federal Tax Attributable to Income of Real Estate Investment Trust	(2,004,940		)	(3,066,973		)	(3,819,436		)	(5,932,047		)
Other	—			—			(11,585		)	—
Total income tax expense (benefit)	$	(614,849	)	$	95,735		$	(1,059,675	)	$	(236,871	)

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The components of income tax expense (benefit) include the following for the periods presented:

Components of Income Tax Expense (Benefit)
	For the Three Months Ended						For the Six Months Ended
	June 30, 2018			June 30, 2017			June 30, 2018			June 30, 2017
Current tax expense (benefit)
Federal	$	(8,537	)	$	52,031		$	(36,676	)	$	21,562
State (net of federal tax expense (benefit))	(2,248		)	5,620			(9,658		)	2,329
Total current tax expense (benefit)	$	(10,785	)	$	57,651		$	(46,334	)	$	23,891
Deferred tax expense (benefit)
Federal	$	(485,243	)	$	39,918		$	(757,981	)	$	(226,782	)
State (net of federal tax expense (benefit))	(118,821		)	(1,834		)	(255,360		)	(33,980		)
Total deferred tax expense (benefit)	$	(604,064	)	$	38,084		$	(1,013,341	)	$	(260,762	)
Total income tax expense (benefit), net	$	(614,849	)	$	95,735		$	(1,059,675	)	$	(236,871	)

7.PROPERTY AND EQUIPMENT

Property and equipment consist of the following:

Property and Equipment
	June 30, 2018			December 31, 2017
Land	$	580,000		$	580,000
Natural gas pipeline	124,303,315			124,303,315
Vehicles and trailers	675,517			650,634
Office equipment and computers	268,559			268,559
Gross property and equipment	$	125,827,391		$	125,802,508
Less: accumulated depreciation	(14,312,665		)	(12,643,636		)
Net property and equipment	$	111,514,726		$	113,158,872

Depreciation expense was $843 thousand and $1.7 million for the three and six months ended June 30, 2018, respectively, and $838 thousand and $1.7 million for the three and six months ended June 30, 2017, respectively.

8.MANAGEMENT AGREEMENT

The Company pays its manager, Corridor, pursuant to a Management Agreement as described in the 2017 CorEnergy 10-K. Fees incurred under the Management Agreement for the three and six months ended June 30, 2018 were $1.9 million and $3.8 million, respectively, compared to $1.8 million and $3.6 million for the three and six months ended June 30, 2017, respectively. Fees incurred under the Management Agreement are reported in the general and administrative line item on the Consolidated Statements of Income.

The Company pays its administrator, Corridor, pursuant to an Administrative Agreement. Fees incurred under the Administrative Agreement for the three and six months ended June 30, 2018 were $70 thousand and $139 thousand, respectively, compared to $67 thousand and $134 thousand for the three and six months ended June 30, 2017, respectively. Fees incurred under the Administrative Agreement are reported in the general and administrative line item on the Consolidated Statements of Income.

9.FAIR VALUE

The following tables set forth the Company's assets and liabilities measured at fair value on a recurring basis, by level within the fair value hierarchy, as of June 30, 2018 and December 31, 2017:

	June 30, 2018
			Fair Value
	Total		Level 1		Level 2		Level 3
Assets:
Other equity securities	$	2,091,181	$	—	$	—	$	2,091,181
Total Assets	$	2,091,181	$	—	$	—	$	2,091,181

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

At June 30, 2018 and December 31, 2017, the only assets and liabilities measured at fair value on a recurring basis were the Company's equity securities.

The changes for all Level 3 securities measured at fair value on a recurring basis using significant unobservable inputs for the six months ended June 30, 2018 and 2017 are as follows:

Level 3 Rollforward
For the Six Months Ended June 30, 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 (Losses), Included In Net Income, Relating to Securities Still Held (1)
Other equity securities	$	2,958,315	$	—	$	—	$	(867,134	)	$	—		$	2,091,181	$	(867,134	)
Total	$	2,958,315	$	—	$	—	$	(867,134	)	$	—		$	2,091,181	$	(867,134	)
For the Six Months Ended June 30, 2017
Other equity securities	$	9,287,209	$	—	$	—	$	70,426		$	(210,477	)	$	9,147,158	$	70,426
Total	$	9,287,209	$	—	$	—	$	70,426		$	(210,477	)	$	9,147,158	$	70,426
(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 six months ended June 30, 2018 and 2017.

Valuation Techniques and Unobservable Inputs

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

As of both June 30, 2018 and December 31, 2017, the Company's investment in Lightfoot and Arc Terminal Joliet Holdings are its only remaining private company investments. The Company's Lightfoot investment consists of a 6.6 percent and 1.5 percent equity interest in Lightfoot LP and Lightfoot GP, respectively. As of both June 30, 2018 and December 31, 2017, Lightfoot's only material asset consists 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. Additionally, the Company owns a 0.6 percent interest in Arc Terminal Joliet Holdings, which was acquired in conjunction with the terms of Zenith's acquisition of Arc Logistics discussed below.

On December 21, 2017, Zenith closed its acquisition of Arc Logistics, except for terms pending with respect to the Gulf LNG arbitration with ENI USA. Under the terms of the agreement, Zenith will 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 that is described below.

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. As a result, the Company recorded a loss on its Lightfoot investment of $881 thousand and $867 thousand for the three and six months ended June 30, 2018, respectively. The loss is recorded in net realized and unrealized gain (loss) on other equity securities in the Consolidated Statements of Income.

The Company's remaining private company investments in Lightfoot and Arc Terminal Joliet holdings represent less than 0.5 percent of its total assets. The fair value of the Company's private company investments at June 30, 2018 and December 31, 2017 was approximately $2.1 million and $3.0 million, respectively. As of June 30, 2018, the Lightfoot fair value estimate is based on

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Level 3 valuation assumptions and judgments, including probability weighted discounted cash flow analyses for various forecasted scenarios. The discount rate used in the cash flow analyses was developed by considering several factors, including the Company's minority interest in the investment. This valuation methodology is considered a change from prior periods. As of December 31, 2017, the Lightfoot fair value estimate was determined using recent transaction data and expected proceeds, discounted using a risk-free rate through the expected receipt date. As of both June 30, 2018 and December 31, 2017, the Arc Terminal Joliet fair value estimate was determined using recent transaction data. 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	June 30, 2018				December 31, 2017
		Carrying     Amount (1)		Fair Value		Carrying     Amount (1)		Fair Value
Financial Assets:
Cash and cash equivalents	Level 1	$	14,175,860	$	14,175,860	$	15,787,069	$	15,787,069
Financing notes receivable (Note 5)	Level 3	$	1,000,000	$	1,000,000	$	1,500,000	$	1,500,000
Financial Liabilities:
Secured Credit Facilities	Level 2	$	38,998,698	$	38,998,698	$	40,745,354	$	40,745,354
Unsecured convertible senior notes	Level 1	$	112,425,677	$	132,032,520	$	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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10.DEBT

The following is a summary of the Company's debt facilities and balances as of June 30, 2018 and December 31, 2017:

	Total Commitment  or Original Principal		Quarterly Principal Payments			June 30, 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	$	—	4.84	%	$	—	4.32	%
MoGas Revolver	1,000,000		—		7/28/2022	—		4.84	%	—		4.32	%
Omega Line of Credit	1,500,000		—		7/31/2019	—		6.09	%	—		5.57	%
Pinedale Secured Credit Facility:
Amended Pinedale Term Credit Facility	41,000,000		882,000		12/29/2022	39,236,000		6.50	%	41,000,000		6.50	%
7.00% Unsecured Convertible Senior Notes	115,000,000		—		6/15/2020	114,000,000		7.00	%	114,000,000		7.00	%
Total Debt						$	153,236,000			$	155,000,000
Less:
Unamortized deferred financing costs (1)						$	333,827			$	375,309
Unamortized discount on 7.00% Convertible Senior Notes						1,477,798				1,847,254
Long-term debt, net of deferred financing costs						$	151,424,375			$	152,777,437
Debt due within one year						$	3,528,000			$	3,528,000
(1) Unamortized deferred financing costs related to our 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 Facility

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.

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 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). As of June 30, 2018, the Company was in compliance with all covenants of the CorEnergy Credit Facility.

As of June 30, 2018, the Company had approximately $145.6 million and $1.0 million of availability under the CorEnergy Revolver and MoGas Revolver, respectively.

Pinedale Credit Facility

On December 20, 2012, Pinedale LP closed on a $70.0 million secured term credit facility. 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 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.

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 Pinedale 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

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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 June 30, 2018, the net assets of Pinedale LP were $139.6 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 three and six months ended June 30, 2018 and 2017 is as follows:

	For the Three Months Ended				For the Six Months Ended
	June 30, 2018		June 30, 2017		June 30, 2018		June 30, 2017
CorEnergy Credit Facility	$	143,635	$	272,074	$	287,270	$	544,148
Pinedale Credit Facility	13,205		—		26,317		—
Total Deferred Debt Cost Amortization Expense (1)(2)	$	156,840	$	272,074	$	313,587	$	544,148
(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 cost 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 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. 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.

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.

Contractual Payments

The remaining contractual principal payments as of June 30, 2018 under the Pinedale credit facility are as follows:

Year	Pinedale Credit Facility
2018	$	1,764,000
2019	3,528,000
2020	3,528,000
2021	3,528,000
2022	26,888,000
Thereafter	—
Total Remaining Contractual Payments	$	39,236,000

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 7.00 percent per annum, payable semi-annually in arrears on June 15 and December 15 of each year, beginning on December 15, 2015. On May 23, 2016, the Company repurchased $1.0 million of its convertible bonds on the open market.

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The following is a summary of the impact of Convertible Notes on interest expense for the three and six months ended June 30, 2018 and 2017:

Convertible Note Interest Expense
	For the Three Months Ended				For the Six Months Ended
	June 30, 2018		June 30, 2017		June 30, 2018		June 30, 2017
7.00% Convertible Notes	$	1,995,000	$	1,995,000	$	3,990,000	$	3,990,000
Discount Amortization	184,728		184,728		369,456		369,456
Deferred Debt Issuance Amortization	12,069		12,069		24,138		24,138
Total Convertible Note Interest Expense	$	2,191,797	$	2,191,797	$	4,383,594	$	4,383,594

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. Including the impact of the convertible debt discount and related deferred debt issuance costs, the effective interest rate on the Convertible Notes is approximately 7.7 percent for each of the three and six months ended June 30, 2018 and 2017.

11.STOCKHOLDERS' EQUITY

PREFERRED STOCK

As of June 30, 2018, the Company has a total of 5,200,000 depository shares outstanding, or 52,000 whole shares of its 7.375% Series A Preferred Stock. See Note 13 ("Subsequent Events") for further information regarding the declaration of a dividend on the 7.375% Series A Preferred Stock.

COMMON STOCK

As of June 30, 2018, the Company has 11,933,774 of common shares issued and outstanding. See Note 13 ("Subsequent Events") for further information regarding the declaration of a dividend on the common stock.

SHELF REGISTRATION

On February 18, 2016, the Company had a new shelf registration statement declared effective by the SEC, 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 June 30, 2018, the Company has issued 79,153 shares of common stock under the its dividend reinvestment plan pursuant to the February 18, 2016 shelf, reducing availability by approximately $2.4 million. Shelf availability was further reduced by approximately $73.8 million as a result of the follow-on offering of additional 7.375% Series A Preferred Stock during the second quarter of 2017. As of June 30, 2018, availability on the current shelf registration is approximately $523.8 million.

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12.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. Diluted EPS for the three and six months ended June 30, 2018 and 2017 excludes the impact to income and the number of shares outstanding from the conversion of the 7.00% Convertible Senior Notes because such impact is antidilutive. If converted, the 7.00% Convertible Senior Notes would result in an additional 3,454,545 common shares outstanding.

	For the Three Months Ended				For the Six Months Ended
	June 30, 2018		June 30, 2017		June 30, 2018		June 30, 2017
Net income attributable to CorEnergy stockholders	$	7,810,849	$	9,000,172	$	15,518,557	$	16,669,650
Less: preferred dividend requirements	2,396,875		2,123,129		4,793,750		3,160,238
Net income attributable to common stockholders	$	5,413,974	$	6,877,043	$	10,724,807	$	13,509,412
Weighted average shares - basic	11,928,297		11,896,616		11,923,627		11,892,670
Basic earnings per share	$	0.45	$	0.58	$	0.90	$	1.14
Net income attributable to common stockholders (from above)	$	5,413,974	$	6,877,043	$	10,724,807	$	13,509,412
Add: After tax effect of convertible interest	—		—		—		—
Income attributable for dilutive securities	$	5,413,974	$	6,877,043	$	10,724,807	$	13,509,412
Weighted average shares - diluted	11,928,297		11,896,616		11,923,627		11,892,670
Diluted earnings per share	$	0.45	$	0.58	$	0.90	$	1.14

13.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:

Common Stock Dividend Declaration

On July 25, 2018, the Company's Board of Directors declared a 2018 second quarter dividend of $0.75 per share for CorEnergy common stock. The dividend is payable on August 31, 2018 to stockholders of record on August 17, 2018.

Preferred Stock Dividend Declaration

On July 25, 2018, 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 is payable on August 31, 2018 to stockholders of record on August 17, 2018.

Preferred Stock Repurchase Program

The Company's Board of Directors authorized a share repurchase program for the Company to buy up to $10.0 million of its preferred stock, which will commence August 6, 2018. The Company plans to repurchase shares from time to time through open market transactions, including through block purchases, in privately negotiated transactions or otherwise. The timing, manner, price and amount of any repurchases are to be determined by senior management, depending on market prices and other conditions, and will be made in accordance with the Company's covenants under the CorEnergy Credit Facility. Purchases may be made through the program through August 5, 2019. The Company is not obligated to repurchase any shares of stock under the program and may terminate the program at any time. The Company did not repurchase any preferred shares during the six months ended June 30, 2018.

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ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion should be read in conjunction with the Consolidated Financial Statements and Notes thereto in this Report on Form 10-Q ("Report") of CorEnergy Infrastructure, Inc. ("the Company," "CorEnergy," "we" or "us"). The forward-looking statements included in this discussion and elsewhere in this Report involve risks and uncertainties, including anticipated financial performance, business prospects, industry trends, stockholder returns, performance of leases by tenants, performance on loans to customers, and other matters, which reflect management's best judgment based on factors currently known. See "Cautionary Statement Concerning Forward-Looking Statements" which is incorporated herein by reference. Actual results and experience could differ materially from the anticipated results and other expectations expressed in our forward-looking statements as a result of a number of factors, including but not limited to those discussed in Part I, Item 1A, "Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2017, filed with the SEC on February 28, 2018, and Part II, Item 1A, "Risk Factors" in this Report.

BUSINESS OBJECTIVE

CorEnergy primarily owns 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 generally 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 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 primarily 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. CorEnergy targets 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.

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Basis of Presentation

The consolidated financial statements include CorEnergy Infrastructure Trust, Inc., as of June 30, 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 tables summarize the financial data and key operating statistics for CorEnergy for the three and six months ended June 30, 2018 and 2017. 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 I, Item 1 of this Report. All information in Part I, Item 2 "Management's Discussion and Analysis of Financial Condition and Results of Operations," except for balance sheet data as of December 31, 2017, is unaudited.

The following table and discussion is a summary of our results of operations for the three and six months ended June 30, 2018 and 2017:

	For the Three Months Ended						For the Six Months Ended
	June 30, 2018			June 30, 2017			June 30, 2018			June 30, 2017
Revenue
Lease revenue	$	18,275,859		$	17,050,092		$	35,867,718		$	34,116,618
Transportation and distribution revenue	3,874,157			4,775,780			7,827,136			9,786,370
Total Revenue	22,150,016			21,825,872			43,694,854			43,902,988
Expenses
Transportation and distribution expenses	1,534,524			1,362,980			3,107,420			2,698,550
General and administrative	3,107,776			2,558,339			5,834,833			5,619,579
Depreciation, amortization and ARO accretion expense	6,290,082			6,005,995			12,579,412			12,011,903
Provision for loan losses	—			—			500,000			—
Total Expenses	10,932,382			9,927,314			22,021,665			20,330,032
Operating Income	$	11,217,634		$	11,898,558		$	21,673,189		$	23,572,956
Other Income (Expense)
Net distributions and dividend income	$	55,714		$	221,440		$	59,665		$	264,902
Net realized and unrealized gain (loss) on other equity securities	(881,100		)	614,634			(867,134		)	70,426
Interest expense	(3,196,248		)	(3,202,837		)	(6,406,838		)	(6,657,234		)
Total Other Expense	(4,021,634		)	(2,366,763		)	(7,214,307		)	(6,321,906		)
Income before income taxes	7,196,000			9,531,795			14,458,882			17,251,050
Income tax expense (benefit), net	(614,849		)	95,735			(1,059,675		)	(236,871		)
Net Income	7,810,849			9,436,060			15,518,557			17,487,921
Less: Net Income attributable to non-controlling interest	—			435,888			—			818,271
Net Income attributable to CorEnergy Stockholders	$	7,810,849		$	9,000,172		$	15,518,557		$	16,669,650
Preferred dividend requirements	2,396,875			2,123,129			4,793,750			3,160,238
Net Income attributable to Common Stockholders	$	5,413,974		$	6,877,043		$	10,724,807		$	13,509,412
Other Financial Data (1)
Adjusted EBITDAre	$	17,563,430		$	16,976,703		$	34,812,266		$	33,915,240
NAREIT FFO	11,553,145			12,287,971			23,002,397			24,331,181
FFO	12,213,745			12,014,732			23,627,544			24,586,094
AFFO	12,348,559			12,499,249			24,375,755			25,814,607
(1) Refer to the "Non-GAAP Financial Measures" section that follows for additional details.

Three Months Ended June 30, 2018 Compared to the Three Months Ended June 30, 2017

Revenue. Consolidated revenues were $22.2 million for the three months ended June 30, 2018 compared to $21.8 million for the three months ended June 30, 2017, representing an increase of $324 thousand. Lease revenue was $18.3 million and $17.1 million for the three months ended June 30, 2018 and 2017, respectively, with the increase of approximately $1.2 million driven primarily by variable rent collected on the Pinedale lease during the second quarter 2018. Transportation and distribution revenue from our subsidiaries MoGas and Omega was $3.9 million and $4.8 million for the three months ended June 30, 2018 and 2017, respectively.

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The $902 thousand decrease 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 in the three months ended June 30, 2018 was $992 thousand lower under the new accounting standard. Refer to Part I, Item I, Note 4 ("Transportation And Distribution Revenue") for additional details.

Transportation and Distribution Expenses. Transportation and distribution expenses were $1.5 million and $1.4 million for the three months ended June 30, 2018 and 2017, respectively, representing an increase of $172 thousand. The increase relates primarily to higher legal, consulting and maintenance costs at MoGas.

General and Administrative Expenses. General and administrative expenses were $3.1 million for the three months ended June 30, 2018 compared to $2.6 million for the three months ended June 30, 2017. The most significant components of the variance from the prior-year period are outlined in the following table and explained below:

	For the Three Months Ended
	June 30, 2018		June 30, 2017
Management fees	$	1,893,774	$	1,812,688
Acquisition and professional fees	788,993		467,391
Other expenses	425,009		278,260
Total	$	3,107,776	$	2,558,339

Management fees are directly proportional to our asset base. For the three months ended June 30, 2018, management fees increased$81 thousand compared to the prior-year period due to the acquisition of the non-controlling interest in Pinedale LP at the end of 2017. See Part I, Item 1, Note 8 ("Management Agreement") for additional information.

Acquisition and professional fees for the three months ended June 30, 2018increased$322 thousand from the prior-year period. A decrease of $186 thousand in asset acquisition expenses was more than offset by a $508 thousand increase in professional fees. The decrease in asset acquisition expenses is primarily the result of elevated expenses in the prior-year period related to multiple acquisition opportunities which had advanced into various stages of due diligence, but did not ultimately result in a transaction. 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. The increase in professional fees during the three months ended June 30, 2018 is primarily attributable to (i) a prior-year reimbursement of legal fees received in 2017 for costs incurred during UPL's bankruptcy as well as (ii) higher legal and consulting costs in the current-year related to monitoring our GIGS asset.

Other expenses for the three months ended June 30, 2018increased$147 thousand compared to the prior-year period. The increase is primarily related to 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 $6.3 million for the three months ended June 30, 2018 compared to $6.0 million for the three months ended June 30, 2017. This increase was primarily related to depreciation expense, which increased$317 thousand from the three months ended June 30, 2018 compared to the three months ended June 30, 2017. The increase in depreciation expense was largely 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.

Net Distributions and Dividend Income. Net distributions and dividend income for the three months ended June 30, 2018 was $56 thousand compared to $221 thousand for the three months ended June 30, 2017. The portion of distributions and dividends deemed to be income versus a return of capital in any period are made 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 during the three months ended June 30, 2018 and 2017 to the net distributions and dividends recorded as income on the Consolidated Statements of Income.

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	For the Three Months Ended
	June 30, 2018		June 30, 2017
Gross cash distributions and dividend income received from investment securities	$	55,714	$	252,213
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	—		—
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	—		30,773
Net distributions and dividends recorded as income	$	55,714	$	221,440

Net Realized and Unrealized Gain (Loss) on Other Equity Securities. For the three months ended June 30, 2018, we recorded a net loss on other equity securities of $881 thousand compared to a $615 thousand net gain recorded the same period in 2017. The net gain and loss recorded are directly related to fluctuations in the valuation of our investment in private securities. Following the acquisition of Arc Logistics by Zenith in December 2017, our remaining private security investments represent less than 0.5 percent of our assets. The net loss recorded in the current-year period related to valuation considerations surrounding the arbitration award delivered to Eni USA and Gulf LNG. See Part I, Item 1, Note 9 ("Fair Value") for additional information. The net gain recorded in the prior year period related primarily to an increase in the valuation of Lightfoot, which was dependent on the public share price of Arc Logistics.

Income Tax Expense (Benefit). Income tax benefit was $615 thousand for the three months ended June 30, 2018, as compared to $96 thousand of income tax expense for the three months ended June 30, 2017. The increased income tax benefit recorded in the current-year period is the result of (i) higher losses generated by our TRS subsidiaries and (ii) an unrealized loss related to our investment in Lightfoot.

Net Income. Net income was $7.8 million and $9.4 million for the three months ended June 30, 2018 and 2017, respectively. For the three months ended June 30, 2018 and 2017, net income attributable to CorEnergy stockholders was $7.8 million and $9.0 million, respectively. After deducting $2.4 million and $2.1 million for the portion of preferred dividends that are allocable to each respective period, net income attributable to common stockholders for the three months ended June 30, 2018 was $5.4 million, or $0.45 per basic and diluted common share as compared to $6.9 million, or $0.58 per basic and diluted common share for the prior-year period.

Six Months Ended June 30, 2018 Compared to the Six Months Ended June 30, 2017

Revenue. Consolidated revenues were $43.7 million for the six months ended June 30, 2018 compared to $43.9 million for the six months ended June 30, 2017, representing a decrease of $208 thousand. Lease revenue was $35.9 million and $34.1 million for the six months ended June 30, 2018 and 2017, respectively, resulting in an increase of $1.8 million. This increase in lease revenue was driven primarily by variable rent collected on the Pinedale lease during the six months ended June 30, 2018. Transportation and distribution revenue from our subsidiaries MoGas and Omega was $7.8 million and $9.8 million for the six months ended June 30, 2018 and 2017, respectively. The $2.0 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 in the six months ended June 30, 2018 was approximately $2.0 million lower under the new accounting standard. Refer to Part I, Item I, Note 4 ("Transportation And Distribution Revenue") for additional details.

Transportation and Distribution Expenses. Transportation and distribution expenses were $3.1 million and $2.7 million for the six months ended June 30, 2018 and 2017, respectively, representing an increase of $409 thousand. The increase relates primarily to higher legal, consulting and maintenance costs at MoGas during 2018.

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General and Administrative Expenses. General and administrative expenses were $5.8 million for the six months ended June 30, 2018 compared to $5.6 million for the six months ended June 30, 2017. The most significant components of the variance from the prior-year period are outlined in the following table and explained below:

	For the Six Months Ended
	June 30, 2018		June 30, 2017
Management fees	$	3,776,284	$	3,630,481
Acquisition and professional fees	1,326,551		1,411,505
Other expenses	731,998		577,593
Total	$	5,834,833	$	5,619,579

Management fees are directly proportional to our asset base. For the six months ended June 30, 2018, management fees increased $146 thousand compared to the prior-year period due to the acquisition of the non-controlling interest in Pinedale LP at the end of 2017. See Part I, Item 1, Note 8 ("Management Agreement") for additional information.

Acquisition and professional fees for the six months ended June 30, 2018decreased$85 thousand from the prior-year period due to a $413 thousanddecrease in asset acquisition expenses, partially offset by a $328 thousandincrease in professional fees. The decrease in asset acquisition expenses is primarily the result of elevated expenses in the prior-year period related to multiple acquisition opportunities which had advanced into various stages of due diligence, but did not ultimately result in a transaction. 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. The increase in professional fees during the six months ended June 30, 2018 is primarily attributable to (i) a prior-year reimbursement of legal fees received in 2017 for costs incurred during UPL's bankruptcy as well as (ii) higher legal and consulting costs in the current-year related to monitoring our GIGS asset.

Other expenses for the six months ended June 30, 2018increased$154 thousand compared to the prior-year period. The increase is primarily related to 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 $12.6 million for the six months ended June 30, 2018 compared to $12.0 million for the six months ended June 30, 2017. This increase was primarily related to depreciation expense, which increased$633 thousand from the six months ended June 30, 2018 to the six months ended June 30, 2017. The increase in depreciation expense was 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 losses. For the six months ended June 30, 2018, we recorded a provision for loan losses of approximately $500 thousand related to an additional write-down on the SWD loans. There were no loan loss provisions recorded for the six months ended June 30, 2017. For additional information, see Part I, Item 1, Note 5 ("Financing Notes Receivable").

Net Distributions and Dividend Income. Net distributions and dividend income for the six months ended June 30, 2018 was $60 thousand compared to $265 thousand for the six months ended June 30, 2017. The portion of distributions and dividends deemed to be income versus a return of capital in any period are made 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 during the six months ended June 30, 2018 and 2017 to the net distributions and dividends recorded as income on the Consolidated Statements of Income.

	For the Six Months Ended
	June 30, 2018		June 30, 2017
Gross cash distributions and dividend income received from investment securities	$	59,665	$	475,379
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	—		61,828
Net distributions and dividends recorded as income	$	59,665	$	264,902

Net Realized and Unrealized Gain (Loss) on Other Equity Securities. For the six months ended June 30, 2018, we recorded a net loss on other equity securities of $867 thousand compared to a net gain of $70 thousand in the prior-year period. The net gain and

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loss recorded are directly related to fluctuations in the valuation of our investment in private securities. Following the acquisition of Arc Logistics by Zenith in December 2017, our remaining private security investments represent less than 0.5 percent of our assets. The net loss recorded during the six months ended June 30, 2018 related to valuation considerations surrounding the arbitration award delivered to Eni USA and Gulf LNG. See Part I, Item 1, Note 9 ("Fair Value") for additional information. The net gain recorded during the six months ended June 30, 2017 primarily related to an increase in the valuation of Lightfoot, which was dependent on the public share price of Arc Logistics.

Interest Expense. For the six months ended June 30, 2018 and 2017, interest expense totaled approximately $6.4 million and $6.7 million, respectively. This decrease was primarily attributable to interest incurred on outstanding borrowings on the CorEnergy Revolver and CorEnergy Term Loan during the prior-year period, partially offset by increased interest on the Amended Pinedale Term Credit Facility during the six months ended June 30, 2018.

Income Tax Benefit. Income tax benefit was $1.1 million and $237 thousand for the six months ended June 30, 2018 and 2017, respectively. The increased benefit in the current year was primarily attributable to (i) higher losses generated by our TRS subsidiaries and (ii) an unrealized loss related to our investment in Lightfoot.

Net Income. Net income was $15.5 million and $17.5 million for the six months ended June 30, 2018 and 2017, respectively. For the six months ended June 30, 2018 and 2017, net income attributable to CorEnergy stockholders was $15.5 million and $16.7 million, respectively. After deducting $4.8 million and $3.2 million for the portion of preferred dividends that are allocable to each respective period, net income attributable to common stockholders for the six months ended June 30, 2018 was $10.7 million, or $0.90 per basic and diluted common share compared to $13.5 million, or $1.14 per basic and diluted common share for the prior-year period.

Common Equity Attributable to CorEnergy Stockholders per Share

As of June 30, 2018, our common equity decreased by approximately $9.0 million to $322.8 million from $331.8 million as of December 31, 2017. This decrease principally consists of: (i) dividends paid to our common stockholders of approximately $17.9 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 $10.7 million; and (iv) $648 thousand of common stock issued pursuant to reinvestment of dividends through the DRIP or directors' compensation plans.

Book Value Per Common Share
Analysis of Equity	June 30, 2018			December 31, 2017
Series A Cumulative Redeemable Preferred Stock 7.375%, $130,000,000 liquidation preference ($2,500 per share, $0.001 par value), 10,000,000 authorized; 52,000 issued and outstanding at June 30, 2018 and December 31, 2017	$	130,000,000		$	130,000,000
Capital stock, non-convertible, $0.001 par value; 11,933,774 and 11,915,830 shares issued and outstanding at June 30, 2018 and December 31, 2017 (100,000,000 shares authorized)	11,934			11,916
Additional paid-in capital	322,815,994			331,773,716
Total CorEnergy Stockholders' Equity	$	452,827,928		$	461,785,632
Subtract: 7.375% Series A Preferred Stock	(130,000,000		)	(130,000,000		)
Total CorEnergy Common Equity	$	322,827,928		$	331,785,632
Common shares outstanding	11,933,774			11,915,830
Book Value per Common Share	$	27.05		$	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

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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; provision for loan losses; 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; 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.

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 Three Months Ended						For the Six Months Ended
	June 30, 2018			June 30, 2017			June 30, 2018			June 30, 2017
Income Attributable to Common Stockholders	$	5,413,974		$	6,877,043		$	10,724,807		$	13,509,412
Add:
Interest expense, net	3,196,248			3,202,837			6,406,838			6,657,234
Depreciation, amortization, and ARO accretion	6,290,082			6,005,995			12,579,412			12,011,903
Less:
Income tax (expense) benefit	614,849			(95,735		)	1,059,675			236,871
Non-controlling interest attributable to depreciation, amortization, and interest expense(1)	—			572,566			—			1,155,119
EBITDAre(2)	$	14,285,455		$	15,609,044		$	28,651,382		$	30,786,559
Add:
Provision for loan losses	—			—			500,000			—
Preferred dividend requirements	2,396,875			2,123,129			4,793,750			3,160,238
Less:
Net realized and unrealized gain (loss) on securities, noncash portion	(881,100		)	583,861			(867,134		)	8,597
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		)
Non-cash settlement of accounts payable	—			171,609			—			171,609
Adjusted EBITDAre(2)	$	17,563,430		$	16,976,703		$	34,812,266		$	33,915,240
(1)ARO accretion expense has no impact on non-controlling interest. For the three and six months ended June 30, 2018, there is no noncontrolling interest outstanding.
(2) Effective March 31, 2018, we 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.

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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 other 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.

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 three and six months ended June 30, 2018 and 2017. 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 losses, net of tax, transaction costs, amortization of debt issuance costs, amortization of deferred lease costs, accretion of asset retirement obligation, income tax expense (benefit) unrelated to securities investments, non-cash costs associated with derivative instruments, 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 Three Months Ended						For the Six Months Ended
	June 30, 2018			June 30, 2017			June 30, 2018			June 30, 2017
Net Income attributable to CorEnergy Stockholders	$	7,810,849		$	9,000,172		$	15,518,557		$	16,669,650
Less:
Preferred Dividend Requirements	2,396,875			2,123,129			4,793,750			3,160,238
Net Income attributable to Common Stockholders	$	5,413,974		$	6,877,043		$	10,724,807		$	13,509,412
Add:
Depreciation	6,139,171			5,822,383			12,277,590			11,644,679
Less:
Non-Controlling Interest attributable to NAREIT FFO reconciling items (1)	—			411,455			—			822,910
NAREIT funds from operations (NAREIT FFO)	$	11,553,145		$	12,287,971		$	23,002,397		$	24,331,181
Add:
Distributions received from investment securities	55,714			252,213			59,665			475,379
Less:
Net distributions and dividend income	55,714			221,440			59,665			264,902
Net realized and unrealized gain (loss) on other equity securities	(881,100		)	614,634			(867,134		)	70,426
Income tax (expense) benefit from investment securities	220,500			(310,622		)	241,987			(114,862		)
Funds from operations adjusted for securities investments (FFO)	$	12,213,745		$	12,014,732		$	23,627,544		$	24,586,094
Add:
Provision for loan losses, net of tax	—			—			500,000			—
Transaction costs	24,615			211,269			56,896			470,051
Amortization of debt issuance costs	353,637			468,871			707,181			937,742
Amortization of deferred lease costs	22,983			22,983			45,966			45,966
Accretion of asset retirement obligation	127,928			160,629			255,856			321,258
Less:
Non-cash settlement of accounts payable	—			171,609			—			171,609
Non-cash gain (loss) associated with derivative instruments	—			(10,619		)	—			16,453
Income tax benefit	394,349			214,887			817,688			351,733
Non-Controlling Interest attributable to AFFO reconciling items (1)	—			3,358			—			6,709
Adjusted funds from operations (AFFO)	$	12,348,559		$	12,499,249		$	24,375,755		$	25,814,607
Weighted Average Shares of Common Stock Outstanding:
Basic	11,928,297			11,896,616			11,923,627			11,892,670
Diluted	15,382,843			15,351,161			15,378,172			15,347,215
NAREIT FFO attributable to Common Stockholders
Basic	$	0.97		$	1.03		$	1.93		$	2.05
Diluted (2)	$	0.89		$	0.94		$	1.78		$	1.87
FFO attributable to Common Stockholders
Basic	$	1.02		$	1.01		$	1.98		$	2.07
Diluted (2)	$	0.94		$	0.93		$	1.82		$	1.89
AFFO attributable to Common Stockholders
Basic	$	1.04		$	1.05		$	2.04		$	2.17
Diluted (3)	$	0.93		$	0.94		$	1.84		$	1.94
(1) There is no noncontrolling interest outstanding for the three and six months ended June 30, 2018.
(2) 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 I, Item 1, Note 10 ("Debt") for additional details.
(3) Diluted per share calculations include a dilutive adjustment for convertible note interest expense. Refer to the Convertible Note Interest Expense table in Part I, Item 1, Note 10 ("Debt") for additional details.

DIVIDENDS

Our portfolio of real property assets, promissory notes, and investment securities generates cash flow to us from which we pay distributions to stockholders. For the period ended June 30, 2018, the primary sources of our stockholder distributions include

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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 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 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. 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.

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.

On February 28, 2018, we paid dividends of $0.75 per share of common stock and $0.4609375 per depositary share for our 7.375% Series A Preferred Stock.

On May 31, 2018, we paid dividends of $0.75 per share of common stock and $0.4609375 per depository share for our 7.375% Series A Preferred Stock.

On July 25, 2018, our Board of Directors declared dividends of $0.75 per share of common stock and $0.4609375 per depositary share for our 7.375% Series A Preferred Stock payable on August 31, 2018.

MAJOR TENANTS

As of June 30, 2018, we had three significant leases. For additional information concerning each of these leases, see Part I, Item 1, Note 3 ("Leased Properties And Leases") included in this Report.

ASSET PORTFOLIO AND RELATED DEVELOPMENTS

For detailed descriptions of our asset portfolio and related operations, please refer to Part I, Item 2 "Properties" in our Annual Report on Form 10-K for the year ended December 31, 2017, and to Part I, Item 1, 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 that occurred during the period ended June 30, 2018.

Grand Isle Gathering System

On June 18, 2018, EGC announced a definitive agreement to be acquired by an affiliate of the privately-held Gulf of Mexico operator, Cox Oil, for approximately $322 million. On July 13, 2018, EGC filed a proxy detailing the terms of the proposed acquisition, which is expected to close in the third quarter of 2018 and requires stockholder approval. Since the announcement of the acquisition agreement, the Company and EGC have had no further discussions about ways in which the Company could have assisted EGC in its efforts to generate adequate liquidity to fund further development.

Pinedale LGS

UPL has continued to see promising results from its horizontal drilling program in the Pinedale field, with at least 700 net locations across 28,000 net acres outside the historical economic boundary of vertical well development and another 23,000 net acres beyond the 1,600 horizontal flank locations already identified. UPL announced that it continues to ramp up horizontal well development and plans to drill 25 to 30 wells in 2018, with a capital expenditure of $400 million. Given natural gas pricing constraints, the company plans to temporarily cease vertical well development, and focus drilling on horizontal wells due to their superior economic returns. UPL anticipates 2018 production between 285 to 295 Bcfe with average daily production of 780-800 MMcfe/d in the second quarter of 2018. Production is expected to grow from this level in the second half of the year from further horizontal well drilling.

Portland Terminal

Pursuant to the Portland Terminal lease agreement, the tenant has the right to repurchase the terminal from us, which first became effective in February 2017. Exercise of the repurchase option is subject to a 90-day notice requirement and the purchase price

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under the lease is based on nine times the greater of (i) the total of base and variable rent for the 12 months immediately preceding the notice or (ii) $7.3 million. The tenant also has the option to terminate the lease on its fifth and tenth anniversaries for a termination fee of $4.0 million and $6.0 million, respectively, subject to providing written notice 12 months in advance of termination.

We have not received any notice from Zenith regarding its intent to exercise either its buy-out option or termination option on the terminal. The 12-month advanced notice for intent to terminate the lease agreement on the fifth anniversary was required to be received by February 1, 2018. However, due to the recent acquisition of Arc Logistics by Zenith and based on our ongoing discussions with Zenith's management team, we entered into amendments with Zenith Terminals which have extended the notice period for the fifth anniversary termination option through September 1, 2018.

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 will continue at the full tariff rate of $12.385 per dekatherm per month until October 31, 2018, at which time the rate will be 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 the 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 anticipates the proposed revenue requirement would be approximately $20.0 million annually, and that the requested rates will go into effect on December 1, 2018, subject to refund upon final ruling.

CONTRACTUAL OBLIGATIONS

The following table summarizes our significant contractual payment obligations as of June 30, 2018:

Contractual Obligations
	Notional Value		Less than 1 year		1-3 years		3-5 years		More than 5 years
Pinedale LP Debt	$	39,236,000	$	3,528,000	$	7,056,000	$	28,652,000	$	—
Interest payments on Pinedale LP Debt			2,445,341		4,202,404		2,642,602		—
Convertible Debt	114,000,000		—		114,000,000		—		—
Interest payments on Convertible Debt			7,980,000		7,980,000		—		—
Totals			$	13,953,341	$	133,238,404	$	31,294,602	$	—

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 I, Item 1, Note 8 ("Management Agreement") included in this Report.

SEASONALITY

Our operating companies, MoGas and Omega, generally 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

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periods, we intend for substantially all of our tenant leases to be designed to mitigate the impact of inflation. Generally, 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 June 30, 2018, we had liquidity of approximately $159.8 million comprised of cash of $14.2 million plus revolver availability of $145.6 million. 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.

Cash Flows - Operating, Investing, and Financing Activities

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

	For the Six Months Ended
	June 30, 2018			June 30, 2017
	(Unaudited)
Net cash provided by (used in):
Operating activities	$	22,517,701		$	27,791,774
Investing activities	(36,384		)	48,083
Financing activities	(24,092,526		)	1,545,748
Net (decrease) increase in cash and cash equivalents	$	(1,611,209	)	$	29,385,605

Cash Flows from Operating Activities

Net cash flows provided by operating activities for the six months ended June 30, 2018 were primarily attributable to (i) lease receipts of $29.3 million ($35.9 million lease revenue, net of $3.7 million of straight-line rent accrued during the period and $2.9 million of unearned revenue received in 2017) and (ii) $6.7 million in net contributions from our operating subsidiaries MoGas and Omega, partially offset by (iii) $5.8 million in general and administrative expenses, (iv) $5.5 million in cash paid for interest and (v) $2.1 million of income tax payments, net.

Net cash flows provided by operating activities for the six months ended June 30, 2017 were primarily attributable to (i) lease receipts of $30.5 million ($34.1 million lease revenue, net of $3.6 million of straight-line rent accrued during the period), (ii) $7.1 million in net contributions from our operating subsidiaries MoGas and Omega, (iii) a $1.2 million reduction in accounts and other receivables during the period and (iv) $436 thousand in distributions and dividends received, partially offset by (v) $5.8 million in cash paid for interest and (vi) $5.6 million in general and administrative expenses.

Cash Flows from Investing Activities

There were no significant cash investing activities for the six months ended June 30, 2018 and 2017.

Cash Flows from Financing Activities

Net cash flows used in financing activities for the six months ended June 30, 2018 were primarily attributable to (i) common and preferred dividends paid of $17.3 million and $4.8 million, respectively, (ii) principal payments of $1.8 million on our secured credit facilities and (iii) $264 thousand of payments related to debt financing costs.

Net cash flows provided by financing activities for the six months ended June 30, 2017 were primarily attributable to (i) net offering proceeds on Series A Preferred Stock of $71.2 million, partially offset by (ii) repayment of principal on the CorEnergy Revolver of $44.0 million, (iii) common and preferred dividends paid of $17.3 million and $3.4 million, respectively, and (iv) principal payments of $4.4 million on our secured credit facilities.

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Revolving and Term Credit Facilities

CorEnergy 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 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 our senior secured recourse leverage ratio. The 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), all of which are substantially the same as under the prior facility.

We were in compliance with all covenants at June 30, 2018 and had approximately $145.6 million of available borrowing capacity on the CorEnergy Revolver. For a summary of the additional material terms of the CorEnergy Credit Facility, please refer to Part IV, Item 15, Note 11 ("Debt") included in our Annual Report on Form 10-K for the year ended December 31, 2017, and Part I, Item 1, Note 10 ("Debt") included in this Report.

Pinedale Credit Facility

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.

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 Pinedale Term Credit Facility).

Outstanding balances under the facility are secured by the Pinedale LGS assets. The Amended Pinedale 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 June 30, 2018.

For a summary of the additional material terms of the Pinedale Term Credit Facility, please see Part IV, Item 15, Note 11 ("Debt") included in our Annual Report on Form 10-K for the year ended December 31, 2017, and Part I, Item 1, Note 10 ("Debt") included in this Report.

Convertible Notes

As of June 30, 2018, we had $114.0 million of face value of the Convertible Notes outstanding. Refer to Part IV, Item 15, Note 11 ("Debt") included in our Annual Report on Form 10-K for the year ended December 31, 2017 and Part I, Item 1, Note 10 ("Debt") included in this Report for additional information concerning the Convertible Notes.

MoGas Credit Facility

On July 28, 2017, the terms of the MoGas Revolver were amended and restated in connection with the CorEnergy Credit Facility, as discussed above. As a result, commitments under the MoGas Revolver were reduced to $1.0 million. Refer to Part I, Item 1, Note 10 ("Debt") for further information. As of June 30, 2018, the co-borrowers were in compliance with all covenants and there are no borrowings outstanding on the MoGas Revolver.

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Mowood/Omega Revolver

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. Following annual extensions, the current maturity of the facility has been amended and extended to July 31, 2019. Interest accrues at LIBOR plus 4 percent and is payable monthly in arrears with no unused fee. There was no outstanding balance at June 30, 2018.

Shelf Registration

On February 18, 2016, we had a new shelf registration statement declared effective by the SEC, 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 June 30, 2018, we have issued 79,153 shares of common stock under our dividend reinvestment plan pursuant to the February 18, 2016 shelf, reducing availability by approximately $2.4 million. Shelf availability was further reduced by approximately $73.8 million as a result of the follow-on offering of additional 7.375% Series A Preferred Stock during the second quarter of 2017. As of June 30, 2018, availability on the current shelf registration is approximately $523.8 million.

Liquidity and Capitalization

Our principal investing activities are 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. These investing activities have generally been financed from the proceeds of our public equity and debt offerings as well as our 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 is our liquidity and capitalization as of June 30, 2018 and December 31, 2017:

Liquidity and Capitalization
	June 30, 2018		December 31, 2017
Cash and cash equivalents	$	14,175,860	$	15,787,069
Revolver availability	$	145,591,246	$	140,499,846
Revolving credit facility	$	—	$	—
Long-term debt (including current maturities)	151,424,375		152,777,437
Stockholders' equity:
Series A Preferred Stock 7.375%, $0.001 par value	130,000,000		130,000,000
Capital stock, non-convertible, $0.001 par value	11,934		11,916
Additional paid-in capital	322,815,994		331,773,716
CorEnergy equity	452,827,928		461,785,632
Total CorEnergy capitalization	$	604,252,303	$	614,563,069

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 both June 30, 2018 and December 31, 2017.

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 GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, recognition of distribution income, and disclosure of contingent assets and liabilities at the date of the consolidated financial statements. Actual results could differ from those estimates.

A discussion of our critical accounting estimates is presented under the heading "Critical Accounting Estimates" in Part II, Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations" in our Annual Report on Form 10-K for the year ended December 31, 2017, as previously filed with the SEC. No material modifications have been made to our critical accounting estimates.

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ITEM 3. 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 and fluctuations in interest rates to be our principal market risks. As of June 30, 2018, there were no material changes to our market risk exposure as compared to the end of our preceding fiscal year ended December 31, 2017.

As of June 30, 2018, the fair value of our securities portfolio (excluding short-term investments) totaled approximately $2.1 million. We estimate that the impact of a 10 percent increase or decrease in the fair value of these securities, net of related deferred taxes, would increase or decrease net assets applicable to common stockholders by approximately $150 thousand.

Our securities portfolio is reported at fair value. The fair value of securities is determined using readily available market quotations from the principal market, if available. Because there are no readily available market quotations for any of the securities in our portfolio, we value 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 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 June 30, 2018, we had long-term debt (net of current maturities) with a carrying value of $147.9 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 June 30, 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 4. CONTROLS AND PROCEDURES

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 Securities Exchange Act of 1934, as amended, 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 information required to be disclosed by us in the reports that we file or submit under the Securities Exchange Act of 1934 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 Rules 13a-15(f) and 15d-15(f) of the Exchange Act, that occurred during the quarterly period ending June 30, 2018 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. 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 1A. RISK FACTORS

Part I, Item 1A, "Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2017, sets forth information relating to important risks and uncertainties that could materially adversely affect our business, financial condition, or operating results. Those risk factors continue to be relevant to an understanding of our business, financial condition, and operating results for the quarter ended June 30, 2018. There have been no material changes to the risk factors contained in our Annual Report on Form 10-K for the year ended December 31, 2017.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

During the six months ended June 30, 2018, we did not sell any securities that were not registered under the 1933 Act, nor did we repurchase any equity securities of the Company.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS

Exhibit No.		Description of Document
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.
12.1*		Computation of Ratio of Earnings to Combined Fixed Charges and Preferred Stock Dividends.
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.
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.
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.
101**		The following materials from CorEnergy Infrastructure Trust, Inc.'s Quarterly Report on Form 10-Q for the quarter ended June 30, 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.
*	Filed herewith.
**	Furnished herewith.

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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 Officer and Principal Financial Officer)
	August 2, 2018
By:	/s/ David J. Schulte
	David J. Schulte
	Chief Executive Officer and Director
	(Principal Executive Officer)
	August 2, 2018

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