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•	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;

•	the ability and willingness of each of our tenants to satisfy their obligations under the respective lease agreements;

•	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;

•	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 recent outbreak of COVID-19 and certain developments in the global oil markets, including the general decline in business activity and demand affecting our tenants' operations and ability or willingness to pay rent;

•	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;

•	our continued ability to access the debt and equity markets, including our ability to continue using our SEC shelf registration statements;

•	our ability to comply with certain debt covenants;

•	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 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;

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

•	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;

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•	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.

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

Basis of Presentation

The accompanying consolidated financial statements include CorEnergy accounts and the accounts of its wholly-owned subsidiaries and have been prepared in accordance with U.S. generally accepted accounting principles ("GAAP") set forth in the Accounting Standards Codification ("ASC"), as published by the Financial Accounting Standards Board ("FASB"), and with the Securities and Exchange Commission ("SEC") instructions to Form 10-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.

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 partnerships.

In June of 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

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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. In November of 2019, the FASB issued ASU 2019-10, Financial Instruments - Credit Losses (Topic 326), Derivatives and Hedging (Topic 815), and Leases (Topic 842) Effective Dates, which deferred the effective dates of these standards for certain entities. Based on the guidance for smaller reporting companies, the effective date of ASU 2016-13 is deferred for the Company until fiscal year 2023 with early adoption permitted, and the Company has elected to defer adoption of this standard.

Although the Company has elected to defer adoption of ASU 2016-13, it will continue to evaluate the potential impact of the standard on its consolidated financial statements. As part of its ongoing assessment work, the Company has formed an implementation team, completed training on the CECL model and has begun developing policies, processes and internal controls.

The Company primarily acquires mid-stream and downstream assets in the U.S. energy sector such as pipelines, storage terminals, and gas and electric distribution systems and leases these assets to operators under triple-net leases. These leases typically include a contracted base rent with escalation clauses and participating rents that are tied to contract-specific criteria. Base rents under the Company's leases are structured on an estimated fair market value rent structure over the initial term, which includes assumptions related to the terminal value of the assets and expectations of tenant renewals. At the conclusion of the initial lease term, the Company's leases may contain fair market value repurchase options or fair market rent renewal terms. These clauses also act as safeguards against the Company's tenants pursuing activities which would undermine or degrade the value of the assets faster than the underlying reserves are depleted. Participating rents are structured to provide exposure to the successful commercial activity of the tenant, and as such, also provide protection in the event that the economic life of the assets is reduced based on accelerated production by the Company's tenants. While the Company is primarily a lessor, certain of its operating subsidiaries are lessees and have entered into lease agreements as discussed further below.

LESSOR - LEASED PROPERTIES

The Company's current leased properties are classified as operating leases and are recorded as leased property in the Consolidated Balance Sheets. Base rent related to the Company's leased property is recognized on a straight-line basis over the term of the lease when collectibility is probable. Participating rent is recognized when it is earned, based on the achievement of specified performance criteria. Base and participating rent are recorded as lease revenue in the Consolidated Statements of Operations. The Company regularly evaluates the collectibility of any deferred rent receivable on a lease by lease basis. The evaluation primarily includes assessing the financial condition and credit quality of the Company's tenants, changes in tenant's payment history and current economic factors. When the collectibility of the deferred rent receivable or future lease payments are no longer probable, the Company will recognize a write-off of the deferred rent receivable as a reduction of revenue in the Consolidated Statements of Operations.

As of June 30, 2020, following the sale of the Pinedale LGS effective as of such date (refer to "Impairment and Sale of the Pinedale Liquids Gathering System" below), the Company had one significant property located in Louisiana and the Gulf of Mexico leased on a triple-net basis to a major tenant, described in the table below. The major tenant is responsible for the payment of all taxes, maintenance, repairs, insurance, and other operating expenses relating to the leased property. The Company's long-term, triple-net leases generally have an initial term with options for renewals. Lease payments are scheduled to increase at varying intervals during the initial term of the lease. The following table summarizes the significant leased property, major tenant and lease term:

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Summary of Leased Property, Major Tenant and Lease Terms
Property	Grand Isle Gathering System
Location	Gulf of Mexico/Louisiana
Tenant	Energy XXI GIGS Services, LLC
Asset Description	Approximately 137 miles of offshore pipeline with total capacity of 120 thousand Bbls/d, including a 16-acre onshore terminal and saltwater disposal system.
Date Acquired	June 2015
Initial Lease Term	11 years
Renewal Option	Equal to the lesser of 9-years or 75 percent of the remaining useful life
Current Monthly Rent Payments	7/1/2019 - 6/30/2020: $3,223,917 7/1/2020 - 6/30/2021: $4,033,583
Estimated Useful Life(1)	15 years
(1) In conjunction with the impairment of the Grand Isle Gathering System discussed below, the remaining estimated useful life of the GIGS asset was adjusted to approximately 15 years beginning in the second quarter of 2020. Additionally, the Company updated the useful life of its asset retirement obligation ("ARO") segments resulting in a change to the timing of the undiscounted cash flows. The timing change resulted in an increase to the ARO asset and liability of approximately $257 thousand.

LEASED PROPERITES AND 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.

The COVID-19 pandemic-related reduction in energy demand and the uncertainty of production from OPEC members, US producers and other international suppliers caused significant disruptions and volatility in the global oil marketplace during the first and second quarters of 2020. In response to COVID-19, governments around the world have implemented increasingly stringent measures to help reduce the spread of the virus, including stay-at-home and shelter-in-place orders, travel restrictions and other measures. These measures have adversely affected the economies and financial markets of the U.S. and many other countries, resulting in an economic downturn that has negatively impacted global demand and prices for the products handled by the Company's pipelines, terminals and other facilities.

The events and conditions described above adversely impacted the Gulf of Mexico operations of the EGC Tenant, the tenant of the GIGS asset, under the Grand Isle Gathering Lease as discussed under "Energy Gulf Coast/Cox Oil" and "Grand Isle Gathering System" below.

Energy Gulf Coast/Cox Oil

Prior to October 29, 2018, EGC was subject to the reporting requirements of the Exchange Act and was required to file with the SEC annual reports containing audited financial statements and quarterly reports containing unaudited financial statements. So long as EGC remained a public reporting company, the Grand Isle Lease Agreement provided this requirement was fulfilled by EGC making its financial statements and reports publicly available through the SEC’s EDGAR system, in lieu of delivering such information directly to the Company. On October 18, 2018, EGC was acquired by an affiliate of privately-held Cox Oil. Upon the filing by EGC of a Form 15 with the SEC on October 29, 2018, EGC's SEC reporting obligations were suspended and it ceased to file such reports.

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

The terms of the Grand Isle Lease Agreement require copies of certain financial statement information be provided that the Company is required to file pursuant to SEC Regulation S-X, as described in Section 2340 of the SEC Financial Reporting Manual. When EGC's financial information ceased to be publicly available, the Company encouraged officials of EGC and Cox Oil and, through Company counsel, the legal counsel to such entities, to satisfy their obligations under the Grand Isle Lease Agreement to provide the required information to the Company for inclusion in its SEC reports. To date, EGC and Cox Oil have refused to fulfill these

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obligations. The Company sought to enforce the obligations of EGC and Cox Oil and obtained a temporary restraining order ("TRO") from a Texas state court, mandating that they deliver the required EGC financial statements for the year ended December 31, 2018. The TRO was stayed pending an appeal by EGC and Cox Oil and, pursuant to its own terms, had lapsed by the time that appeal was denied on January 6, 2020. The case was remanded to the trial court for further proceedings. In May 2020, the trial court granted the Company's motion for summary judgment mandating the tenant deliver the required financial statements. The Company believes that it is entitled to such relief and will continue to pursue this litigation and all viable options to obtain and file the necessary financial statements. The Company expects to file the financial statement information that is required by Regulation S-X by amendment to its Annual Reports on Form 10-K for the year ended December 31, 2019, once such information is made available in accordance with the terms of the lease.

On April 1, 2020, the EGC Tenant, a wholly owned indirect subsidiary of Cox Oil, elected to cease paying rent due. EGC Tenant is contractually obligated to pay rent and rent continues to accrue whether or not oil is being shipped. EGC Tenant is a special purpose entity engaged solely in activities related to the lease, and it does not own or operate any wells. EGC, parent of the EGC Tenant, owns and operates wells, including those connected to GIGS, and is the guarantor of the EGC Tenant's obligations under the lease. Following EGC Tenant's failure to pay rent due for April of 2020, and following discussions with Cox Oil management concerning its various operations, the Company sent EGC Tenant and EGC a notice of non-payment. After the required two-day cure period, a default occurred under the lease.

The EGC Tenant also failed to make required rent payments for May, June, July and August of 2020. As a result, the Company initiated litigation in the State Court of Texas to recover the unpaid rent, plus interest, for April, May, June and July of 2020 from the EGC Tenant. Further, EGC filed an action to attempt to set aside the guarantee obligations of EGC under the lease. The Company intends to enforce its rights under the lease and expects to be able to enforce the guaranty.

Grand Isle Gathering System

The Company identified the EGC Tenant's nonpayment of rent discussed above along with the significant decline in the global oil market as indicators of impairment for the GIGS asset. As a result, the Company assessed the GIGS asset for impairment as of March 31, 2020. The Company performed a step 1 impairment assessment on the GIGS asset by estimating the undiscounted contractual cash flows relating to the lease using probability-weighted scenarios, which indicated that the GIGS asset's carrying value was not recoverable. As a result, the fair value of the GIGS asset was estimated through the use of probability-weighted discounted estimated cash flow scenarios to measure the impairment loss. The probability-weighted cash flows used to assess recoverability of the GIGS asset and measure its fair value were developed using assumptions related to the Grand Isle Lease Agreement and near-term crude oil and water price and volume projections reflective of the current environment and management's projections for long-term average prices and volumes. In addition to near and long-term price assumptions, other key assumptions include the timing and collectibility of lease payments, operating costs, timing of incurring such costs and the use of an appropriate discount rate. The Company believes its estimates and models used to determine fair value are similar to what a market participant would use.

The Company engaged specialists and other third-parties to assist with the valuation methodology and analysis of certain underlying assumptions. The fair value measurement of the GIGS asset was based, in part, on significant inputs not observable in the market (as discussed above) and thus represents a Level 3 measurement. The significant unobservable input used includes a discount rate based on an estimated weighted average cost of capital of a theoretical market participant. We utilized a weighted average discount rate of 10.0 percent when deriving the fair value of the GIGS asset impaired during the quarter. The weighted average discount rate reflects management's best estimate of inputs a market participant would utilize. For the six months ended June 30, 2020, the Company recognized a $140.3 million loss on impairment of leased property related to the GIGS asset in the Consolidated Statements of Operations. As of June 30, 2020, the carrying value of the GIGS asset is $66.0 million, which is included in leased properties on the Consolidated Balance Sheet.

The Company previously recognized a deferred rent receivable for the Grand Isle Gathering Lease, which primarily represents timing differences between the straight-line revenue recognition and contractual lease receipts over the lease term. Given the EGC's Tenant's nonpayment of rent in the second quarter of 2020 and the Company's expectations surrounding the collectibility of the contractual lease payments under the lease, the Company does not currently expect the deferred rent receivable to be recoverable. Accordingly, the Company recognized a non-cash write-off of the deferred rent receivable of $30.1 million for the six months ended June 30, 2020. The non-cash write-off was recognized as a reduction of revenue in the Consolidated Statements of Operations.

Impairment and Sale of the Pinedale Liquids Gathering System

On April 14, 2020, UPL, the parent and guarantor of the lease obligations of the tenant and operator of the Company's Pinedale LGS, announced that its significant indebtedness and extremely challenging current market conditions raised a substantial doubt

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about its ability to continue as a going concern. The going concern qualification in UPL's financial statements filed in its 2019 10-K resulted in defaults under UPL's credit and term loan agreement. UPL also disclosed that it elected not to make interest payments on certain outstanding indebtedness, triggering a 30-day grace period. If such interest payments were not made by the end of the grace period, an event of default would occur, potentially causing its outstanding indebtedness to become immediately due and payable. UPL further disclosed that if it was unable to obtain sufficient additional capital to repay the outstanding indebtedness and sufficient liquidity to meet its operating needs, it may be necessary for UPL to seek protection from creditors under Chapter 11 of the U.S. Bankruptcy Code.

On May 14, 2020, UPL filed a voluntary petition to reorganize under Chapter 11 of the U.S. Bankruptcy Code. The filing includes Ultra Wyoming, the operator of the Pinedale LGS and tenant under the Pinedale Lease Agreement with the Company’s indirect wholly owned subsidiary Pinedale LP. The bankruptcy filing of both the guarantor, UPL, and the tenant constitute defaults under the terms of the Pinedale Lease Agreement. The bankruptcy filing imposed a stay of CorEnergy’s ability to exercise remedies for the foregoing defaults. Ultra Wyoming also filed a motion to reject the Pinedale Lease Agreement, with a request that such motion be effective June 30, 2020. Pending the effective date of the rejection, Section 365 of the Bankruptcy Code generally requires Ultra Wyoming to comply on a timely basis with the provisions of the Pinedale Lease Agreement, including the payment provisions. Accordingly, the Company received the rent payments due on the first day of April, May and June 2020.

Pinedale LP, along with Prudential, the lender under the Amended Pinedale Term Credit Facility discussed in Note 10 ("Debt"), commenced discussions with UPL which resulted in UPL presenting an initial offer to purchase the Pinedale LGS. The Amended Pinedale Term Credit Facility was secured by the Pinedale LGS and was not secured by any assets of CorEnergy or its other subsidiaries.

On June 5, 2020, Pinedale LP filed a motion with the U.S. Bankruptcy Court objecting to Ultra Wyoming's motion to reject the Pinedale Lease Agreement while continuing its negotiations with UPL. Pinedale LP and the Company agreed in principle to terms with Ultra Wyoming to sell the Pinedale LGS for $18.0 million cash as set forth in a non-binding term sheet that was filed with the U.S. Bankruptcy Court in UPL’s Chapter 11 case along with a motion for approval of the transaction on June 22, 2020. A copy of the draft definitive purchase and sale agreement was also filed with the motion. The closing of the sale was subject to the satisfaction of certain closing conditions, including but not limited to (i) a release of all liens under the Amended Pinedale Term Credit Facility, (ii) a release by Pinedale LP of all claims against UPL and Ultra Wyoming arising from the rejection or termination of the Pinedale Lease Agreement, (iii) the release by Ultra Wyoming of all claims against Pinedale LP and the Company and (iv) approval of the definitive purchase and sale agreement and the closing of the transaction by the bankruptcy court in UPL's Chapter 11 case.

On June 26, 2020, the U.S. Bankruptcy Court in UPL’s Chapter 11 case approved the sale of the Pinedale LGS. Following such approval, on June 29, 2020, Pinedale LP entered into the purchase and sale agreement (the "Sale Agreement") with Ultra Wyoming. On June 30, 2020, Pinedale LP closed on the sale of the Pinedale LGS to its tenant, Ultra Wyoming, for total cash consideration of $18.0 million, and the Pinedale Lease Agreement was terminated. The sale was completed pursuant to the terms of the Sale Agreement previously approved by the bankruptcy court as discussed above. In connection with the closing of the sale, the Company and Pinedale LP entered into a mutual release of all claims related to the Pinedale LGS and the Pinedale Lease Agreement with UPL and Ultra Wyoming, including a release by Pinedale LP of all claims against UPL and Ultra Wyoming arising from the rejection or termination of the Pinedale Lease Agreement.

In conjunction with the sale of the Pinedale LGS described above, Pinedale LP and the Company entered into a compromise and release agreement (the "Release Agreement") with Prudential related to the Amended Pinedale Term Credit Facility, which had an outstanding balance of approximately $32.0 million, net of $132 thousand of deferred debt issuance costs. Pursuant to the Release Agreement, the $18.0 million sale proceeds from the Sale Agreement were provided by Ultra Wyoming directly to Prudential. The Company also provided the remaining cash available at Pinedale LP of approximately $3.3 million (including $198 thousand for accrued interest) to Prudential in exchange for (i) the release of all liens on the Pinedale LGS and the other assets of Pinedale LP, (ii) the termination of the Company’s pledge of equity interests of the general partner of Pinedale LP, (iii) the termination and satisfaction in full of the obligations of Pinedale LP under the Amended Pinedale Term Credit Facility and (iv) a general release of any other obligations of Pinedale LP and/or the Company and their respective directors, officers, employees or agents pertaining to the Amended Pinedale Term Credit Facility.

During the negotiation and closing of the sale of the Pinedale LGS to Ultra Wyoming, the Company determined impairment indicators existed as the value to be received from the sale was less than the carrying value of the asset. As a result of these indicators and the sale of the Pinedale LGS, the Company recognized a loss on impairment and disposal of leased property in the Consolidated Statement of Operations of approximately $146.5 million for the three and six months ended June 30, 2020. Further, the sale of the Pinedale LGS resulted in the termination of the Pinedale Lease Agreement, and the Company recognized a loss on termination of lease of approximately $458 thousand for the three and six months ended June 30, 2020. These losses were partially offset by

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the settlement of the Amended Pinedale Term Credit Facility with Prudential (as discussed above and in Note 10 ("Debt")), which resulted in a gain on extinguishment of debt of $11.0 million for the three and six months ended June 30, 2020.

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

	As a Percentage of (1)
	Leased Properties						Lease Revenues
	As of						For the Three Months Ended						For the Six Months Ended
	June 30, 2020			December 31, 2019			June 30, 2020			June 30, 2019			June 30, 2020			June 30, 2019
Pinedale LGS(2)	—	%		44.4	%		99.6	%		38.8	%		52.1	%		38.9	%
Grand Isle Gathering System(3)	98.1	%		55.3	%		—	%		61.1	%		47.7	%		61.0	%
(1) Insignificant leases are not presented; thus, percentages may not sum to 100%.
(2) Pinedale LGS lease revenues include variable rent of $0 and $28 thousand for the three and six months ended June 30, 2020, respectively, compared to $1.0 million and $2.1 million for the three and six months ended June 30, 2019, respectively. The Pinedale LGS was sold to Ultra Wyoming and the Pinedale Lease Agreement was terminated on June 30, 2020, as discussed above.
(3) As of June 30, 2020, the Grand Isle Gathering System's percentage of leased properties increased as a result of the sale of the Pinedale LGS on June 30, 2020. For the six months ended June 30, 2020, the Grand Isle Gathering System's percentage of lease revenues is exclusive of the deferred rent receivable write-off discussed above.

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

	For the Three Months Ended								For the Six Months Ended
	June 30, 2020				June 30, 2019				June 30, 2020				June 30, 2019
Depreciation Expense
GIGS	$	1,190,911			$	2,440,790			$	3,631,499			$	4,881,581
Pinedale	1,478,239				2,217,360				3,695,599				4,434,720
United Property Systems	9,831				9,831				19,662				19,455
Total Depreciation Expense	$	2,678,981			$	4,667,981			$	7,346,760			$	9,335,756
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	$	116,514			$	110,993			$	228,685			$	221,985
Total ARO Accretion Expense	$	116,514			$	110,993			$	228,685			$	221,985

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, 2020				December 31, 2019
Net Deferred Lease Costs
GIGS	$	183,473			$	198,755
Pinedale	—				488,981
Total Deferred Lease Costs, net	$	183,473			$	687,736

LESSEE - LEASED PROPERTIES

The Company's operating subsidiaries currently lease single-use office space with remaining lease terms of approximately two years, some of which may include renewal options. These leases are classified as operating leases and immaterial to the consolidated financial statements. The Company recognizes lease expense in the Consolidated Statements of Operations on a straight-line basis over the remaining lease term.

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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 improvement. 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. System maintenance and improvement contracts are specific and tailored to the customer's needs, have no alternative use and have an enforceable right to payment as the services are provided. Revenue is recognized on an input method, based on the actual cost of service as a measure of the performance obligation satisfaction. Differences between amounts invoiced and revenue recognized under the input method are reflected as an asset or liability on the Consolidated Balance Sheets. The costs of system improvement projects are recognized as a financing arrangement in accordance with guidance in the lease standard while the margin is recognized in accordance with the revenue standard as discussed above.

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. 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. Following the November 2018 rate decline, recognized performance obligations exceeded amounts invoiced and the contract liability began to decline at a rate of approximately $138 thousand per quarter and will continue to decline at the same rate through the end of the contract in October 2030. As of June 30, 2020, the revenue allocated to the remaining performance obligation under this contract is approximately $55.4 million.

The table below summarizes the Company's contract liability balance related to its transportation and distribution revenue contracts as of June 30, 2020:

	Contract Liability(1)
	June 30, 2020				December 31, 2019
Beginning Balance January 1	$	6,850,790			$	6,522,354
Unrecognized Performance Obligations	(10,222		)		887,916
Recognized Performance Obligations	(577,470		)		(559,480		)
Ending Balance	$	6,263,098			$	6,850,790
(1) The contract liability balance is included in unearned revenue in the Consolidated Balance Sheets.

The Company's contract asset balance was $33 thousand and $206 thousand as of June 30, 2020 and December 31, 2019, respectively. The contract asset balance is included in prepaid expenses and other assets 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, 2020 and 2019:

	For the Three Months Ended						For the Six Months Ended
	June 30, 2020			June 30, 2019			June 30, 2020			June 30, 2019
Natural gas transportation contracts	68.0	%		57.6	%		68.4	%		59.5	%
Natural gas distribution contracts	27.2	%		35.0	%		25.0	%		34.9	%

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.

Four Wood Financing Note Receivable

On December 12, 2018, Four Wood Corridor granted SWD Enterprises, LLC, the previous debtor, approval to sell the assets securing the SWD loans to Compass SWD, LLC ("Compass SWD") in exchange for Compass SWD executing a new loan agreement with Four Wood Corridor for $1.3 million (the "Compass REIT Loan"). On June 12, 2019, Four Wood Corridor entered into an

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amended and restated Compass REIT Loan. The amended note had a two-year term maturing on June 30, 2021 with monthly principal payments of approximately $11 thousand and interest accruing on the outstanding principal at an annual rate of 8.5 percent. The amended and restated Compass REIT Loan is secured by real and personal property that provides saltwater disposal services for the oil and natural gas industry and pledged ownership interests of Compass SWD members.

On May 22, 2020, the terms of the Compass REIT Loan were amended (i) to extend the maturity date from June 30, 2021 to November 30, 2024 and (ii) to reduce payments to interest only through December 31, 2020. Additionally, the amended Compass REIT Loan will continue to accrue interest at an annual rate of 8.5 percent through May 31, 2021. Subsequent to May 31, 2021 interest will accrue at an annual rate of 12.0 percent. Monthly principal payments of approximately $11 thousand will resume on January 1, 2021 and increase annually beginning on June 30, 2021 through the maturity date. As of June 30, 2020 and December 31, 2019, the Compass REIT Loan was valued at $1.2 million.

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, 2020 and December 31, 2019, are as follows:

Deferred Tax Assets and Liabilities
	June 30, 2020				December 31, 2019
Deferred Tax Assets:
Deferred contract revenue	$	1,458,883			$	1,529,473
Net operating loss carryforwards	6,138,726				5,622,052
Accrued liabilities	—				424,604
Capital loss carryforward	92,418				104,595
Other	6,184				6,184
Sub-total	$	7,696,211			$	7,686,908
Valuation allowance	(92,418		)		(104,595		)
Sub-total	$	7,603,793			$	7,582,313
Deferred Tax Liabilities:
Cost recovery of leased and fixed assets	$	(3,264,463	)		$	(2,953,319	)
Other	(44,294		)		(35,433		)
Sub-total	$	(3,308,757	)		$	(2,988,752	)
Total net deferred tax asset	$	4,295,036			$	4,593,561

As of June 30, 2020, 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, 2015 remain open to examination by federal and state tax authorities.

On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act (the "CARES Act") was enacted in response to the COVID-19 pandemic. The CARES Act, among other things, permits net operating loss ("NOL") carryovers and carrybacks to offset 100 percent of taxable income for taxable years beginning before 2021. In addition, the CARES Act allows NOLs originating in 2018, 2019 and 2020 to be carried back to each of the five preceding taxable years to generate a refund of previously paid income taxes. Certain of the Company’s TRSs have NOLs totaling approximately $1.2 million that are eligible for carryback under the CARES Act. The benefit of these carrybacks has been recorded as an increase to income taxes receivable and a reduction to deferred tax assets. Certain NOLs which were initially measured at the current corporate income tax rate of 21 percent are being carried back to offset taxable income that was taxed at a pre-Tax Cuts and Jobs Act of 2017 rate of 34 percent. The benefit received from the rate differential is reflected in the income tax provision for the three and six months ended June 30, 2020.

For the year ended December 31, 2019, the Company generated a capital loss carryforward resulting from the liquidation of Lightfoot. The capital loss decreased upon receipt of the final 2019 K-1's in the first quarter of 2020. The amount of the carryforward for tax purposes was approximately $440 thousand and $500 thousand as of June 30, 2020 and December 31, 2019, respectively, and if not utilized, this carryforward will expire as of December 31, 2024. Management assessed the available evidence and determined that it is more likely than not that the capital loss carryforward will not be utilized prior to expiration. Due to the uncertainty of realizing this deferred tax asset, a valuation allowance of $92 thousand and $105 thousand was recorded equal to the amount of the tax benefit of this carryforward at June 30, 2020 and December 31, 2019, respectively. In the future, if the

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Company concludes, based on existence of sufficient evidence, that it should realize more or less of its deferred tax assets, the valuation allowance will be adjusted accordingly in the period such conclusion is made.

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, 2020 and 2019 to income (loss) 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, 2020				June 30, 2019				June 30, 2020				June 30, 2019
Application of statutory income tax rate	$	(28,876,735	)		$	2,078,209			$	(62,910,824	)		$	2,984,102
State income taxes, net of federal tax expense	(9,298		)		7,538				25,211				523,564
Federal Tax Attributable to Income of Real Estate Investment Trust	28,811,858				(2,025,403		)		62,946,202				(2,941,388		)
Other	348				2,355				(159,138		)		(56,244		)
Total income tax expense (benefit)	$	(73,827	)		$	62,699			$	(98,549	)		$	510,034

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, 2020				June 30, 2019				June 30, 2020				June 30, 2019
Current tax expense (benefit)
Federal	$	(2,431	)		$	—			$	(412,074	)		$	216,093
State (net of federal tax expense (benefit))	—				—				15,000				137,651
Total current tax expense (benefit)	$	(2,431	)		$	—			$	(397,074	)		$	353,744
Deferred tax expense (benefit)