SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
Dec. 31, 2023
Accounting Policies [Abstract]
SIGNIFICANT ACCOUNTING POLICIES	SIGNIFICANT ACCOUNTING POLICIES A. Use of Estimates – The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. In December 2023, the Company completed an assessment of the useful lives of its crude oil pipelines and related equipment. Due to advances in green energy initiatives in the State of California, the Company determined the useful life of the primary asset (crude oil pipelines) should be 25 years. This resulted in changes to useful lives across our crude oil pipeline asset portfolio. However, our primary asset, as defined under ASC 360, "Property, Plant and Equipment," decreased from 35 years to 25 years. This change in accounting estimate was effective beginning December 1, 2023. Based on the carrying amount of crude oil pipelines and related equipment that was in-service as of December 1, 2023, this change increased depreciation expense by $41 thousand for the year ended December 31, 2023. B. Leased Property and Leases – In February of 2016, the FASB issued ASU 2016-02, Leases ("ASU 2016-02" or "ASC 842"), which amends the existing accounting standards for lease accounting and requires, lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. Beginning in 2019, for the underlying asset class related to single-use office space, the Company accounts for each separate lease component and non-lease component as a single lease component. For the underlying lessor asset class related to pipelines residing on military bases, the Company accounts for each separate lease component and non-lease component as a single lease component if the non-lease components otherwise are accounted for in accordance with the revenue standard, and both the following criteria are met: (i) the timing and pattern of revenue recognition are the same for the non-lease component(s) and the related lease component and (ii) the lease component will be classified as an operating lease. The Company carried forward the accounting treatment for land easements under existing agreements, which are currently accounted for within property, plant and equipment. Land easements are reassessed under ASC 842 when such agreements are modified. The Company's current leased properties are classified as operating leases and are recorded as leased property, net of accumulated depreciation, in the Consolidated Balance Sheets. Initial direct costs incurred in connection with the creation and execution of a lease prior to January 1, 2019 are capitalized and amortized over the lease term. Subsequent to January 1, 2019, initial direct costs under ASC 842 are incremental costs of a lease that would not have been incurred if the lease had not been obtained and may include commissions or payments made to an existing tenant as an incentive to terminate its lease. Base rent related to the Company's leased property is recognized on a straight-line basis over the term of the lease when collectability is 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. Rental payments received in advance are classified as unearned revenue and included as a liability within the Consolidated Balance Sheets. Unearned revenue is amortized ratably over the lease period as revenue recognition criteria are met. Rental payments received in arrears are accrued and classified as deferred rent receivable and included in assets within the Consolidated Balance Sheets. Under the Company's previously held triple-net leases, the tenant was required to pay property taxes and insurance directly to the applicable third-party providers. Consistent with guidance in ASC 842, the Company will present the cost and the lessee's direct payment to the third-party under the triple-net leases on a net basis in the Consolidated Statements of Operations. C. Property and Equipment – Property and equipment are stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful life of the asset. Expenditures for repairs and maintenance are charged to operations as incurred, and improvements, which maintain the existing operating capacity of assets or extend their useful lives, are capitalized and depreciated over the remaining estimated useful life of the asset. The Company initially records long-lived assets at their purchase price plus any direct acquisition costs, unless the transaction is accounted for as a business combination, in which case the acquisition costs are expensed as incurred. If the transaction is accounted for as a business combination, the Company allocates the purchase price to the acquired tangible and intangible assets and liabilities based on their estimated fair values. D. Long-Lived Asset Impairment – The Company's long-lived assets consist primarily of oil and natural gas pipelines that have been obtained through asset acquisitions and a business combination. Management continually monitors its business, the business environment and performance of its operations to determine if an event has occurred that indicates that the carrying value of a long-lived asset group may be impaired. When a triggering event occurs, which is a determination that involves judgment, management utilizes cash flow projections to assess its ability to recover the carrying value of the asset group based on the long-lived assets' ability to generate future cash flows on an undiscounted basis over the remaining useful life of the primary asset. Management's projected cash flows of long-lived assets are primarily based on estimated cash flows that extend many years into the future. If those cash flow projections indicate that the long-lived asset's carrying value is not recoverable, management records an impairment charge for the excess of carrying value of the asset over its fair value. The estimate of fair value considers a number of factors, including the potential value that would be received if the asset were sold, discount rates and projected cash flows. Inputs and assumptions used in the cash flow models include estimates of projected volumes transported on the Company's pipelines, projected tariff rates and estimated operating costs, among others. Due to the imprecise nature of these projections and assumptions, actual results can differ from management's estimates. E. Financing Notes Receivable – Financing notes receivable are presented at face value plus accrued interest receivable and deferred loan origination costs and net of related direct loan origination income. Each quarter, the Company reviews its financing notes receivable to determine if the balances are realizable based on factors affecting the collectability of those balances. Factors may include credit quality, timeliness of required periodic payments, past due status and management discussions with obligors. The Company evaluates the collectability of both interest and principal of each of its loans to determine if an allowance is needed. An allowance will be recorded when based on current information and events, the Company determines it is probable that it will be unable to collect all amounts due according to the existing contractual terms. If the Company determines an allowance is necessary, the amount deemed uncollectible is expensed in the period of determination. An insignificant delay or shortfall in the amount of payments does not necessarily result in the recording of an allowance. Generally, when interest and/or principal payments on a loan become past due, or if the Company does not otherwise expect the borrower to be able to service its debt and other obligations, the Company will place the loan on non-accrual status and will typically cease recognizing financing revenue on that loan until all principal and interest have been brought current. Interest income recognition is resumed if and when the previously reserved-for financing notes become contractually current and performance has been demonstrated. Payments received subsequent to the recording of an allowance will be recorded as a reduction to principal. During the year ended December 31, 2023, the Company recorded a $50 thousand provision for loan loss upon the adoption of ASU 2016-13 Financial Instruments—Credit Losses (Topic 326), and no provision was recorded during the year ended December 31, 2022. The Company's financing notes receivable are discussed more fully in Note 6 ("Financing Notes Receivable"). F. Fair Value Measurements – FASB ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. Various inputs are used in determining the fair value of the Company's assets and liabilities. These inputs are summarized in the three broad levels listed below: •Level 1 - quoted prices in active markets for identical investments •Level 2 - other significant observable inputs (including quoted prices for similar investments, market corroborated inputs, etc.) •Level 3 - significant unobservable inputs (including the Company's own assumptions in determining the fair value of investments) See Note 13 ("Fair Value") for further discussion of the Company's fair value measurements. G. Cash and Cash Equivalents – The Company maintains cash balances at financial institutions in amounts that regularly exceed FDIC-insured limits. The Company's cash equivalents are comprised of short-term, liquid money market instruments. H. Accounts and other receivables – Accounts receivable are presented at face value net of an allowance for doubtful accounts within accounts and other receivables on the balance sheet. Accounts are considered past due based on the terms of sale with the customers. The Company reviews accounts for collectability based on an analysis of specific outstanding receivables, current economic conditions and past collection experience. At December 31, 2023 and 2022, the Company determined that an allowance for credit losses was not necessary. I. Goodwill – Goodwill represented the excess of the amount paid for the Corridor InfraTrust Management, Inc. ("Corridor") and MoGas business over the fair value of the net identifiable assets acquired. To comply with ASC 350, Intangibles - Goodwill and Other ("ASC 350"), the Company performed an impairment test for goodwill annually, or more frequently in the event that a triggering event had occurred. December 31st was the Company's annual testing date associated with its goodwill. The Company wrote off 100% of the goodwill balance as of December 31, 2022. J. Debt Discount and Debt Issuance Costs – Costs incurred for the issuance of new debt are capitalized and amortized into interest expense over the debt term. Issuance costs related to long-term debt are recorded as a direct deduction from the carrying amount of that debt liability, net of accumulated amortization. Issuance costs related to line-of-credit arrangements however, are presented as an asset instead of a direct deduction from the carrying amount of the debt. In accordance with ASC 470, Debt ("ASC 470"), the Company recorded its Convertible Notes at the aggregate principal amount, less discount. The Company is amortizing the debt discount over the life of the Convertible Notes as additional non-cash interest expense utilizing the effective interest method. Refer to Note 14 ("Debt") for additional information. K. Asset Retirement Obligations – The Company follows ASC 410-20, Asset Retirement Obligations ("ARO"), which requires that an asset retirement obligation associated with the retirement of a long-lived asset be recognized as a liability in the period in which it is incurred and becomes determinable, with an offsetting increase in the carrying amount of the associated asset. The Company measures changes in the ARO liability due to passage of time by applying an interest method of allocation to the amount of the liability at the beginning of the period. The increase in the carrying amount of the liability is recognized as an expense classified as an operating item in the Consolidated Statements of Operations, hereinafter referred to as ARO accretion expense. The Company periodically reassesses the timing and amount of cash flows anticipated associated with the ARO and adjusts the fair value of the liability accordingly under the guidance in ASC 410-20. The fair value of the obligation at the acquisition date was capitalized as part of the carrying amount of the related long-lived assets and is being depreciated over the asset's remaining useful life. The useful lives of most pipeline gathering systems are primarily derived from available supply resources and ultimate consumption of those resources by end users. Adjustments to the ARO resulting from reassessments of the timing and amount of cash flows will result in changes to the retirement costs capitalized as part of the carrying amount of the asset. Upon decommissioning of the ARO or a portion thereof, the Company reduces the fair value of the liability and recognizes a (gain) loss on settlement of ARO as an operating item in the Consolidated Statements of Operations for the difference between the liability and actual decommissioning costs incurred. If a reasonable estimate cannot be made at the time the liability is incurred, CorEnergy will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of CorEnergy's asset retirement obligations are based on its legal obligation to perform remedial activity when it permanently ceases operations of the long-lived assets. CorEnergy therefore considers the settlement date of these obligations to be indeterminable. Accordingly, CorEnergy cannot calculate an associated asset retirement liability for these obligations at this time. CorEnergy will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable. As of and for the periods ended December 31, 2023 and 2022, the Company had no asset retirement obligations. On February 4, 2021, the Company disposed of the ARO upon providing the GIGS asset as partial consideration for the Crimson Transaction. Refer to Note 5 ("Leased Properties And Leases") for further details. L. Revenue Recognition – In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers ("ASU 2014-09" or "ASC 606"), which became effective for all public entities on January 1, 2018. ASC 606 supersedes previously existing revenue recognition standards with a single model unless those contracts are within the scope of other standards (e.g. leases). The model requires an entity to recognize as revenue the amount of consideration to which it expects to be entitled for the transfer of promised goods or services to customers. Specific recognition policies for the Company's revenue items are as follows: •Transportation and distribution revenue – The Company's contracts related to transportation and distribution revenue are primarily comprised of a mix of oil and natural gas supply, transportation and distribution performance obligations, as well as limited performance obligations related to system maintenance and improvement. Transportation revenues are recognized by Crimson and MoGas and distribution revenues are recognized by Omega and Omega Gas Marketing, LLC. ◦Under the Company's oil and natural gas supply, transportation and distribution performance obligations, the customer simultaneously receives and consumes the benefit of the services as the commodities are 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) Federal Energy Regulatory Commission ("FERC") regulated rates or negotiated rates in the case of transportation agreements and (iii) contracted amounts (with annual consumer price index ("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 oil and natural gas supply, transportation and distribution performance obligations is recognized on a right to invoice basis as the performance obligations are met, which represents what the Company expects to receive in consideration and is representative of value delivered to the customer. The Company has a contract with one customer, Spire, Inc. ("Spire"), that has fixed pricing which varies over the contract term. For this specific contract, the transaction price has been allocated ratably over the contractual performance obligation beginning in 2018 with the adoption of ASC 606. All invoicing is done in the month following service, with payment typically due a month from invoice date. •Pipeline loss allowance - The Company's crude oil transportation revenue includes amounts earned for pipeline loss allowance ("PLA"). PLA revenue, recorded within transportation revenue, represents the estimated realizable value of the earned loss allowance volumes received by the Company as applicable under the tariff or contract. As is common in the pipeline transportation industry, as crude oil is transported, the Company earns a small percentage of the crude oil volume transported to offset any measurement uncertainty or actual volumes lost in transit. The Company will settle the PLA with its shippers either in-kind or in cash. PLA received by the Company typically exceeds actual pipeline losses in transit and typically results in a benefit to the Company. For PLA volumes received in-kind, the Company records these in inventory. ◦When PLA is paid in-kind, the barrels are valued at current market price less standard deductions, recorded as inventory and recognized as non-cash consideration revenue, concurrent with related transportation services. PLA paid in cash is treated in the same way as in-kind, but no inventory is created. In accordance with ASC 606, when control of the PLA volumes has been transferred to the purchaser, the Company records this as revenue at the contractual sales price within PLA revenue and PLA cost of revenues. ◦Under a contract with the Department of Defense ("DOD"), gas sales and cost of gas sales are presented on a net basis in the transportation and distribution revenue line. The Company continues to present the gas sales and cost of gas sales on a net basis upon adoption of ASC 606. •Pipeline loss allowance subsequent sales and cost of revenue - PLA volumes received in-kind by the Company that are initially recorded in inventory and subsequently sold are recorded in pipeline loss allowance subsequent sales at the market price less standard deductions for which they are contractually sold. At the time of the sale, the cost of the PLA volumes sold are expensed in pipeline loss allowance subsequent sales cost of revenue based on the carrying value of those volumes, which is valued using an average costing method at the lower of cost or net realizable value. •Financing revenue – Historically, financing notes receivable have been considered a core product offering and therefore the related income is presented as a component of operating income. For increasing rate loans, base interest income is recorded ratably over the life of the loan, using the effective interest rate. The net amount of deferred loan origination income and costs are amortized on a straight-line basis over the life of the loan and reported as an adjustment to yield in financing revenue. Participating financing revenues are recorded when specific performance criteria have been met. •Lease revenue – Refer to Note 5 ("Leased Properties And Leases"), for the Company's lease revenue recognition policy. M. Transportation and distribution expense – Included here are Crimson's cost of operating and maintaining the crude oil pipelines, MoGas' costs of operating and maintaining the natural gas transmission line, and Omega's costs of operating and maintaining the natural gas distribution system. These costs are incurred both internally and externally. The internal costs relate to system control, pipeline operations, maintenance, insurance and taxes. Other internal costs include payroll for employees associated with gas control, field employees and management. The external costs consist of professional services such as audit and accounting, legal and regulatory and engineering. Under the Company's contract with the DOD, amounts paid by Omega for gas and propane are netted against sales and are presented in the transportation and distribution revenue line. See paragraph (M) above. N. Other Income Recognition – Specific policies for the Company's other income items are as follows: •Net distributions and other income – Includes interest income earned on the Company's money market instruments and distributions and dividends from historical investments. Distributions and dividends from investments were recorded on their ex-dates and were reflected as other income within the accompanying Consolidated Statements of Operations. Distributions received from the Company's investments were generally characterized as ordinary income, capital gains and distributions received from investment securities. The portion characterized as return of capital was paid by the Company's investees from their cash flow from operations. The Company recorded investment income, capital gains and distributions received from investment securities based on estimates made at the time such distributions were received. Such estimates were based on information available from each company and other industry sources. These estimates may have subsequently been revised based on information received from the entities after their tax reporting periods were concluded, as the actual character of these distributions was not known until after the fiscal year end of the Company. •Net realized and unrealized gain (loss) from investments – Securities transactions were accounted for on the date the securities were purchased or sold. Realized gains and losses were reported on an identified cost basis. The Company recorded investment income and return of capital based on estimates made at the time such distributions were received. Such estimates were based on information available from the portfolio company and other industry sources. These estimates may have subsequently been revised based on information received from the portfolio company after their tax reporting periods were concluded, as the actual character of these distributions were not known until after the Company's fiscal year end. O. Asset Acquisition Expenses – Costs incurred in connection with the research of real property acquisitions not accounted for as business combinations are expensed until it is determined that the acquisition of the real property is probable. Upon such determination, costs incurred in connection with the acquisition of the property are capitalized as described in paragraph (C) above. Deferred costs related to an acquisition that the Company has determined, based on management's judgment, not to pursue are expensed in the period in which such determination is made. Costs incurred in connection with a business combination are expensed as incurred. P. Offering Costs – Offering costs related to the issuance of common or preferred stock are charged to additional paid-in capital when the stock is issued. Q. Stock-based Compensation - The fair value of share-based payments is estimated using the quoted market price of the Company's common stock and pricing models as of the date of grant as further discussed in Note 15 ("Stockholders' Equity"). The resulting cost is recognized on a straight-line basis over the period during which an employee is required to provide service in exchange for the awards, usually the vesting period. Forfeitures are accounted for in the period in which they occur. In addition to service-based awards, the Company grants fully vested Common Stock to the Board and certain members of the executive team. R. Earnings (Loss) Per Share – Subsequent to the issuance of our Class B Common Stock in July of 2021, the Company applies the two-class method for calculating and presenting earnings (loss) per common share. The two-class method is an earnings allocation formula that determines earnings per share for each class of common stock according to dividends declared or accumulated and participation rights in undistributed earnings and losses of all participating securities. Under this method: i.Income or loss from continuing operations (“net income”) is reduced by the amount of dividends declared in the current period for each class of stock and by the contractual amount of dividends that must be accumulated for the current period. ii.The remaining earnings or loss (“undistributed earnings or loss”) are allocated to the participating securities to the extent each security may share in earnings as if all the earnings or losses for the period had been distributed. iii.The total distributed and undistributed earnings and losses are allocated to each participating security which is then divided by the number of weighted average outstanding shares of the participating security to which the earnings are allocated to determine the earnings or loss per share for the participating security. iv.Basic and diluted net income or loss per share data are presented for each class of common stock. In applying the two-class method, the Company determined undistributed earnings and losses should be allocated equally on a pro rata basis between the Common Stock and the Class B Common Stock due to the contractual participation rights of the Class B Common Stock which participate pari-passu with Common Stock in regard to undistributed earnings and losses. S. Federal and State Income Taxation – The Company is treated as a REIT for federal income tax purposes. Because certain of its assets may not produce REIT-qualifying income or be treated as interests in real property, those assets are held in wholly-owned taxable REIT subsidiaries ("TRSs") in order to limit the potential that such assets and income could prevent the Company from qualifying as a REIT. As a REIT, the Company holds and operates certain of its assets through one or more wholly-owned TRSs. The Company's use of TRSs enables it to continue to engage in certain businesses while complying with REIT qualification requirements and also allows it to retain income generated by these businesses for reinvestment without the requirement of distributing those earnings. In the future, the Company may elect to reorganize and transfer certain assets or operations from its TRSs to the Company or other subsidiaries, including qualified REIT subsidiaries. The Company's other investments were limited partnerships or limited liability companies which were treated as partnerships for federal and state income tax purposes. As a limited partner, the Company reported its allocable share of taxable income in computing its own taxable income. To the extent held by a TRS, the TRS's tax expense or benefit was included in the Consolidated Statements of Operations based on the component of income or gains and losses to which such expense or benefit related. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. A valuation allowance is recognized if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized. It is expected that for the year ended December 31, 2023, and future periods, any deferred tax liability or asset generated will be related entirely to the assets and activities of the Company's TRSs. If the Company ceased to qualify as a REIT, the Company, as a C corporation, would be obligated to pay federal and state income tax on its taxable income. T. Recent Accounting Pronouncements – 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 model ("CECL model"), applies to financial assets subject to credit losses and measured at amortized cost, as well as certain off-balance sheet credit exposures. Consistent with the guidance for smaller reporting companies, the Company has adopted this standard as of January 1, 2023. Trade receivables - Accounts receivable from the transportation and distribution of crude oil and natural gas are generally settled with counterparties within 60 days of the service month. The Company has a high historical rate of collectability of greater than 99% of total revenue and, as such, has adopted an impairment model based on an evaluation of its aging schedule. As of December 31, 2023 the Company's calculated allowance for credit losses was immaterial. Financing note receivable - Refer to Note 6 ("Financing Notes Receivable") for further discussion. The Company utilized the modified retrospective approach for implementation and recorded a $50 thousand cumulative-effect adjustment to beginning retained earnings as of January 1, 2023. Other receivable - the Company has a receivable of $1.1 million with a reserve of $550 thousand related to a start-up entity which plans to produce blue hydrogen recorded in prepaid and other assets on the Company's Consolidated Balance Sheet. The Company periodically assesses recoverability of this asset to determine adequacy of the reserve. As the disbursements related to this project occurred during 2023, the balance of the reserve was $0 at January 1, 2023.

A. Use of Estimates – The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

In December 2023, the Company completed an assessment of the useful lives of its crude oil pipelines and related equipment. Due to advances in green energy initiatives in the State of California, the Company determined the useful life of the primary asset (crude oil pipelines) should be 25 years. This resulted in changes to useful lives across our crude oil pipeline asset portfolio. However, our primary asset, as defined under ASC 360, "Property, Plant and Equipment," decreased from 35 years to 25 years. This change in accounting estimate was effective beginning December 1, 2023. Based on the carrying amount of crude oil pipelines and related equipment that was in-service as of December 1, 2023, this change increased depreciation expense by $41 thousand for the year ended December 31, 2023.

Beginning in 2019, for the underlying asset class related to single-use office space, the Company accounts for each separate lease component and non-lease component as a single lease component. For the underlying lessor asset class related to pipelines residing on military bases, the Company accounts for each separate lease component and non-lease component as a single lease component if the non-lease components otherwise are accounted for in accordance with the revenue standard, and both the following criteria are met: (i) the timing and pattern of revenue recognition are the same for the non-lease component(s) and the related lease component and (ii) the lease component will be classified as an operating lease. The Company carried forward the accounting treatment for land easements under existing agreements, which are currently accounted for within property, plant and equipment. Land easements are reassessed under ASC 842 when such agreements are modified.

The Company's current leased properties are classified as operating leases and are recorded as leased property, net of accumulated depreciation, in the Consolidated Balance Sheets. Initial direct costs incurred in connection with the creation and execution of a lease prior to January 1, 2019 are capitalized and amortized over the lease term. Subsequent to January 1, 2019, initial direct costs under ASC 842 are incremental costs of a lease that would not have been incurred if the lease had not been obtained and may include commissions or payments made to an existing tenant as an incentive to terminate its lease. Base rent related to the Company's leased property is recognized on a straight-line basis over the term of the lease when collectability is 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. Rental payments received in advance are classified as unearned revenue and included as a liability within the Consolidated Balance Sheets. Unearned revenue is amortized ratably over the lease period as revenue recognition criteria are met. Rental payments received in arrears are accrued and classified as deferred rent receivable and included in assets within the Consolidated Balance Sheets.

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

D. Long-Lived Asset Impairment – The Company's long-lived assets consist primarily of oil and natural gas pipelines that have been obtained through asset acquisitions and a business combination. Management continually monitors its business, the business environment and performance of its operations to determine if an event has occurred that indicates that the carrying value of a long-lived asset group may be impaired. When a triggering event occurs, which is a determination that involves judgment, management utilizes cash flow projections to assess its ability to recover the carrying value of the asset group based on the long-lived assets' ability to generate future cash flows on an undiscounted basis over the remaining useful life of the primary asset.

Management's projected cash flows of long-lived assets are primarily based on estimated cash flows that extend many years into the future. If those cash flow projections indicate that the long-lived asset's carrying value is not recoverable, management records an impairment charge for the excess of carrying value of the asset over its fair value. The estimate of fair value considers a number of factors, including the potential value that would be received if the asset were sold, discount rates and projected cash flows. Inputs and assumptions used in the cash flow models include estimates of projected volumes transported on the Company's pipelines, projected tariff rates and estimated operating costs, among others. Due to the imprecise nature of these projections and assumptions, actual results can differ from management's estimates.

E. Financing Notes Receivable – Financing notes receivable are presented at face value plus accrued interest receivable and deferred loan origination costs and net of related direct loan origination income. Each quarter, the Company reviews its financing notes receivable to determine if the balances are realizable based on factors affecting the collectability of those balances. Factors may include credit quality, timeliness of required periodic payments, past due status and management discussions with obligors. The Company evaluates the collectability of both interest and principal of each of its loans to determine if an allowance is needed. An allowance will be recorded when based on current information and events, the Company determines it is probable that it will be unable to collect all amounts due according to the existing contractual terms. If the Company determines an allowance is necessary, the amount deemed uncollectible is expensed in the period of determination. An insignificant delay or shortfall in the amount of payments does not necessarily result in the recording of an allowance. Generally, when interest and/or principal payments on a loan become past due, or if the Company does not otherwise expect the borrower to be able to service its debt and other obligations, the Company will place the loan on non-accrual status and will typically cease recognizing financing revenue on that loan until all principal and interest have been brought current. Interest income recognition is resumed if and when the previously reserved-for financing notes become contractually current and performance has been demonstrated. Payments received subsequent to the recording of an allowance will be recorded as a reduction to principal. During the year ended December 31, 2023, the Company recorded a $50 thousand provision for loan loss upon the adoption of ASU 2016-13 Financial Instruments—Credit Losses (Topic 326), and no provision was recorded during the year ended December 31, 2022. The Company's financing notes receivable are discussed more fully in Note 6 ("Financing Notes Receivable").

H. Accounts and other receivables – Accounts receivable are presented at face value net of an allowance for doubtful accounts within accounts and other receivables on the balance sheet. Accounts are considered past due based on the terms of sale with the customers. The Company reviews accounts for collectability based on an analysis of specific outstanding receivables, current economic conditions and past collection experience. At December 31, 2023 and 2022, the Company determined that an allowance for credit losses was not necessary.

I. Goodwill – Goodwill represented the excess of the amount paid for the Corridor InfraTrust Management, Inc. ("Corridor") and MoGas business over the fair value of the net identifiable assets acquired. To comply with ASC 350, Intangibles - Goodwill and Other ("ASC 350"), the Company performed an impairment test for goodwill annually, or more frequently in the event that a triggering event had occurred. December 31st was the Company's annual testing date associated with its goodwill. The Company wrote off 100% of the goodwill balance as of December 31, 2022.

J. Debt Discount and Debt Issuance Costs – Costs incurred for the issuance of new debt are capitalized and amortized into interest expense over the debt term. Issuance costs related to long-term debt are recorded as a direct deduction from the carrying amount of that debt liability, net of accumulated amortization. Issuance costs related to line-of-credit arrangements however, are presented as an asset instead of a direct deduction from the carrying amount of the debt. In accordance with ASC 470, Debt ("ASC 470"), the Company recorded its Convertible Notes at the aggregate principal amount, less discount. The Company is amortizing the debt discount over the life of the Convertible Notes as additional non-cash interest expense utilizing the effective interest method. Refer to Note 14 ("Debt") for additional information.

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

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

If a reasonable estimate cannot be made at the time the liability is incurred, CorEnergy will record the liability when sufficient information is available to estimate the liability’s fair value. Certain of CorEnergy's asset retirement obligations are based on its legal obligation to perform remedial activity when it permanently ceases operations of the long-lived assets. CorEnergy therefore considers the settlement date of these obligations to be indeterminable. Accordingly, CorEnergy cannot calculate an associated asset retirement liability for these obligations at this time. CorEnergy will measure and recognize the fair value of these asset retirement obligations when the settlement date is determinable. As of and for the periods ended December 31, 2023 and 2022, the Company had no asset retirement obligations.

L. Revenue Recognition – In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers ("ASU 2014-09" or "ASC 606"), which became effective for all public entities on January 1, 2018. ASC 606 supersedes previously existing revenue recognition standards with a single model unless those contracts are within the scope of other standards (e.g. leases). The model requires an entity to recognize as revenue the amount of consideration to which it expects to be entitled for the transfer of promised goods or services to customers.

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

◦Under the Company's oil and natural gas supply, transportation and distribution performance obligations, the customer simultaneously receives and consumes the benefit of the services as the commodities are 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) Federal Energy Regulatory Commission ("FERC") regulated rates or negotiated rates in the case of transportation agreements and (iii) contracted amounts (with annual consumer price index ("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 oil and natural gas supply, transportation and distribution performance obligations is recognized on a right to invoice basis as the performance obligations are met, which represents what the Company expects to receive in consideration and is representative of value delivered to the customer. The Company has a contract with one customer, Spire, Inc. ("Spire"), that has fixed pricing which varies over the contract term. For this specific contract, the transaction price has been allocated ratably over the contractual performance obligation beginning in 2018 with the adoption of ASC 606. All invoicing is done in the month following service, with payment typically due a month from invoice date.

•Pipeline loss allowance - The Company's crude oil transportation revenue includes amounts earned for pipeline loss allowance ("PLA"). PLA revenue, recorded within transportation revenue, represents the estimated realizable value of the earned loss allowance volumes received by the Company as applicable under the tariff or contract. As is common in the pipeline transportation industry, as crude oil is transported, the Company earns a small percentage of the crude oil volume transported to offset any measurement uncertainty or actual volumes lost in transit. The Company will settle the PLA with its shippers either in-kind or in cash. PLA received by the Company typically exceeds actual pipeline losses in transit and typically results in a benefit to the Company. For PLA volumes received in-kind, the Company records these in inventory.

◦When PLA is paid in-kind, the barrels are valued at current market price less standard deductions, recorded as inventory and recognized as non-cash consideration revenue, concurrent with related transportation services. PLA paid in cash is treated in the same way as in-kind, but no inventory is created. In accordance with ASC 606, when control of the PLA volumes has been transferred to the purchaser, the Company records this as revenue at the contractual sales price within PLA revenue and PLA cost of revenues.

•Pipeline loss allowance subsequent sales and cost of revenue - PLA volumes received in-kind by the Company that are initially recorded in inventory and subsequently sold are recorded in pipeline loss allowance subsequent sales at the market price less standard deductions for which they are contractually sold. At the time of the sale, the cost of the PLA volumes sold are expensed in pipeline loss allowance subsequent sales cost of revenue based on the carrying value of those volumes, which is valued using an average costing method at the lower of cost or net realizable value.

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

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

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

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

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

R. Earnings (Loss) Per Share – Subsequent to the issuance of our Class B Common Stock in July of 2021, the Company applies the two-class method for calculating and presenting earnings (loss) per common share. The two-class method is an earnings allocation formula that determines earnings per share for each class of common stock according to dividends declared or accumulated and participation rights in undistributed earnings and losses of all participating securities. Under this method:

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

The Company's other investments were limited partnerships or limited liability companies which were treated as partnerships for federal and state income tax purposes. As a limited partner, the Company reported its allocable share of taxable income in computing its own taxable income. To the extent held by a TRS, the TRS's tax expense or benefit was included in the Consolidated Statements of Operations based on the component of income or gains and losses to which such expense or benefit related. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. A valuation allowance is recognized if, based on the weight of available evidence, it is more likely than not that some portion or all of the deferred income tax asset will not be realized. It is expected that for the year ended December 31, 2023, and future periods, any deferred tax liability or asset generated will be related entirely to the assets and activities of the Company's TRSs.

T. Recent Accounting Pronouncements – 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 model ("CECL model"), applies to financial assets subject to credit losses and measured at amortized cost, as well as certain off-balance sheet credit exposures. Consistent with the guidance for smaller reporting companies, the Company has adopted this standard as of January 1, 2023.

Trade receivables - Accounts receivable from the transportation and distribution of crude oil and natural gas are generally settled with counterparties within 60 days of the service month. The Company has a high historical rate of collectability of greater than 99% of total revenue and, as such, has adopted an impairment model based on an evaluation of its aging schedule. As of December 31, 2023 the Company's calculated allowance for credit losses was immaterial.