HPK HighPeak Energy Inc

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 1. Organization and Nature of Operations

HighPeak Energy, Inc. ("HighPeak Energy" or the "Company,") is a Delaware corporation, formed in October 2019. See the Company’s Annual Report on Form 10-K for the year ended December 31, 2021 for further information regarding the formation of the Company.

HighPeak Energy’s common stock and warrants are listed and traded on the Nasdaq Global Market (the "Nasdaq") under the ticker symbols “HPK” and “HPKEW,” respectively. HighPeak Energy’s Contingent Value Rights (“CVRs”) are currently traded on the Over-The-Counter market under the ticker symbol “HPKER.” The Company is an independent crude oil and natural gas exploration and production company that explores for, develops and produces crude oil, NGL and natural gas in the Permian Basin in West Texas, more specifically, the Midland Basin in Howard and Borden Counties. Our acreage is composed of two core areas, Flat Top in the northern portion of Howard County extending into southern Borden County and Signal Peak in the southern portion of Howard County.

NOTE 2. Basis of Presentation and Summary of Significant Accounting Policies

Presentation. In the opinion of management, the unaudited interim condensed consolidated financial statements of the Company as of June 30, 2022 and for the three and six months ended June 30, 2022 and 2021 include all adjustments and accruals, consisting only of normal, recurring adjustments and accruals necessary for a fair presentation of the results for the interim periods in conformity with generally accepted accounting principles in the United States ("GAAP"). The operating results for the three and six months ended June 30, 2022 are not indicative of results for a full year.

Certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted in accordance with the rules and regulations of the United States Securities and Exchange Commission (the "SEC"). These unaudited interim condensed consolidated financial statements should be read together with the consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021.

Principles of consolidation. The consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries since their acquisition or formation. All material intercompany balances and transactions have been eliminated. Certain reclassifications have been made to prior period amounts to conform to the current period’s presentation.

Use of estimates in the preparation of financial statements. Preparation of the Company's consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Depletion of crude oil and natural gas properties and evaluations for impairment of proved and unproved crude oil and natural gas properties, in part, is determined using estimates of proved, probable and possible crude oil, NGL and natural gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved, probable and possible reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved crude oil and natural gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves, commodity price outlooks and future undiscounted and discounted net cash flows. In addition, evaluations for impairment of unproved crude oil and natural gas properties on a project-by-project basis are also subject to numerous uncertainties including, among others, estimates of future recoverable reserves, results of exploration activities, commodity price outlooks, planned future sales or expirations of all or a portion of such projects. Other items subject to such estimates and assumptions include, but are not limited to, the carrying value of crude oil and natural gas properties, asset retirement obligations, equity-based compensation, fair value of derivatives and estimates of income taxes. Actual results could differ from the estimates and assumptions utilized.

Cash and cash equivalents. The Company’s cash and cash equivalents include depository accounts held by banks with original issuance maturities of 90 days or less. The Company’s cash and cash equivalents are generally held in financial institutions in amounts that may exceed the insurance limits of the Federal Deposit Insurance Corporation. However, management believes that the Company’s counterparty risks are minimal based on the reputation and history of the institutions selected.

Accounts receivable. As of June 30, 2022 and December 31, 2021, the Company’s accounts receivables primarily consist of amounts due from the sale of crude oil, NGL and natural gas of $69.0 million and $29.0 million, respectively, and are based on estimates of sales volumes and realized prices the Company anticipates it will receive, $8.9 million and zero, respectively, of receivables for purchase price adjustments related to the Hannathon Acquisition, receivables related to refunds from pipe suppliers of zero and $3.2 million, respectively, current U.S. federal income tax receivables of $3.2 million and $3.2 million, respectively, joint interest receivables of $9.1 million and $3.1 million, respectively, and receivables related to settlements of derivative contracts of zero and $771,000, respectively. The Company’s share of crude oil, NGL and natural gas production is sold to various purchasers who must be prequalified under the Company’s credit risk policies and procedures. The Company’s credit risk related to collecting accounts receivables is mitigated by using credit and other financial criteria to evaluate the credit standing of the entity obligated to make payment on the accounts receivable, and where appropriate, the Company obtains assurances of payment, such as a guarantee by the parent company of the counterparty or other credit support. The Company routinely reviews outstanding balances and establishes allowances for bad debts equal to the estimable portions of accounts receivable for which failure to collect is considered probable. As of June 30, 2022 and December 31, 2021, the Company had no allowance for doubtful accounts.

Concentration of credit risk. The Company is subject to credit risk resulting from the concentration of its crude oil and natural gas receivables with significant purchasers. For the six months ended June 30, 2022 and 2021, sales to the Company’s largest purchaser accounted for approximately 88% and 95%, respectively, of the Company’s total crude oil, NGL and natural gas sales revenues. The Company generally does not require collateral and does not believe the loss of this particular purchaser would materially impact its operating results, as crude oil and natural gas are fungible products with well-established markets and numerous purchasers in various regions.

Prepaid expenses. Prepaid expenses are comprised primarily of tubulars that the Company has prepaid for the suppliers to produce the tubulars in time such as to guarantee their availability when we need them for our current drilling program, prepaid drilling and completion costs on wells being drilled and completed by third party operators where we own a non-operated working interest, prepaid caliche that will be used on future locations and roads in our development areas, prepaid insurance costs, software maintenance costs and listing fees that will be amortized over the life of the policies and prepaid software maintenance fees that will be amortized over the life of the contracts. Prepaid expenses as of June 30, 2022 and December 31, 2021 is $19.1 million and $7.2 million, respectively.

Inventory. Inventory is comprised primarily of crude oil and natural gas drilling or repair items such as tubing, casing, proppant used to fracture-stimulate crude oil and natural gas wells, water, chemicals, pumps, vessels, operating supplies and ordinary maintenance materials and parts. The materials and supplies inventory is primarily acquired for use in future drilling or repair operations and is carried at the lower of cost or net realizable value, on a weighted average cost basis. Valuation allowances for materials and supplies inventories are recorded as reductions to the carrying values of the materials and supplies inventories in the Company’s consolidated balance sheet and as charges to other expense in the consolidated statements of operations. The Company’s materials and supplies inventory as of June 30, 2022 and December 31, 2021 is $6.2 million and $3.3 million, respectively, and the Company has not recognized any valuation allowance to date.

Crude oil and natural gas properties. The Company utilizes the successful efforts method of accounting for its crude oil and natural gas properties. Under this method, all costs associated with productive wells and nonproductive development wells are capitalized while nonproductive exploration costs and geological and geophysical expenditures are expensed.

The Company does not carry the costs of drilling an exploratory well as an asset in its consolidated balance sheet following the completion of drilling unless both of the following conditions are met: (i) the well has found a sufficient quantity of reserves to justify its completion as a producing well and (ii) the Company is making sufficient progress assessing the reserves and the economic and operating viability of the project.

Due to the capital-intensive nature and the geographical location of certain projects, it may take an extended period of time to evaluate the future potential of an exploration project and the economics associated with making a determination on its commercial viability. In these instances, the project’s feasibility is not contingent upon price improvements or advances in technology, but rather the Company’s ongoing efforts and expenditures related to accurately predict the hydrocarbon recoverability based on well information, gaining access to other companies’ production data in the area, transportation or processing facilities and/or getting partner approval to drill additional appraisal wells. These activities are ongoing and are being pursued constantly. Consequently, the Company’s assessment of suspended exploratory well costs is continuous until a decision can be made that the project has found sufficient proved reserves to sanction the project or is noncommercial and is charged to exploration and abandonment expense. See Note 6 for additional information.

The capitalized costs of proved properties are depleted using the unit-of-production method based on proved reserves for leasehold costs and proved developed reserves for drilling, completion and other crude oil and natural gas property costs. Costs of unproved leasehold costs are excluded from depletion until proved reserves are established or, if unsuccessful, impairment is determined.

Proceeds from the sales of individual properties are credited to proved or unproved oil and natural gas properties, as the case may be, if doing so does not materially impact the depletion rate of an amortization base. Generally, no gain or loss is recorded until an entire amortization base is sold. However, gain or loss is recorded from the sale of less than an entire amortization base if the disposition is significant enough to materially impact the depletion rate of the remaining properties in the amortization base.

The Company performs assessments of its long-lived assets to be held and used, including proved crude oil and natural gas properties accounted for under the successful efforts method of accounting, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected future cash flows is less than the carrying amount of the assets. In these circumstances, the Company recognizes an impairment charge for the amount by which the carrying amount of the assets exceeds the estimated fair value of the assets.

Unproved crude oil and natural gas properties are periodically assessed for impairment on a project-by-project basis. These impairment assessments are affected by the estimates of future recoverable reserves, results of exploration activities, commodity price outlooks, planned future sales or expirations of all or a portion of such projects. If the estimated future net cash flows attributable to such projects are not expected to be sufficient to fully recover the costs invested in each project, the Company will recognize an impairment charge at that time.

Other property and equipment, net. Other property and equipment is recorded at cost. The carrying values of other property and equipment, net of accumulated depreciation of $562,000 and $438,000 as of June 30, 2022 and December 31, 2021, respectively, are as follows (in thousands):

Other property and equipment is depreciated over its estimated useful life on a straight-line basis. Land is not depreciated. Transportation equipment is generally depreciated over five years, buildings are generally depreciated over forty years, field equipment is generally depreciated over seven years and information technology is generally depreciated over three years. Leasehold improvements are amortized over the lesser of their estimated useful lives or the underlying terms of the associated leases.

The Company reviews its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If such assets are considered to be impaired, the impairment to be recorded is measured by the amount by which the carrying amount of the asset exceeds its estimated fair value. The estimated fair value is determined using either a discounted future cash flow model or another appropriate fair value method.

Aid-in-construction assets. As of June 30, 2022 and December 31, 2021, the Company has aid-in-construction assets totaling $3.7 million and $3.9 million, respectively, included in other noncurrent assets. The Company contracted with the natural gas gatherer and processor in its Flat Top area to construct a low-pressure gas gathering system to transport the Company’s natural gas to its processing facility. The Company agreed to incur the cost to construct the system in return for future payments based on gross system throughput, including any third-party natural gas that is potentially tied into the system in the future. Based on the Company’s current projections of its natural gas reserves in Flat Top, it is anticipated that the full amount will be paid back in less than four years. The contract calls for future aid-in-construction fundings if expansions of the system are necessary at the sole discretion of the Company.

Debt issuance costs and original issue discount. The Company has paid a total of $11.7 million in debt issuance costs, $9.1 million of which was incurred during the six months ended June 30, 2022, related to the issuance of senior unsecured notes and amendments to its revolving credit facility. Amortization based on the straight-line method over the terms of the senior unsecured notes and the revolving credit facility which approximates the effective interest method was $1.8 million and $77,000 during the six months ended June 30, 2022 and 2021, respectively. In addition, the company realized a $14.8 million discount on the issuance of its senior unsecured notes that is being amortized over the life of the notes which approximates the effective interest method and was $2.7 million and zero during the six months ended June 30, 2022 and 2021, respectively. As of June 30, 2022 and December 31, 2021, the net debt issuance costs and discount are netted against the outstanding long-term debt on the accompanying balance sheets in accordance with GAAP.

Leases. The Company enters into leases for drilling rigs, storage tanks, equipment and buildings and recognizes lease expense on a straight-line basis over the lease term. Lease right-of-use assets and liabilities are initially recorded on the lease commencement date based on the present value of lease payments over the lease term. As most of the Company’s lease contracts do not provide an implicit discount rate, the Company uses its incremental borrowing rate, which is determined based on information available at the commencement date of a lease. Leases may include renewal, purchase or termination options that can extend or shorten the term of a lease. The exercise of those options is at the Company’s sole discretion and is evaluated at inception and throughout the contract to determine if a modification of the lease term is required. Leases with an initial term of 12 months or less are generally not recorded as lease right-of-use assets and liabilities. See Note 10 for additional information.

Current liabilities. Current liabilities as of June 30, 2022 and December 31, 2021 totaled approximately $272.1 million and $103.0 million, respectively, including trade accounts payable, derivative liabilities, revenues payable, advances from joint interest owners and accruals for capital expenditures, operating and general and administrative expenses, interest expense, operating leases, dividends and dividend equivalents and other miscellaneous items.

Asset retirement obligations. The Company records a liability for the fair value of an asset retirement obligation in the period in which the associated asset is acquired or placed into service, if a reasonable estimate of fair value can be made. Asset retirement obligations are generally capitalized as part of the carrying value of the long-lived asset to which it relates. Conditional asset retirement obligations meet the definition of liabilities and are recorded when incurred and when fair value can be reasonably estimated. See Note 8 for additional information.

Revenue recognition. The Company follows FASB ASC 606, “Revenue from Contracts with Customers,” (“ASC 606”) whereby the Company recognizes revenues from the sales of crude oil and natural gas to its purchasers and presents them disaggregated on the Company’s consolidated statements of operations.

The Company enters into contracts with purchasers to sell its crude oil and natural gas production. Revenue on these contracts is recognized in accordance with the five-step revenue recognition model prescribed in ASC 606. Specifically, revenue is recognized when the Company’s performance obligations under these contracts are satisfied, which generally occurs with the transfer of control of the crude oil and natural gas to the purchaser. Control is generally considered transferred when the following criteria are met: (i) transfer of physical custody, (ii) transfer of title, (iii) transfer of risk of loss and (iv) relinquishment of any repurchase rights or other similar rights. Given the nature of the products sold, revenue is recognized at a point in time based on the amount of consideration the Company expects to receive in accordance with the price specified in the contract. Consideration under the crude oil and natural gas marketing contracts is typically received from the purchaser one to two months after production. As of June 30, 2022 and December 31, 2021, the Company had receivables related to contracts with purchasers of approximately $69.0 million and $29.0 million, respectively.

Crude Oil Contracts. The Company’s crude oil marketing contracts transfer physical custody and title at or near the wellhead, which is generally when control of the crude oil has been transferred to the purchaser. The crude oil produced is sold under contracts using market-based pricing which is then adjusted for the differentials based upon delivery location and crude oil quality. Since the differentials are incurred after the transfer of control of the crude oil, the differentials are included in crude oil sales on the consolidated statements of operations as they represent part of the transaction price of the contract.

Natural Gas Contracts. The majority of the Company’s natural gas is sold at the lease location, which is generally when control of the natural gas has been transferred to the purchaser. The natural gas is sold under (i) percentage of proceeds processing contracts or (ii) a hybrid of percentage of proceeds and fee-based contracts. Under the majority of the Company’s contracts, the purchaser gathers the natural gas in the field where it is produced and transports it to natural gas processing plants where NGL products are extracted. The NGL products and remaining residue natural gas are then sold by the purchaser. Under percentage of proceeds and hybrid percentage of proceeds and fee-based contracts, the Company receives a percentage of the value for the extracted liquids and the residue natural gas. Since control of the natural gas transfers upstream of the transportation and processing activities, revenue is recognized as the net amount received from the purchaser.

The Company does not disclose the value of unsatisfied performance obligations under its contracts with customers as it applies the practical exemption in accordance with ASC 606. The exemption, as described in ASC 606-10-50-14(a), applies to variable consideration that is recognized as control of the product is transferred to the customer. Since each unit of product represents a separate performance obligation, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.

Derivatives. All the Company’s derivatives are accounted for as non-hedge derivatives and are recorded at estimated fair value in the consolidated balance sheets. All changes in the fair values of its derivative contracts are recorded as gains or losses in the earnings of the periods in which they occur. The Company enters into derivatives under master netting arrangements, which, in an event of default, allows the Company to offset payables to and receivables from the defaulting counterparty. The Company classifies the fair value amounts of derivative assets and liabilities executed under master netting arrangements as net current or noncurrent derivative assets or net current or noncurrent derivative liabilities, whichever the case may be, by commodity and counterparty.

The Company’s credit risk related to derivatives is a counterparties’ failure to perform under derivative contracts owed to the Company. The Company uses credit and other financial criteria to evaluate the credit standing of, and to select, counterparties to its derivative instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative instruments, associated credit risk is mitigated by the Company’s credit risk policies and procedures.

The Company has entered into International Swap Dealers Association Master Agreements (“ISDA Agreements”) with each of its derivative counterparties. The terms of the ISDA Agreements provide the Company and the counterparties with rights of set off upon the occurrence of defined acts of default by either the Company or a counterparty to a derivative, whereby the party not in default may set off all derivative liabilities owed to the defaulting party against all derivative asset receivables from the defaulting party. See Note 5 for additional information.

Income taxes. The provision for income taxes is determined using the asset and liability approach of accounting for income taxes. Under this approach, 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 carrying amounts for income tax purposes and net operating loss and tax credit carryforwards. The amount of deferred taxes on these temporary differences is determined using the tax rates that are expected to apply to the period when the asset is realized or the liability is settled, as applicable, based on tax rates and laws in the respective tax jurisdiction enacted as of the balance sheet date.

The Company reviews its deferred tax assets for recoverability and establishes a valuation allowance based on projected future taxable income, applicable tax strategies and the expected timing of the reversals of existing temporary differences. A valuation allowance is provided when it is more likely than not (likelihood of greater than 50 percent) that some portion or all the deferred tax assets will not be realized. The Company had not established a valuation allowance as of June 30, 2022 and December 31, 2021.

The Company recognizes the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities, based upon the technical merits of the position. If all or a portion of the unrecognized tax benefit is sustained upon examination by the taxing authorities, the tax benefit will be recognized as a reduction to the Company’s deferred tax liability and will affect the Company’s effective tax rate in the period it is recognized. See Note 13 for additional information.

The Company records any tax-related interest charges as interest expense and any tax-related penalties as other expense in the consolidated statements of operations of which there have been none to date.

The Company is also subject to Texas Margin Tax. The Company realized no Texas Margin Tax in the accompanying consolidated financial statements as we do not anticipate owing any Texas Margin Tax for the periods presented.

Stock-based compensation. Stock-based compensation expense for stock option awards is measured at the grant date or modification date, as applicable, using the fair value of the award, and is recorded, net of forfeitures, on a straight-line basis over the requisite service period of the respective award. The fair value of stock option awards is determined on the grant date or modification date, as applicable, using a Black-Scholes option valuation model with the following inputs; (i) the grant date’s closing stock price, (ii) the exercise price of the stock options, (iii) the expected term of the stock option, (iv) the estimated risk-free adjusted interest rate for the duration of the option’s expected term, (v) the expected annual dividend yield on the underlying stock and (vi) the expected volatility over the option’s expected term.

Stock-based compensation for HighPeak Energy common stock issued to outside directors with no restrictions thereon, is measured at the grant date using the fair value of the award and is recognized as stock-based compensation in the accompanying financial statements immediately. Stock-based compensation for restricted stock awarded to outside directors, employee members of the board of directors and certain other employees is measured at the grant date using the fair value of the award and is recognized on a straight-line basis over the requisite service period of the respective award.

Segments. Based on the Company’s organizational structure, the Company has one operating segment, which is crude oil and natural gas development, exploration and production. In addition, the Company has a single, company-wide management team that allocates capital resources to maximize profitability and measures financial performance as a single enterprise.

Impact of the COVID-19 Pandemic. A novel strain of the coronavirus disease ("COVID-19") surfaced in late 2019 and spread around the world, including to the United States. In March 2020, the World Health Organization declared COVID-19 a pandemic, and the President of the United States declared the COVID-19 outbreak a national emergency. The COVID-19 pandemic significantly affected the global economy, disrupted global supply chains and created significant volatility in the financial markets. In addition, the COVID-19 pandemic resulted in travel restrictions, business closures and other restrictions that have disrupted the demand for crude oil throughout the world and when combined with pressures on the global supply-demand balance for crude oil and related products, resulted in significant volatility in crude oil prices beginning late February 2020. The length of this demand disruption is unknown, and there is significant uncertainty regarding the long-term impact of the effects of the COVID-19 pandemic to global crude oil demand.

Recently adopted accounting pronouncements. There are no recently adopted accounting pronouncements. 

New accounting pronouncements not yet adopted.  In October 2021, the FASB issued ASU 2021-08, “Business Combinations (Topic 805) – Accounting for Contract Assets and Contract Liabilities from Contracts with Customers.” This update requires the acquirer in a business combination to record contract asset and liabilities following Topic 606 – “Revenue from Contracts with Customers” at acquisition as if it had originated the contract, rather than at fair value. This update is effective for public business entities beginning after December 15, 2022 with early adoption permitted.  The Company continues to evaluate the provisions of this update but does not believe the adoption will have a material impact on its financial position, results of operations or liquidity.

The Company considers the applicability and the impact of all ASUs.  ASUs not discussed above were assessed and determined to be either not applicable, the effects of adoption are not expected to be material or are clarifications of ASUs previously disclosed. 

NOTE 3. Acquisitions

Acquisitions. During the six months ended June 30, 2022, the Company incurred a total of $515.4 million in acquisition costs primarily related to a series of agreements to acquire various crude oil and natural gas properties contiguous to its Signal Peak and Flat Top operating areas in Howard and Borden counties, consisting of approximately 34,500 net acres and associated producing properties, water system infrastructure and in-field fluid gathering pipelines. Included in the acquisition costs is the issuance of 10,853,634 shares of HighPeak Energy common stock valued at $265.0 million on the respective closing dates. All the aforementioned acquisitions were accounted for as asset acquisitions as substantially all the gross assets acquired are concentrated in a group of similar identifiable assets. The consideration paid was allocated to the individual assets acquired and liabilities assumed based on their relative fair values. All transaction costs associated with the acquisitions were capitalized.

NOTE 4. Fair Value Measurements

The Company determines fair value based on the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company's own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.

The three input levels of the fair value hierarchy are as follows:

Assets and liabilities measured at fair value on a recurring basis. Assets and liabilities measured at fair value on a recurring basis as of June 30, 2022 and December 31, 2021 are as follows (in thousands):

Commodity price derivatives. The Company’s commodity price derivatives are currently made up of crude oil and natural gas swap contracts. The Company measures derivatives using an industry-standard pricing model that is provided by a third party. The inputs utilized in the third-party discounted cash flow and option-pricing models for valuing commodity price derivatives include forward prices for crude oil, contracted volumes, volatility factors and time to maturity, which are considered Level 2 inputs.

Assets and liabilities measured at fair value on a nonrecurring basis. Certain assets and liabilities are measured at fair value on a nonrecurring basis. These assets and liabilities are not measured at fair value on an ongoing basis but are subject to fair value adjustments in certain circumstances. Specifically, (i) stock-based compensation is measured at fair value on the date of grant based on Level 1 inputs for restricted stock awards or Level 2 inputs for stock option awards based upon market data, and (ii) the estimates and fair value measurements used for the evaluation of proved property for potential impairment using Level 3 inputs based upon market conditions in the area. The Company assesses the recoverability of the carrying amount of certain assets and liabilities whenever events or changes in circumstances indicate the carrying amount of an asset or liability may not be recoverable. These assets and liabilities can include inventories, proved and unproved crude oil and natural gas properties and other long-lived assets that are written down to fair value when they are impaired or held for sale. The Company did not record any impairments to proved or unproved crude oil and natural gas properties for the periods presented in the accompanying consolidated financial statements.

Financial instruments not carried at fair value. Carrying values and fair values of financial instruments that are not carried at fair value in the consolidating balance sheets are as follows (in thousands):

The Company has other financial instruments consisting primarily of accounts receivable, accounts payable, long-term debt, specifically the revolving credit facility, and other current assets and liabilities that approximate fair value due to the nature of the instrument and their relatively short maturities.

NOTE 5. Derivative Financial Instruments

The Company primarily utilizes commodity swap contracts to (i) reduce the effect of price volatility on the commodities the Company produces and sells, and (ii) support the Company’s capital budgeting and expenditure plans, (iii) protect the Company’s borrowing base under its Revolving Credit Facility, (iv) adhere to the hedge obligations included in the senior unsecured notes and (v) support the payment of contractual obligations.

The following table summarizes the effect of derivatives on the Company’s consolidated statements of operations (in thousands):

Crude oil production derivatives. The Company sells its crude oil production at the lease and the sales contracts governing such crude oil production are tied directly to, or are correlated with, NYMEX WTI crude oil prices. As such, the Company uses NYMEX WTI derivative contracts to manage future crude oil price volatility.

The Company’s outstanding crude oil derivative contracts as of June 30, 2022 and the weighted average crude oil prices per barrel for those contracts are as follows:

Natural gas production derivatives. The Company sells its natural gas production at the lease and the sales contracts governing such natural gas production are tied directly to, or are correlated with, NYMEX HH natural gas prices. As such, the Company uses NYMEX HH derivative contracts to manage future natural gas price volatility.

The Company’s outstanding natural gas derivative contracts as of June 30, 2022 and the weighted average natural gas prices per MMBtu for those contracts are as follows:

The Company uses credit and other financial criteria to evaluate the credit standings of, and to select, counterparties to its derivative financial instruments. Although the Company does not obtain collateral or otherwise secure the fair value of its derivative financial instruments, associated credit risk is mitigated by the Company’s credit risk policies and procedures.

Net derivative liabilities associated with the Company’s open commodity derivatives by counterparty are as follows (in thousands):

NOTE 6. Exploratory Well Costs

The Company capitalizes exploratory well and project costs until a determination is made that the well or project has either found proved reserves, is impaired or is sold. The Company's capitalized exploratory well and project costs are included in proved properties in the consolidated balance sheets. If the exploratory well or project is determined to be impaired, the impaired costs are charged to exploration and abandonments expense.

The changes in capitalized exploratory well costs are as follows (in thousands):

All capitalized exploratory well costs have been capitalized for less than one year based on the date of drilling.

(a) Debt issuance costs as of June 30, 2022 and December 31, 2021 consisted of $11.7 million and $2.6 million, respectively, in costs less accumulated amortization of $2.3 million and $502,000, respectively.

(b) Discounts as of June 30, 2022 and December 31, 2021 consisted of $14.8 million and zero, respectively, in discounts less accumulated amortization of $2.7 million and zero, respectively.

Revolving Credit Facility. In December 2020, the Company entered into a Credit Agreement with Fifth Third Bank, National Association (“Fifth Third”) as the administrative agent and sole lender to establish a revolving credit facility (“Revolving Credit Facility”) that matures on June 17, 2024 (subject to a springing maturity date of October 1, 2023 if the Senior Notes are outstanding on such date). The Revolving Credit Facility had an initial borrowing base of $40.0 million. However, the Company elected to reduce the aggregate elected commitments under the Revolving Credit Facility to $20.0 million. In June 2021, the Company entered into the First Amendment to, among other things, (i) complete the semi-annual borrowing base redetermination process which increased the borrowing base from $40.0 million to $125.0 million and (ii) modify the terms of the Credit Agreement to increase the aggregate elected commitments from $20.0 million to $125.0 million. A syndicate of banks joined the credit facility at differing levels of commitments with Fifth Third remaining the administrative agent. In October 2021, the Company entered into the Second Amendment to, among other things, (i) complete a semi-annual borrowing base redetermination process, which increased the borrowing base from $125.0 million to $195.0 million and (ii) modify the terms of the Credit Agreement to increase the aggregate elected commitments from $125.0 million to $195.0 million. In February 2022, the Company entered into the Third Amendment to, among other things, (i) reduce the borrowing base from $195.0 million to $138.8 million, (ii) modify the terms of the Credit Agreement to reduce the aggregate elected commitments from $195.0 million to $138.8 million, (iii) update the maturity date to a springing maturity date, which will cause the Credit Agreement to mature on October 1, 2023 if the Senior Notes are not retired by that date, (iv) allow the Company to redeem the Senior Notes with proceeds of a refinancing, with proceeds of an equity offering or with cash, in each case, subject to certain customary conditions and (v) replace the USD LIBOR rates with Term SOFR rates. In June 2022, simultaneous with the closing of one of the aforementioned acquisitions, the Company entered into the Fourth Amendment to the Revolving Credit Facility to, among other things, (i) increase (a) the aggregate elected commitments to $400.0 million, (b) the borrowing base to $400.0 million and (c) the maximum credit amount to $1.5 billion, (ii) increase the excess cash threshold to $75.0 million, (iii) modify the affirmative hedging requirement and (iv) increase the number of banks included in the syndicate at differing levels of commitments with Fifth Third remaining the administrative agent.

The borrowing capacity under the Revolving Credit Facility is equal to the lowest of (i) the borrowing base (which stands at $400.0 million as of June 30, 2022), (ii) the aggregate elected commitments (which stand at $400.0 million as of June 30, 2022) and (iii) $1.5 billion. As of June 30, 2022 and December 31, 2021, the Company had $285.0 million and $100.0 million, respectively, outstanding borrowings under the Revolving Credit Facility. Borrowings under the Revolving Credit Facility prior to February 2022 bore interest, at the option of the Company, based on (a) a rate per annum equal to the higher of (i) the prime rate announced from time to time by Fifth Third, (ii) the weighted average of the rates on overnight federal funds transactions with members of the Federal Reserve System during the last preceding business day plus 0.5 percent and (iii) the Adjusted LIBO Rate for one-month Interest Period, plus a margin (the “Applicable Margin”) which was determined by the Borrowing Base Utilization Percentage as defined in the Revolving Credit Facility or (b) the LIBO Rate for a one, three or six month Interest Period multiplied by the Statutory Reserve Rate. As of February 2022, borrowings under the Revolving Credit Facility bear interest at the option of the Company, based on (a) the prime rate announced from time to time by Fifth Third or (b) a rate equal to the higher of (i) zero percent per annum and (ii) SOFR relating to quotations for 1 or 3 months. Letters of credit outstanding under the Revolving Credit Facility are subject to a per annum fee, representing the Applicable Margin plus 0.125 percent. The Company also pays commitment fees on undrawn amounts under the Revolving Credit Facility equal to 0.50 percent. Borrowings under the Revolving Credit Facility are secured by a first lien security interest on substantially all assets of the Company and its restricted subsidiaries, including mortgages on the Company’s and its restricted subsidiaries’ crude oil and natural gas properties. The Revolving Credit Facility is scheduled to have the borrowing base redetermined semiannually in April and October. Additionally, the Company and Fifth Third each have the option for a wild card evaluation between redeterminations.

The Revolving Credit Facility requires the maintenance of a ratio of total debt to EBITDAX, subject to certain adjustments, not to exceed 3.00 to 1.00 as of the last day of any fiscal quarter and a current ratio, subject to certain adjustments, of at least 1.00 to 1.00 as of the last day of any fiscal quarter.

The Company has limited equity cure rights for a breach of the above-listed financial covenants. Additionally, the Revolving Credit Facility contains additional restrictive covenants that limit the ability of the Company and its restricted subsidiaries to, among other things, incur additional indebtedness, incur additional liens, make investments and loans, enter into mergers and acquisitions, make or declare dividends and other payments, enter into certain hedging transactions, sell assets and engage in transactions with affiliates. The Revolving Credit Facility contains customary mandatory prepayments, including a monthly mandatory prepayment if the Consolidated Cash Balance (as defined in the Credit Agreement) is in excess of $75.0 million. In addition, the Credit Agreement is subject to customary events of default, including a change in control. If an event of default occurs and is continuing, the administrative agent or the majority of the lenders may accelerate any amounts outstanding and terminate lender commitments.

Senior Notes. In February 2022, the Company issued $225.0 million aggregate principal amount of 10.00% senior unsecured notes that will mature on February 15, 2024 (“Senior Notes”). The Company received proceeds, net of $21.2 million of issuance costs and discounts, of $203.8 million. The net proceeds were used to pay down the balance of our Revolving Credit Facility to zero at closing and to fund our ongoing capital development program with subsequent draws on the Revolving Credit Facility. Interest on the Senior Notes will be payable on August 15 and February 15 of each year.

Both the Revolving Credit Facility and the Senior Notes have hedging obligations that the Company adheres to.

NOTE 8. Asset Retirement Obligations

The Company’s asset retirement obligations primarily relate to the future plugging and abandonment of wells and related facilities. Market risk premiums associated with asset retirement obligations are estimated to represent a component of the Company’s credit-adjusted risk-free rate that is utilized in the calculations of asset retirement obligations.

Asset retirement obligations activity is as follows (in thousands):

As of June 30, 2022 and December 31, 2021, all asset retirement obligations are considered noncurrent and classified as such in the accompanying consolidated balance sheets.

NOTE 9. Incentive Plans

401(k) Plan. The HighPeak Energy Employees, Inc 401(k) Plan (the “401(k) Plan”) is a defined contribution plan established under Section 401 of the Internal Revenue Code of 1986, as amended (the "Code"). All regular full-time and part-time employees of the Company are eligible to participate in the 401(k) Plan after three continuous months of employment with the Company. Participants may contribute up to 80 percent of their annual base salary into the 401(k) Plan. Matching contributions are made to the 401(k) Plan in cash by the Company in amounts equal to 100 percent of a participant’s contributions to the 401(k) Plan up to four percent of the participant’s annual base salary (the “Matching Contribution”). Each participant’s account is credited with the participant’s contributions, Matching Contributions and allocations of the 401(k) Plan’s earnings. Participants are fully vested in their account balances at their eligibility date. During the six months ended June 30, 2022 and 2021, the Company contributed $141,000 and $111,000 to the 401(k) Plan, respectively.

Long-Term Incentive Plan. The Company’s Amended & Restated Long Term Incentive Plan (“LTIP”) provides for the grant of stock options, dividend equivalents, cash awards and substitute awards to officers and employees of the Company, as well as stock awards to directors and employees of the Company. The number of shares available for grant pursuant to awards under the LTIP as of June 30, 2022 are as follows:

Stock Options. Stock option awards were granted to employees on August 24, 2020, November 4, 2021 and May 4, 2022. Stock-based compensation expense related to the Company’s stock option awards for the three and six months ended June 30, 2022 and 2021 was $10.8 million and $1.9 million, respectively, and as of June 30, 2022 and December 31, 2021 there was $1.9 million and $1.8 million, respectively, of unrecognized stock-based compensation expense related to unvested stock option awards. The unrecognized compensation expense will be recognized on a straight-line basis over the remaining vesting periods of the awards, which is a period of less than two years.

The Company estimates the fair value of stock options granted on the grant date using a Black-Scholes option valuation model, which requires the Company to make several assumptions. The expected term of options granted was determined based on the simplified method of the midpoint between the vesting dates and the contractual term of the options. The risk-free interest rate is based on the U.S. treasury yield curve rate for the expected term of the option at the date of grant and the volatility was based on the volatility of either an index of exploration and production crude oil and natural gas companies or on a peer group of companies with similar characteristics of the Company on the date of grant since the Company had minimal or did not have any trading history. More detailed stock options activity and details are as follows:

Restricted Stock Issued to Employee Members of the Board. A total of 1,500,500 shares of restricted stock was approved by the board of directors to be granted to certain employee members of the board of the Company on November 4, 2021, which vest on the three-year anniversary of such grant assuming the employees remain in his or her position as of the anniversary date. Therefore, stock-based compensation expense of $3.6 million was recognized during the six months ended June 30, 2022 and the remaining $16.8 million will be recognized over the remaining restricted period, which was based upon the closing price of the stock on the date of the restricted stock issuance. The board of directors also cancelled the previously issued equity-based liability bonuses and approved a total of 600,000 shares of restricted stock to be granted to certain employees of the Company on June 1, 2022, which vest on November 4, 2024, assuming the employees remain in his or her position as of that date and cancelled certain contractual equity-based bonuses to such employees. Therefore, stock-based compensation expense of $3.8 million was recognized during the six months ended June 30, 2022, and the remaining $16.4 million will be recognized over the remaining restricted period, which was based upon the closing price of the stock on the date of the restricted stock issuance.

Stock Issued to Outside Directors. A total of 21,184 shares of restricted stock was approved by the board of directors to be granted to the outside directors of the Company on June 1, 2022, which will vest at the next annual meeting, assuming the board members maintain their positions on the board. Therefore, stock-based compensation expense of $61,000 was recognized during the six months ended June 30, 2022 and the remaining $672,000 will be recognized between July 2022 and June 2023, which was based upon the closing price of the stock on the date of the restricted stock issuance. In addition, a total of 67,779 shares of restricted stock was approved by the board of directors to be granted to the outside directors of the Company on June 1, 2021, which vested in January 2022. Therefore, the remaining stock-based compensation expense of $284,000 was recognized during the six months ended June 30, 2022, which was based upon the closing price of the stock on the date of the restricted stock issuance.

NOTE 10. Commitments and Contingencies

Leases. The Company follows ASC Topic 842, “Leases” to account for its operating and finance leases. Therefore, as of June 30, 2022 the Company had right-of-use assets totaling $579,000 included in other noncurrent assets and operating lease liabilities totaling $591,000, $475,000 of which are included in other current liabilities and $116,000 of which are included in other noncurrent liabilities, and as of December 31, 2021 the Company had right-of-use assets totaling $852,000 included in other noncurrent assets and operating lease liabilities totaling $856,000, $513,000 of which are included in other current liabilities and $343,000 of which are included in other noncurrent liabilities on the accompanying consolidated balance sheets. The Company does not currently have any finance right-of-use leases. Maturities of the operating lease obligations are as follows (in thousands):

Legal actions. From time to time, the Company may be a party to various proceedings and claims incidental to its business. While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to these proceedings and claims will not have a material adverse effect on the Company's consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. The Company records reserves for contingencies when information available indicates that a loss is probable, and the amount of the loss can be reasonably estimated.

Indemnifications. The Company has agreed to indemnify its directors, officers and certain employees and agents with respect to claims and damages arising from acts or omissions taken in such capacity, as well as with respect to certain litigation.

Environmental. Environmental expenditures that relate to an existing condition caused by past operations and have no future economic benefits are expensed. Environmental expenditures that extend the life of the related property or mitigate or prevent future environmental contamination are capitalized. Liabilities for expenditures that will not qualify for capitalization are recorded when environmental assessment and/or remediation is probable, and the costs can be reasonably estimated. Such liabilities are undiscounted unless the timing of cash payments for the liability is fixed or reliably determinable. Environmental liabilities normally involve estimates that are subject to revision until settlement or remediation occurs.

Crude oil delivery commitments. In May 2021, the Company entered into a crude oil marketing contract with Lion as the purchaser and DKL Permian Gathering, LLC (“DKL”) as the gatherer and transporter. The contract includes the Company’s current and future crude oil production from the majority of its horizontal wells in Flat Top where DKL is constructing a crude oil gathering system and custody transfer meters to most of all the Company’s central tank batteries. The contract contains a minimum volume commitment commencing October 2021 based on the gross barrels delivered at the Company’s central tank battery facilities and is 5,000 Bopd for the first year, 7,500 Bopd for the second year and 10,000 Bopd for the remaining eight years of the contract. However, the Company has the ability under the contract to cumulatively bank excess volumes delivered to offset future minimum volume commitments. For the period from October 1, 2021 to June 30, 2022, the Company has delivered approximately 17,503 Bopd under the contract. The remaining monetary commitment as of June 30, 2022, if the Company never delivers any additional volumes under the agreement, is approximately $22.2 million.

Natural gas purchasing replacement contract. In May 2021, the Company entered into a replacement natural gas purchase contract with WTG Gas Processing, L.P. (“WTG”) as the gatherer, processor and purchaser of the Company’s current and future gross natural gas production in Flat Top. The replacement contract provides the Company with improved natural gas and NGL pricing and requires WTG to expand its current low-pressure gathering system, which eliminates the need for in-field compression in Flat Top to accommodate the Company’s increased natural gas production volumes based on the current plan of development. The Company will provide WTG with certain aid-in-construction payments to be reimbursed over time based on throughput through the system. The replacement contract does not contain any minimum volume commitments.

Power contracts. In June 2021, the Company entered into a contract with Priority Power Management, LLC (“Priority Power”) whereby Priority Power will develop an electric high-voltage (“EHV”) substation, medium voltage distribution systems and a 13-megawatt direct current solar photovoltaic facility located on approximately 80 acres of land owned by the Company north of Big Spring, Texas in Howard County to provide for the Company’s electrical power needs in its Flat Top operating area including powering drilling rigs and day-to-day operations. The EHV substation was interconnected with the ERCOT transmission grid in May 2022 via the local electric utility, has an initial capacity of up to 50 megavolt amperes and was designed for future expansion capability. The solar generation facility will be interconnected with the medium voltage distribution system that will be energized from the new EHV substation. Priority Power will develop, finance, engineer, construct, operate and maintain the project facilities.

Also in June 2021, the Company entered into a contract with Oncor Electric Delivery Company, LLC (“Oncor”) to construct certain facilities to deliver electricity to the aforementioned substation. In conjunction with this contract, the Company issued a $1.9 million letter of credit to Oncor until such time as the Company’s load meets or exceeds 12 megawatts as measured during any fifteen (15) minute interval on or before May 20, 2023.

Finally, in June 2022, the Company entered into a contract with TXU Energy Retail Company LLC (“TXU”) to provide a block of electric power via the aforementioned transmission system at an attractive variable rate, which fluctuates based on the usage by the Company through May 31, 2032.  In conjunction with this contract, the Company issued a $1.7 million letter of Credit in lieu of a deposit to TXU that is cancellable at the end of the contract term. 

Sand commitments. The Company is party to an agreement whereby it has agreed to purchase at least 600,000 tons of sand over a two-year period beginning at the commencement date of the sand mine being operational, which was late in the second quarter of 2022. There are stipulations in the agreement that reduce this commitment should we experience a downturn in oil prices. However, generally if the Company never takes delivery of any sand under the agreement, the monetary commitment as of June 30, 2022 is approximately $8.7 million.

NOTE 11. Related Party Transactions

Water Treatment. In September 2021, the Company entered into a contract with Pilot Exploration, Inc., (“Pilot”), whose President and CEO is an outside director of the Company, to deploy Pilot’s proprietary water treatment technology in the Company’s Flat Top area to treat up to 25,000 barrels of produced water per day such that it can be reused in the Company’s completion operations or sold to third parties for their completion operations. This contract was set to expire on March 1, 2022, however it was extended to July 1, 2022 based on the early results of the project. During the six months ended June 30, 2022, the Company paid $1.4 million to Pilot for such services.

In May 2022, the Company entered into an agreement with Pilot to utilize Pilot’s proprietary water treatment technology in the Company’s Flat Top area to treat produced water such that it can be reused in the Company’s completion operations or sold to third parties for their completion operations. During the one-year term of the agreement, beginning no later than October 1, 2022, the Company has agreed to a minimum volume commitment of 29.2 million barrels of produced water while maintaining the ability to bank excess produced water processed each month toward the minimum volume commitment. The monetary commitment, if the Company never delivers any produced water to be treated under the agreement, is approximately $6.0 million.

NOTE 12. Major Customers

Lion Oil Trading and Transportation, LLC (“Lion”) accounted for approximately 88% and 95% of the Company’s revenues during the six months ended June 30, 2022 and 2021, respectively. Based on the current demand for crude oil and natural gas and the availability of other purchasers, management believes the loss of this major purchaser would not have a material adverse effect on our financial condition and results of operations because crude oil and natural gas are fungible products with well-established markets and numerous purchasers.

The reconciliation between the income tax expense computed by multiplying pre-tax income by the U.S. federal statutory rate and the reported amounts of income tax expense is as follows (in thousands, except rate):

The tax effects of temporary differences that give rise to significant portions of the deferred tax assets and liabilities were as follows as of June 30, 2022 and December 31, 2021 (in thousands):

The effective income tax rate differs from the U.S. statutory rate of 21 percent primarily due to reversing a portion of its deferred tax asset related to stock-based compensation, deferred state income taxes and other permanent differences between GAAP income and taxable income.

As required by ASC Topic 740, “Income Taxes,” (“ASC 740”) the Company uses reasonable judgments and makes estimates and assumptions related to evaluating the probability of uncertain tax positions. The Company bases its estimates and assumptions on the potential liability related to an assessment of whether the income tax position will “more likely than not” be sustained in an income tax audit. Based on that analysis, the Company believes the Company has not taken any material uncertain tax positions, and therefore has not recorded an income tax liability related to uncertain tax positions. However, if actual results materially differ, the Company’s effective income tax rate and cash flows could be affected in the period of discovery or resolution. The Company also reviews the estimates and assumptions used in evaluating the probability of realizing the future benefits of the Company’s deferred tax assets and records a valuation allowance when the Company believes that a portion or all the deferred tax assets may not be realized. If the Company is unable to realize the expected future benefits of its deferred tax assets, the Company is required to provide a valuation allowance. The Company uses its history and experience, overall profitability, future management plans, tax planning strategies, and current economic information to evaluate the amount of valuation allowance to record. As of June 30, 2022 and December 31, 2021, the Company had not recorded a valuation allowance for deferred tax assets arising from its operations because the Company believed they met the “more likely than not” criteria as defined by the recognition and measurement provisions of ASC 740. The Company reversed a portion of its deferred tax asset related to stock-based compensation based on the assumption that the tax deduction will be subject to IRC Section 162(m) limits when the stock options are exercised and the restricted stock vests. IRC Section 162(m) limits compensation deductions to $1.0 million per year for certain Company executives. This resulted in a $3.4 million reduction in the deferred tax asset and reduced the amount of income tax benefit realized during the six months ended June 30, 2022.

The Company is also subject to Texas Margin Tax. The Company realized no current Texas Margin Tax in the accompanying consolidated financial statements as we do not anticipate owing any Texas Margin Tax for 2022 or 2021. However, the Company has recognized a deferred Texas Margin Tax liability of $2.5 million and $1.8 million as of June 30, 2022 and December 31, 2021, respectively, in the accompanying consolidated financial statements.

NOTE 14. Earnings Per Share

The Company uses the two-class method of calculating earnings per share because certain of the Company’s stock-based awards qualify as participating securities.

The Company’s basic earnings per share attributable to common stockholders is computed as (i) net income as reported, (ii) less participating basic earnings (iii) divided by weighted average basic common shares outstanding. The Company’s diluted earnings per share attributable to common stockholders is computed as (i) basic earnings attributable to common stockholders, (ii) plus reallocation of participating earnings (iii) divided by weighted average diluted common shares outstanding.

The following table reconciles the Company’s earnings from operations and earnings attributable to common stockholders to the basic and diluted earnings used to determine the Company’s earnings per share amounts for the three and six months ended June 30, 2022 and 2021 under the two-class method (in thousands):

The calculation for weighted average shares reflects shares outstanding over the reporting period based on the actual number of days the shares were outstanding.

NOTE 15. Stockholders’ Equity

Issuance of Common Stock. On March 25, 2022, June 21, 2022 and June 27, 2022, respectively, the Company issued 6,960,000, 371,517 and 3,522,117 shares of HighPeak Energy common stock related to the aforementioned crude oil and natural gas property acquisitions. On June 1, 2022, the Company issued 21,184 and 600,000 shares of restricted stock to outside directors and certain employees, respectively. The remaining 977,588 shares of HighPeak Energy common stock issued during the six months ended June 30, 2022 were the result of warrants (965,588 shares) and stock options (12,000 shares) being exercised.

Dividends and dividend equivalents. In April 2022, the board of directors of the Company declared a quarterly dividend of $0.025 per share of common stock outstanding which resulted in a total of $2.6 million in dividends being paid on May 25, 2022. In addition, under the terms of the LTIP, the Company paid a dividend equivalent per share to all vested stock option holders of $214,000 in May 2022 and will accrue a dividend equivalent per share to all unvested stock option holders which is payable upon vesting of up to an additional $36,000, assuming no forfeitures. In addition, the Company will accrue an additional combined $53,000 in dividends on the restricted stock issued to management directors and certain employees that will be payable upon vesting.

In January 2022, the board of directors of the Company approved a quarterly dividend of $0.025 per share of common stock outstanding which resulted in a total of $2.4 million in dividends being paid on February 25, 2022. In addition, under the terms of the LTIP, the Company paid a dividend equivalent per share to all vested stock option holders and accrued a dividend equivalent per share to all unvested stock option holders payable upon vesting, which equates to a total payment of $214,000 in February 2022 and up to an additional $36,000, assuming no forfeitures. In addition, the Company accrued an additional combined $53,000 in dividends on the restricted stock issued to management directors and certain employees that will be payable upon vesting.

Outstanding Securities. At June 30, 2022 and December 31, 2021, the Company had 109,226,591 and 96,774,185 shares of common stock outstanding, respectively, 8,290,572 and 9,500,166 warrants outstanding, respectively, with an exercise price of $11.50 per share that expire on August 21, 2025 and 10,209,300 and 10,209,300 CVRs outstanding, respectively, that give the holders a right to receive up to 2.125 shares of HighPeak Energy common stock per CVR to satisfy the Preferred Returns (with an equivalent number of shares of Company common stock held by HighPeak Energy, LP (“HighPeak I”) and HighPeak Energy II, LP (“HighPeak II”) being collectively forfeited in connection therewith). As such, HighPeak I and HighPeak II have placed a total of 21,694,763 shares of common stock of the Company in escrow.