SANDRIDGE ENERGY, INC. The following discussion and analysis is intended to help the reader understand our business, financial condition, results of operations, liquidity and capital resources. This discussion and analysis should be read in conjunction with other sections of this report, including: "Business" in Item 1 and "Financial Statements and Supplementary Data" in Item 8. Our discussion and analysis includes the following subjects:
•Overview;
•Consolidated Results of Operations;
•Liquidity and Capital Resources;
•Valuation Allowance; and
•Critical Accounting Policies and Estimates.
We have applied theSecurities and Exchange Commission's adopted FAST Act Modernization and Simplification of Regulation S-K, which limits the discussion to the two most recent calendar years. This discussion and analysis deals with comparisons of material changes in the consolidated financial statements for years endedDecember 31, 2022 and 2021. For the comparison of the years endedDecember 31, 2021 and 2020, see "Management's Discussion and Analysis of Consolidated Results of Operations" in Part II, Item 7 of our 2021 Annual Report on Form 10-K, filed with theSecurities and Exchange Commission onMarch 10, 2022 . Overview We are an independent oil and natural gas company with a principal focus on acquisition, development and production activities in theU.S. Mid-Continent. Prior toFebruary 5, 2021 , we held assets in theNorth Park Basin , which have been sold in their entirety.
Operational Activities
For the year endedDecember 31, 2022 , there were eight operated wells drilled and six wells completed. There was no drilling activity on our operated acreage during the year endedDecember 31, 2021 . However, we brought wells that were previously not producing on to production as part of our well reactivation program during the year endedDecember 31, 2021 .
The chart below shows production by product for the years ended
[[Image Removed: sd-20221231_g1.jpg]]
(1)For the year ended
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Total production for the Company in 2022 was composed of approximately 14.7% oil, 54.4% natural gas and 30.9% NGLs compared to 14.1% oil, 52.5% natural gas and 33.4% NGLs in 2021.
Mid-Continent total production for the years ended
Year Ended December 31,
2022 2021
Oil 14.7 % 13.2 %
NGL 30.9 % 33.7 %
Natural gas 54.4 % 53.1 %
Total 100.0 % 100.0 %
Highlighted Events
•Consistent with our 2022 capital development program, we drilled eight wells
and completed six wells during the year ended December 31, 2022 .
•On October 5, 2022 the Company's Board of Directors appointed Ms. Nancy Dunlap
to serve as a member of the Board. Ms. Dunlap also joined the Audit Committee.
•As part of our well reactivation program, we returned 50 wells to production
for the year ended December 31, 2022 .
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Outlook
We will continue to focus on growing the cash value and generation capability of
our asset base in a safe, responsible and efficient manner, while exercising
prudent capital allocations to projects we believe provide high rates of returns
in the current commodity price environment. These projects include (1) a
continuation of our well reactivation program, (2) artificial lift conversions
to more efficient and cost effective systems and (3) focused drilling in
high-graded areas. We will continue to monitor forward-looking commodity prices,
results, costs and other factors that could influence returns on investments,
which will continue to shape our disciplined development decisions in 2023 and
beyond. We will also continue to maintain optionality to execute on value
accretive merger and acquisition opportunities that could bring synergies,
leverage our core competencies, compliment our portfolio of assets, further
utilize our NOLs or otherwise yield attractive returns for our shareholders.
Consolidated Results of Operations
The majority of our consolidated revenues and cash flow are generated from the
production and sale of oil, natural gas and NGLs. Our revenues, profitability
and future growth depend substantially on prevailing prices received for our
production, the quantity of oil, natural gas and NGLs we produce, and our
ability to find and economically develop and produce our reserves. Prices for
oil, natural gas and NGLs fluctuate widely and are difficult to predict. To
provide information on the general trend in pricing, the average annual NYMEX
prices for oil and natural gas for recent years are presented in the table
below:
Year Ended December 31,
2022 2021
NYMEX WTI Oil (per Bbl) $ 94.90 $ 68.18
NYMEX Henry Hub Natural gas (per Mcf) $ 6.68 $ 4.04
In order to reduce our exposure to price fluctuations, from time to time we enter into commodity derivative contracts for a portion of our anticipated future oil, natural gas, and NGL production as discussed in Item 7A. "Quantitative and Qualitative Disclosures About Market Risk." During periods where the strike prices for our commodity derivative contracts are below market prices at the time of settlement, we may not fully benefit from increases in the market price of oil, natural gas and NGLs. Conversely, during periods of declining market prices of oil, natural gas and NGL, our commodity derivative contracts may partially offset declining revenues and cash flow to the extent strike prices for our contracts are above market prices at the time of settlement.
Acquisitions and Divestitures of Properties
2021 Acquisitions and Divestitures
OnApril 22, 2021 , we announced the acquisition of all the overriding royalty interest assets ofSandRidge Mississippian Trust I (the "Trust"). The gross purchase price was$4.9 million (net$3.6 million , given our 26.9% ownership of the Trust). OnFebruary 5, 2021 , we sold all of our oil and natural gas properties and related assets of theNorth Park Basin ("NPB") inColorado for a purchase price of$47 million in cash. Net proceeds were$39.7 million in cash as a result of customary effective to close date adjustments and a$0.8 million post-close adjustment made during the second half of the year. The sale resulted in an$18.9 million gain after the post-close adjustment. 44
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Oil, Natural Gas and NGL Production and Pricing
The table below presents production and pricing information for the years endedDecember 31, 2022 and 2021. Year Ended December 31, 2022 2021 Change % Change Production data (in thousands) Oil (MBbls) 949 957 (8) (1) % NGL (MBbls) 1,997 2,267 (270) (12) % Natural gas (MMcf) 21,101 21,417 (316) (1) % Total volumes (MBoe) 6,463 6,793 (330) (5) % Average daily total volumes (MBoe/d) 17.7 18.6 (0.9) (5) % Average prices-as reported (1) Oil (per Bbl)$ 92.21 $ 65.10 $ 27.11 42 % NGL (per Bbl)$ 31.88 $ 22.42 $ 9.46 42 % Natural gas (per Mcf)$ 4.88 $ 2.60 $ 2.28 88 % Total (per Boe)$ 39.34 $ 24.86 $ 14.48 58 % Average prices-including impact of derivative contract settlements Oil (per Bbl)$ 92.21 $ 65.10 $ 27.11 42 % NGL (per Bbl)$ 31.72 $ 22.28 $ 9.44 42 % Natural gas (per Mcf)$ 4.97 $ 2.51 $ 2.46 98 % Total (per Boe)$ 39.58 $ 24.53 $ 15.05 61 % ___________________
(1)Prices represent actual average prices for the periods presented and do not include the impact of derivative transactions.
The table below presents production by area of operation for the years ended
Year Ended December 31,
2022 2021
% of Total % of Total
Production (MBoe) Production Production (MBoe) Production
Mid-Continent 6,463 100.0 % 6,726 99.0 %
North Park Basin - - % 67 1.0 %
Total 6,463 100.0 % 6,793 100.0 %
Revenues
Consolidated revenues for the years ended December 31, 2022 and 2021 are
presented in the table below (in
thousands).
Year Ended December 31,
2022 2021 Change % Change
Revenues
Oil $ 87,528 $ 62,297 $ 25,231 41 %
NGL 63,663 50,836 12,827 25 %
Natural gas 103,067 55,749 47,318 85 %
Total revenues $ 254,258 $ 168,882 $ 85,376 51 %
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Variances in oil, natural gas and NGL revenues attributable to changes in the average prices received for our production and total production volumes sold for the years endedDecember 31, 2022 and 2021 are shown in the table below (in thousands):
2021 oil, natural gas and NGL revenues
Oil, natural gas and NGL revenues increased primarily due to improvements in realized commodity prices. Production volumes for the year endedDecember 31, 2022 decreased slightly due to the natural declines of our producing wells, which were partially offset from the production from our well reactivations and new well activity for the year.
Operating Expenses
Operating expenses for the years endedDecember 31, 2022 and 2021 consisted of the following (in thousands): Year Ended December 31, 2022 2021 Change % Change Lease operating expenses$ 41,286 $ 35,999 $ 5,287 14.7 % Production, ad valorem, and other taxes 15,880 9,918 5,962 60.1 % Depreciation and depletion-oil and natural gas 11,542 9,372 2,170 23.2 % Depreciation and amortization-other 6,342 6,073 269 4.4 % Total operating expenses$ 75,050 $ 61,362 $ 13,688 22.3 % Lease operating expenses ($/Boe)$ 6.39 $ 5.30 $ 1.09 20.6 %
Production, ad valorem, and other taxes ($/Boe)
$ 1.00 68.6 % Depreciation and amortization-oil and natural gas ($/Boe)$ 1.79 $ 1.38 $ 0.41 29.7 % Production, ad valorem, and other taxes (% of oil, natural gas, and NGL revenue) 6.2 % 5.9 % 0.4 % 5.5 %
The increase in lease operating expenses was primarily due to inflationary
pressures, a higher number of producing wells and higher workover expenses due
to our well reactivation program during the year ended
Production, ad valorem, and other taxes increased primarily due to the increase in production taxes as a result of increased revenues.
The increase in depreciation and depletion for oil and natural gas properties was primarily the result of increased capital expenditures from higher drilling and completion activity which increased our depletion rate.
Full cost pool impairment. We did not record a full cost ceiling limitation
impairment for the years ended
Calculation of the full cost ceiling test is based on, among other factors, trailing twelve-monthSEC prices as adjusted for price differentials and other contractual arrangements. TheSEC prices utilized in the calculation of proved reserves included in the full cost ceiling test atDecember 31, 2022 were$93.67 per barrel of oil and$6.36 per MMBtu of natural gas, before price differential adjustments.
Based on the
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calculation of our December 31, 2022 ceiling test, no full cost ceiling
limitation impairment is indicated for the first quarter of 2023.
However, a full cost ceiling limitation impairment may still be realized in the
first quarter of 2023 and in subsequent quarters based on the outcome of
numerous other factors such as additional declines in the actual trailing
twelve-month SEC prices, production, lower commodity prices, changes in
estimated future development costs and operating expenses, and other revisions
to our proved reserves. Any such ceiling test impairments in 2023 could be
material to our net earnings.
Full cost pool impairments have no impact to our cash flow or liquidity.
Other Operating Expenses
Other operating expenses for the years ended
Year Ended December 31,
2022 2021 Change % Change
General and administrative $ 9,449 $ 9,675 (226) (2.3) %
Restructuring expenses 382 792 (410) (51.8) %
Employee termination benefits - 49 (49) (100.0) %
(Gain) loss on derivative contracts (5,975) 2,251 (8,226) (365.4) %
(Gain) loss on sale of assets - (18,952) 18,952 (100.0) %
Other operating expense (income) (99) (382)
283 (74.1) %
Total other operating expenses
General and administrative expenses decreased for the year endedDecember 31, 2022 compared to the year endedDecember 31, 2021 due to continued efforts of cost control initiatives.
Restructuring expenses represent fees and costs associated with our predecessor
company's 2016 bankruptcy filing and our exit from NPB in
Year Ended December 31,
2022 2021
(Gain) loss on derivative contracts $ (5,975) $ 2,251
Cash paid (received) on settlements $ (1,525) $ 2,230
Our derivative contracts are not designated as accounting hedges and, as a
result, changes in the fair value of our commodity derivative contracts are
recorded quarterly as a component of operating expenses. Internally, management
views the settlement of commodity derivative contracts at contractual maturity
as adjustments to the price received for oil and natural gas production to
determine "effective prices." In general, cash is received on settlement of
contracts due to lower oil and natural gas prices at the time of settlement
compared to the contract price for our commodity derivative contracts, and cash
is paid on settlement of contracts due to higher oil and natural gas prices at
the time of settlement compared to the contract price for our commodity
derivative contracts. See Item 7A. "Quantitative and Qualitative Disclosures
about Market Risk" of this report for additional discussion of our commodity
derivatives.
Gain on sale of assets for the year ended
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Interest (income) expense, net for the years ended
Year Ended December 31,
2022 2021
Interest expense
Interest expense on debt and letters of
credit $ 37 $ 377
Interest expense on right of use assets 36 26
Write off of debt issuance costs - 174
Amortization of debt issuance costs,
premium and discounts - 57
Capitalized interest - (252)
Interest expense - other 143 25
Total 216 407
Less: interest income (2,026) (3)
Total interest (income) expense, net
Interest (income) expense, net during the year endedDecember 31, 2022 is primarily comprised of interest income received from cash deposits partially offset by interest paid on royalty obligations of$0.1 million , interest on vehicle leases and letters of credit. Interest expense incurred during the year endedDecember 31, 2021 is primarily comprised of interest and fees paid on the 2020 Credit Facility. The 2020 Credit Facility has been fully repaid and terminated as ofSeptember 2, 2021 . As a result of the termination of the 2020 Credit Facility,$0.2 million of deferred financing costs were expensed to Interest expense.
Other income (expense), net
Other income (expense), net for the years ended
Year Ended December 31,
2022 2021
Other income (expense), net
Other income, net$ 378 $ 3,055 Total other income$ 378 $ 3,055 The Other income (expense), net line item for the year endedDecember 31, 2022 is primarily comprised of gains on the sale of fleet vehicles and the removal of previously accrued liabilities due to a change in estimate. For the year endedDecember 31, 2021 , Other income (expense), net is primarily comprised of the removal of$2.4 million of an allowance for doubtful accounts as a result of the$2.4 million being collected inOctober 2021 . 48 -------------------------------------------------------------------------------- Table of Contents Liquidity and Capital Resources AtDecember 31, 2022 , our cash and cash equivalents, including restricted cash, was$257.5 million . For the next twelve months, we expect to have ample liquidity with cash on hand and cash from operations. As ofMarch 8, 2023 , the Company had no outstanding term or revolving debt obligations. Our commodity derivative contracts are subject to credit risk of our counterparties being financially able to settle the transaction. We monitor the credit ratings of our derivative counterparties and consider our counterparties' credit default risk ratings in determining the fair value of our derivative contracts. However, any future failures by one or more counterparties could negatively impact our cash flow from operations.
Working Capital and Sources and Uses of Cash
Our principal sources of liquidity for 2022 included cash flow from operations and cash on hand.
Our working capital increased to$241.6 million atDecember 31, 2022 , compared to$97.7 million atDecember 31, 2021 . The positive impact on working capital resulted primarily from an increase in cash and cash equivalents atDecember 31, 2022 as a result of cash flows from operations, partially offset by increased accrued liabilities driven largely by our increased capital expenditure activity in 2022. We intend to spend between$26 million and$35 million in our 2023 capital budget plan, excluding any expenditures for acquisitions. We intend to fund capital expenditures and other commitments for the next 12 months using cash flows from our operations and cash on hand. We will endeavor to keep our capital spending within or very close to our projected cash flows from operations subject to changing industry conditions or events.
Cash Flows
Our cash flows from operations are substantially dependent on current and future prices for oil and natural gas, which historically have been, and may continue to be, volatile. For example, during the period fromJanuary 2018 throughDecember 2022 , the NYMEX WTI settled price for oil fluctuated between a high of$123.64 per Bbl and a low of$(36.98) per Bbl, and the month-end NYMEX Henry Hub settled price for gas fluctuated between a high of$24.74 per Mcf and a low of$1.38 per Mcf. If oil or natural gas prices decline from current levels, they could have a material adverse effect on our financial position, results of operations, cash flows and quantities of oil, natural gas and NGL reserves that may be economically produced. Further, if our future capital expenditures are limited or deferred, or we are unsuccessful in developing reserves and adding production through our capital program, the value of our oil and natural gas properties, financial condition and results of operations could be adversely affected.
Cash flows for the years ended
Year Ended
2022 2021
Cash flows provided by operating activities $ 164,696 $ 110,260
Cash flows provided by (used in) investing activities (45,117) 22,973
Cash flows (used in) financing activities (1,635) (21,975)
Net increase in cash, cash equivalents and restricted cash
$ 111,258
Cash Flows from Operating Activities
The$54.4 million increase in operating cash flows for the year endedDecember 31, 2022 compared to 2021, is primarily due to increased revenues which is the result of improved commodity prices as discussed above, offset by a slight decrease in production. The changes in operating assets and liabilities do not include changes in accounts payable or accrued expenses attributable to capital expenditures noted in the capital expenditure table below.
See "Consolidated Results of Operations" for further analysis of the changes in revenues and operating expenses.
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Cash Flows from Investing Activities
During the year ended December 31, 2022 , cash flows used in investing activities
primarily reflects capital expenditures of $44.1 million related to drilling,
capital workovers, well reactivations, and inventory purchases and $1.4 million
related to an acquisition of proved reserves. Cash outflows were partially
offset by $0.4 million of proceeds from the sale of assets.
During the year ended December 31, 2021 , cash flows provided by investing
activities primarily reflects $38.2 million of net cash proceeds primarily from
the sale of the NPB assets partially offset by capital expenditures of $11.6
million and the acquisition of overriding royalty interests for $3.6 million .
See "Note 3- Acquisitions, Divestitures and Disposal of Assets and Oil and Gas
Properties " to the accompanying consolidated financial statements included in
Item 8 of this report for additional information.
Capital Expenditures.
Our capital expenditures for the years ended
Year Ended December 31,
2022 2021
Capital Expenditures
Drilling and completions $ 38,077 $ 1,087
Capital workovers 10,322 8,958
Leasehold and geophysical 809 905
Capital expenditures, excluding acquisitions (on an accrual basis)
49,208 10,950 Acquisitions 1,431 3,545 Current year total capital expenditures, including acquisitions 50,639 14,495 Change in capital accruals (5,123) 633 Total cash paid for capital expenditures$ 45,516 $ 15,128
Capital expenditures, excluding acquisitions, for development activities
increased for the year ended
Cash Flows from Financing Activities
Our financing activities used$1.6 million of cash for the year endedDecember 31, 2022 , consisted primarily of$1.2 million of cash used for tax withholdings paid in exchange for shares withheld on employee vested stock awards that were settled by net exercise, and finance lease payments of$0.5 million offset by$0.1 million of proceeds from the exercise of stock options. Net exercises of stock awards allows the holder of a stock award to tender back to us a number of shares at fair value upon the vesting of such stock award, that equals the employee payroll tax obligation due. We then remit a cash payment to the relevant taxing authority on behalf of the employee for their payroll tax obligations resulting from the vesting of their stock award. Our financing activities used$22.0 million in of cash for the year endedDecember 31, 2021 , consisting primarily of repayments of borrowings under the 2020 Credit Facility of$20.0 million , finance lease payments of$1.0 million and cash used for tax withholdings paid in exchange for shares withheld on employee vested stock awards that were settled by net exercise of$0.9 million .
Share Repurchase Program
OnAugust 16, 2021 , our Board approved the initiation of a share repurchase program authorizing us to purchase up to an aggregate of$25.0 million of our common stock beginning as early asAugust 16, 2021 . We did not repurchase any common stock under the Program during the year ended 2022. 50
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Contractual Obligations and Off-Balance Sheet Arrangements
AtDecember 31, 2022 , our contractual obligations included asset retirement obligations and short and long-term leases. Additionally, we have certain financial instruments representing potential commitments that were incurred in the normal course of business to support our operations, including surety bonds. The underlying liabilities insured by these instruments are reflected in our balance sheets, where applicable. Therefore, no additional liability is reflected for the surety bonds or other instruments. As ofDecember 31, 2022 , we had future contractual payment commitments under various agreements, which are summarized below. The short-term leases and operating lease are not recorded in the accompanying consolidated balance sheets. Payments Due by Period Less than More than Total 1 year 1-3 years 3-5 years 5 years (In thousands)
Asset retirement obligations (1)
$ 127 $ 47,508 Operating lease 167 167 - - - Short-term leases 2,076 2,076 - - - Finance lease 1,059 459 600 - - Total$ 67,011 $ 18,776 $ 600 $ 127 $ 47,508 ____________________ (1)Asset retirement obligations are based on estimates and assumptions that affect the reported amounts as ofDecember 31, 2022 . These estimates and assumptions can be inherently unpredictable and may differ from actual results given the uncertainty of when we may be required to plug and abandon a well or retire an asset. As a result, we may not incur all of the estimated costs for the current asset retirement obligation as depicted above. During the year endedDecember 31, 2022 , plugging and abandonment costs incurred were$2.6 million . Valuation Allowance Upon emergence from bankruptcy and the application of fresh start accounting in 2016, our tax basis in property, plant, and equipment exceeded the book carrying value of our assets. Additionally, we had significantU.S. federal net operating losses remaining after the attribute reduction caused by the restructuring transactions. As such, the successor Company had significant deferred tax assets to consume upon emergence. In assessing the realizability of the deferred tax assets, we consider whether it is more likely than not that some or all of the deferred tax assets will not be realized. The ultimate realization of the deferred tax assets is dependent upon the generation of future income in periods in which the deferred tax assets can be utilized. In prior years, we determined that the deferred tax assets did not meet the more likely than not threshold of being utilized and thus recorded a valuation allowance. As ofDecember 31, 2022 , we have partially released our valuation allowance on our deferred tax assets by$64.5 million . We anticipate being able to utilize these deferred tax assets based on the generation of future income. A change in the estimate of future income could cause the valuation allowance to be adjusted in subsequent periods.
See "Note 13-Income Taxes" to the accompanying consolidated financial statements for additional discussion of income tax related matters.
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Critical Accounting Estimates
The discussion and analysis of the Company's financial condition and results of operations are based upon the Company's consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted inthe United States of America . The preparation of the Company's financial statements requires management to make assumptions and prepare estimates that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Estimates are based on historical experience and various other assumptions believed to be reasonable; however, actual results may differ significantly. The Company's critical accounting policies and additional information on significant estimates are discussed below. See "Note 1-Summary of Significant Accounting Policies" to the Company's accompanying consolidated financial statements in Item 8 of this report for additional discussion of significant accounting policies. Proved Reserves. Approximately 95.0% of the Company's reserves were estimated by independent petroleum engineers as ofDecember 31, 2022 . Estimates of proved reserves are based on the quantities of oil, natural gas and NGLs that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under existing economic and operating conditions. However, there are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future revenues, rates of production and timing of development expenditures, including many factors beyond the Company's control. Estimating reserves is a complex process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact manner and relies on assumptions and subjective interpretations of available geologic, geophysical, engineering and production data. The accuracy of reserve estimates is a function of the quality and quantity of available data, engineering and geological interpretation and judgment. In addition, as a result of volatility and changing market conditions, commodity prices and future development costs will change from period to period, causing estimates of proved reserves to change, as well as causing estimates of future net revenues to change. For the years endedDecember 31, 2022 and 2021, the Company revised its proved reserves from prior years' reports by approximately 8.1 MMBoe and 43.3 MMBoe, respectively, due to increases inSEC prices used to value reserves at the end of the applicable period, production performance indicating more (or less) reserves in place, larger (or smaller) reservoir size than initially estimated or additional proved reserve bookings within the original field boundaries among other factors. Estimates of proved reserves are key components of the Company's financial estimates used to determine depreciation and depletion on oil and natural gas properties and its full cost ceiling limitation. Future revisions to estimates of proved reserves may be material and could materially affect the Company's future depreciation, depletion and impairment expenses. Depreciation and depletion ofOil and Natural Gas Properties . In accordance with full cost accounting rules, capitalized costs are amortized using the unit-of-production method. Under this method, depreciation and depletion is computed at the end of each quarter by multiplying total production for the quarter by a depletion rate. The depletion rate is determined by dividing the total unamortized cost base plus future development costs by net equivalent proved reserves at the beginning of the quarter. Impairment ofOil and Natural Gas Properties . In accordance with full cost accounting rules, capitalized costs are subject to a limitation. The capitalized cost of oil and natural gas properties, net of accumulated depreciation, depletion and impairment, less related deferred income taxes and electrical infrastructure costs, may not exceed an amount equal to the ceiling limitation. The Company calculates its full cost ceiling limitation usingSEC prices adjusted for basis or location differentials, held constant over the life of the reserves. If capitalized costs exceed the ceiling limitation, the excess must be charged to expense. Once incurred, a write-down cannot be reversed at a later date. The Company did not record any impairment for the years endedDecember 31, 2022 or 2021.
See "Consolidated Results of Operations" and "Note 9-Impairment" to the Company's accompanying consolidated financial statements in Item 8 of this report for a discussion of the Company's impairments.
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Asset Retirement Obligations. Asset retirement obligations represent the
estimate of fair value of the cost to plug, abandon and remediate the Company's
wells at the end of their productive lives, in accordance with applicable
federal and state laws. The Company estimates the fair value of an asset's
retirement obligation in the period in which the liability is incurred (at the
time the wells are drilled or acquired). Estimating future asset retirement
obligations requires management to make estimates and judgments regarding
timing, existence of a liability and what constitutes adequate restoration. The
Company employs a present value technique to estimate the fair value of an asset
retirement obligation, which reflects certain assumptions and requires
significant judgment, including an inflation rate, its credit-adjusted,
risk-free interest rate, the estimated settlement date of the liability and the
estimated current cost to settle the liability based on third-party quotes and
current actual costs. Inherent in the present value calculation are the timing
of settlement and changes in the legal, regulatory, environmental and political
environments, which are subject to change. Changes in timing or to the original
estimate of cash flows will result in changes to the carrying amount of the
liability.
Income Taxes. Deferred income taxes are recorded for temporary differences
between the financial statement and income tax basis of assets and liabilities.
Deferred tax assets are recognized for temporary differences that will be
deductible in future years' tax returns and for operating loss and tax credit
carryforwards. Deferred tax assets are reduced by a valuation allowance if it is
deemed more likely than not that some or all of the deferred tax assets will not
be realized. Deferred tax liabilities are recognized for temporary differences
that will be taxable in future years' tax returns. In assessing the
realizability of the deferred tax assets, we consider whether it is more likely
than not that some or all of the deferred tax assets will not be realized. The
ultimate realization of the deferred tax assets is dependent upon the generation
of future income in periods in which the deferred tax assets can be utilized. In
prior years, we determined that the deferred tax assets did not meet the more
likely than not threshold of being utilized and thus recorded a valuation
allowance. As of December 31, 2022 , we have partially released our valuation
allowance on our deferred tax assets by $64.5 million . We anticipate being able
to utilize these deferred tax assets based on the generation of future income. A
change in the estimate of future income could cause the valuation allowance to
be adjusted in subsequent periods.
New Accounting Pronouncements. For a discussion of recently adopted accounting
standards and recent accounting standards not yet adopted, see "Note 1-Summary
of Significant Accounting Policies" to the Company's accompanying consolidated
financial statements in Item 8 of this report.
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