SM ENERGY REPORTS RECORD 2024 RESULTS AND TRANSFORMATIVE 2025 OPERATING PLAN; AND ANNOUNCES OFFICER RETIREMENT AND NEW APPOINTMENTS

• Focusing on operational execution to realize a step change in scale through the successful integration of the Company's recently acquired Uinta Basin assets; delivering low breakeven, high return wells across the portfolio by optimizing capital efficiency; demonstrating innovation; and remaining a leader in stewardship.
• Returning capital to stockholders by generating free cash flow to support our increased $0.80 per share annual fixed dividend, transferring enterprise value to equity holders by pursuing reduced debt to a target of 1 times leverage; and resuming the Company's share buyback program, as appropriate, given $500.0 million in authorization.
• Expanding our portfolio of top-tier economic drilling inventory through acquisition and exploration, and the application of advanced analytics, new technologies and development optimization.

Chief Executive Officer Herb Vogel comments: "2024 was an outstanding year. The SM Energy team delivered a significant increase in scale as measured by the 23% increase in daily oil production, 12% increase in estimated net proved reserves, approximate 40% increase in gross drilling locations and 24% expansion in our core portfolio net acreage. We remained focused on operational execution, continuing to deliver superior well performance and organically growing our portfolio while also delivering return of capital equating to an approximate 4% yield to market capitalization.

As we commence 2025, we are first focused on the integration of our Utah operations where results are expected to be accretive to all financial metrics. The balance sheet is in excellent shape, and we intend to prioritize the generation of free cash flow to pay our fixed dividend and reduce debt, followed by share repurchases once we achieve target leverage. We designed our 2025 operational plan to optimize free cash flow, considering a multi-year period, which will employ our differential technical capabilities to deliver superior well performance and drive capital efficiency. We are well poised for an excellent 2025."

OFFICER RETIREMENT AND NEW APPOINTMENTS

The Company announces the retirement of Jennifer Martin Samuels, the Company's Vice President - Investor Relations and ESG Stewardship. Ms. Samuels' retirement from her current position will be effective March 7, 2025, and she plans to remain with the Company in an advisory capacity until later this year.

The Company also announces several officer appointments, all of which are effective March 2, 2025.

• Dean Lutey was promoted to the position of Senior Vice President - Chief Information Officer. Mr. Lutey has served in the role of Vice President - Chief Information Officer since 2021 and previously Vice President - Information Technology since 2013. Mr. Lutey joined the Company in 2008 as Manager of Production Services. Mr. Lutey has more than 28 years of experience in information technology.
• Pat Lytle was promoted to the position of Senior Vice President - Finance. Mr. Lytle has served in the role of Vice President - Chief Accounting Officer and Controller since 2021 and joined the Company in 2007 as a Senior Accountant. Mr. Lytle has more than 20 years of accounting and finance experience in the energy industry. He will assume the Investor Relations and ESG Stewardship responsibilities as well as oversee the financial planning and treasury functions.
• Richard Jenkins was promoted to the position of Senior Vice President - Utah. Mr. Jenkins has served as Vice President - Utah since 2024 and previously Vice President - Operations since 2023. Mr. Jenkins joined the Company in 2010 as a Senior Reservoir Engineer. Mr. Jenkins has more than 17 years of experience in the oil and gas industry.
• Alan Bennett was promoted to the position of Vice President and Controller. Mr. Bennett most recently served as Senior Director of Financial Planning and Analysis and joined the Company in 2011 as a Senior Accountant. Mr. Bennett previously served as Director of Operations Accounting and has more than 18 years of accounting and finance experience in the energy industry. Mr. Bennett will serve as the Company's principal accounting officer.

ESTIMATED NET PROVED RESERVES AT YEAR-END 2024

Estimated net proved reserves at year-end 2024 were 678 MMBoe. Estimated net proved reserves were 51% in South Texas, 34% in the Midland Basin, and 15% in the Uinta Basin, and were comprised of 44% oil, 38% natural gas and 18% NGLs. Net proved reserves were 60% developed and 40% undeveloped.

• The ratio of estimated net proved reserves at year-end 2024 to 2024 net production is 10.9 years.
• 2024 SEC pricing was $75.48 per Bbl oil, $2.13 per MMBtu natural gas and $28.29 per Bbl NGLs, down 4% and 19% and up 2%, respectively, compared to 2023 SEC pricing.
• Our Uinta Basin acquisitions added estimated net proved reserves of approximately 100 MMBoe, 38% of which were developed.

STANDARDIZED MEASURE

The standardized measure of discounted future net cash flows from estimated net proved reserves was $7.27 billion at year-end 2024, up from $6.28 billion at year-end 2023. The 16% increase in the standardized measure compared with year-end 2023 is predominantly due to the increase in estimated net proved reserves, partially offset by lower SEC pricing for oil and gas used in the calculation. Pre-tax PV-10⁽¹⁾ was $8.36 billion.

FOURTH QUARTER AND FULL YEAR 2024 RESULTS

Details and discussions of fourth quarter and full year 2024 net production and commodity pricing are given below, along with summary tables:

• Fourth quarter production volumes were 19.1 MMBoe, or 208.0 MBoe/d, and were 51% oil. Production volumes increased 22% sequentially and oil production volumes increased 38% sequentially with the addition of the Uinta Basin assets acquired on October 1, 2024. Fourth quarter volumes were affected by approximately 3 MBoe/d as a result of downtime from third-party crude takeaway and the decision to reject ethane at certain gas processing plants due to better economics with strong natural gas prices.
• Full year production volumes of 62.4 MMBoe (170.5 MBoe/d) were up 12% from 2023. Production volumes were 48% from South Texas, 47% from the Midland Basin, and 5% from the Uinta Basin. Volumes were 47% oil, 37% natural gas and 16% NGLs.

• In the fourth quarter, benchmark pricing included NYMEX WTI at $70.27/Bbl, NYMEX Henry Hub natural gas at $2.79/MMBtu and OPIS Composite NGLs at $29.29/Bbl. For the full year, benchmark pricing included NYMEX WTI at $75.72/Bbl, NYMEX Henry Hub natural gas at $2.27/MMBtu and OPIS Composite NGLs at $28.30/Bbl.
• In the fourth quarter, the average realized price before the effect of hedges was $43.68 per Boe, and the average realized price after the effect of hedges was $44.85 per Boe.⁽¹⁾ For the full year, the average realized price before the effect of hedges was $42.81 per Boe, and the average realized price after the effect of hedges was $43.91 per Boe.⁽¹⁾
• The effect of commodity derivative settlements for the fourth quarter and full year was a gain of $1.17 per Boe, or $22.4 million, and a gain of $1.10 per Boe, or $68.7 million, respectively.

For additional operating metrics and regional detail, please see the Financial Highlights section below and the accompanying slide deck.

CAPITAL EXPENDITURES AND ACTIVITY

In the fourth quarter 2024, capital expenditures of $353.5 million before change in accruals of $8.8 million totaled $362.3 million.⁽¹⁾ During the fourth quarter of 2024, the Company drilled 45 net wells and added 37 net flowing completions. During the fourth quarter, faster than expected drilling and completion times accelerated certain costs into the fourth quarter 2024. For the full year 2024, capital expenditures of $1.31 billion before change in accruals of $24.3 million totaled $1.29 billion⁽¹⁾ and the Company drilled 142 net wells and added 135 net flowing completions.

NET INCOME AND NET INCOME PER SHARE

Fourth quarter 2024 net income was $188.3 million, or $1.64 per diluted common share, compared with net income of $247.1 million, or $2.12 per diluted common share, for the same period in 2023. The current year period benefited on a per share basis from 36% higher production volumes, a 3% increase in the realized price per Boe after the effect of net derivative settlements and fewer shares outstanding, offset by certain higher per unit expenses and increased income tax and net interest expense. For the full year 2024, net income was $770.3 million, or $6.67 per diluted common share, compared with net income of $817.9 million, or $6.86 per diluted common share, for the full year 2023. Full year net income compared with the prior year reflects a 12% increase in production volumes, a 2% increase in the realized price per Boe after the effect of net derivative settlements, and fewer shares outstanding, offset predominantly by net interest and tax expenses.

NET CASH PROVIDED BY OPERATING ACTIVITIES

Fourth quarter 2024 net cash provided by operating activities of $577.9 million before net change in working capital of $(26.6) million totaled $551.2 million,⁽¹⁾ representing an increase of $127.5 million, or 30%, from $423.7 million⁽¹⁾ in the same period in 2023. The increase from the prior year period was primarily due to higher production volumes and a higher realized price per Boe after the effect of net derivative settlements, partially offset by certain higher per unit expenses and higher cash taxes. For the full year 2024, net cash provided by operating activities of $1.78 billion before net changes in working capital of $(11.2) million totaled $1.77 billion,⁽¹⁾ representing an increase of $192.4 million, or 12%, from $1.58 billion⁽¹⁾ in 2023. The increase in 2024 is predominantly due to higher production volumes and a higher realized price per Boe after the effect of net derivative settlements, partially offset by higher cash taxes.

ADJUSTED EBITDAX⁽¹⁾ AND ADJUSTED NET INCOME⁽¹⁾ 

Fourth quarter 2024 Adjusted EBITDAX⁽¹⁾ was $610.8 million, up $165.6 million, or 37%, from $445.1 million in the same period in 2023. For the full year 2024, Adjusted EBITDAX⁽¹⁾ was $1.99 billion, compared with $1.71 billion in 2023.

Fourth quarter 2024 adjusted net income⁽¹⁾ was $220.2 million, or $1.91 per diluted common share, which compares with adjusted net income⁽¹⁾ of $181.5 million, or $1.56 per diluted common share, for the same period in 2023. For the full year 2024, adjusted net income⁽¹⁾ was $785.1 million, or $6.80 per diluted common share, compared with adjusted net income⁽¹⁾ of $702.5 million, or $5.89 per diluted common share, in 2023.

ADJUSTED FREE CASH FLOW⁽¹⁾

Fourth quarter 2024 cash flow from operations before net change in working capital totaled $551.2 million,⁽¹⁾ and capital expenditures before changes in accruals totaled $362.3 million,⁽¹⁾ delivering Adjusted free cash flow of $188.9 million.⁽¹⁾ For the full year 2024, cash flow from operations before net change in working capital totaled $1.77 billion,⁽¹⁾ and capital expenditures before changes in accruals totaled $1.29 billion,⁽¹⁾ delivering Adjusted free cash flow of $485.0 million.⁽¹⁾

FINANCIAL POSITION, LIQUIDITY AND NET DEBT-TO-ADJUSTED EBITDAX⁽¹⁾

At year-end 2024, the outstanding principal amount of the Company's long-term debt was $2.80 billion including $68.5 million drawn on the Company's senior secured revolving credit facility. At year-end 2024, cash and cash equivalents were zero and net debt⁽¹⁾ was $2.80 billion, up $1.84 billion from year-end 2023.

As of December 31, 2024, the Company's borrowing base and commitments under its senior secured revolving credit facility were $3.00 billion and $2.00 billion, respectively, and combined with the balance drawn on the Company's senior secured revolving credit facility, available liquidity was $1.93 billion.

At year-end 2024, the Net debt-to-Adjusted EBITDAX⁽¹⁾ ratio was 1.4.

COMMODITY DERIVATIVES

As of February 14, 2025, commodity derivative positions for 2025 include:

SWAPS & COLLARS:

• Oil: Approximately 12,600 MBbls, or slightly more than 30%, of expected 2025 net oil production is hedged at a weighted-average price of $69.02/Bbl (collar floors and swaps) to $74.89/Bbl (collar ceilings and swaps), excludes basis swaps.
• Natural gas: Approximately 43,200 BBtu, or slightly less than 30%, of expected 2025 net natural gas production is hedged at an average price of $3.43/MMBtu (weighted-average of collar floors and swaps) to $4.44/MMBtu (weighted-average of collar ceilings and swaps), excludes basis swaps.

BASIS SWAPS:

• Oil, Midland Basin differential: Approximately 4,600 MBbls of expected 2025 net oil Midland Basin oil production are hedged to the local price point at a positive weighted-average price of $1.18/Bbl.
• Oil, MEH differential: Approximately 2,100 MBbls of expected 2025 net South Texas oil production are hedged to the local price point at a positive weighted-average price of $1.86/Bbl.
• Gas, WAHA differential: Approximately 20,500 BBtu of expected 2025 net Midland Basin natural gas production are hedged to WAHA at a weighted-average price of ($0.66)/MMBtu.
• Gas, HSC differential: Approximately 900 BBtu of expected 2025 net South Texas natural gas production are hedged to HSC at a weighted-average price of $0.0025/MMBtu.

A detailed schedule of these and other hedge positions are provided in the accompanying slide deck.

2025 OPERATING PLAN AND GUIDANCE

Discussion in this release of the Company's 2025 operating plan guidance includes the term "capital expenditures," which is defined to include adjustments for capital accruals, and is a non-GAAP measure. In reliance on the exception provided by Item 10(e)(1)(i)(B) of Regulation S-K, the Company is unable to provide a reconciliation of forward-looking non-GAAP capital expenditures because components of the calculations are inherently unpredictable, such as changes to, and the timing of, capital accruals, unknown future events, and estimating certain future GAAP measures. The inability to project certain components of the calculation could significantly affect the accuracy of a reconciliation.

KEY ASSUMPTIONS

• Benchmark pricing assumptions are $70.00 per Bbl WTI; $3.25 per MMBtu natural gas; $27.00 per Bbl NGLs.
• Hedges currently in place.
• Processing ethane in the second and third quarters, rejecting ethane in the first and fourth quarters. Rejecting ethane reduces overall volumes by approximately 3.5-4.0 MBoe/d during those periods.

GUIDANCE FULL YEAR 2025:

• Net production volumes are expected to range between 200-215 MBoe/d, and net oil production is expected to comprise 51%-52%, or average approximately 102-112 MBbls/d. At the midpoint, this implies a year-over-year increase in production of 22% on a Boe basis and increase in oil production of 33%.
• Capital expenditures adjusted for capital accruals⁽¹⁾ are expected to approximate $1.3 billion, excluding acquisitions and certain non-operated activity to be confirmed later in the year.
  • Drill, complete and equip ("DC&E") expenditures are expected to be allocated approximately 35%-40% to Utah, 35%-40% to the Midland Basin and 25% to South Texas. The program assumes DC&E makes up approximately 90% of the budget and facilities, land and other make up the remainder. The capital program also assumes $25 million for capitalized interest.
  • The Company expects to drill approximately 105 net wells and complete approximately 150 net wells.
• Net production costs:
  • LOE is expected to average between $5.30-$5.50/Boe, which includes workover activity;
  • Transportation is expected to average between $4.10-$4.40/Boe;
  • Production and ad valorem taxes are expected to average between $2.50-$2.70/Boe.
• G&A is expected to be approximately $160 million, including approximately $25 million of non-cash costs. This includes approximately $7 million in one-time expenses associated with the Uinta Basin integration efforts.
• Exploration/capitalized overhead is expected to approximate $75 million.
• DD&A is expected to be approximately $15/Boe.
• Cash taxes are expected to range between $75-$95 million.

GUIDANCE FIRST QUARTER 2025:

• Capital expenditures are expected to range between $425-435 million. This includes drilling approximately 40 net wells and completing approximately 45 net wells, which constitutes approximately one-third of the full year program. Capital expenditures are weighted to the first half of the year as the Company completes the near-term Uinta Basin plan initiated by the seller.
• Net production is expected to be approximately 191-198 MBoe/d at 52%-53% oil.
• LOE is expected to average between $5.45-$5.55/Boe.
• G&A is expected to be approximately $40-$42 million and includes $3-$4 million in one-time expenses related to the Uinta Basin integration efforts.

UPCOMING EVENTS

EARNINGS Q&A WEBCAST AND CONFERENCE CALL

February 20, 2025 – Please join SM Energy management at 8:00 a.m. Mountain time/10:00 a.m. Eastern time for the 2024 financial and operating results/2025 operating plan Q&A session. This discussion will be accessible via:

• Webcast (available live and for replay) – on the Company's website at sm-energy.com/investors (replay accessible approximately 1 hour after the live call); or
• Telephone - join the live conference call by registering at https://event.choruscall.com/mediaframe/webcast.html?webcastid=I0Wr8SaS. Dial-in for domestic toll free/International is 877-407-6050 / +1 201-689-8022.

CONFERENCE PARTICIPATION

• February 25, 2025 – J.P. Morgan 2024 Global High Yield & Leveraged Finance Conference. Executive Vice President and Chief Financial Officer Wade Pursell will present at 6:00 a.m. Mountain time/8:00 a.m. Eastern time and will participate in investor meetings at the event. Executive Vice President and Chief Operating Officer Beth McDonald will join Mr. Pursell in investor meetings at the event. The Company plans to post an investor presentation to the Company's website at sm-energy.com/investors before the event. The presentation will not be webcast.
• March 5-6, 2025 – DEP Thrive Energy Conference. President and Chief Executive Officer Herb Vogel, and Executive Vice President and Chief Operating Officer Beth McDonald, will participate in investor meetings at the event.
• March 17, 2025 – 37th Annual ROTH Conference. Executive Vice President and Chief Financial Officer Wade Pursell will participate in investor meetings at the event.

DISCLOSURES

FORWARD LOOKING STATEMENTS

This release contains forward-looking statements within the meaning of securities laws. The words "anticipate," "deliver," "demonstrate," "establish," "estimate," "expects," "goal," "generate," "maintain," "objectives," "optimize," "target," and similar expressions are intended to identify forward-looking statements. Forward-looking statements in this release include, among other things, estimated net proved reserves at year-end 2024 and the ratio of estimated net proved reserves at year-end 2024 to 2024 net production, expected future commodity prices, assumptions and projections for the first quarter and full year 2025 regarding guidance for production, production growth and oil mix as a percentage of total production (including net production and percentage oil increases attributable to the Company's Uinta Basin assets), capital expenditures, operating costs (including lease operating expenses, transportation costs and taxes), general and administrative expenses, exploration expenses and DD&A, the number of net wells to be drilled and completed, the percentage of future production that is hedged, the allocation of activity and capital expenditures among our operating areas and activities, and the Company's 2025 strategic objectives and operational plan, including plans successfully integrate the Company's recently acquired Uinta Basin assets, delivering low breakeven and high-return wells, and optimizing capital efficiency; returning capital to stockholders through dividends, debt reduction to a target of one times leverage, and share repurchases; increasing scale; and expanding the Company's portfolio through acquisition and exploration, and the application of new technologies. These statements involve known and unknown risks, which may cause SM Energy's actual results to differ materially from results expressed or implied by the forward-looking statements. Future results may be impacted by the risks discussed in the Risk Factors section of SM Energy's most recent Annual Report on Form 10-K, as such risk factors may be updated from time to time in the Company's other periodic reports filed with the Securities and Exchange Commission, specifically the 2024 Form 10-K. The forward-looking statements contained herein speak as of the date of this release. Although SM Energy may from time to time voluntarily update its prior forward-looking statements, it disclaims any commitment to do so, except as required by securities laws.

RESERVE DISCLOSURE

The SEC requires oil and natural gas companies, in their filings with the SEC, to disclose estimated net proved reserves, which are those quantities of oil, natural gas and NGLs, that, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs and under existing economic conditions (using the trailing 12-month average first-day-of-the-month prices), operating methods and government regulations prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The SEC also permits the disclosure of separate estimates of probable or possible reserves that meet SEC definitions for such reserves; however, the Company currently does not disclose probable or possible reserves in its SEC filings.

Estimated net proved reserves attributable to the Company at December 31, 2024, are estimated utilizing SEC reserve recognition standards and pricing assumptions based on the trailing 12-month average first-day-of-the-month prices of $75.48 per Bbl of oil, $2.13 per MMBtu of natural gas, and $28.29 per Bbl of NGLs. At least 80% of the PV-10 of the Company's estimate of its total estimated net proved reserves as of December 31, 2024, was audited by Ryder Scott Company, L.P.

FOOTNOTE 1: Indicates a non-GAAP measure or metric. Please refer to the "Definitions of non-GAAP Measures and Metrics as Calculated by the Company" section in Financial Highlights, and the corresponding reconciliations to the most directly-comparable GAAP financial measures for additional information.

ABOUT THE COMPANY

SM Energy Company is an independent energy company engaged in the acquisition, exploration, development, and production of crude oil, natural gas, and NGLs in the states of Texas and Utah. SM Energy routinely posts important information about the Company on its website. For more information about SM Energy, please visit its website at www.sm-energy.com.

SM ENERGY INVESTOR CONTACTS

Jennifer Martin Samuels, jsamuels@sm-energy.com, 303-864-2507
Lindsay Miller, lmiller@sm-energy.com, 303-830-5860

DEFINITIONS OF NON-GAAP MEASURES AND METRICS AS CALCULATED BY THE COMPANY

To supplement the presentation of its financial results prepared in accordance with U.S. generally accepted accounting principles (GAAP), the Company provides certain non-GAAP measures and metrics, which are used by management and the investment community to assess the Company's financial condition, results of operations, and cash flows, as well as compare performance from period to period and across the Company's peer group. The Company believes these measures and metrics are widely used by the investment community, including investors, research analysts and others, to evaluate and compare recurring financial results among upstream oil and gas companies in making investment decisions or recommendations. These measures and metrics, as presented, may have differing calculations among companies and investment professionals and may not be directly comparable to the same measures and metrics provided by others. A non-GAAP measure should not be considered in isolation or as a substitute for the most directly comparable GAAP measure or any other measure of a company's financial or operating performance presented in accordance with GAAP. Reconciliations of each of the Company's non-GAAP measures to the most directly comparable GAAP measure are presented below. These measures may not be comparable to similarly titled measures of other companies.

Adjusted EBITDAX: Adjusted EBITDAX is calculated as net income before interest expense, interest income, income taxes, depletion, depreciation, and amortization expense, exploration expense, property abandonment and impairment expense, non-cash stock-based compensation expense, derivative gains and losses net of settlements, gains and losses on divestitures, gains and losses on extinguishment of debt, and certain other items. Adjusted EBITDAX excludes certain items that the Company believes affect the comparability of operating results and can exclude items that are generally non-recurring in nature or whose timing and/or amount cannot be reasonably estimated. Adjusted EBITDAX is a non-GAAP measure that the Company believes provides useful additional information to investors and analysts, as a performance measure, for analysis of the Company's ability to internally generate funds for exploration, development, acquisitions, and to service debt. The Company is also subject to financial covenants under the Company's Credit Agreement, a material source of liquidity for the Company, based on Adjusted EBITDAX ratios. Please reference the Company's 2024 Form 10-K for discussion of the Credit Agreement and its covenants.

Adjusted free cash flow: Adjusted free cash flow is calculated as net cash provided by operating activities before net change in working capital less capital expenditures before changes in accruals. The Company uses this measure as representative of the cash from operations, in excess of capital expenditures that provides liquidity to fund discretionary obligations such as debt reduction, returning cash to stockholders or expanding the business.

Adjusted net income and adjusted net income per diluted common share: Adjusted net income and adjusted net income per diluted common share excludes certain items that the Company believes affect the comparability of operating results, including items that are generally non-recurring in nature or whose timing and/or amount cannot be reasonably estimated. These items include non-cash and other adjustments, such as derivative gains and losses net of settlements, impairments, net (gain) loss on divestiture activity, gains and losses on extinguishment of debt, and accruals for non-recurring matters. The Company uses these measures to evaluate the comparability of the Company's ongoing operational results and trends and believes these measures provide useful information to investors for analysis of the Company's fundamental business on a recurring basis.

Net debt: Net debt is calculated as the total principal amount of outstanding senior notes plus amounts drawn on the revolving credit facility less cash and cash equivalents (also referred to as total funded debt). The Company uses net debt as a measure of financial position and believes this measure provides useful additional information to investors to evaluate the Company's capital structure and financial leverage.

Net debt-to-Adjusted EBITDAX: Net debt-to-Adjusted EBITDAX is calculated as Net Debt (defined above) divided by Adjusted EBITDAX (defined above) for the trailing twelve-month period (also referred to as leverage ratio). A variation of this calculation is a financial covenant under the Company's Credit Agreement. The Company and the investment community may use this metric in understanding the Company's ability to service its debt and identify trends in its leverage position. The Company reconciles the two non-GAAP measure components of this calculation.

Post-hedge: Post-hedge is calculated as the average realized price after the effects of commodity net derivative settlements. The Company believes this metric is useful to management and the investment community to understand the effects of commodity net derivative settlements on average realized price.

Pre-Tax PV-10: Pre-Tax PV-10 is the present value of estimated future revenue to be generated from the production of estimated net proved reserves, net of estimated production and future development costs, based on prices used in estimating the proved reserves and costs in effect as of the date indicated (unless such costs are subject to change pursuant to contractual provisions), without giving effect to non-property related expenses such as general and administrative expenses, debt service, future income tax expenses, or depreciation, depletion, and amortization, discounted using an annual discount rate of 10 percent. While this measure does not include the effect of income taxes as it would in the use of the standardized measure of discounted future net cash flows calculation, it does provide an indicative representation of the relative value of the Company on a comparative basis to other companies and from period to period. This measure is presented because management believes it provides useful information to investors for analysis of the Company's fundamental business on a recurring basis.