SM ENERGY REPORTS 2023 RESULTS AND 2024 OPERATING PLAN

Author: phinds Category: Oil & Gas News

Feb. 21, 2024 /PRNewswire/ — SM Energy Company (the “Company”) (NYSE: SM) today announced certain fourth quarter and full year 2023 operating and financial results, year-end 2023 estimated net proved reserves and its 2024 operating plan.

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Highlights include:

Excellent financial results and operational performance:

  • Net income for the full year 2023 was $817.9 million, or $6.86 per diluted common share, and for the fourth quarter 2023 was $247.1 million, or $2.12 per diluted common share. Adjusted net income(1) was $5.89 per diluted common share for the full year 2023 and $1.56 per diluted common share for the fourth quarter 2023.
  • Net cash provided by operating activities for the full year 2023 of $1.57 billion before net change in working capital of $4.6 million totaled $1.58 billion.(1) Net cash provided by operating activities for the fourth quarter 2023 of $476.5 million before net change in working capital of $(52.8) million totaled $423.7 million.(1) Adjusted EBITDAX(1) was $1.71 billion for the full year 2023 and $445.1 million for the fourth quarter 2023.
  • Return of capital to stockholders through share repurchases and fixed dividends increased in 2023 to $299.6 million, an approximate 7% yield to current market capitalization. The Company has repurchased approximately 8.3 million shares from announcement of its return of capital program on September 7, 2022 through year-end 2023.
  • The Company ended 2023 with a further strengthened balance sheet. The outstanding principal amount of the Company’s long-term debt was $1.59 billion and cash and cash equivalents were $616.2 million, resulting in net debt(1) of $969.0 million, which met the Company’s target of less than $1 billion net debt. At year-end 2023, the net debt-to-Adjusted EBITDAX(1) ratio was 0.57.
  • Estimated net proved reserves of 605 MMBoe set a Company record and were up 13% at year-end 2023 over year-end 2022. The ratio of estimated net proved reserves at year-end 2023 to 2023 net production is 10.9 years.
  • Midland Basin leasehold acreage increased 29,700 net acres, or 37%, as the Company’s differential geosciences expertise and land team pursue organic replacement of the Company’s high quality inventory.
  • As previously reported, net production for the full year 2023 was up 5% from 2022 to 55.5 MMBoe, or 152.0 MBoe/d, and fourth quarter 2023 net production was 14.1 MMBoe, or 153.5 MBoe/d, while capital expenditures of $989.4 million before changes in accruals of $80.8 million were $1.07 billion(1) for the full year 2023 and capital expenditures of $222.7 million before changes in accruals of $45.1 million were $267.8 million(1) for the fourth quarter 2023, beating expectations.
  • Stewardship is a component of operational excellence and safety is our top priority. The Company demonstrated superior safety metrics in 2023, including a total recordable incident rate of 0.20 per 200,000 hours worked (contractors plus employees), which is a 38% improvement from 2022. In addition, the Company’s reported spill rate for 2023 was 0.006 per 1,000 Bbls of produced fluids, which is a 45% improvement from 2022. Performance-based compensation for all employees is tied to these metrics. In addition, the Company received a Leadership level score of A- from the CDP for participation in the 2023 Climate Change Questionnaire, an improvement from a Management level score of B received in 2022.

Looking ahead to the 2024 strategy and plan, the Company targets value creation through:

  • Focusing on operational execution to deliver low breakeven, high return wells. The Company seeks to: continue its leadership among peers in optimizing capital efficiency and well performance, demonstrate innovation, and maintain focus on ESG stewardship.
  • Returning capital to stockholders through share repurchases and dividends, while transferring value to stockholders through reduced debt. The Company’s sustainable fixed annual dividend of $0.72 per share plus its share repurchase program, with $214.9 million remaining available, provide the ability to deliver a solid return, while callable bonds offer the opportunity to reduce absolute debt with cash on hand.
  • Maintaining and expanding portfolio quality and depth. This includes delineation and development of assets acquired in 2023 and employing geoscience strengths toward continued inventory growth.

Chief Executive Officer Herb Vogel comments: “In 2023, we delivered excellent financial and operating results, grew our Midland Basin footprint by 37%, increased net proved reserves to a record 605 MMBoe, reduced net debt(1) by 15%, announced an increase in our sustainable dividend and returned $300 million to stockholders. We achieved this with industry leading safety metrics, our top priority. We are exceptionally well positioned as we enter 2024, and we have set forth a plan that we expect will combine our low breakeven cost portfolio and differential technical capabilities to deliver optimized operational performance, inventory growth and an attractive return of capital to our stockholders. 2023 results exceeded expectations and the 2024 outlook supports another great year.”

Estimated net proved reserves at year-end 2023 were 605 MMBoe. Estimated net proved reserves were 56% in South Texas and 44% in the Midland Basin, and were comprised of 38% oil, 42% natural gas and 20% NGLs. Net proved reserves were 56% developed and 44% undeveloped.

  • The ratio of estimated net proved reserves at year-end 2023 to 2023 net production is 10.9 years.
  • 2023 SEC pricing was $78.22 per Bbl oil, $2.64 per Mcf natural gas and $27.72 per Bbl NGLs, down 16%, 58% and 35%, respectively, compared to 2022 SEC pricing.
  • South Texas net proved reserves increased 56 MMBoe compared with 2022 as a result of continued Austin Chalk success.
  • Estimated net PDP reserves of 334 MMBoe surpassed the Company’s previous peak of 308 MMBoe, set at the end of 2022.

STANDARDIZED MEASURE

The standardized measure of discounted future net cash flows from estimated net proved reserves was $6.28 billion at year-end 2023, down from $9.96 billion at year-end 2022. The 37% decline in the standardized measure compared with year-end 2022 is predominantly due to the significantly lower SEC pricing across commodities used in the calculation, partially offset by the increase in estimated net proved reserves. Pre-tax PV-10(1) was $7.38 billion.

NET INCOME, NET INCOME PER SHARE AND NET CASH PROVIDED BY OPERATING ACTIVITIES

Fourth quarter 2023 net income was $247.1 million, or $2.12 per diluted common share, compared with net income of $258.5 million, or $2.09 per diluted common share, for the same period in 2022. The current year period benefited on a per share basis from higher production volumes, lower per unit production costs, lower income tax expense and fewer shares outstanding, largely offset by higher exploration and per unit DD&A expense. For the full year 2023, net income was $817.9 million, or $6.86 per diluted common share, compared with net income of $1.11 billion, or $8.96 per diluted common share, for the full year 2022. Full year net income compared with the prior year reflects a 13% decrease in the realized price per Boe after the effect of net derivative settlements and higher per unit DD&A expense, partially offset by lower per unit production costs and lower interest expense.

Fourth quarter 2023 net cash provided by operating activities of $476.5 million before net change in working capital of $(52.8) million totaled $423.7 million,(1) which was up $76.5 million, or 22%, from $347.2 million(1) in the same period in 2022. The increase from the prior year period was due to higher production volumes, a higher realized price per Boe after the effect of net derivative settlements and lower per unit production costs. For the full year 2023, net cash provided by operating activities of $1.57 billion before net changes in working capital of $4.6 million totaled $1.58 billion,(1) which was down $179.5 million, or 10%, from $1.76 billion(1) in 2022. The decline in 2023 is predominantly due to a lower realized price per Boe after the effect of net derivative settlements, partially offset by higher production volumes and lower per unit costs.

ADJUSTED EBITDAX,(1) ADJUSTED NET INCOME(1) AND NET DEBT-TO-ADJUSTED EBITDAX(1)

Fourth quarter 2023 Adjusted EBITDAX(1) was $445.1 million, up $71.3 million, or 19%, from $373.9 million in the same period in 2022. For the full year 2023, Adjusted EBITDAX(1) was $1.71 billion, compared with $1.92 billion in 2022.

Fourth quarter 2023 adjusted net income(1) was $181.5 million, or $1.56 per diluted common share, which compares with adjusted net income(1) of $159.2 million, or $1.29 per diluted common share, for the same period in 2022. For the full year 2023, adjusted net income(1) was $702.5 million, or $5.89 per diluted common share, compared with adjusted net income(1) of $904.0 million, or $7.29 per diluted common share, in 2022.

At December 31, 2023, Net debt-to-Adjusted EBITDAX(1) was 0.57 times.

FINANCIAL POSITION, LIQUIDITY AND CAPITAL EXPENDITURES

At year-end 2023, the outstanding principal amount of the Company’s long-term debt was $1.59 billion with zero drawn on the Company’s senior secured revolving credit facility. At year-end 2023, cash and cash equivalents were $616.2 million and net debt(1) was $969.0 million, down $171.2 million from year-end 2022. As of December 31, 2023, the Company’s borrowing base and commitments under its senior secured revolving credit facility were $2.50 billion and $1.25 billion, respectively, and combined with the cash and cash equivalents balance, provided $1.86 billion in available liquidity.

In the fourth quarter 2023, capital expenditures of $222.7 million adjusted for increased capital accruals of $45.1 million totaled $267.8 million.(1) During the fourth quarter of 2023, the Company drilled 28 net wells and added 11 net flowing completions. For the full year 2023, capital expenditures of $989.4 million adjusted for increased capital accruals of $80.8 million totaled $1.07 billion(1) and the Company drilled 89 net wells and added 92 net flowing completions.

COMMODITY DERIVATIVES

As of February 8, 2024, commodity derivative positions for 2024 include:

SWAPS & COLLARS:

  • Oil: Approximately 6,800 MBbls, or slightly less than 30%, of expected 2024 net oil production is hedged at a weighted-average price of $70.70/Bbl (collar floors and swaps) to $82.78/Bbl (collar ceilings and swaps), excludes basis swaps.
  • Natural gas: Approximately 31,900 BBtu, or slightly less than 25% of expected 2024 net natural gas production is hedged at an average price of $3.47/MMBtu (weighted-average of collar floors and swaps, excludes basis swaps).

BASIS SWAPS:

  • Oil, Midland Basin differential: Approximately 4,900 MBbls of expected 2024 net oil production are hedged to the local price point at a positive weighted-average $1.21/Bbl.
  • Gas, WAHA differential: Approximately 21,000 BBtu of expected 2024 net natural gas production are hedged to WAHA at a weighted-average price of ($0.86)/MMBtu.
  • Gas, HSC differential: Approximately 17,400 BBtu of expected 2024 net natural gas production are hedged to HSC at a weighted-average price of ($0.25)/MMBtu.

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

2024 OPERATING PLAN AND GUIDANCE

Discussion in this release of the Company’s 2024 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 10l(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 $75.00 per Bbl WTI; $2.75 per MMBtu natural gas; $27.00 per Bbl NGLs.
  • Hedges currently in place.
  • Processing ethane for the full year.

GUIDANCE FULL YEAR 2024:

  • Net production volumes are expected to range between 56-59 MMBoe, or 153-161 MBoe/d, at ~44% oil. At the midpoint, this implies an increase of 3%-4% year over year on a Boe basis and an increase of approximately 6% year over year in oil production.
  • Capital expenditures adjusted for capital accruals(1) are expected to range between $1.16 and $1.20 billion, excluding acquisitions.
    • The capital program is expected to increase the allocation to Midland Basin activity to enable the assessment of the Company’s expanded acreage position as well as to manage the commodity mix in light of higher anticipated natural gas prices post-2024. The allocation of drilling and completion capital is expected to be roughly 60% to the Midland Basin and 40% to South Texas and assumes the fourth rig in the Midland Basin remains in place for the majority of 2024.
    • The capital program includes approximately $40 million for facilities, which includes extension of the South Texas oil handling facilities, water handling and disposal infrastructure, and upgrades at the 2023 Klondike area acquisition. The capital program also assumes $22 million for capitalized interest.
    • The Company expects to drill and complete 115-120 total net wells, with roughly 60% in the Midland Basin and 40% in South Texas.
  • Net production costs:
    • LOE is expected to average between $5.30-$5.60/Boe, which includes workover activity;
    • Transportation is expected to average between $2.30-$2.40/Boe;
    • Production and ad valorem taxes are expected to average between $2.80-$2.90/Boe.
  • G&A: is expected to be approximately $125 million, including approximately $20 million of non-cash costs.
  • Exploration/capitalized overhead: is expected to approximate $60 million.
  • DD&A: is expected to average between $12-$13/Boe.

GUIDANCE FIRST QUARTER 2024:

  • Capital expenditures: are expected to be approximately $300 million, which includes drilling approximately 28 net wells, completing approximately 20 net wells. Capital expenditures are weighted to the first half of the year, which includes approximately 60% of 2024 well completions.
  • Net production: is expected to be approximately 13.0 MMBoe, or approximately 143 MBoe/d, at 43%-44% oil. Net production volumes include the effect of adverse weather during January.

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