Northern Oil and Gas, Inc. press release

NOG Announces Third Quarter 2026 Results

2026-11-05

NYSE - New York Stock Exchange · Oil · Natural Gas · Natural Gas Liquids · United States · Production & Operations

Raises 2026 Production Guidance

HIGHLIGHTS

Record quarterly production of 156,239 Boe per day (48% oil), a 19% increase from the third quarter of 2025 and a 7.3% increase from the second quarter of 2026 Record natural gas production of 488,391 Mcf per day, a 39% increase from the third quarter of 2025 and a 5.2% increase from the second quarter of 2026 GAAP net loss of $111.8 million, record Adjusted EBITDA of $444.5 million, and Adjusted Net Income of $142.2 million, meaningfully improved over the second quarter of 2026. See “Non-GAAP Financial Measures” below Cash flow from operations of $397.7 million as compared to $321.6 million in the second quarter of 2026. Generated $148.6 million of Free Cash Flow, up 25.0% from the third quarter of 2025. See “Non-GAAP Financial Measures” below Capital expenditures of $247.3 million, excluding non-budgeted acquisitions and other Completed 19 Ground Game transactions adding over 1,060 net acres and an additional 2.9 net wells for $56.5 million, inclusive of associated development costs Retired over $100 million of total debt and achieved a net debt-to-annualized Adjusted EBITDA ratio of sub 1.5x Issued $500 million of 7.5% Senior Notes due in 2034 Repurchased 667,989 shares of common stock at an average price of $23.96, including commissions Raised 2026 annual production guidance to a range of 147,000 to 150,000 Boepd

Northern Oil and Gas, Inc. (NYSE: NOG) (“NOG” or “Company”) today announced the Company’s third quarter results.

MANAGEMENT COMMENTS

“The third quarter was a record for NOG, and the drivers matter as much as the results. We set new highs for total production, natural gas volumes and Adjusted EBITDA, and generated nearly $150 million of Free Cash Flow even as activity increased across our oil-weighted basins. Our assets are self-funding their own growth and still generating substantial excess cash, and we’re putting that cash to work. We cut total debt by more than $100 million, brought leverage below 1.5 times a quarter ahead of our year-end goal, and continued buying back our own shares,” stated Nick O’Grady, Chief Executive Officer.

“With every region performing, we are raising full-year production guidance while holding our capital budget unchanged. Put simply, we expect to deliver more for the same capital. Our shares, like many in our sector, trade at a deep discount to the value of the assets underneath them. We don’t see that as a setback. We see it as an opportunity which we intend to seize upon. This quarter’s records are not a ceiling. We are a company run by investors, for investors, and we intend to keep delivering like one.”

FINANCIAL RESULTS

Oil and natural gas sales for the third quarter were $697.7 million. Third quarter GAAP net loss was $111.8 million or $1.06 per diluted share, driven by non-cash mark-to-market losses on derivatives. Third quarter Adjusted Net Income was $142.2 million or $1.32 per adjusted diluted share. Adjusted EBITDA in the third quarter was $444.5 million, an 11% increase from the second quarter of 2026, driven primarily by increased production volumes. See “Non-GAAP Financial Measures” below.

PRODUCTION

Third quarter 2026 production averaged 156,239 Boe per day _, _a 19% increase from the third quarter of 2025. Oil represented approximately 48% of total production in the third quarter at an average of 74,837 Bbls per day. During the quarter, NOG added 23.9 net wells to production, compared to 12.7 net wells in the second quarter, excluding major acquisitions. Year to date, the Company has added 53.7 net wells to production.

Well performance continues to be strong across all of NOG’s basins. Appalachian volumes set another production record as the wells from our completed joint development program in West Virginia continue to outperform and our Utica joint development begins to accelerate activity. Consistent with the first half of 2026, in the third quarter NOG’s Uinta Assets continued to outperform versus internal estimates both on legacy production as well as on the 2026 development program.

PRICING

During the third quarter, NOG’s unhedged net realized oil price was $82.83 per Bbl. The Company’s average differential to WTI prices was $2.84, as compared to $3.03 in the second quarter of 2026 and improved by 27% from the third quarter of 2025. NOG’s unhedged net realized gas price in the third quarter was $2.84 per Mcf, representing a 98% realization compared with Henry Hub pricing. Natural gas realizations have improved meaningfully year to date as Waha pricing has normalized and NGL realizations continue to show strength.

HEDGING

In the third quarter, the Company recorded a non-cash unrealized mark-to-market loss on derivatives of approximately $308.0 million, driven by changes to the value of the Company’s derivatives portfolio. Realized hedge losses were $51.4 million as gains on the Company’s natural gas hedges were more than offset by losses on the Company’s crude oil hedges.

OPERATING COSTS

Lease operating costs were $143.5 million in the third quarter of 2026, or $9.98 per Boe, 2% higher on a per unit basis compared to the third quarter of 2025, driven in part by higher processing costs. Production taxes were $48.3 million in the third quarter of 2026, compared to $28.7 million in the third quarter of 2025 due to higher revenues derived by higher oil prices as well as record gas volumes. Third quarter general and administrative (“G&A”) costs totaled $18.0 million or $1.25 per Boe, as compared to $1.17 per Boe in the third quarter of 2025. The increase was primarily driven by higher general corporate costs to support the Company’s growth initiatives. NOG’s adjusted cash G&A costs, which excludes non-cash share-based compensation and acquisition cost amounts of $4.5 million and $0.9 million, respectively, totaled $12.6 million or $0.88 per Boe in the third quarter, down $0.06 per Boe compared to the second quarter of 2026.

CAPITAL EXPENDITURES AND ACQUISITIONS

Capital expenditures for the third quarter were $247.3 million (excluding non-budgeted acquisitions and other). This was comprised of $190.7 million of total drilling and completion (“D&C”) capital on organic assets, and $56.5 million of Ground Game activity, inclusive of associated development costs. Normalized well costs on the Company’s AFE elections improved 2.9% quarter over quarter averaging approximately $739 per lateral foot in the third quarter, as compared to $761 in the second quarter of 2026. NOG’s Williston Basin spending was 33% of the capital expenditures for the third quarter followed by the Permian at 31%, Appalachian at 16%, the Duvernay at 11% and the Uinta at 9%.

LIQUIDITY AND CAPITAL RESOURCES

NOG had total liquidity of $1.6 billion as of September 30, 2026, consisting of $1,577.0 million of committed borrowing availability under its Revolving Credit Facility and $26.4 million of cash on hand. The Company has a weighted average debt maturity of 5.3 years and its earliest maturity is not until 2029. NOG exited the quarter with a net debt to annualized Adjusted EBITDA ratio of 1.47 times.

In August, NOG issued $500 million of 7.5% Senior Notes due 2034 in an oversubscribed offering. Proceeds of the offering were used to pay down a portion of the outstanding balance under the Company’s revolving credit facility and for general corporate purposes.

In November, the Company completed its semi-annual borrowing base redetermination under its reserves-based revolving credit facility (the “Facility”). In connection with the redetermination, the elected commitment and borrowing base remain unchanged at $1.8 billion and $1.975 billion, respectively.

SHAREHOLDER RETURNS

In August 2026, the Company’s board of directors declared a cash dividend on the Company’s common stock in the amount of $0.45 per share. The dividend was paid on October 30, 2026, to stockholders of record as of the close of business on September 29, 2026.

In November 2026, the Company’s board of directors declared a cash dividend on the Company’s common stock in the amount of $0.45 per share. The dividend will be paid on January 29, 2027, to stockholders of record as of the close of business on December 30, 2026.

During the third quarter, the Company repurchased 667,989 shares of its common stock at an average price of $23.96, including commissions.

In July 2026, NOG’s Board of Directors authorized a $150.0 million increase to the Company’s common stock repurchase program, which provides a current total repurchase capacity of approximately $227.2 million as of September 30, 2026.

2026 ANNUAL GUIDANCE

NOG is raising its annual production guidance for the year to reflect outperformance in the third quarter. The Company is maintaining its Capital Expenditures budget guidance but expects Cap Ex to trend toward the high-end of the range based on current activity levels. Ranges for operating costs, production taxes and cash G&A have been adjusted to reflect costs incurred year to date. Ranges for oil differentials and gas realizations have been adjusted for year to date actuals and expectations for the fourth quarter.

| | Previous Guidance

(August 2026) | | Revised FY 2026

Guidance | | Annual Production (2-stream, Boe per day) | 143,000 - 148,000 | | 147,000 - 150,000 | | Annual Oil Production (Bbls per day) | 71,500 - 73,500 | | 71,750 - 73,500 | | Total Budgeted Capital Expenditures ($ in millions) | $850 - $900 | | $850 - $900 | | Net Total Wells Turned-in-Line | 74.0 - 76.0 | | 74.0 - 76.0 |

| Operating Expenses and Differentials | | | | | LOE/Production Expenses (per Boe) | $9.70 - $9.80 | | $9.75 - $9.85 | | Production Taxes (as a percentage of Oil & Gas Sales) | 7.5% - 8.0% | | 7.00% - 7.25% | | Oil Differential to NYMEX WTI (per Bbl) | ($5.00 - $5.40) | | ($4.00 - $4.50) | | Gas Realization as a Percentage of NYMEX Henry Hub (per Mcf) | 70.0% - 75.0% | | 77.5% - 82.5% | | DD&A Rate (per Boe) | $15.00 - $15.50 | | $15.00 - $15.50 |

| General and Administrative Expense (per Boe): | | | | | Non-Cash | $0.25 - $0.30 | | $0.25 - $0.30 | | Cash (excluding transaction costs on non-budgeted acquisitions) | $0.83 - $0.86 | | $0.85 - $0.90 |

THIRD QUARTER 2026 RESULTS

The following tables set forth selected operating and financial data for the periods indicated.

| | Three Months Ended September 30, | | | | | | | | | | | | | | 2026 | | | | 2025 | | | % Change | | | | Net Production: | | | | | | | | | | | | | Oil (MBbl) | | 6,885 | | | | 6,656 | | | | 3 | % | | Natural Gas (MMcf) | | 44,932 | | | | 32,407 | | | | 39 | % | | Total (MBoe) | | 14,374 | | | | 12,057 | | | | 19 | % | | | | | | | | | | | | | | | Average Daily Production: | | | | | | | | | | | | | Oil (Bbl) | | 74,837 | | | | 72,348 | | | | 3 | % | | Natural Gas (Mcf) | | 488,391 | | | | 352,250 | | | | 39 | % | | Total (Boe) | | 156,239 | | | | 131,054 | | | | 19 | % | | | | | | | | | | | | | | | Average Sales Prices: | | | | | | | | | | | | | Oil (per Bbl) | $ | 82.83 | | | $ | 61.08 | | | | 36 | % | | Effect of Gain (Loss) on Settled Oil Derivatives on Average Price (per Bbl) | | (10.51 | ) | | | 4.78 | | | | (320 | )% | | Oil Net of Settled Oil Derivatives (per Bbl) | | 72.32 | | | | 65.86 | | | | 10 | % | | | | | | | | | | | | | | | Natural Gas and NGLs (per Mcf) | | 2.84 | | | | 2.52 | | | | 13 | % | | Effect of Gain on Settled Natural Gas Derivatives on Average Price (per Mcf) | | 0.47 | | | | 0.73 | | | | (36 | )% | | Natural Gas and NGLs Net of Settled Natural Gas and NGL Derivatives (per Mcf) | | 3.31 | | | | 3.25 | | | | 2 | % | | | | | | | | | | | | | | | Realized Price on a Boe Basis Excluding Settled Commodity Derivatives | | 48.54 | | | | 40.49 | | | | 20 | % | | Effect of Gain (Loss) on Settled Commodity Derivatives on Average Price (per Boe) | | (3.58 | ) | | | 4.59 | | | | (178 | )% | | Realized Price on a Boe Basis Including Settled Commodity Derivatives | | 44.96 | | | | 45.08 | | | | — | % | | | | | | | | | | | | | | | Costs and Expenses (per Boe): | | | | | | | | | | | | | Production Expenses | $ | 9.98 | | | $ | 9.81 | | | | 2 | % | | Production Taxes | | 3.36 | | | | 2.38 | | | | 41 | % | | General and Administrative Expenses | | 1.25 | | | | 1.17 | | | | 7 | % | | Depletion, Depreciation, Amortization and Accretion | | 14.47 | | | | 16.53 | | | | (12 | )% | | | | | | | | | | | | | | | Net Producing Wells at Period End | | 1,391.2 | | | | 1,174.2 | | | | 18 | % |

HEDGING UPDATE

NOG hedges portions of its expected production volumes to increase the predictability of its cash flow and to help maintain a strong financial position. The following table summarizes NOG’s open crude oil commodity derivative contracts scheduled to settle after September 30, 2026.

| | | Crude Oil Commodity Derivative Swaps (1) | | Crude Oil Commodity Derivative Collars | | | | | | | | | | | | | | | | | | Contract Period | | Volume (Bbls/Day) | | Weighted Average Price

($/Bbl) | | Collar Sub-Floor Volume (Bbls/Day) | | Collar Floor Volume (Bbls/Day) | | Collar Ceiling Volume (Bbls/Day) | | Weighted Average Sub-Floor Price

($/Bbl) | | Weighted Average Floor Price

($/Bbl) | | Weighted Average Ceiling Price

($/Bbl) | | | | | | 2026 (1) | | | | | | | | | | | | | | | | | | | | | | Q4 | | 19,745 | | | 68.26 | | 2,250 | | 19,187 | | 26,680 | | | 47.22 | | | 62.34 | | | 71.44 | | 2027 (1) | | | | | | | | | | | | | | | | | | | | | | Q1 | | 12,375 | | $ | 72.14 | | 5,000 | | 9,250 | | 9,250 | | $ | 47.50 | | $ | 63.81 | | $ | 77.64 | | Q2 | | 9,950 | | | 70.49 | | 5,500 | | 9,750 | | 9,750 | | | 48.64 | | | 64.13 | | | 76.88 | | Q3 | | 5,500 | | | 70.50 | | 3,421 | | 6,842 | | 6,842 | | | 50.85 | | | 66.46 | | | 78.80 | | Q4 | | 5,500 | | | 70.50 | | 3,000 | | 6,000 | | 6,000 | | | 51.67 | | | 67.43 | | | 79.82 | | 2028 (1) | | | | | | | | | | | | | | | | | | | | | | Q1 | | 500 | | $ | 70.04 | | — | | — | | — | | $ | — | | $ | — | | $ | — | | Q2 | | 500 | | | 70.04 | | — | | — | | — | | | — | | | — | | | — | | Q3 | | 500 | | | 70.04 | | — | | — | | — | | | — | | | — | | | — | | Q4 | | 500 | | | 70.04 | | — | | — | | — | | | — | | | — | | | — | | 2029 (1) | | | | | | | | | | | | | | | | | | | | | | Q1 | | 500 | | $ | 70.04 | | — | | — | | — | | $ | — | | $ | — | | $ | — | | Q2 | | 500 | | | 70.04 | | — | | — | | — | | | — | | | — | | | — | | Q3 | | 500 | | | 70.04 | | — | | — | | — | | | — | | | — | | | — | | Q4 | | 500 | | | 70.04 | | — | | — | | — | | | — | | | — | | | — |

| _ | | | (1) | Includes derivative contracts entered into as of October 27, 2026. This table does not include volumes subject to swaptions and call options, which are crude oil derivative contracts NOG has entered into which may increase swapped volumes at the option of NOG’s counterparties. This table also does not include basis swaps. |

The following table summarizes NOG’s open natural gas commodity derivative contracts scheduled to settle after September 30, 2026.

| | | Natural Gas Commodity Derivative Swaps (1) | | Natural Gas Commodity Derivative Collars | | | | | | | | | | | | | Contract Period | | Volume (MMBTU/Day) | | Weighted Average Price ($/MMBTU) | | Collar Floor Volume (MMBTU/Day) | | Collar Ceiling Volume (MMBTU/Day) | | Weighted Average Floor Price

($/MMBTU) | | Weighted Average Ceiling Price

($/MMBTU) | | | | | 2026 (1) | | | | | | | | | | | | | | | | | Q4 | | 131,685 | | | 4.16 | | 160,214 | | 160,214 | | | 3.35 | | | 5.03 | | 2027 (1) | | | | | | | | | | | | | | | | | Q1 | | 79,167 | | $ | 3.98 | | 67,500 | | 67,500 | | $ | 3.00 | | $ | 4.85 | | Q2 | | 80,879 | | | 3.98 | | 55,604 | | 55,604 | | | 3.00 | | | 4.44 | | Q3 | | 80,000 | | | 3.98 | | 55,000 | | 55,000 | | | 3.00 | | | 4.44 | | Q4 | | 64,783 | | | 3.94 | | 39,837 | | 39,837 | | | 3.04 | | | 4.41 | | 2028 (1) | | | | | | | | | | | | | | | | | Q1 | | 28,077 | | $ | 3.83 | | 9,890 | | 9,890 | | $ | 3.50 | | $ | 4.17 | | Q2 | | 20,220 | | | 3.83 | | 10,110 | | 10,110 | | | 3.50 | | | 4.17 | | Q3 | | 20,000 | | | 3.83 | | 10,000 | | 10,000 | | | 3.50 | | | 4.17 | | Q4 | | 16,630 | | | 3.85 | | 10,000 | | 10,000 | | | 3.50 | | | 4.07 | | 2029 (1) | | | | | | | | | | | | | | | | | Q1 | | — | | $ | — | | 9,889 | | 9,889 | | $ | 3.50 | | $ | 3.88 | | Q2 | | — | | | — | | 10,110 | | 10,110 | | | 3.50 | | | 3.88 | | Q3 | | — | | | — | | 10,000 | | 10,000 | | | 3.50 | | | 3.88 | | Q4 | | — | | | — | | 6,630 | | 6,630 | | | 3.50 | | | 3.88 |

| _ | | | (1) | Includes derivative contracts entered into as of October 27, 2026. This table does not include volumes subject to swaptions and call options, which are natural gas derivative contracts NOG has entered into which may increase swapped volumes at the option of NOG’s counterparties. This table also does not include basis swaps. |

The following table summarizes NOG’s open NGL commodity derivative contracts scheduled to settle after September 30, 2026.

| Natural Gas Liquids Commodity Derivative Swaps (1) | | | | | | | | Swaps | | | | Contract Period | | Volume

(BBL/Day) | | Weighted Average Price

($/BBL) | | 2026 (1) | | | | | | Q4 | | 875 | | 33.32 | | 2027 (1) | | | | | | Q1 | | 725 | | $ 32.30 | | Q2 | | 650 | | 30.73 | | Q3 | | 625 | | 30.69 | | Q4 | | 575 | | 30.87 |

| _ | | | (1) | Includes derivative contracts entered into as of October 27, 2026. |

The following table presents NOG’s settlements on commodity derivative instruments and unsettled gains and losses on open commodity derivative instruments for the periods presented, which is included in the revenue section of NOG’s statement of operations:

| | Three Months Ended

September 30, | | | | | | | | (In thousands) | | 2026 | | | | 2025 | | | Cash Received (Paid) on Settled Derivatives, Net | $ | (51,403 | ) | | $ | 55,390 | | | Non-Cash Mark-to-Market Gain (Loss) on Derivatives | | (308,047 | ) | | | 15,379 | | | Gain (Loss) on Commodity Derivatives, Net | $ | (359,450 | ) | | $ | 70,769 | |

CAPITAL EXPENDITURES & DRILLING ACTIVITY

| (In thousands, except for net well data and dollars per foot) | | Three Months Ended September 30, 2026 | | | Capital Expenditures Incurred: | | | | | Organic Drilling and Development Capital Expenditures | | $ | 190,739 | | Ground Game Acquisition Capital Expenditures, Inclusive of Development Costs | | $ | 56,515 | | Other | | $ | 4,947 | | Non-Budgeted Acquisitions | | $ | 8,272 | | | | | | | Net Wells Added to Production | | | 23.9 | | | | | | | Net Producing Wells (Period-End) | | | 1,391.2 | | | | | | | Net Wells in Process (Period-End) | | | 45.8 | | | | | | | Weighted Average Gross AFE for Wells Elected to | | $ | 10,610 | | Weighted Average Gross AFE for Wells Elected to, normalized for lateral length ($ per foot) | | $ | 739 |

THIRD QUARTER 2026 EARNINGS RELEASE CONFERENCE CALL

In conjunction with NOG’s release of its financial and operating results, investors, analysts and other interested parties are invited to listen to a conference call with management on Friday, November 6, 2026 at 8:00 a.m. Central Time.

Those wishing to listen to the conference call may do so via webcast or phone as follows:

Webcast : https://events.q4inc.com/attendee/139482049 Dial-In Number : (833) 461-5787 (US/Canada) and (585) 542-9983 (International) Conference ID : 139482049 - NOG Third Quarter 2026 Earnings Conference Call Replay Dial-In Number : (833) 309-1852 (US/Canada) and (929) 828-5978 (International) Replay Access Code : 139482049 - Replay will be available through November 5, 2027

ABOUT NOG

Northern Oil and Gas (NOG) is the largest publicly traded dedicated non-operator in the United States, built on a differentiated strategy of acquiring non-operated minority working interests and mineral rights across the premier basins of North America. By combining deep industry relationships with disciplined capital allocation, NOG has built a scaled, diversified portfolio that generates durable production and strong cash flow for its shareholders. More information about NOG can be found at www.noginc.com .

SAFE HARBOR

This press release contains forward-looking statements regarding future events and future results that are subject to the safe harbors created under the Securities Act of 1933, as amended, and the Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included in this release regarding NOG’s financial position, operating and financial performance, business strategy, dividend plans and practices, plans and objectives of management for future operations, industry conditions, indebtedness covenant compliance, capital expenditures, production, cash flow, borrowing base under NOG’s Revolving Credit Facility, NOG’s intention or ability to pay or increase dividends on its capital stock, and impairment are forward-looking statements. When used in this release, forward-looking statements are generally accompanied by terms or phrases such as “estimate,” “project,” “predict,” “believe,” “expect,” “continue,” “anticipate,” “target,” “could,” “plan,” “intend,” “seek,” “goal,” “will,” “should,” “may” or other words and similar expressions that convey the uncertainty of future events or outcomes. Items contemplating or making assumptions about actual or potential future production, sales, market size, collaborations, cash flows, and trends or operating results also constitute such forward-looking statements.