# EDGAR Filing Document

**Accession Number:** 0001104485
**File Stem:** 0001104485-25-000156
**Filing Date:** 2025-11
**Character Count:** 41899
**Document Hash:** cfcab7ba501cfc8b8781b141a9194b95
**Contains OCR:** False
**Source Format:** 

## Filing Content

## Filing Summary
**0001104485-25-000156.hdr.sgml**: 20251106

**ACCESSION NUMBER**: 0001104485-25-000156

**CONFORMED SUBMISSION TYPE**: 8-K

**PUBLIC DOCUMENT COUNT**: 13

**CONFORMED PERIOD OF REPORT**: 20251106

**ITEM INFORMATION**: Results of Operations and Financial Condition

**ITEM INFORMATION**: Financial Statements and Exhibits

**FILED AS OF DATE**: 20251106

**DATE AS OF CHANGE**: 20251106

**FILER**: 

**COMPANY DATA:**
- **COMPANY CONFORMED NAME:** NORTHERN OIL & GAS, INC.
- **CENTRAL INDEX KEY:** 0001104485
- **STANDARD INDUSTRIAL CLASSIFICATION:** CRUDE PETROLEUM & NATURAL GAS [1311]
- **ORGANIZATION NAME:** 01 Energy & Transportation
- **EIN:** 953848122
- **FISCAL YEAR END:** 1231

**FILING VALUES:**
- **FORM TYPE:** 8-K
- **SEC ACT:** 1934 Act
- **SEC FILE NUMBER:** 001-33999
- **FILM NUMBER:** 251458390

**BUSINESS ADDRESS:**
- **STREET 1:** 4350 BAKER ROAD
- **STREET 2:** SUITE 400
- **CITY:** MINNETONKA
- **STATE:** MN
- **ZIP:** 55343
- **BUSINESS PHONE:** 952-476-9800

**MAIL ADDRESS:**
- **STREET 1:** 4350 BAKER ROAD
- **STREET 2:** SUITE 400
- **CITY:** MINNETONKA
- **STATE:** MN
- **ZIP:** 55343

**FORMER COMPANY:**
- **FORMER CONFORMED NAME:** KENTEX PETROLEUM INC
- **DATE OF NAME CHANGE:** 20000128

?xml version='1.0' encoding='ASCII'? nog-20251106

**UNITED STATES**

**SECURITIES AND EXCHANGE COMMISSION**

**Washington, D.C. 20549**

**FORM 8-K**

**CURRENT REPORT**

**Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934**

Date of Report (Date of earliest event reported): November 6, 2025

**NORTHERN OIL AND GAS, INC.**

(Exact name of Registrant as specified in its charter)

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| | | |
|:---|:---|:---|
| &nbsp;&nbsp;**Delaware** | &nbsp;&nbsp;**001-33999** | &nbsp;&nbsp;**95-3848122** |
| &nbsp;&nbsp;(State or other jurisdiction <br>of incorporation) | &nbsp;&nbsp;(Commission File Number) | &nbsp;&nbsp;(IRS Employer <br>Identification No.) |

---

---

| | |
|:---|:---|
| &nbsp;&nbsp;**4350 Baker Road, Suite 400** <br>**Minnetonka, Minnesota** | **55343** |
| &nbsp;&nbsp;(Address of principal executive offices) | &nbsp;&nbsp;(Zip Code) |

---

Registrant's telephone number, including area code (**952**) **476-9800**

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

☐&nbsp;&nbsp;&nbsp;&nbsp;Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐&nbsp;&nbsp;&nbsp;&nbsp;Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17CFR 240.14a-12)

☐&nbsp;&nbsp;&nbsp;&nbsp;Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐&nbsp;&nbsp;&nbsp;&nbsp;Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:

---

| | | |
|:---|:---|:---|
| **Title of each class** | **Trading Symbol(s)** | **Name of each exchange on which registered** |
| Common Stock, par value $0.001 | NOG | New York Stock Exchange |

---

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

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**Item 2.02.**&nbsp;&nbsp;&nbsp;&nbsp;**<u>Results of Operations and Financial Condition</u>.**

On November 6, 2025, Northern Oil and Gas, Inc. issued a press release announcing 2025 third quarter financial and operating results. A copy of the press release is furnished as Exhibit 99.1 hereto.

**Item 9.01.**&nbsp;&nbsp;&nbsp;&nbsp;**<u>Financial Statements and Exhibits</u>.**

---

| | |
|:---|:---|
| **Exhibit Number** | **Description** |
| <u>[99.1](exhibit991-2025qx3earnings.htm)</u> | Press release of Northern Oil and Gas, Inc., dated November 6, 2025. |
| 104 | The cover page from this Current Report on Form 8-K, formatted in Inline XBRL |

---

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**SIGNATURES**

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersigned hereunto duly authorized.

---

| | |
|:---|:---|
| Date: November 6, 2025 | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;**NORTHERN OIL AND GAS, INC.**<br>By <u>/s/ Erik J. Romslo</u> <br>Erik J. Romslo<br>*Chief Legal Officer and Secretary* |

---

## Exhibit 99.1

**Exhibit 99.1**

**NOG Announces Third Quarter 2025 Results**

**THIRD QUARTER HIGHLIGHTS**

• Total quarterly production of 131,054 Boe per day (55% oil), up 8% from the third quarter of 2024

• Oil volumes of 72,348 Bbl per day, up 2.0% from the third quarter of 2024

• Record Appalachian volumes of 135.9 MMcf per day

• GAAP net loss of $129.1 million, Adjusted EBITDA of $387.1 million, and Adjusted Net Income of $101.8 million. See "Non-GAAP Financial Measures" below

• Cash flow from operations of $362.1 million. Excluding changes in net working capital, cash flow from operations was $344.3 million, a 9% decrease from the third quarter of 2024

• Generated $118.9 million of Free Cash Flow. See "Non-GAAP Financial Measures" below

• Capital expenditures, excluding non-budgeted acquisitions and other, was $272.0 million, reflecting heightened ground game activity

• Completed 22 ground game transactions adding over 2,500 net acres and an additional 5.8 net wells for $59.8 million, inclusive of associated development costs

• Acquired ~1,000 net royalty acres (~8,000 royalty acres standardized to 1/8th royalty) located primarily in Duchesne and Uintah Counties, UT for an unadjusted closing price of $98.3 million

• On October 1, 2025, issued $725.0 million of 7.875% Senior Notes due 2033 and repurchased 97% or $684.9 million, of 8.125% Senior Notes due 2028

• On November 5, 2025 amended and restated the Company's Revolving Credit Facility lowering borrowing costs and extending maturity to 2030

• Tightened capital expenditure guidance to a range of $950 - $1,025 million

• Raised 2025 annual production guidance to a range of 132,500 - 134,000 Boepd, with oil production increased to a range of 75,000 - 76,500 Boepd

MINNEAPOLIS (BUSINESS WIRE) - November 6, 2025 - Northern Oil and Gas, Inc. (NYSE: NOG) ("NOG" or "Company") today announced the Company's third quarter results.

**MANAGEMENT COMMENTS** 

"Our portfolio and strategy remain resilient amid volatile market conditions. NOG is well positioned to navigate such markets to find opportunities for our investors. We seek and evaluate value-creating, accretive transactions that can position NOG for countercyclical upside convexity for the long-term. At the same time, our existing assets are delivering better than expected, capital efficient performance. The Company continues to generate solid cash flow, remains well protected with strong hedges, and continues to see robust, low breakeven activity on our assets as we head into 2026," commented Nick O'Grady, NOG's Chief Executive Officer.

**THIRD QUARTER FINANCIAL RESULTS**

Oil and natural gas sales for the third quarter were $482.2 million. Third quarter GAAP net loss was $129.1 million or $1.33 loss per basic and diluted share driven by a non-cash impairment charge of $318.7 million. Third quarter Adjusted Net Income was $101.8 million or $1.03 per adjusted diluted share. Adjusted EBITDA in the third quarter was $387.1 million, a 6% decrease from the third quarter of 2024, reflecting the impact of commodity mix and a 7% decrease in realized price on a Boe basis including settled commodity derivatives. See "Non-GAAP Financial Measures" below.

**PRODUCTION**

Third quarter production was 131,054 Boe per day, 2.3% below the second quarter of 2025 and an 8% increase from the third quarter of 2024. Oil represented 55% of total production in the third quarter with 72,348 Bbls per day, down 6% from the second quarter of 2025 and an increase of 2% from the third quarter of 2024. NOG had 16.5 net wells added to production during the third quarter, compared to 20.8 net wells added to production in the second quarter of 2025. The third quarter marked the low point for net wells additions, in line with forecast, with the expectation of an acceleration of TILs in the fourth quarter. Well performance continues to be strong across all of NOG's basins. Appalachian volumes set another production record as our Appalachian joint development program continues to consistently deliver TILs according to plan.

------

**PRICING**

During the third quarter, NOG's unhedged net realized oil price was $61.08 per Bbl. The Company's average differential to WTI prices was $3.89, a 27% improvement from the second quarter of 2025, driven primarily by improved differentials in the Williston, Permian, and Uinta Basins. NOG's unhedged net realized gas price in the third quarter was $2.52 per Mcf, representing an 82% realization compared with Henry Hub pricing. Natural gas realizations remained inline with the second quarter of 2025, as stable NGL prices offset lower absolute natural gas prices.

**OPERATING COSTS**

Lease operating costs were $118.3 million in the third quarter of 2025, or $9.81 per Boe, improved by 1.4% on a per unit basis compared to the second quarter of 2025. Production taxes were $28.7 million in the third quarter of 2025, compared to $35.6 million in the second quarter of 2025, a decrease primarily due to production mix. Third quarter general and administrative ("G&A") costs totaled $14.1 million or $1.17 per Boe, as compared to $1.28 per Boe in the second quarter of 2025. NOG's adjusted cash G&A costs, which excludes non-cash share-based compensation and acquisition cost amounts of $4.0 million and $0.2 million, respectively, totaled $9.9 million or $0.82 per Boe in the third quarter, down $0.07 per Boe compared to the second quarter of 2025.

**CAPITAL EXPENDITURES AND ACQUISITIONS&nbsp;&nbsp;&nbsp;&nbsp;**

Capital expenditures for the third quarter were $272.0 million (excluding non-budgeted acquisitions and other). This was comprised of $212.2 million of total drilling and completion ("D&C") capital on organic assets, and $59.8 million of Ground Game activity inclusive of associated development costs. D&C capital was up 18.7% quarter over quarter, in line with expectations. Normalized well costs on the Company's AFE elections declined sequentially, averaging approximately $806 per lateral foot in the third quarter, as compared to $841 in the second quarter of 2025 and $932 on average during 2024. NOG's Permian Basin spending was 49% of the capital expenditures for the third quarter, the Williston was 25%, the Uinta was 5% and the Appalachian was 21%.

**LIQUIDITY AND CAPITAL RESOURCES**

NOG had total liquidity of $1.2 billion as of September 30, 2025, consisting of $1.1 billion of committed borrowing availability under its Revolving Credit Facility and $31.6 million cash on hand.

In October, NOG issued $725 million of 7.875% Senior Notes due 2033 in a significantly oversubscribed offering. Proceeds from the offering were used to fund the repurchase of approximately 97%, or $684.9 million, of NOG's 8.125% Senior Notes due 2028. The issuance of the 2033 Senior Notes and concurrent tender offer for the 2028 Senior Notes at the time of issuance extended the Company's weighted average debt maturity from 3.2 years to 5.0 years.

On November 5, 2025, the Company entered into an amended and restated revolving credit facility. The size of the revolving credit facility was unchanged, with the borrowing base at $1.8 billion and an elected commitment amount of $1.6 billion. The maturity date was extended from June 2027 to November 2030, further enhancing NOG's weighted average debt maturity to six years. In addition, the cost of borrowing on the facility was substantially improved with a reduction of 60 basis points.

**OTHER MATTERS**

NOG accounts for its assets under the Full Cost method, as opposed to the Successful Efforts method, which does not perform historical price-based asset tests. Driven by lower average oil prices, the Company recorded a non-cash impairment charge of $318.7 million in the third quarter of 2025 under the "ceiling test" of its full cost pool of oil and gas assets. This non-cash charge will have no impact on cash flows of the Company.

**SHAREHOLDER RETURNS**

In the third quarter of 2025, the Company paid a cash dividend of $0.45 per share to NOG's stockholders of record as of June 27, 2025.

In August 2025, the Company declared a cash dividend of $0.45 per share to NOG's stockholders of record as of September 29, 2025, which was paid on October 31, 2025.

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In November 2025, the Company declared a cash dividend of $0.45 per share to NOG's stockholders of record as of December 30, 2025, which is payable on January 30, 2025

During the first three quarters of 2025, the Company has returned $179.7 million to shareholders in the form of dividends of $129.7 million and common stock repurchases of $50.0 million. No common stock was repurchased in the third quarter.

**2025 ANNUAL GUIDANCE** 

As previously announced, NOG has increased annual production guidance and tightened its annual capital expenditure guidance range. These changes and certain additional line item changes are reflected in the table below.

---

| | | |
|:---|:---|:---|
| | **Prior Guidance** | **Revised Guidance** |
| &nbsp;&nbsp;Annual Production *(Boe per day)* | 130000 – 133000 | 132500 – 134000 |
| &nbsp;&nbsp;Annual Oil Production *(Bbls per day)* | 74000 – 76000 | 75000 – 76500 |
| &nbsp;&nbsp;Total Capital Expenditures *($ in millions)* | $925 – $1050 | $950 – $1025 |
| &nbsp;&nbsp;Net Oil Wells Turned-in-Line (TIL) | 73.0 – 76.0 | 71.0 – 74.0 |
| &nbsp;&nbsp;Net Total Wells Turned-in-Line (TIL) | 83.0 – 85.0 | 80.0 – 83.0 |
| &nbsp;&nbsp;Net Wells Spud | 75.0 – 85.0 | 75.0 – 85.0 |

---

---

| | | |
|:---|:---|:---|
| **Operating Expenses and Differentials** | | |
| &nbsp;&nbsp;Production Expenses *(per Boe)* | $9.25 – $9.60 | $9.40 – $9.75 |
| &nbsp;&nbsp;Production Taxes *(as a percentage of Oil & Gas Sales)* | 7.5% – 8.5% | 7.0% – 8.0% |
| &nbsp;&nbsp;Average Differential to NYMEX WTI *(per Bbl)* | ($5.25) – ($5.75) | ($5.25) – ($5.75) |
| &nbsp;&nbsp;Average Realization as a Percentage of NYMEX Henry Hub *(per Mcf)* | 85.0% – 90.0% | 85.0% – 90.0% |
| &nbsp;&nbsp;DD&A *(per Boe)* | $16.00 – $17.00 | $16.00 – $17.00 |

---

---

| | |
|:---|:---|
| **General and Administrative Expense *(per Boe):*** | |
| &nbsp;&nbsp;Non-Cash | $0.25 – $0.30 |
| &nbsp;&nbsp;Cash *(excluding transaction costs on non-budgeted acquisitions)* | $0.85 – $0.90 |

---

------

**THIRD QUARTER 2025 RESULTS**

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

---

| | | | |
|:---|:---|:---|:---|
| | **Three Months Ended September 30,** | **Three Months Ended September 30,** | **Three Months Ended September 30,** |
| | **2025** | **2024** | **% Change** |
| **Net Production:** |  |  |  |
| Oil (MBbl) | 6656 | 6524 | 2% |
| Natural Gas (MMcf) | 32407 | 28098 | 15% |
| &nbsp;&nbsp;Total (MBoe) | 12057 | 11207 | 8% |
| **Average Daily Production:** |  |  |  |
| Oil (Bbl) | 72348 | 70913 | 2% |
| Natural Gas (Mcf) | 352250 | 305413 | 15% |
| &nbsp;&nbsp;Total (Boe) | 131054 | 121815 | 8% |
| **Average Sales Prices:** |  |  |  |
| Oil (per Bbl) <sup>(1)</sup> | $61.08 | $71.82 | (15)% |
| Effect of Gain on Settled Oil Derivatives on Average Price (per Bbl) | 4.78 | 0.20 |  |
| Oil Net of Settled Oil Derivatives (per Bbl) <sup>(1)</sup> | 65.86 | 72.02 | (9)% |
| Natural Gas and NGLs (per MCF) | 2.52 | 1.60 | 58% |
| Effect of Gain on Settled Natural Gas Derivatives on Average Price (per Mcf) | 0.73 | 1.01 |  |
| Natural Gas and NGLs Net of Settled Natural Gas and NGL Derivatives (per Mcf) | 3.25 | 2.61 | 25% |
| Realized Price on a Boe Basis Excluding Settled Commodity Derivatives <sup>(1)</sup>  | 40.49 | 45.82 | (12)% |
| Effect of Gain on Settled Commodity Derivatives on Average Price (per Boe) | 4.59 | 2.65 |  |
| Realized Price on a Boe Basis Including Settled Commodity Derivatives <sup>(1)</sup>  | 45.08 | 48.47 | (7)% |
| **Costs and Expenses (per Boe):** |  |  |  |
| Production Expenses | $9.81 | $9.54 | 3% |
| Production Taxes | 2.38 | 1.31 | 82% |
| General and Administrative Expenses | 1.17 | 0.89 | 31% |
| Depletion, Depreciation, Amortization and Accretion | 16.53 | 16.57 | —% |
| **Net Producing Wells at Period End** | 1174.2 | 1049.8 | 12% |

---

*______________*

<sup>(1)&nbsp;&nbsp;&nbsp;&nbsp;</sup>Excludes the impact of certain non-cash adjustments to oil revenues.

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**HEDGING**

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, 2025.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| | **Crude Oil Commodity Derivative Swaps**<sup>(1)</sup> | **Crude Oil Commodity Derivative Swaps**<sup>(1)</sup> | **Crude Oil Commodity Derivative Collars** | **Crude Oil Commodity Derivative Collars** | **Crude Oil Commodity Derivative Collars** | **Crude Oil Commodity Derivative Collars** |
|<br>**Contract Period** | **Volume (Bbls/Day)** | **Weighted Average Price ($/Bbl)** | **Collar Call Volume (Bbls/Day)** | **Collar Put Volume (Bbls/Day)** | **Weighted Average Ceiling Price <br>($/Bbl)** | **Weighted Average Floor Price <br>($/Bbl)** |
| **2025:** | | | | | | |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 32933 | $71.35 | 24766 | 19473 | $77.55 | $69.15 |
| **2026:** |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Q1 | 21465 | $69.88 | 34680 | 27187 | $72.98 | $62.94 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q2 | 14954 | 67.99 | 24680 | 17187 | 71.35 | 63.55 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q3 | 16245 | 68.93 | 19680 | 12187 | 72.33 | 65.01 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 16245 | 68.91 | 19680 | 12187 | 72.33 | 65.01 |

---

_____________

<sup>(1)</sup> Includes derivative contracts entered into as of October 22, 2025. 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, 2025.

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| | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|
| | **Natural Gas Commodity Derivative Swaps**<sup>(1)</sup> | **Natural Gas Commodity Derivative Swaps**<sup>(1)</sup> | **Natural Gas Commodity Derivative Collars** | **Natural Gas Commodity Derivative Collars** | **Natural Gas Commodity Derivative Collars** | **Natural Gas Commodity Derivative Collars** |
|<br>**Contract Period** | **Volume (MMBTU/Day)** | **Weighted Average Price ($/MMBTU)** | **Collar Call Volume (MMBTU/Day)** | **Collar Put Volume (MMBTU/Day)** | **Weighted Average Ceiling Price <br>($/MMBTU)** | **Weighted Average Floor Price <br>($/MMBTU)** |
| **2025:** | | | | | | |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 128188 | $4.02 | 111418 | 111418 | $4.85 | $3.20 |
| **2026:** |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Q1 | 93889 | $4.06 | 129036 | 129036 | $4.94 | $3.36 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q2 | 75824 | 3.89 | 128513 | 128513 | 4.93 | 3.37 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q3 | 75000 | 3.98 | 120486 | 120486 | 4.89 | 3.39 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 83207 | 4.21 | 106627 | 106627 | 5.16 | 3.40 |
| **2027:** |  |  |  |  |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Q1 | 5000 | $3.04 | 27944 | 27944 | $5.12 | $3.23 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q2 | 5055 | 2.96 | 15165 | 15165 | 3.86 | 3.00 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q3 | 5000 | 2.96 | 15000 | 15000 | 3.86 | 3.00 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 4946 | 2.96 | 9946 | 9946 | 3.86 | 3.00 |

---

_____________

<sup>(1)</sup> Includes derivative contracts entered into as of October 22, 2025. This table does not include basis swaps.

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The following table summarizes NOG's open NGL commodity derivative contracts scheduled to settle after September 30, 2025.

---

| | | |
|:---|:---|:---|
| **NGL Contracts** | **NGL Contracts** | **NGL Contracts** |
| | **Swaps** | |
| **Contract Period** | **Volume<br>(BBL)** | **Weighted Average Price <br>($/BBL)** |
| **2025:** | | |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 133400 | $36.71 |
| **2026:** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Q1 | 92250 | $36.00 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q2 | 106925 | 33.32 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q3 | 96600 | 33.03 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 80500 | 33.32 |
| **2027:** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Q1 | 65250 | $32.30 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q2 | 59150 | 30.73 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q3 | 57500 | 30.69 |
| &nbsp;&nbsp;&nbsp;&nbsp;Q4 | 52900 | 30.87 |

---

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<br>September 30,** | **Three Months Ended<br>September 30,** |
| ***(In thousands)*** | **2025** | **2024** |
| Cash Received on Settled Derivatives | $55390 | $29709 |
| Non-Cash Mark-to-Market Gain on Derivatives | 15379 | 208441 |
| Gain on Commodity Derivatives, Net | $70769 | $238150 |

---

------

**CAPITAL EXPENDITURES & DRILLING ACTIVITY**

---

| | |
|:---|:---|
| ***(In thousands, except for net well data and dollars per foot)*** | **Three Months Ended September 30, 2025** |
| **Capital Expenditures Incurred:** | |
| Organic Drilling and Development Capital Expenditures | $212176 |
| Ground Game Drilling and Development Capital Expenditures | $15831 |
| Ground Game Acquisition Capital Expenditures inclusive of pre-closing development costs | $43988 |
| Other | $1935 |
| Non-Budgeted Acquisitions | $89157 |
| Net Wells Added to Production | 16.5 |
| Net Producing Wells (Period-End) | 1174.2 |
| Net Wells in Process (Period-End) | 53.5 |
| Weighted Average Gross AFE for Wells Elected to | $10297 |
| Weighted Average Gross AFE for Wells Elected to, normalized for lateral length ($ per foot) | $806 |

---

**THIRD QUARTER 2025 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 7, 2025 at 8:00 a.m. Central Time.

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

<u>Webcast</u>: https://events.q4inc.com/attendee/769766358

<u>Dial-In Number</u>: (800) 715-9871 (US/Canada) and (646) 307-1963 (International)

<u>Conference ID</u>: 4503139 - NOG Third Quarter 2025 Earnings Conference Call

<u>Replay Dial-In Number</u>: (800) 770-2030 (US/Canada) and (647) 362-9199 (International)

<u>Replay Access Code</u>: 4503139 - Replay will be available through November 6, 2026

**ABOUT NOG**

NOG is a real asset company with a primary strategy of acquiring and investing in non-operated minority working and mineral interests in the premier hydrocarbon producing basins within the contiguous United States. More information about NOG can be found at www.noginc.com.

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**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.

Forward-looking statements involve inherent risks and uncertainties, and important factors (many of which are beyond NOG's control) that could cause actual results to differ materially from those set forth in the forward-looking statements, including the following: changes in crude oil and natural gas prices, the pace of drilling and completions activity on NOG's current properties and properties pending acquisition; infrastructure constraints and related factors affecting NOG's properties; general economic or industry conditions, whether internationally, nationally and/or in the communities in which NOG conducts business, including any future economic downturn, cost inflation, supply chain disruptions, the impact of continued or further inflation, disruption in the financial markets, changes in the interest rate environment and actions taken by OPEC and other oil producing countries as it pertains to the global supply and demand of, and prices for, crude oil, natural gas and NGLs; ongoing legal disputes over, and potential shutdown of, the Dakota Access Pipeline; NOG's ability to identify and consummate additional development opportunities and potential or pending acquisition transactions, the projected capital efficiency savings and other operating efficiencies and synergies resulting from NOG's acquisition transactions, integration and benefits of property acquisitions, or the effects of such acquisitions on NOG's cash position and levels of indebtedness; changes in NOG's reserves estimates or the value thereof; disruption to NOG's business due to acquisitions and other significant transactions; changes in local, state, and federal laws, regulations or policies that may affect NOG's business or NOG's industry (such as the effects of tax law changes, and changes in environmental, health, and safety regulation and regulations addressing climate change, and trade policy and tariffs); conditions of the securities markets; risks associated with NOG's 3.625% convertible senior notes due 2029 (the "Convertible Notes"), including the potential impact that the Convertible Notes may have on NOG's financial position and liquidity, potential dilution, and that provisions of the Convertible Notes could delay or prevent a beneficial takeover of NOG; the potential impact of the capped call transactions undertaken in tandem with the Convertible Notes issuances, including counterparty risk; increasing attention to environmental, social and governance matters; NOG's ability to raise or access capital on acceptable terms; cyber-incidents could have a material adverse effect on NOG's business, financial condition or results of operations; changes in accounting principles, policies or guidelines; events beyond NOG's control, including a global or domestic health crisis, acts of terrorism, political or economic instability or armed conflict in oil and gas producing regions; and other economic, competitive, governmental, regulatory and technical factors affecting NOG's operations, products and prices. Additional information concerning potential factors that could affect future results is included in the section entitled "Item 1A. Risk Factors" and other sections of NOG's most recent Annual Report on Form 10-K for the year ended December 31, 2024, and Quarterly Report on Form 10-Q, as updated from time to time in amendments and subsequent reports filed with the SEC, which describe factors that could cause NOG's actual results to differ from those set forth in the forward-looking statements.

NOG has based these forward-looking statements on its current expectations and assumptions about future events. While management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond NOG's control. Accordingly, results actually achieved may differ materially from expected results described in these statements. NOG does not undertake, and specifically disclaims, any duty to update or revise any forward-looking statements, except as may be required by the federal securities laws.

**CONTACT:**

Evelyn Infurna

Vice President of Investor Relations

952-476-9800

ir@northernoil.com

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**CONDENSED STATEMENTS OF OPERATIONS**

**(UNAUDITED)**

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| | | |
|:---|:---|:---|
| | **Three Months Ended<br>September 30,** | **Three Months Ended<br>September 30,** |
| ***(In thousands, except share and per share data)*** | **2025** | **2024** |
| **Revenues** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Oil and Gas Sales | $482243 | $513541 |
| &nbsp;&nbsp;&nbsp;&nbsp;Gain on Commodity Derivatives, Net | 70769 | 238150 |
| &nbsp;&nbsp;&nbsp;&nbsp;Other Revenues | 3625 | 1947 |
| Total Revenues | 556637 | 753638 |
| **Operating Expenses** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Production Expenses | 118316 | 106902 |
| &nbsp;&nbsp;&nbsp;&nbsp;Production Taxes | 28688 | 14671 |
| &nbsp;&nbsp;&nbsp;&nbsp;General and Administrative Expenses | 14102 | 10005 |
| &nbsp;&nbsp;&nbsp;&nbsp;Depletion, Depreciation, Amortization and Accretion | 199351 | 185657 |
| &nbsp;&nbsp;&nbsp;&nbsp;Impairment of Oil and Gas Assets | 318674 |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Other Expenses | 3267 | 2463 |
| Total Operating Expenses | 682398 | 319698 |
| **Income (Loss) From Operations** | (125761) | 433940 |
| **Other Income (Expense)** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Interest Expense | (42975) | (36837) |
| &nbsp;&nbsp;&nbsp;&nbsp;Loss on Unsettled Interest Rate Derivatives, Net | (131) | (20) |
| &nbsp;&nbsp;&nbsp;&nbsp;Other Income | 65 | 140 |
| Total Other Expense, Net | (43041) | (36717) |
| **Income (Loss) Before Income Taxes** | (168802) | 397223 |
| **Income Tax Expense (Benefit)** | (39728) | 98777 |
| **Net Income (Loss)** | $(129074) | $298446 |
| **Net Income (Loss) Attributable to Common Stockholders** | $(129074) | $298446 |
| Net Income (Loss) Per Common Share – Basic | $(1.33) | $3.00 |
| Net Income (Loss) Per Common Share – Diluted | $(1.33) | $2.96 |
| Weighted Average Common Shares Outstanding – Basic | 97123889 | 99494313 |
| Weighted Average Common Shares Outstanding – Diluted | 97123889 | 100724784 |

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**CONDENSED BALANCE SHEETS**

**(UNAUDITED)**

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| | | |
|:---|:---|:---|
| ***(In thousands, except par value and share data)*** | **September 30, 2025** | **December 31, 2024** |
| **Assets** | | |
| Current Assets: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Cash and Cash Equivalents | $31648 | $8933 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts Receivable, Net | 333957 | 389673 |
| &nbsp;&nbsp;&nbsp;&nbsp;Advances to Operators | 24251 | 12291 |
| &nbsp;&nbsp;&nbsp;&nbsp;Prepaid Expenses and Other | 6816 | 5271 |
| &nbsp;&nbsp;&nbsp;&nbsp;Derivative Instruments | 129169 | 46525 |
| &nbsp;&nbsp;&nbsp;&nbsp;Income Tax Receivable | 16642 | 38050 |
| Total Current Assets | 542483 | 500743 |
| Property and Equipment: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Oil and Natural Gas Properties, Full Cost Method of Accounting |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Proved | 11174354 | 10307376 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Unproved | 74704 | 42702 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Other Property and Equipment | 8916 | 8197 |
| Total Property and Equipment | 11257974 | 10358275 |
| &nbsp;&nbsp;&nbsp;&nbsp;Less – Accumulated Depreciation, Depletion and Impairment | (6318690) | (5276105) |
| Total Property and Equipment, Net | 4939284 | 5082170 |
| Derivative Instruments | 1009 | 9832 |
| Other Noncurrent Assets, Net | 11413 | 11077 |
| **Total Assets** | $5494189 | $5603822 |
| **Liabilities and Stockholders' Equity** | **Liabilities and Stockholders' Equity** | **Liabilities and Stockholders' Equity** |
| Current Liabilities: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Accounts Payable | $160259 | $202866 |
| &nbsp;&nbsp;&nbsp;&nbsp;Accrued Liabilities and Other | 334505 | 321489 |
| &nbsp;&nbsp;&nbsp;&nbsp;Derivative Instruments | 578 | 19915 |
| Total Current Liabilities | 495342 | 544270 |
| Long-term Debt, Net | 2345879 | 2369294 |
| Deferred Tax Liability | 263247 | 228038 |
| Derivative Instruments | 94071 | 93606 |
| Asset Retirement Obligations | 49354 | 45907 |
| Other Noncurrent Liabilities | 1898 | 2272 |
| **Total Liabilities** | $3249791 | $3283387 |
| **Commitments and Contingencies** |  |  |
| **Stockholders' Equity** |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;Common Stock, Par Value $0.001; 270,000,000 Shares Authorized;<br> 97,602,978 Shares Outstanding at 9/30/2025 <br> 99,113,645 Shares Outstanding at 12/31/2024 | 500 | 501 |
| &nbsp;&nbsp;&nbsp;&nbsp;Additional Paid-In Capital | 1691887 | 1877416 |
| &nbsp;&nbsp;&nbsp;&nbsp;Retained Earnings | 552011 | 442518 |
| Total Stockholders' Equity | 2244398 | 2320435 |
| **Total Liabilities and Stockholders' Equity** | $5494189 | $5603822 |

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**Non-GAAP Financial Measures**

Adjusted Net Income, Adjusted EBITDA and Free Cash Flow are non-GAAP measures. NOG defines Adjusted Net Income as income before income taxes, excluding (i) (gain) loss on unsettled commodity derivatives, net of tax, (ii) (gain) loss on extinguishment of debt, net of tax, (iii) contingent consideration (gain) loss, net of tax, (iv) acquisition transaction costs, net of tax, (v) (gain) loss on unsettled interest rate derivatives, net of tax, and (vi) impairment of long-lived assets, net of tax. NOG defines Adjusted EBITDA as net income before (i) interest expense, (ii) income taxes, (iii) depreciation, depletion, amortization and accretion, (iv) non-cash stock-based compensation expense, (v) (gain) loss on extinguishment of debt, (vi) contingent consideration (gain) loss (vii) acquisition transaction costs, (viii) (gain) loss on unsettled interest rate derivatives, (ix) (gain) loss on unsettled commodity derivatives, (x) impairment of long-lived assets, and (xi) other non-cash adjustments. NOG defines Free Cash Flow as cash flows from operations before changes in working capital and other items, less (i) capital expenditures, excluding non-budgeted acquisitions and changes in accrued capital expenditures and other items. A reconciliation of each of these measures to the most directly comparable GAAP measure is included below.

Management believes the use of these non-GAAP financial measures provides useful information to investors to gain an overall understanding of current financial performance. Management believes Adjusted Net Income and Adjusted EBITDA provide useful information to both management and investors by excluding certain expenses and unrealized commodity gains and losses that management believes are not indicative of NOG's core operating results. Management believes that Free Cash Flow is useful to investors as a measure of a company's ability to internally fund its budgeted capital expenditures, to service or incur additional debt, and to measure success in creating stockholder value. In addition, these non-GAAP financial measures are used by management for budgeting and forecasting as well as subsequently measuring NOG's performance, and management believes it is providing investors with financial measures that most closely align to its internal measurement processes. The non-GAAP financial measures included herein may be defined differently than similar measures used by other companies and should not be considered an alternative to, or more meaningful than, the comparable GAAP measures. From time to time NOG provides forward-looking Free Cash Flow estimates or targets; however, NOG is unable to provide a quantitative reconciliation of the forward looking non-GAAP measure to its most directly comparable forward looking GAAP measure because management cannot reliably quantify certain of the necessary components of such forward looking GAAP measure. The reconciling items in future periods could be significant.

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**Reconciliation of Adjusted Net Income**

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| | | |
|:---|:---|:---|
| | **Three Months Ended<br>September 30,** | **Three Months Ended<br>September 30,** |
| ***(In thousands, except share and per share data)*** | **2025** | **2024** |
| Income (Loss) Before Income Taxes | $(168802) | $397223 |
| Add: |  |  |
| &nbsp;&nbsp;Impact of Selected Items: |  |  |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Gain on Unsettled Commodity Derivatives | (15379) | (208441) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Acquisition Transaction Costs | 165 | (1901) |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Loss on Unsettled Interest Rate Derivatives | 131 | 20 |
| &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;Impairment of Oil and Gas Assets | 318674 |  |
| Adjusted Income Before Adjusted Income Tax Expense | 134789 | 186901 |
| Adjusted Income Tax Expense <sup>(1)</sup> | (33023) | (45791) |
| Adjusted Net Income (non-GAAP) | $101766 | $141110 |
| Weighted Average Shares Outstanding – Basic | 97123889 | 99494313 |
| Weighted Average Shares Outstanding – Diluted | 97123889 | 100724784 |
| Less: |  |  |
| &nbsp;&nbsp;Dilutive Effect of Convertible Notes <sup>(2)</sup> |  | 115626 |
| Add: |  |  |
| &nbsp;&nbsp;Dilutive Effect of Restricted Stock <sup>(3)</sup> | 1721481 |  |
| Weighted Average Shares Outstanding – Adjusted Diluted | 98845370 | 100609158 |
| Income (Loss) Before Income Taxes Per Common Share – Basic | $(1.74) | $3.99 |
| Add: |  |  |
| &nbsp;&nbsp;Impact of Selected Items | 3.13 | (2.11) |
| &nbsp;&nbsp;Impact of Income Tax | (0.34) | (0.46) |
| Adjusted Net Income Per Common Share – Basic | $1.05 | $1.42 |
| Income (Loss) Before Income Taxes Per Common Share – Adjusted Diluted | $(1.71) | $3.95 |
| Add: |  |  |
| &nbsp;&nbsp;Impact of Selected Items | 3.07 | (2.09) |
| &nbsp;&nbsp;Impact of Income Tax | (0.33) | (0.46) |
| Adjusted Net Income Per Common Share – Adjusted Diluted | $1.03 | $1.40 |

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**______________**

<sup>(1)</sup> For the three months ended September 30, 2025 and September 30, 2024, this represents a tax impact using an estimated tax rate of 24.5%.

<sup>(2)</sup> Weighted average shares outstanding - diluted, on a GAAP basis, includes diluted shares attributable to the Company's Convertible Notes due 2029. However, the offsetting impact of the capped call transactions that the Company entered into in connection therewith is not recognized on a GAAP basis. As a result, for purposes of this calculation, the Company excludes the dilutive shares to the extent they would be offset by the capped calls.

<sup>(3)</sup> Weighted average shares outstanding - diluted, on a GAAP basis, does not include the dilutive effect of restricted stock when the Company is in a loss position. As a result, for purposes of this calculation, the Company includes the dilutive shares attributable to the restricted stock.

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**Reconciliation of Adjusted EBITDA**

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| | | |
|:---|:---|:---|
| | **Three Months Ended<br>September 30,** | **Three Months Ended<br>September 30,** |
| ***(In thousands)*** | **2025** | **2024** |
| Net Income (Loss) | $(129074) | $298446 |
| Add: |  |  |
| &nbsp;&nbsp;Interest Expense | 42975 | 36837 |
| &nbsp;&nbsp;Income Tax Expense (Benefit) | (39728) | 98777 |
| &nbsp;&nbsp;Depreciation, Depletion, Amortization and Accretion | 199351 | 185657 |
| &nbsp;&nbsp;Non-Cash Stock-Based Compensation | 4016 | 3018 |
| &nbsp;&nbsp;Other Adjustments | 6000 |  |
| &nbsp;&nbsp;Acquisition Transaction Costs | 165 | (1901) |
| &nbsp;&nbsp;Loss on Unsettled Interest Rate Derivatives | 131 | 20 |
| &nbsp;&nbsp;Gain on Unsettled Commodity Derivatives | (15379) | (208441) |
| &nbsp;&nbsp;Impairment of Oil and Gas Assets | 318674 |  |
| Adjusted EBITDA | $387131 | $412413 |

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**Reconciliation of Free Cash Flow**

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| | |
|:---|:---|
| | **Three Months Ended<br>September 30,** |
| ***(In thousands)*** | **2025** |
| Net Cash Provided by Operating Activities | $423120 |
| &nbsp;&nbsp;Exclude: Changes in Working Capital and Other Items | (30295) |
| &nbsp;&nbsp;Less: Capital Expenditures <sup>(1)</sup> | (273931) |
| Free Cash Flow | $118894 |

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_______________

<sup>(1)&nbsp;&nbsp;&nbsp;&nbsp;</sup>Capital expenditures are calculated as follows:

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| | |
|:---|:---|
| | **Three Months Ended<br>September 30,** |
| &nbsp;&nbsp;&nbsp;&nbsp;***(In thousands)*** | **2025** |
| Cash Paid for Capital Expenditures | $352339 |
| &nbsp;&nbsp;Less: Non-Budgeted Acquisitions | (79536) |
| &nbsp;&nbsp;Plus: Change in Accrued Capital Expenditures and Other | 1128 |
| Capital Expenditures | $273931 |

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