HIGHLIGHTS

• Third quarter total production of 57,647 Boe per day, up 98% from the third quarter of 2020
• Oil production of 34,035 Bbl per day, up 52% from the third quarter of 2020
• Third quarter GAAP cash flow from operations of $94.4 million. Excluding changes in net working capital, cash flow from operations was $122.3 million, up 253% from the third quarter of 2020
• Total capital expenditures of $63.2 million during the third quarter, excluding the closing of our previously-announced Permian acquisition on August 2, 2021
• Free Cash Flow (non-GAAP) of $55.4 million, post-preferred stock dividends. See “Non-GAAP Financial Measures” below
• Announced $154.0 million Williston Basin acquisition in October; closed on the acquisition of Permian Basin properties on August 2, 2021
• Updated 2021 guidance includes increased annual production, reduced unit costs, reduced capital expenditures and improved pricing differentials

Northern Oil and Gas today announced the company’s third quarter results and provided updated 2021 guidance.

“The third quarter again demonstrated Northern’s stellar business execution,” commented Nick O’Grady, Northern’s Chief Executive Officer. “We delivered record free cash flow yet again and closed a significant Permian acquisition in the third quarter. In October, we announced the signing of another meaningfully accretive transaction, as we relentlessly seek to increase shareholder value. We see significant additional opportunities to further benefit shareholders and remain dedicated to building a diversified, low-leverage entity, with steadily increasing cash returns.”

THIRD QUARTER FINANCIAL RESULTS

Oil and natural gas sales for the third quarter were $259.7 million, up 15% over the second quarter. Third quarter GAAP net income, inclusive of a $71.8 million non-cash net mark-to-market loss on derivatives, was $12.6 million or $0.19 per diluted share. Third quarter Adjusted Net Income was $64.1 million or $0.84 per diluted share, which was reduced by $20.8 million (or $0.27 per diluted share) by the net deferred tax effect from adjustments primarily related to changes in the mark-to-market values of derivatives. Adjusted Net Income was up from $27.5 million or $0.51 per diluted share in the third quarter of 2020. Adjusted EBITDA in the third quarter was $136.1 million, up 65% from the third quarter of 2020. See “Non-GAAP Financial Measures” below.

PRODUCTION

Third quarter production was 57,647 Boe per day, a 6% increase from the second quarter of 2021 and a 98% increase from the third quarter of 2020. Oil represented 59% of total production in the third quarter. Oil production was 34,035 Bbl per day, a 2% increase over the second quarter of 2021 and a 52% increase over the third quarter of 2020. Northern had 6.5 net wells turned in-line during the third quarter, compared to 10.5 net wells turned in-line in the second quarter of 2021. Northern’s Marcellus production made up 21% of total volumes in the third quarter, and were up quarter-over-quarter with the first EQT-operated pad coming online. Northern’s Permian production made up 4% of volumes in the third quarter, reflecting a partial quarter impact from recently closed acquisitions, and are expected to ramp substantially in the fourth quarter.

PRICING

During the third quarter, NYMEX West Texas Intermediate (“WTI”) crude oil averaged $70.54 per Bbl, and NYMEX natural gas at Henry Hub averaged $4.31 per million cubic feet (“Mcf”). Northern’s unhedged net realized oil price in the third quarter was $64.91, representing a $5.63 differential to WTI prices. Northern’s unhedged net realized gas price in the third quarter was $4.33 per Mcf, representing approximately 100% realizations compared with Henry Hub pricing.

OPERATING COSTS

Lease operating costs were $43.2 million in the third quarter of 2021, or $8.15 per Boe, down over 5% on a per unit basis compared to the second quarter of 2021. The reduction in unit costs was driven by increased low-cost Marcellus and Permian production, partially offset by lower new completions and higher processing costs associated with strong NGL prices. Third quarter general and administrative (“G&A”) costs totaled $5.5 million or $1.04 per Boe. This includes $0.7 million of legal and other transaction expenses in connection with the Permian and Williston acquisitions and $0.7 million of non-cash stock-based compensation. Northern’s G&A costs excluding these amounts totaled $4.1 million or $0.78 per Boe in the third quarter, down 44% versus the third quarter in the prior year.

CAPITAL EXPENDITURES AND ACQUISITIONS

Capital spending for the third quarter was $63.2 million, down 8% from the second quarter of 2021. Spending was made up of $53.0 million of total drilling and completion (“D&C”) capital on organic and ground game assets, and $10.2 million of ground game acquisition spending and other items. These amounts exclude our unbudgeted acquisitions, such as the Permian acquisition that closed in August 2021. Our Williston Basin spending made up 73% of the total capital expenditures for the quarter, the Permian made up 20%, the Marcellus made up 5% and other items made up 2%. On the ground game acquisition front, Northern closed on 6 transactions during the third quarter totaling 2.2 net wells, 1,077 net mineral acres, and 182 net royalty acres (standardized to a 1/8 royalty interest).

WILLISTON BASIN ACQUISITION

On October 7, 2021, Northern announced that it entered into a definitive agreement to acquire non-operated interests across over 400 producing wellbores located primarily in Williams, McKenzie, Mountrail and Dunn Counties, ND for a purchase price of $154.0 million in cash, subject to typical closing adjustments. Northern has updated corporate guidance for the assets to be acquired in the guidance section below, which assumes a mid-to-late November closing date.

LIQUIDITY AND CAPITAL RESOURCES

Northern had total liquidity of $343.0 million as of September 30, 2021, consisting of cash of $2.0 million, and $341.0 million of committed borrowing availability under the revolving credit facility.

As of September 30, 2021, Northern’s total borrowings were $869.0 million, down $119.8 million since September 30, 2020. Total borrowings consist of $550.0 million in senior unsecured notes and $319.0 million outstanding on Northern’s revolving credit facility.

On November 3, 2021, Northern completed its regularly scheduled borrowing base redetermination, increasing both its elected commitment and borrowing base. Northern’s lending syndicate voted unanimously to increase the borrowing base to $850.0 million. Northern has chosen a $750.0 million elected commitment amount. Pro forma for this increase, as of September 30, 2021, we had $431.0 of committed borrowing availability under the revolving credit facility. The new borrowing base does not include any reserve value for Northern’s pending Williston Basin acquisition.

KeyFacts Energy Industry Directory: Northern Oil and Gas

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