Business Wire | Nov 5, 2021 06:30AM EDT

Northern Oil and Gas, Inc. Announces Third Quarter 2021 Results and Updates Guidance

Nov. 05, 2021

MINNEAPOLIS--(BUSINESS WIRE)--Nov. 05, 2021--Northern Oil and Gas, Inc. (NYSE American: NOG) ("Northern") today announced the company's third quarter results and provided updated 2021 guidance.

MANAGEMENT COMMENTS

"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.

STOCKHOLDER RETURNS

On August 3, 2021, Northern's Board of Directors declared a regular quarterly cash dividend for Northern's common stock of $0.045 per share for stockholders of record as of September 30, 2021, which was paid on October 29, 2021. This represented a 50% increase from the prior quarter.

On October 7, 2021, Northern Management announced its plan to submit a request to Northern's Board of Directors for a 33.3% increase to the quarterly common stock dividend to $0.06 per share upon closing of the Williston Basin acquisition that is expected to close in mid-November 2021.

On October 15, 2021, Northern's Board of Directors declared all current and accrued cash dividends for Northern's Series A Preferred Stock, to be paid on November 15, 2021, in the total amount of $7.2 million.

2021 FULL YEAR GUIDANCE (all forecasts are provided on a 2-stream production basis)

Prior Current

Annual Production (Boe per day) 49,500 - 51,750 - 53,750^ 54,250 (1)

Oil as a Percentage of Sales Volumes 63% - 64% 63% - 64%

Net Wells Added to Production 38 - 40 38 - 40

Total Capital Expenditures (in millions)^ $215 - $260 $215 - $250(2)

------------------

(1)

Includes approximately 500 - 560 Boe per day, annualized, from the pending Williston Basin acquisition, expected to close in mid to late November 2021.

(2)

Excludes non-budgeted acquisitions of Marcellus, Williston and Permian properties, but includes post-closing capital expenditures.

------------------

Includes approximately 500 - 560 Boe per day, annualized, from the pending(1) Williston Basin acquisition, expected to close in mid to late November 2021.

(2) Excludes non-budgeted acquisitions of Marcellus, Williston and Permian properties, but includes post-closing capital expenditures.

Operating Expenses and Differentials:

Prior

Current

Production Expenses (per Boe)

$8.60 - $8.90

$8.60 - $8.80

Production Taxes

9% - 10% of

Oil & Gas Sales

9% - 10% of

Oil & Gas Sales

Average Differential to NYMEX WTI (per Bbl)

$6.25 - $7.25

$5.75 - $6.25

Average Realization as a Percentage of NYMEX Henry Hub (per Mcf)

80% - 100%

90% - 100%

Operating Expenses and Differentials: Prior Current

Production Expenses (per Boe) $8.60 - $8.60 - $8.90 $8.80

9% - 10% of 9% - 10% ofProduction Taxes Oil & Gas Oil & Gas Sales Sales

Average Differential to NYMEX WTI (per Bbl) $6.25 - $5.75 - $7.25 $6.25

Average Realization as a Percentage of NYMEX Henry 80% - 100% 90% - 100%Hub (per Mcf)

Prior

Current

General and Administrative Expense (per Boe):

Cash (excluding Marcellus, Williston and Permian transaction costs)

$0.80 - $0.85

$0.80 - $0.85

Non-Cash

$0.18

$0.18

THIRD QUARTER 2021 RESULTS

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

Prior Current

General and Administrative Expense (per Boe):

Cash (excluding Marcellus, Williston and Permian $0.80 - $0.80 -transaction costs) $0.85 $0.85

Non-Cash $0.18 $0.18

THIRD QUARTER 2021 RESULTS

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

Three Months Ended September 30,

2021 2020 % Change

Net Production:

Oil (Bbl) 3,131,182 2,054,847 52 %

Natural Gas and NGLs (Mcf) 13,034,251 3,706,853 252 %

Total (Boe) 5,303,557 2,672,656 98 %



Average Daily Production:

Oil (Bbl) 34,035 22,335 52 %

Natural Gas and NGLs (Mcf) 141,677 40,292 252 %

Total (Boe) 57,647 29,051 98 %



Average Sales Prices:

Oil (per Bbl) $ 64.91 $ 34.36 89 %

Effect of Gain (Loss) on Settled Oil (12.52 ) 21.11 Derivatives on Average Price (per Bbl)

Oil Net of Settled Oil Derivatives (per 52.39 55.47 (6 )%Bbl)



Natural Gas and NGLs (per Mcf) 4.33 0.83

Effect of Gain (Loss) on Settled Natural (1.31 ) 0.13 Gas Derivatives on Average Price (per Mcf)

Natural Gas and NGLs Net of Settled Natural 3.02 0.96 Gas Derivatives (per Mcf)



Realized Price on a Boe Basis Excluding 48.96 27.57 78 %Settled Commodity Derivatives

Effect of Gain (Loss) on Settled Commodity (10.62 ) 16.40 Derivatives on Average Price (per Boe)

Realized Price on a Boe Basis Including 38.34 43.97 (13 )%Settled Commodity Derivatives



Costs and Expenses (per Boe):

Production Expenses $ 8.15 $ 9.04 (10 )%

Production Taxes 3.76 2.60 45 %

General and Administrative Expenses 1.04 1.72 (40 )%

Depletion, Depreciation, Amortization and 6.77 11.52 (41 )%Accretion



Net Producing Wells at Period End 601.8 468.8 28 %

HEDGING

Northern 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 Northern's open crude oil commodity derivative swap contracts scheduled to settle after September 30, 2021.

Crude Oil Commodity Derivative Swaps^(1)

Contract Volume Volume (Bbls/ Weighted Average Price (perPeriod (Bbls) Day) Bbl)

2021:

Q4 2,326,956 25,293 $55.27

2022:

Q1 2,137,480 23,750 $57.01

Q2 2,047,500 22,500 $57.55

Q3 2,058,500 22,375 $57.14

Q4 1,943,500 21,125 $56.96

2023:

Q1 596,250 6,625 $59.30

Q2 420,875 4,625 $61.72

Q3 115,000 1,250 $64.93

Q4 115,000 1,250 $64.93

_____________

(1)

This table does not include volumes subject to swaptions and call options, which could increase the amount of volumes hedged at the option of Northern's counterparties. This table also does not include basis swaps. For additional information, see Note 11 to our financial statements included in our Form 10-Q filed with the SEC for the quarter ended September 30, 2021.

The following table summarizes Northern's open natural gas commodity derivative swap contracts scheduled to settle after September 30, 2021.

_____________

This table does not include volumes subject to swaptions and call options, which could increase the amount of volumes hedged at the option of(1) Northern's counterparties. This table also does not include basis swaps. For additional information, see Note 11 to our financial statements included in our Form 10-Q filed with the SEC for the quarter ended September 30, 2021.

The following table summarizes Northern's open natural gas commodity derivative swap contracts scheduled to settle after September 30, 2021.

Natural Gas Commodity Derivative Swaps

Contract Gas Volume (MMBTU/ Weighted Average Price (perPeriod (MMBTU) Day) Mcf)

2021:

Q4 8,784,210 95,481 $2.82

2022:

Q1 6,257,291 69,525 $3.07

Q2 5,460,000 60,000 $2.95

Q3 5,520,000 60,000 $2.95

Q4 4,300,000 46,739 $2.94

_____________

(1)

This table does not include volumes subject to collars. This table also does not include basis swaps. For additional information, see Note 11 to our financial statements included in our Form 10-Q filed with the SEC for the quarter ended September 30, 2021.

The following table presents Northern'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 Northern's statement of operations:

_____________

This table does not include volumes subject to collars. This table also(1) does not include basis swaps. For additional information, see Note 11 to our financial statements included in our Form 10-Q filed with the SEC for the quarter ended September 30, 2021.

The following table presents Northern'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 Northern's statement of operations:

Three Months Ended Nine Months Ended September 30, September 30,

(In thousands) 2021 2020 2021 2020

Cash Received(Paid) on $ (56,318 ) $ 43,837 $ (91,470 ) $ 152,782 Derivatives:

Non-Cash Gain(Loss) on (71,845 ) (70,198 ) (373,540 ) 124,800 Derivatives:

Gain (Loss) onDerivative $ (128,163 ) $ (26,361 ) $ (465,010 ) $ 277,582 Instruments, Net

CAPITAL EXPENDITURES & DRILLING ACTIVITY

(In millions, except for net well data) Three Months Ended September 30, 2021

Capital Expenditures Incurred:

Organic Drilling and Development Capital Expenditures $ 37.7

Ground Game Drilling and Development Capital Expenditures $ 15.3

Ground Game Acquisition Capital Expenditures $ 8.8

Other $ 1.4

Non-Budgeted Acquisitions $ 106.4



Net Wells Added to Production 6.5



Net Producing Wells (Period-End) 601.8



Net Wells in Process (Period-End) 43.1

Decrease in Wells in Process over Prior Period (0.6 )



Weighted Average Gross AFE for Wells Elected to $6.9 million

THIRD QUARTER 2021 EARNINGS RELEASE CONFERENCE CALL

In conjunction with Northern'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 5, 2021 at 10:00 a.m. Central Time.

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

Webcast: https://78449.themediaframe.com/dataconf/productusers/nog/mediaframe/46821/indexl.html Dial-In Number: (866) 373-3407 (US/Canada) and (412) 902-1037 (International) Conference ID: 13723773 - Northern Oil and Gas, Inc. Third Quarter 2021 Earnings Call Replay Dial-In Number: (877) 660-6853 (US/Canada) and (201) 612-7415 (International) Replay Access Code: 13723773 - Replay will be available through November 12, 2021

UPCOMING CONFERENCE SCHEDULE

Bank of America Global Energy Conference

November 17-18, 2021



Piper Sandler Energy & Power Symposium

December 1-2, 2021



Capital One 16th Annual Energy Conference

December 6-8, 2021

ABOUT NORTHERN OIL AND GAS

Northern Oil and Gas, Inc. is a company with a primary strategy of investing in non-operated minority working and mineral interests in oil & gas properties, with a core area of focus in the premier basins within the United States. More information about Northern Oil and Gas, Inc. can be found at www.northernoil.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 (the "Securities Act") and the Securities Exchange Act of 1934 (the "Exchange Act"). All statements other than statements of historical facts included in this release regarding Northern's financial position, operating and financial performance, business strategy, plans and objectives of management for future operations, industry conditions, and indebtedness covenant compliance 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 and sales, market size, collaborations, 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 Northern'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 Northern's properties and properties pending acquisition; Northern's ability to acquire additional development opportunities; potential or pending acquisition transactions; Northern's ability to consummate pending acquisitions, and the anticipated timing of such consummation; the projected capital efficiency savings and other operating efficiencies and synergies resulting from Northern's acquisition transactions; integration and benefits of property acquisitions, or the effects of such acquisitions on Northern's cash position and levels of indebtedness; changes in Northern's reserves estimates or the value thereof; disruptions to Northern's business due to acquisitions and other significant transactions; infrastructure constraints and related factors affecting Northern's properties; ongoing legal disputes over and potential shutdown of the Dakota Access Pipeline; the COVID-19 pandemic and its related economic repercussions and effect on the oil and natural gas industry; general economic or industry conditions, nationally and/or in the communities in which Northern conducts business; changes in the interest rate environment, legislation or regulatory requirements; conditions of the securities markets; Northern's ability to raise or access capital; changes in accounting principles, policies or guidelines; and financial or political instability, health-related epidemics, acts of war or terrorism, and other economic, competitive, governmental, regulatory and technical factors affecting Northern's operations, products and prices.

Northern 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 Northern's control. Northern does not undertake any duty to update or revise any forward-looking statements, except as may be required by the federal securities laws.

CONDENSED STATEMENTS OF OPERATIONS

(UNAUDITED)

Three Months Ended Nine Months Ended September 30, September 30,

(In thousands,except share 2021 2020 2021 2020and per sharedata)

Revenues

Oil and Gas $ 259,669 $ 73,680 $ 642,717 $ 224,541 Sales

Gain (Loss) onCommodity (128,163 ) (26,361 ) (465,010 ) 277,582 Derivatives,Net

Other Revenue 1 3 2 12

Total Revenues 131,507 47,321 177,709 502,135



Operating Expenses

Production 43,236 24,159 120,246 88,132 Expenses

Production 19,932 6,936 51,899 20,750 Taxes

General andAdministrative 5,490 4,605 19,878 14,185 Expense

Depletion,Depreciation, 35,885 30,786 98,013 129,350 Amortizationand Accretion

Impairment - 199,489 - 962,205 Expense

TotalOperating 104,543 265,975 290,036 1,214,622 Expenses



Income (Loss)From 26,964 (218,653 ) (112,327 ) (712,487 ) Operations



Other Income (Expense)

InterestExpense, Net (14,586 ) (14,637 ) (43,120 ) (45,145 ) ofCapitalization

Write-off ofDebt Issuance - (1,543 ) - (1,543 ) Costs

Gain (Loss) onUnsettledInterest Rate 92 224 454 (1,205 ) Derivatives,Net

Gain (Loss) onExtinguishment - 1,592 (13,087 ) (3,718 ) of Debt, Net

ContingentConsideration 82 - (292 ) - Gain (Loss)

Other Income 2 13 5 14 (Expense)

Total OtherIncome (14,410 ) (14,351 ) (56,040 ) (51,597 ) (Expense)



Income (Loss)Before Income 12,554 (233,004 ) (168,367 ) (764,084 ) Taxes



Income TaxProvision - - - (166 ) (Benefit)



Net Income $ 12,554 $ (233,004 ) $ (168,367 ) $ (763,918 ) (Loss)



CumulativePreferred (3,605 ) (3,718 ) (11,154 ) (10,986 ) Stock Dividend



Net Income(Loss)Attributable $ 8,949 $ (236,722 ) $ (179,521 ) $ (774,904 ) to CommonStockholders



Net Income(Loss) Per $ 0.14 $ (5.44 ) $ (2.97 ) $ (18.53 ) Common Share -Basic

Net Income(Loss) Per $ 0.13 $ (5.44 ) $ (2.97 ) $ (18.53 ) Common Share -Diluted

WeightedAverage CommonShares 65,856,479 43,517,074 60,404,584 41,812,553 Outstanding -Basic

WeightedAverage CommonShares 66,629,566 43,517,074 60,404,584 41,812,553 Outstanding -Diluted

CONDENSED BALANCE SHEETS

(In thousands, except par value and share data)

September 30, 2021

December 31, 2020

Assets

(Unaudited)

Current Assets:

Cash and Cash Equivalents

$

2,006

$

1,428

Accounts Receivable, Net

158,047

71,015

Advances to Operators

5,137

476

Prepaid Expenses and Other

2,393

1,420

Derivative Instruments

-

51,290

Total Current Assets

167,583

125,629

Property and Equipment:

Oil and Natural Gas Properties, Full Cost Method of Accounting

Proved

4,804,687

4,393,533

Unproved

24,656

10,031

Other Property and Equipment

2,779

2,451

Total Property and Equipment

4,832,122

4,406,015

Less - Accumulated Depreciation, Depletion and Impairment

(3,767,613

)

(3,670,811

)

Total Property and Equipment, Net

1,064,509

735,204

Derivative Instruments

-

111

Other Noncurrent Assets, Net

11,970

11,145

Total Assets

$

1,244,062

$

872,089

Liabilities and Stockholders' Equity (Deficit)

Current Liabilities:

Accounts Payable

$

65,912

$

35,803

Accrued Liabilities

100,443

68,673

Accrued Interest

4,248

8,341

Derivative Instruments

182,692

3,078

Contingent Consideration

242

493

Current Portion of Long-term Debt

-

65,000

Other Current Liabilities

1,635

1,087

Total Current Liabilities

355,172

182,475

Long-term Debt

858,415

879,843

Derivative Instruments

156,731

14,659

Asset Retirement Obligations

27,106

18,366

Other Noncurrent Liabilities

4,349

50

Total Liabilities

$

1,401,773

$

1,095,393

Commitments and Contingencies (Note 8)

CONDENSED BALANCE SHEETS

(In thousands, except par value and share data) September 30, December 31, 2021 2020

Assets (Unaudited)

Current Assets:

Cash and Cash Equivalents $ 2,006 $ 1,428

Accounts Receivable, Net 158,047 71,015

Advances to Operators 5,137 476

Prepaid Expenses and Other 2,393 1,420

Derivative Instruments - 51,290

Total Current Assets 167,583 125,629



Property and Equipment:

Oil and Natural Gas Properties, Full Cost Method of Accounting

Proved 4,804,687 4,393,533

Unproved 24,656 10,031

Other Property and Equipment 2,779 2,451

Total Property and Equipment 4,832,122 4,406,015

Less - Accumulated Depreciation, Depletion and (3,767,613 ) (3,670,811 ) Impairment

Total Property and Equipment, Net 1,064,509 735,204



Derivative Instruments - 111

Other Noncurrent Assets, Net 11,970 11,145



Total Assets $ 1,244,062 $ 872,089



Liabilities and Stockholders' Equity (Deficit)

Current Liabilities:

Accounts Payable $ 65,912 $ 35,803

Accrued Liabilities 100,443 68,673

Accrued Interest 4,248 8,341

Derivative Instruments 182,692 3,078

Contingent Consideration 242 493

Current Portion of Long-term Debt - 65,000

Other Current Liabilities 1,635 1,087

Total Current Liabilities 355,172 182,475



Long-term Debt 858,415 879,843

Derivative Instruments 156,731 14,659

Asset Retirement Obligations 27,106 18,366

Other Noncurrent Liabilities 4,349 50



Total Liabilities $ 1,401,773 $ 1,095,393



Commitments and Contingencies (Note 8)



Stockholders' Equity (Deficit)

Preferred Stock, Par Value $.001; 5,000,000 Shares Authorized;

2,218,732 Series A Shares Outstanding at 6/30/2021

2,218,732 Series A Shares Outstanding at 12/31/2020

2

2

Common Stock, Par Value $.001; 135,000,000 Shares Authorized;

66,178,148 Shares Outstanding at 9/30/2021

45,908,779 Shares Outstanding at 12/31/2020

468

448

Additional Paid-In Capital

1,790,542

1,556,602

Retained Deficit

(1,948,723

)

(1,780,356

)

Total Stockholders' Equity (Deficit)

(157,710

)

(223,304

)

Total Liabilities and Stockholders' Equity (Deficit)

$

1,244,062

$

872,089

Non-GAAP Financial Measures

Adjusted Net Income, Adjusted EBITDA and Free Cash Flow are non-GAAP measures. Northern defines Adjusted Net Income (Loss) as net income (loss) excluding (i) (gain) loss on unsettled commodity derivatives, net of tax, (ii) write-off of debt issuance costs, net of tax, (iii) (gain) loss on extinguishment of debt, net of tax, (iv) contingent consideration (gain) loss, net of tax, (v) acquisition transaction costs, net of tax, (vi) (gain) loss on unsettled interest rate derivatives, net of tax and (vii) impairment expense. Northern defines Adjusted EBITDA as net income (loss) before (i) interest expense, (ii) income taxes, (iii) depreciation, depletion, amortization and accretion, (iv) non-cash stock-based compensation expense, (v) severance-cash, (vi) write-off of debt issuance costs, (vii) (gain) loss on extinguishment of debt, (viii) contingent consideration (gain) loss, (ix) acquisition transaction costs, (x) gain (loss) on unsettled interest rate derivatives (xi) (gain) loss on unsettled commodity derivatives, and (xii) impairment expense. Northern 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 (ii) preferred stock dividends. 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 Northern'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 Northern'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 Northern provides forward-looking Free Cash Flow estimates or targets; however, Northern 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.

Stockholders' Equity (Deficit)

Preferred Stock, Par Value $.001; 5,000,000Shares Authorized;

2,218,732 Series A Shares Outstanding at 6/30/ 2 2 2021

2,218,732 Series A Shares Outstanding at 12/31/2020

Common Stock, Par Value $.001; 135,000,000Shares Authorized; 468 448 66,178,148 Shares Outstanding at 9/30/2021

45,908,779 Shares Outstanding at 12/31/2020

Additional Paid-In Capital 1,790,542 1,556,602

Retained Deficit (1,948,723 ) (1,780,356 )

Total Stockholders' Equity (Deficit) (157,710 ) (223,304 )

Total Liabilities and Stockholders' Equity $ 1,244,062 $ 872,089 (Deficit)

Non-GAAP Financial Measures

Adjusted Net Income, Adjusted EBITDA and Free Cash Flow are non-GAAP measures. Northern defines Adjusted Net Income (Loss) as net income (loss) excluding (i) (gain) loss on unsettled commodity derivatives, net of tax, (ii) write-off of debt issuance costs, net of tax, (iii) (gain) loss on extinguishment of debt, net of tax, (iv) contingent consideration (gain) loss, net of tax, (v) acquisition transaction costs, net of tax, (vi) (gain) loss on unsettled interest rate derivatives, net of tax and (vii) impairment expense. Northern defines Adjusted EBITDA as net income (loss) before (i) interest expense, (ii) income taxes, (iii) depreciation, depletion, amortization and accretion, (iv) non-cash stock-based compensation expense, (v) severance-cash, (vi) write-off of debt issuance costs, (vii) (gain) loss on extinguishment of debt, (viii) contingent consideration (gain) loss, (ix) acquisition transaction costs, (x) gain (loss) on unsettled interest rate derivatives (xi) (gain) loss on unsettled commodity derivatives, and (xii) impairment expense. Northern 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 (ii) preferred stock dividends. 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 Northern'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 Northern'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 Northern provides forward-looking Free Cash Flow estimates or targets; however, Northern 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.

Reconciliation of Adjusted Net Income

Three Months Ended Nine Months Ended September 30, September 30,

(In thousands,except share 2021 2020 2021 2020and per sharedata)

Net Income $ 12,554 $ (233,004 ) $ (168,367 ) $ (763,918 ) (Loss)

Add:

Impact ofSelected Items:

(Gain) Loss onUnsettled 71,845 70,198 373,540 (124,800 ) CommodityDerivatives

Write-off ofDebt Issuance - 1,543 - 1,543 Costs

(Gain) Loss onExtinguishment - (1,592 ) 13,087 3,718 of Debt

ContingentConsideration (82 ) - 292 - (Gain) Loss

AcquisitionTransaction 677 - 6,204 - Costs

(Gain) Loss onUnsettled (92 ) (224 ) (454 ) 1,205 Interest RateDerivatives

Impairment - 199,489 - 962,205 Expense

SelectedItems, Before 72,347 269,415 392,670 843,871 Income Taxes

Income Tax ofSelected Items (20,801 ) (8,921 ) (54,954 ) (19,588 ) ^(1)

SelectedItems, Net of 51,547 260,495 337,716 824,283 Income Taxes

Adjusted Net $ 64,100 $ 27,490 $ 169,349 $ 60,365 Income



WeightedAverage Shares 65,856,479 43,517,074 60,404,584 41,812,553 Outstanding -Basic

WeightedAverage Shares 76,348,278 53,582,333 70,888,853 51,707,412 Outstanding -Diluted



Net Income(Loss) Per $ 0.19 $ (5.35 ) $ (2.79 ) $ (18.27 ) Common Share -Basic

Add:

Impact ofSelected Items 1.10 6.18 6.50 20.18 Before IncomeTax

Impact ofIncome Tax on (0.32 ) (0.20 ) (0.91 ) (0.47 ) Selected Items

Adjusted NetIncome Per $ 0.97 $ 0.63 $ 2.80 $ 1.44 Common Share -Basic



Net Income(Loss) Per $ 0.16 $ (4.35 ) $ (2.38 ) $ (14.77 ) Common Share -Diluted

Add:

Impact ofSelected Items 0.95 5.03 5.55 16.32 Before IncomeTax

Impact ofIncome Tax on (0.27 ) (0.17 ) (0.78 ) (0.38 ) Selected Items

Adjusted NetIncome Per $ 0.84 $ 0.51 $ 2.39 $ 1.17 Common Share -Diluted

______________

(1)

For the three and nine months ended September 30, 2021, this represents a tax impact using an estimated tax rate of 24.5%, which includes an adjustment of $3.1 million and $41.2 million, respectively, for a change in valuation allowance. For the three and nine months ended September 30, 2020, this represents a tax impact using an estimated tax rate of 24.5%, which includes an adjustment of $57.1 million and $187.2 million, respectively, for a change in valuation allowance.

______________

For the three and nine months ended September 30, 2021, this represents a tax impact using an estimated tax rate of 24.5%, which includes an adjustment of $3.1 million and $41.2 million, respectively, for a change(1) in valuation allowance. For the three and nine months ended September 30, 2020, this represents a tax impact using an estimated tax rate of 24.5%, which includes an adjustment of $57.1 million and $187.2 million, respectively, for a change in valuation allowance.

Reconciliation of Adjusted EBITDA

Three Months EndedSeptember 30,

Nine Months EndedSeptember 30,

(In thousands)

2021

2020

2021

2020

Net Income (Loss)

$

12,554

$

(233,004

)

$

(168,367

)

$

(763,918

)

Add:

Interest Expense

14,586

14,637

43,120

45,145

Income Tax Provision (Benefit)

-

-

-

(166

)

Depreciation, Depletion, Amortization and Accretion

35,885

30,786

98,013

129,350

Impairment of Other Current Assets

-

-

-

-

Non-Cash Stock-Based Compensation

699

889

-

3,182

Severance-Cash

-

-

-

759

Write-off of Debt Issuance Costs

-

1,543

-

1,543

(Gain) Loss on Extinguishment of Debt

-

(1,592

)

13,087

3,718

Contingent Consideration (Gain) Loss

(82

)

-

292

-

Acquisition Transaction Costs

677

-

6,204

-

(Gain) Loss on Unsettled Interest Rate Derivatives

(92

)

(224

)

(454

)

1,205

(Gain) Loss on Unsettled Commodity Derivatives

71,845

70,198

373,540

(124,800

)

Impairment Expense

-

199,489

-

962,205

Adjusted EBITDA

$

136,071

$

82,723

$

367,685

$

258,224

Reconciliation of Adjusted EBITDA

Three Months Ended Nine Months Ended September 30, September 30,

(In thousands) 2021 2020 2021 2020

Net Income $ 12,554 $ (233,004 ) $ (168,367 ) $ (763,918 ) (Loss)

Add:

Interest 14,586 14,637 43,120 45,145 Expense

Income TaxProvision - - - (166 ) (Benefit)

Depreciation,Depletion, 35,885 30,786 98,013 129,350 Amortizationand Accretion

Impairment ofOther Current - - - - Assets

Non-CashStock-Based 699 889 - 3,182 Compensation

Severance-Cash - - - 759

Write-off ofDebt Issuance - 1,543 - 1,543 Costs

(Gain) Loss onExtinguishment - (1,592 ) 13,087 3,718 of Debt

ContingentConsideration (82 ) - 292 - (Gain) Loss

AcquisitionTransaction 677 - 6,204 - Costs

(Gain) Loss onUnsettled (92 ) (224 ) (454 ) 1,205 Interest RateDerivatives

(Gain) Loss onUnsettled 71,845 70,198 373,540 (124,800 ) CommodityDerivatives

Impairment - 199,489 - 962,205 Expense

Adjusted $ 136,071 $ 82,723 $ 367,685 $ 258,224 EBITDA

Reconciliation of Free Cash Flow

Three Months EndedSeptember 30,

(In thousands)

2021

Net Cash Provided by Operating Activities

$

94,413

Exclude: Changes in Working Capital and Other Items

27,888

Less: Capital Expenditures (1)

(63,278

)

Less: Series A Preferred Dividends

(3,605

)

Free Cash Flow

$

55,418

Reconciliation of Free Cash Flow

Three Months Ended September 30,

(In thousands) 2021

Net Cash Provided by Operating Activities $ 94,413

Exclude: Changes in Working Capital and Other Items 27,888

Less: Capital Expenditures ^(1) (63,278 )

Less: Series A Preferred Dividends (3,605 )

Free Cash Flow $ 55,418

_______________

(1)

Capital expenditures are calculated as follows:

_______________

(1) Capital expenditures are calculated as follows:

Three Months EndedSeptember 30,

(In thousands)

2021

Cash Paid for Capital Expenditures

$

163,120

Less: Non-Budgeted Acquisitions

(106,197

)

Plus: Change in Accrued Capital Expenditures and Other

6,355

Capital Expenditures

$

63,278

View source version on businesswire.com: https://www.businesswire.com/news/home/20211105005300/en/

CONTACT: Mike Kelly, CFA Chief Strategy Officer 952-476-9800 mkelly@northernoil.com