NOG Announces Fourth Quarter and Full Year 2021 Results

HIGHLIGHTS

  • Fourth quarter production of 64,155 Boe per day (59.2% oil), an increase of 11% from the third quarter of 2021
  • Fourth quarter GAAP cash flow from operations of $133.1 million. Excluding changes in net working capital, cash flow from operations was $158.0 million, an increase of 29% from the third quarter of 2021
  • Total capital expenditures of $83.7 million during the fourth quarter, excluding previously-announced non-budgeted acquisitions
  • Free Cash Flow (non-GAAP) of $70.7 million during the fourth quarter, post-preferred stock dividends, increased 28% from the third quarter of 2021. See “Non-GAAP Financial Measures” below
  • Initiates 2022 production guidance of 70,000 - 75,000 Boe per day, with $350 - $415 million total planned capital expenditures
  • Closed Veritas acquisition in the Permian Basin, largest acquisition in NOG’s history, on January 27, 2022
  • Announced a Base Dividend Growth plan in December 2021, highlighted by planned 20% average dividend growth per quarter through 2023
  • Retired $7.2 million in face value of Convertible Preferred Stock

MINNEAPOLIS--(BUSINESS WIRE)-- Northern Oil and Gas, Inc. (NYSE: NOG) (“Northern,” or “NOG”) today announced the company’s fourth quarter and full year 2021 results.

MANAGEMENT COMMENTS

“2021 was a truly transformational year for NOG,” commented Nick O’Grady, NOG’s Chief Executive Officer. “We enter 2022 with a stronger asset base and balance sheet, and with a formalized plan of increasing shareholder returns. We are an increasingly diversified, balanced business, with opportunities to self-fund accretive growth while steadily increasing returns to our shareholders.”

FINANCIAL RESULTS

Oil and natural gas sales for the fourth quarter were $332.4 million, an increase of 28% over the third quarter. Fourth quarter GAAP net income was $171.1 million or $2.13 per diluted share. Fourth quarter Adjusted Net Income was $87.0 million or $1.06 per diluted share, an increase of $35.7 million or $0.64 per diluted share over the prior year. Adjusted EBITDA in the fourth quarter was $175.3 million, an increase of 29% over the third quarter.

Oil and natural gas sales for full year 2021 were $975.1 million, an increase of 201% over full year 2020. Full year 2021 Adjusted Net Income was $256.3 million or $3.49 per diluted share. Full year 2021 GAAP net loss was $8.4 million or $0.13 per diluted share. Full year 2021 Adjusted EBITDA was $543.0 million, an increase of 54% over the prior year. (See “Non-GAAP Financial Measures” below.)

PRODUCTION

Fourth quarter production was 64,155 Boe per day, an 11% increase from the third quarter. Oil represented 59.2% of production in the fourth quarter. NOG had 12.1 net wells turned online during the fourth quarter, compared to 6.5 net wells turned online in the third quarter of 2021. NOG saw production outperform internal expectations in the fourth quarter, most notably in its Appalachian properties. Full year 2021 production was 53,792 Boe per day, above the high end of NOG’s 2021 guidance.

PRICING

During the fourth quarter, NYMEX West Texas Intermediate (“WTI”) crude oil averaged $77.31 per Bbl, and NYMEX natural gas at Henry Hub averaged $4.74 per Mcf. NOG’s unhedged net realized oil price in the fourth quarter was $71.67 per Bbl, representing a $5.64 differential to WTI prices. NOG’s fourth quarter unhedged net realized gas price was $5.68 per Mcf, representing approximately 120% realizations compared with Henry Hub pricing.

For full year 2021, NOG’s realized oil differential was $5.15 per Bbl. NOG’s full year unhedged net realized gas price was $4.57 per Mcf, representing approximately 119% realizations compared with Henry Hub pricing.

OPERATING COSTS

Lease operating costs were $50.6 million in the fourth quarter of 2021, or $8.57 per Boe, an increase of 5% on a per unit basis compared to the third quarter. The increase in unit costs was primarily driven by the acquisition of higher unit cost production in the Williston Basin. Continued high NGL prices, which results in higher processing charges, also increased unit costs, but was more than offset by higher natural gas revenues.

Fourth quarter general and administrative (“G&A”) costs totaled $10.5 million, which includes non-cash stock-based compensation. Cash G&A costs totaled $9.1 million or $1.54 per Boe in the fourth quarter, which included certain transaction costs associated with our Permian and Williston acquisitions. Excluding approximately $2.0 million of such transaction costs, remaining cash G&A was $7.1 million, or $1.20 per Boe.

CAPITAL EXPENDITURES AND ACQUISITIONS

Capital spending for the fourth quarter, excluding non-budgeted acquisitions, was $83.7 million. This was comprised of $49.1 million of organic drilling and completion (“D&C”) capital and $34.6 million of total acquisition spending and other items, inclusive of ground game D&C spending. NOG had 12.1 net wells turned online in the fourth quarter. Wells in process totaled 42.5 net wells as of December 31, 2021. On the ground game acquisition front, NOG closed on 9 transactions during the fourth quarter totaling 9.6 net wells, and 317 net mineral acres. Total 2021 capital expenditures, excluding non-budgeted acquisitions, were $253.4 million, slightly above NOG’s guidance for 2021 driven by significant ground game opportunities executed and an acceleration of completion activity in the fourth quarter.

RESERVES

Total proved reserves at December 31, 2021, increased 135% from year-end 2020 to 287.7 million barrels of oil equivalent (59% proved developed) with an associated pre-tax PV-10 value of $3.3 billion (72% proved developed) at SEC Pricing. Total reserve replacement ratio was 270%, excluding acquired reserves. NOG’s PV-10 and proved reserve values at year-end 2021 do not include the recently closed Veritas transaction. The Veritas assets had an audited year-end 2021 proved reserve PV-10 value of $428 million at SEC Pricing. NOG’s year-end 2021 proforma PV-10 inclusive of Veritas was $3.8 billion. The reserves are calculated under SEC guidelines relating to both commodity price assumptions and a maximum five year drill schedule. The SEC Pricing used as of December 31, 2021, after adjustment to reflect applicable transportation and quality differentials, was $62.25 per barrel of oil and $3.37 per Mcf of natural gas, significantly below current price levels. See “Non-GAAP Financial Measures” below regarding PV-10 value.

LIQUIDITY, CAPITAL RESOURCES, AND RECENT ACQUISITIONS

As of December 31, 2021, NOG had $9.5 million in cash and $55.0 million of borrowings outstanding on its revolving credit facility. NOG had total liquidity of $704.5 million as of December 31, 2021, consisting of cash and committed borrowing availability under the revolving credit facility. Additionally, NOG had $40.7 million in an escrow account as of December 31, 2021, as a deposit on the Veritas acquisition that was signed in November 2021 and closed in January 2022.

In November 2021, NOG executed both common equity and senior debt offerings. NOG issued 11.0 million shares of common equity for gross proceeds of $220.0 million. NOG also raised $213.5 million of gross proceeds, plus accrued interest, by issuing $200 million of principal amount of 8.125% Senior Unsecured Notes due 2028 at 106.75% of par value. With the net proceeds from these transactions, NOG retired debt under its existing revolving credit facility and, ultimately, closed on the Comstock and Veritas acquisitions described below.

On November 16, 2021, NOG paid the adjusted cash purchase price of $154.0 million to close its Comstock acquisition, funded by the $7.7 million deposit previously paid, cash on hand and borrowings on its revolving credit facility. The cash consideration included typical closing adjustments, and remains subject to final post-closing settlement between NOG and the seller.

On January 27, 2022, NOG paid the adjusted cash purchase price of $419.4 million to close its Veritas acquisition, funded by the $40.7 million deposit previously paid, cash on hand and borrowings on its revolving credit facility. The cash consideration included typical closing adjustments, and remains subject to final post-closing settlement between NOG and the seller. NOG also issued approximately 1.9 million common stock warrants to Veritas as additional purchase consideration.

STOCKHOLDER RETURNS

On November 11, 2021, NOG’s Board of Directors declared a regular quarterly cash dividend for NOG’s common stock of $0.08 per share for stockholders of record as of December 30, 2021, which was paid on January 31, 2022. This represented a 78% increase from the prior quarter.

On February 1, 2022, NOG’s Board of Directors declared a regular quarterly cash dividend for NOG’s common stock of $0.14 per share for stockholders of record as of March 30, 2022, which will be paid on April 29, 2022. This represented a 75% increase from the fourth quarter.

In February 2022, NOG repurchased $7.2 million of liquidation preference value of its 6.500% Series A Perpetual Cumulative Convertible Preferred Stock from three separate holders. These repurchases are expected to reduce NOG’s annual preferred dividend payments by approximately $467,000 and additionally reduce NOG’s diluted common stock share count by approximately 316,000 shares.

2022 ANNUAL GUIDANCE

NOG anticipates approximately 70,000 - 75,000 Boe per day of production in 2022, an increase of approximately 35% at the midpoint from 2021 levels. NOG currently expects total capital spending in the range of $350 - $415 million for 2022. NOG expects approximately 45% of its 2022 budget to be spent on the Williston, 45% on the Permian, and the remaining 10% on the Appalachian and other.

 

2022 Guidance

Annual Production (Boe per day)

70,000 - 75,000

Oil as a Percentage of Sales Volumes

59.5 - 61.5%

Total Capital Expenditures ($ in millions)

$350 - $415

Net Wells Added to Production

48 - 52

Operating Expenses and Differentials

 

Production Expenses (per Boe)

$8.50 - $8.85

Production Taxes (as a percentage of Oil & Gas Sales)

8.0 - 9.0%

Average Differential to NYMEX WTI (per Bbl)

($5.75) - ($6.25)

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

100% - 110%

General and Administrative Expense (per Boe):

 

Non-Cash

$0.20 - $0.30

Cash (excluding transaction costs on non-budgeted acquisitions)

$0.80 - $0.85

PROVED RESERVES AS OF DECEMBER 31, 2021

 

SEC Pricing Proved Reserves(1)

 

Reserve Volumes

 

PV-10(3)

Reserve Category

Oil
(MBbls)

 

Natural Gas
(MMcf)

 

Total
(MBoe)(2)

 

%

 

Amount
(In
thousands)

 

%

PDP Properties

84,920

 

491,852

 

166,895

 

58

 

 

$

2,328,766

 

70

PDNP Properties

2,585

 

6,706

 

3,703

 

1

 

 

 

71,209

 

2

PUD Properties

43,890

 

439,165

 

117,084

 

41

 

 

 

941,114

 

28

Total

131,395

 

937,723

 

287,682

 

100

 

$

3,341,089

 

100

________________

(1)

The SEC Pricing Proved Reserves table above values oil and natural gas reserve quantities and related discounted future net cash flows as of December 31, 2021 based on average prices of $66.56 per barrel of oil and $3.60 per MMbtu of natural gas. Under SEC guidelines, these prices represent the average prices per barrel of oil and per MMbtu of natural gas at the beginning of each month in the 12-month period prior to the end of the reporting period. The average resulting price used as of December 31, 2021, after adjustment to reflect applicable transportation and quality differentials, was $62.25 per barrel of oil and $3.37 per Mcf of natural gas.

(2)

Boe are computed based on a conversion ratio of one Boe for each barrel of oil and one Boe for every 6,000 cubic feet (i.e., 6 Mcf) of natural gas.

(3)

Pre-tax PV10%, or “PV-10,” may be considered a non-GAAP financial measure as defined by the SEC. See “Non-GAAP Financial Measures” below.

FOURTH QUARTER 2021 RESULTS

The following table sets forth selected operating and financial data for the periods indicated.

 

Three Months Ended
December 31,

 

2021

 

2020

 

% Change

Net Production:

 

 

 

 

 

Oil (Bbl)

 

3,492,556

 

 

 

2,508,618

 

 

39

%

Natural Gas and NGLs (Mcf)

 

14,458,119

 

 

 

4,675,896

 

 

209

%

Total (Boe)

 

5,902,243

 

 

 

3,287,934

 

 

80

%

 

 

 

 

 

 

Average Daily Production:

 

 

 

 

 

Oil (Bbl)

 

37,963

 

 

 

27,268

 

 

39

%

Natural Gas and NGL (Mcf)

 

157,153

 

 

 

50,825

 

 

209

%

Total (Boe)

 

64,155

 

 

 

35,738

 

 

80

%

 

 

 

 

 

 

Average Sales Prices:

 

 

 

 

 

Oil (per Bbl)

$

71.67

 

 

$

35.69

 

 

101

%

Effect of Gain on Settled Derivatives on Average Price (per Bbl)

 

(15.71

)

 

 

14.51

 

 

 

Oil Net of Settled Derivatives (per Bbl)

 

55.96

 

 

 

50.20

 

 

11

%

 

 

 

 

 

 

Natural Gas and NGLs (per Mcf)

 

5.68

 

 

 

2.13

 

 

167

%

Effect of Gain (Loss) on Settled Derivatives on Average Price (per Mcf)

 

(1.33

)

 

 

(0.20

)

 

 

Natural Gas Net of Settled Derivatives (per Mcf)

 

4.35

 

 

 

1.93

 

 

125

%

 

 

 

 

 

 

Realized Price on a Boe Basis Excluding Settled Commodity Derivatives

 

56.31

 

 

 

30.27

 

 

86

%

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

 

(12.60

)

 

 

10.79

 

 

 

Realized Price on a Boe Basis Including Settled Commodity Derivatives

 

43.72

 

 

 

41.06

 

 

6

%

 

 

 

 

 

 

 

 

 

 

 

 

Costs and Expenses (per Boe):

 

 

 

 

 

Production Expenses

$

8.57

 

 

$

8.58

 

 

%

Production Taxes

 

4.25

 

 

 

2.75

 

 

55

%

General and Administrative Expense

 

1.77

 

 

 

1.33

 

 

33

%

Depletion, Depreciation, Amortization and Accretion

 

7.25

 

 

 

9.97

 

 

(27

)%

 

 

 

 

 

 

Net Producing Wells at Period End

 

680.8

 

 

 

475.1

 

 

43

%

FULL YEAR 2021 RESULTS

The following table sets forth selected operating and financial data for the periods indicated.

 

Years Ended December 31,

 

2021

 

2020

 

% Change

Net Production:

 

 

 

 

 

Oil (Bbl)

 

12,288,358

 

 

 

9,361,138

 

31

%

Natural Gas and NGLs (Mcf)

 

44,073,941

 

 

 

16,473,287

 

168

%

Total (Boe)

 

19,634,015

 

 

 

12,106,686

 

62

%

 

 

 

 

 

 

Average Daily Production:

 

 

 

 

 

Oil (Bbl)

 

33,667

 

 

 

25,577

 

32

%

Natural Gas and NGL (Mcf)

 

120,751

 

 

 

45,009

 

168

%

Total (Boe)

 

53,792

 

 

 

33,078

 

63

%

 

 

 

 

 

 

Average Sales Prices:

 

 

 

 

 

Oil (per Bbl)

$

62.94

 

 

$

32.61

 

93

%

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

 

(10.17

)

 

 

20.08

 

 

Oil Net of Settled Oil Derivatives (per Bbl)

 

52.77

 

 

 

52.69

 

%

 

 

 

 

 

 

Natural Gas and NGLs (per Mcf)

 

4.57

 

 

 

1.14

 

301

%

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

 

(0.92

)

 

 

0.02

 

 

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

 

3.65

 

 

 

1.16

 

215

%

 

 

 

 

 

 

Realized Price on a Boe Basis Excluding Settled Commodity Derivatives

 

49.66

 

 

 

26.77

 

86

%

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

 

(8.45

)

 

 

15.55

 

 

Realized Price on a Boe Basis Including Settled Commodity Derivatives

 

41.21

 

 

 

42.32

 

(9

)%

 

 

 

 

 

 

Costs and Expenses (per Boe):

 

 

 

 

 

Production Expenses

$

8.70

 

 

$

9.61

 

(9

)%

Production Taxes

 

3.92

 

 

 

2.46

 

59

%

General and Administrative Expenses

 

1.55

 

 

 

1.53

 

1

%

Depletion, Depreciation, Amortization and Accretion

 

7.17

 

 

 

13.39

 

(46

)%

 

 

 

 

 

 

Net Producing Wells at Period-End

 

680.8

 

 

 

475.1

 

43

%

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 swap contracts scheduled to settle after December 31, 2021.

Crude Oil Commodity Derivative Swaps

Contract Period

 

Volume (Bbls)

 

Volume (Bbls/Day)

 

Weighted Average Price
(per Bbl)

2022:

 

 

 

 

 

 

Q1

 

2,690,980

 

29,900

 

$60.68

Q2

 

2,598,000

 

28,549

 

$60.80

Q3

 

2,559,900

 

27,825

 

$60.02

Q4

 

2,398,900

 

26,075

 

$59.54

2023(1):

 

 

 

 

 

 

Q1

 

1,131,750

 

12,575

 

$64.07

Q2

 

923,650

 

10,150

 

$65.38

Q3

 

581,900

 

6,325

 

$66.96

Q4

 

572,700

 

6,225

 

$66.57

2024(1):

 

 

 

 

 

 

Q1

 

136,500

 

1,500

 

$64.65

Q2

 

136,500

 

1,500

 

$64.19

Q3

 

138,000

 

1,500

 

$63.51

Q4

 

138,000

 

1,500

 

$62.96

_____________

(1)

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. For additional information, see Note 12 to our financial statements included in our Form 10-K filed with the SEC for the year ended December 31, 2021.

The following table summarizes NOG’s open natural gas commodity derivative swap contracts scheduled to settle after December 31, 2021.

Natural Gas Commodity Derivative Swaps

Contract Period

 

Gas (MMBTU)

 

Volume (MMBTU/Day)

 

Weighted Average Price
(per Mcf)

 

 

 

 

 

 

 

2022(1):

 

 

 

 

 

 

Q1

 

6,814,132

 

75,713

 

$3.25

Q2

 

8,715,000

 

95,769

 

$3.11

Q3

 

9,660,000

 

105,000

 

$3.18

Q4

 

8,880,000

 

96,522

 

$3.48

2023:

 

 

 

 

 

 

Q1

 

5,690,000

 

63,222

 

$3.78

Q2

 

1,840,000

 

20,220

 

$3.34

Q3

 

1,840,000

 

20,000

 

$3.43

Q4

 

1,437,000

 

15,620

 

$3.50

2024:

 

 

 

 

 

 

Q1

 

630,000

 

6,923

 

$3.22

Q2

 

644,000

 

7,077

 

$3.22

Q3

 

644,000

 

7,000

 

$3.22

Q4

 

427,000

 

4,641

 

$3.22

_____________

(1)

This table does not include volumes subject to collars. This table also does not include basis swaps. For additional information, see Note 12 to our financial statements included in our Form 10-K filed with the SEC for the year ended December 31, 2021.

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
December 31,

 

Twelve Months Ended
December 31,

(In thousands)

2021

 

2020

 

2021

 

2020

Cash Received (Paid) on Derivatives

$

(74,353

)

 

$

35,482

 

 

$

(165,823

)

 

$

188,234

Non-Cash Gain (Loss) on Derivatives

 

61,170

 

 

 

(84,923

)

 

 

(312,370

)

 

 

39,878

Gain (Loss) on Derivative Instruments, Net

$

(13,183

)

 

$

(49,441

)

 

$

(478,193

)

 

$

228,112

CAPITAL EXPENDITURES & DRILLING ACTIVITY

(In millions, except for net well data)

 

Three Months Ended
December 31, 2021

 

Year Ended December 31,
2021

Capital Expenditures Incurred:

 

 

 

 

Organic Drilling and Development Capital Expenditures

 

$49.1

 

$161.8

Ground Game Drilling and Development Capital Expenditures

 

$26.7

 

$50.8

Ground Game Acquisition Capital Expenditures

 

$8.8

 

$37.9

Other

 

$(0.9)

 

$2.9

Non-Budgeted Acquisitions

 

$146.8

 

$402.8

 

 

 

 

 

Net Wells Added to Production

 

12.1

 

35.8

 

 

 

 

 

Net Producing Wells (Period-End)

 

 

 

680.8

 

 

 

 

 

Net Wells in Process (Period-End)

 

 

 

42.5

Change in Wells in Process over Prior Period

 

(0.6)

 

14.5

 

 

 

 

 

Weighted Average AFE for Wells Elected to

 

$7.1

 

$6.9

Capitalized costs are a function of the number of net well additions during the period, and changes in wells in process from the prior year-end. Capital expenditures attributable to the increase of 14.5 in net wells in process during the year ended December 31, 2021 are reflected in the annual amounts incurred for drilling and development capital expenditures.

ACREAGE

As of December 31, 2021, NOG controlled leasehold of approximately 245,431 net acres in the Williston, Permian and Appalachian Basins in the United States, and approximately 88% of this total acreage position was developed, held by production, or held by operations.

FOURTH QUARTER 2021 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, February 25, 2022 at 8:00 a.m. Central Time.

Those wishing to listen to the conference call may do so via the company’s website, www.northernoil.com, or by phone as follows:

Website: https://themediaframe.com/mediaframe/webcast.html?webcastid=EctAX0qH
Dial-In Number: (866) 373-3407 (US/Canada) and (412) 902-1037 (International)
Conference ID: 13726752 - Fourth Quarter 2021 Earnings Call
Replay Dial-In Number: (877) 660-6853 (US/Canada) and (201) 612-7415 (International)
Replay Access Code: 13726752 - Replay will be available through March 4, 2022

ABOUT NORTHERN OIL AND GAS

NOG 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 NOG 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 NOG’s financial position, operating and financial performance, business strategy, dividend plans and practices, 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 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 properties and properties pending acquisition; NOG’s ability to acquire additional development opportunities; potential or pending acquisition transactions; NOG’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 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; disruptions to NOG’s business due to acquisitions and other significant transactions; infrastructure constraints and related factors affecting NOG’s properties; cost inflation or supply chain disruption; 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 NOG conducts business; changes in the interest rate environment, legislation or regulatory requirements; conditions of the securities markets; NOG’s ability to raise or access capital; cyber-related risks; 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 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 more recent Annual Report on Form 10-K 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. NOG does not undertake any duty to update or revise any forward-looking statements, except as may be required by the federal securities laws.

NORTHERN OIL AND GAS, INC.

STATEMENTS OF OPERATIONS

 

 

Three Months Ended
December 31,

 

Year Ended
December 31,

(In thousands, except share and per share data)

2021

 

2020

 

2021

 

2020

Revenues

 

 

 

 

 

 

 

Oil and Natural Gas Sales

$

332,372

 

 

$

99,511

 

 

$

975,089

 

 

$

324,052

 

Gain (Loss) on Derivative Instruments, Net

 

(13,183

)

 

 

(49,441

)

 

 

(478,193

)

 

 

228,141

 

Other Revenue

 

1

 

 

 

4

 

 

 

3

 

 

 

17

 

Total Revenues

 

319,190

 

 

 

50,074

 

 

 

496,899

 

 

 

552,210

 

 

 

 

 

 

 

 

 

Operating Expenses

 

 

 

 

 

 

 

Production Expenses

 

50,571

 

 

 

28,204

 

 

 

170,817

 

 

 

116,336

 

Production Taxes

 

25,056

 

 

 

9,034

 

 

 

76,954

 

 

 

29,783

 

General and Administrative Expenses

 

10,463

 

 

 

4,361

 

 

 

30,341

 

 

 

18,546

 

Depletion, Depreciation, Amortization and Accretion

 

42,814

 

 

 

32,769

 

 

 

140,828

 

 

 

162,120

 

Impairment Expense

 

 

 

 

104,463

 

 

 

 

 

 

1,066,668

 

Total Operating Expenses

 

128,904

 

 

 

121,539

 

 

 

418,940

 

 

 

1,393,453

 

 

 

 

 

 

 

 

 

Income (Loss) From Operations

 

190,286

 

 

 

(62,527

)

 

 

77,959

 

 

 

(841,243

)

 

 

 

 

 

 

 

 

Other Income (Expense)

 

 

 

 

 

 

 

Interest Expense, Net of Capitalization

 

(15,899

)

 

 

(13,358

)

 

 

(59,020

)

 

 

(58,503

)

Write-off of Debt Issuance Costs

 

 

 

 

 

 

 

 

 

 

(1,543

)

Gain (Loss) on Unsettled Interest Rate Derivatives

 

589

 

 

 

186

 

 

 

1,043

 

 

 

(1,019

)

Loss on the Extinguishment of Debt

 

 

 

 

 

 

 

(13,087

)

 

 

(3,718

)

Contingent Consideration Loss

 

 

 

 

(169

)

 

 

(292

)

 

 

(169

)

Other Income (Expense)

 

(16

)

 

 

(25

)

 

 

(9

)

 

 

(12

)

Total Other Income (Expense)

 

(15,326

)

 

 

(13,366

)

 

 

(71,365

)

 

 

(64,964

)

 

 

 

 

 

 

 

 

Income (Loss) Before Income Taxes

 

174,960

 

 

 

(107,939

)

 

 

6,594

 

 

 

(906,207

)

 

 

 

 

 

 

 

 

Income Tax Expense (Benefit)

 

233

 

 

 

 

 

 

233

 

 

 

(166

)

 

 

 

 

 

 

 

 

Net Income (Loss)

 

174,727

 

 

 

(107,939

)

 

 

6,361

 

 

$

(906,041

)

 

 

 

 

 

 

 

 

Cumulative Preferred Stock Dividend

 

(3,605

)

 

 

(1,029

)

 

 

(14,761

)

 

 

(15,266

)

 

 

 

 

 

 

 

 

Net Income (Loss) Attributable to Common Shareholders

$

171,122

 

 

$

(143,152

)

 

$

(8,400

)

 

$

(921,307

)

 

 

 

 

 

 

 

 

Net Income (Loss) Per Common Share – Basic

$

2.42

 

 

$

(3.14

)

 

$

(0.13

)

 

$

(21.55

)

Net Income (Loss) Per Common Share – Diluted

$

2.13

 

 

$

(3.14

)

 

$

(0.13

)

 

$

(21.55

)

Weighted Average Shares Outstanding – Basic

 

70,660,131

 

 

 

45,520,634

 

 

 

62,989,543

 

 

 

42,744,639

 

Weighted Average Shares Outstanding – Diluted

 

81,849,627

 

 

 

45,520,634

 

 

 

62,989,543

 

 

 

42,744,639

 

_________

The accompanying notes are an integral part of these financial statements.

NORTHERN OIL AND GAS, INC.

BALANCE SHEETS

 

(In thousands, except par value and share data)

December 31, 2021

 

December 31, 2020

Assets

 

 

 

Current Assets:

 

 

 

Cash and Cash Equivalents

$

9,519

 

 

$

1,428

 

Accounts Receivable, Net

 

193,554

 

 

 

71,015

 

Advances to Operators

 

6,319

 

 

 

476

 

Prepaid Expenses and Other

 

3,417

 

 

 

1,420

 

Derivative Instruments

 

2,519

 

 

 

51,290

 

Total Current Assets

 

215,328

 

 

 

125,629

 

 

 

 

 

Property and Equipment:

 

 

 

Oil and Natural Gas Properties, Full Cost Method of Accounting

 

 

 

Proved

 

5,034,769

 

 

 

4,393,533

 

Unproved

 

24,998

 

 

 

10,031

 

Other Property and Equipment

 

2,616

 

 

 

2,451

 

Total Property and Equipment

 

5,062,383

 

 

 

4,406,015

 

Less – Accumulated Depreciation, Depletion and Impairment

 

(3,809,041

)

 

 

(3,670,811

)

Total Property and Equipment, Net

 

1,253,342

 

 

 

735,204

 

 

 

 

 

Derivative Instruments

 

1,863

 

 

 

111

 

Acquisition Deposit

 

40,650

 

 

 

 

Other Noncurrent Assets, Net

 

11,683

 

 

 

11,145

 

 

 

 

 

Total Assets

$

1,522,866

 

 

$

872,089

 

 

 

 

 

Liabilities and Stockholders' Equity

 

 

 

Current Liabilities:

 

 

 

Accounts Payable

$

65,464

 

 

$

35,803

 

Accrued Liabilities

 

105,590

 

 

 

68,673

 

Accrued Interest

 

20,498

 

 

 

8,341

 

Derivative Instruments

 

134,283

 

 

 

3,078

 

Contingent Consideration

 

 

 

 

493

 

Other Current Liabilities

 

1,722

 

 

 

1,087

 

Current Portion of Long-term Debt

 

 

 

 

65,000

 

Total Current Liabilities

 

327,557

 

 

 

182,475

 

 

 

 

 

Long-term Debt, Net

 

803,437

 

 

 

879,843

 

Derivative Instruments

 

147,762

 

 

 

14,659

 

Asset Retirement Obligations

 

25,865

 

 

 

18,366

 

Other Noncurrent Liabilities

 

3,110

 

 

 

50

 

 

 

 

 

Total Liabilities

 

1,307,731

 

 

$

1,095,393

 

 

 

 

 

Commitments and Contingencies

 

 

 

 

 

 

 

Stockholders' Equity (Deficit)

 

 

 

Preferred Stock, Par Value $0.001 ; 5,000,000 Authorized

2,218,732 Shares Outstanding at 12/31/2021

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

 

2

 

 

 

2

 

Common Stock, Par Value $0.001; 135,000,000 Authorized;

77,341,921 Shares Outstanding at 12/31/2021

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

 

479

 

 

 

448

 

Additional Paid-In Capital

 

1,988,649

 

 

 

1,556,602

 

Retained Deficit

 

(1,773,996

)

 

 

(1,780,356

)

Total Stockholders’ Equity (Deficit)

 

215,135

 

 

 

(223,304

)

Total Liabilities and Stockholders' Equity (Deficit)

$

1,522,866

 

 

$

872,089

 

___________

The accompanying notes are an integral part of these financial statements.

Non-GAAP Financial Measures

Adjusted Net Income, Adjusted EBITDA and Free Cash Flow are non-GAAP measures. Net income (loss) is the most directly comparable GAAP measure for both Adjusted Net Income and Adjusted EBITDA. Cash flows from operations is the most directly comparable GAAP measure for Free Cash Flow. NOG defines Adjusted Net Income (Loss) as net income (loss) excluding (i) unrealized (gain) loss on unsettled commodity derivatives, net of tax, (ii) financing expense, net of tax, (iii) impairment of other current assets, net of tax, (iv) write-off of debt issuance costs, net of tax, (v) loss on the extinguishment of debt, net of tax, (vi) debt exchange derivative (gain) loss, net of tax, (vii) contingent consideration loss, net of tax, (viii) acquisition transaction costs, net of tax, (ix) impairment expense, net of tax, and (x) gain (loss) on unsettled interest rate derivatives, net of tax. NOG defines Adjusted EBITDA as net income (loss) before (i) interest expense, (ii) income taxes, (iii) depreciation, depletion, amortization, and accretion, (iv) (gain) loss on unsettled commodity derivatives, (v) non-cash stock based compensation expense, (vi) write-off of debt issuance costs, (vii) loss on the extinguishment of debt, (viii) impairment of other current assets, (ix) debt exchange derivative (gain) loss, (x) contingent consideration loss, (xi) financing expense, (xii) impairment expense, (xiii) (gain) loss on unsettled interest rate derivatives, and (xiv) cash severance expense. 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 (ii) preferred stock dividends. A reconciliation of each of these measures to the most directly comparable GAAP measure is included below.

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. Specifically, management believes the non-GAAP financial measures included herein provide useful information to both management and investors by excluding certain items that management believes are not indicative of NOG’s core operating results. 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.

Pre-tax PV10%, or PV-10, may be considered a non-GAAP financial measure as defined by the SEC and is derived from the standardized measure of discounted future net cash flows, which is the most directly comparable GAAP measure for proved reserves calculated using SEC pricing. PV-10 is a computation of the Standardized Measure of discounted future net cash flows on a pre-tax basis. PV-10 is equal to the Standardized Measure of discounted future net cash flows at the applicable date, before deducting future income taxes, discounted at 10 percent. Management believes that the presentation of PV-10 is relevant and useful to investors because it presents the discounted future net cash flows attributable to NOG’s estimated net proved reserves prior to taking into account future corporate income taxes, and it is a useful measure for evaluating the relative monetary significance of NOG’s oil and natural gas properties. Further, investors may utilize the measure as a basis for comparison of the relative size and value of NOG’s reserves to other companies. Management uses this measure when assessing the potential return on investment related to NOG’s oil and natural gas properties. PV-10, however, is not a substitute for the Standardized Measure of discounted future net cash flows. A reconciliation of PV-10 to the Standardized Measure is included below.

Reconciliation of Adjusted Net Income

 

Three Months Ended
December 31,

 

Years Ended
December 31,

(In thousands, except share and per share data)

2021

 

2020

 

2021

 

2020

Income (Loss) Before Taxes

$

174,727

 

 

$

(142,123

)

 

$

6,361

 

 

$

(906,041

)

Add:

 

 

 

 

 

 

 

Impact of Selected Items:

 

 

 

 

 

 

 

(Gain) Loss on Unsettled Commodity Derivatives

 

(61,170

)

 

 

84,923

 

 

 

312,370

 

 

 

(39,878

)

Impairment Expense

 

 

 

 

104,463

 

 

 

 

 

 

1,066,668

 

Write-off of Debt Issuance Costs

 

 

 

 

 

 

 

 

 

 

1,543

 

Loss on the Extinguishment of Debt

 

 

 

 

 

 

 

13,087

 

 

 

3,718

 

(Gain) Loss on Unsettled Interest Rate Derivatives

 

(589

)

 

 

(186

)

 

 

(1,043

)

 

 

1,019

 

Contingent Consideration Loss

 

 

 

 

169

 

 

 

292

 

 

 

169

 

Acquisition Transaction Costs

 

1,986

 

 

 

 

 

 

8,190

 

 

 

 

Adjusted Income Before Adjusted Income Tax Expense

 

115,188

 

 

 

47,246

 

 

 

339,491

 

 

 

127,032

 

 

 

 

 

 

 

 

 

Adjusted Income Tax Expense

 

(28,221

)

 

 

(11,575

)

 

 

(83,175

)

 

 

(31,123

)

 

 

 

 

 

 

 

 

Adjusted Net Income (non-GAAP)

$

86,967

 

 

$

35,670

 

 

$

256,316

 

 

$

95,910

 

 

 

 

 

 

 

 

 

Weighted Average Shares Outstanding – Basic

 

70,660,131

 

 

 

45,520,634

 

 

 

62,989,543

 

 

 

42,744,639

 

Weighted Average Shares Outstanding – Diluted

 

81,849,627

 

 

 

55,381,388

 

 

 

73,366,750

 

 

 

52,659,217

 

 

 

 

 

 

 

 

 

Income (Loss) Before Taxes Per Common Share – Basic

$

2.48

 

 

$

(3.12

)

 

$

0.10

 

 

$

(21.20

)

Add:

 

 

 

 

 

 

 

Impact of Selected Items

 

(0.85

)

 

 

4.16

 

 

 

5.28

 

 

 

24.17

 

Impact of Income Tax

 

(0.40

)

 

 

(0.26

)

 

 

(1.31

)

 

 

(0.73

)

Adjusted Net Income Per Common Share – Basic

$

1.23

 

 

$

0.78

 

 

$

4.07

 

 

$

2.24

 

 

 

 

 

 

 

 

 

Income (Loss) Before Taxes Per Common Share – Diluted

$

2.14

 

 

$

(2.57

)

 

$

0.09

 

 

$

(17.21

)

Add:

 

 

 

 

 

 

 

Impact of Selected Items

 

(0.73

)

 

 

3.42

 

 

 

4.54

 

 

 

19.62

 

Impact of Income Tax

 

(0.35

)

 

 

(0.21

)

 

 

(1.14

)

 

 

(0.59

)

Adjusted Net Income Per Common Share – Diluted

$

1.06

 

 

$

0.64

 

 

$

3.49

 

 

$

1.82

 

_______________

(1)

For the 2021 columns, this represents a tax impact using an estimated tax rate of 24.5% for the three and twelve months ended December 31, 2021. For the 2020 columns, this represents a tax impact using an estimated tax rate of 24.5% for the three and twelve months ended December 31, 2020.

Reconciliation of Adjusted EBITDA

 

Three Months Ended
December 31,

 

Year Ended
December 31,

(In thousands)

2021

 

2020

 

2021

 

2020

Net Income (Loss)

$

174,727

 

 

$

(142,123

)

 

$

6,361

 

 

$

(906,041

)

Add:

 

 

 

 

 

 

 

Interest Expense

 

15,899

 

 

 

13,358

 

 

 

59,020

 

 

 

58,503

 

Income Tax Provision (Benefit)

 

233

 

 

 

 

 

 

233

 

 

 

(166

)

Depreciation, Depletion, Amortization and Accretion

 

42,814

 

 

 

32,769

 

 

 

140,828

 

 

 

162,120

 

Non-Cash Stock-Based Compensation

 

1,374

 

 

 

936

 

 

 

3,621

 

 

 

4,119

 

Write-off of Debt Issuance Costs

 

 

 

 

 

 

 

 

 

 

1,543

 

Loss on the Extinguishment of Debt

 

 

 

 

 

 

 

13,087

 

 

 

3,718

 

Contingent Consideration Loss

 

 

 

 

169

 

 

 

292

 

 

 

169

 

Acquisition Transaction Costs

 

1,986

 

 

 

 

 

 

8,190

 

 

 

 

(Gain) Loss on Unsettled Interest Rate Derivatives

 

(589

)

 

 

(186

)

 

 

1,019

 

 

 

1,019

 

(Gain) Loss on Unsettled Commodity Derivatives

 

(61,170

)

 

 

84,923

 

 

 

(39,878

)

 

 

(39,878

)

Impairment Expense

 

 

 

 

104,463

 

 

 

 

 

 

1,066,668

 

Adjusted EBITDA

$

175,275

 

 

$

94,309

 

 

$

542,959

 

 

$

351,774

 

Reconciliation of Free Cash Flow

 

Three Months Ended
December 31,

(In thousands)

2021

Net Cash Provided by Operating Activities

$

133,102

 

Exclude: Changes in Working Capital and Other Items

 

24,907

 

Less: Capital Expenditures (1)

 

(83,671

)

Less: Series A Preferred Dividends

 

(3,605

)

Free Cash Flow

$

70,732

 

_______________

(1)

Capital expenditures are calculated as follows:

 

Three Months Ended
December 31,

(In thousands)

2021

Cash Paid for Capital Expenditures

$

228,751

 

Less: Non-Budgeted Acquisitions

 

(146,753

)

Plus: Change in Accrued Capital Expenditures and Other

 

1,673

 

Capital Expenditures

$

83,671

 

Reconciliation of PV-10

The following table reconciles the pre-tax PV10% value of our SEC Pricing Proved Reserves as of December 31, 2021 to the Standardized Measure of discounted future net cash flows.

SEC Pricing Proved Reserves

(In thousands)

Standardized Measure Reconciliation

Pre-Tax Present Value of Estimated Future Net Revenues (Pre-Tax PV10%)

$3,341,089

Future Income Taxes, Discounted at 10%(1)

(450,980)

Standardized Measure of Discounted Future Net Cash Flows

$2,890,109

(1)

The expected tax benefits to be realized from utilization of the net operating loss and tax credit carryforwards are used in the computation of future income tax cash flows. As a result of available net operating loss carryforwards and the remaining tax basis of our assets at December 31, 2021, our future income taxes were significantly reduced.

 

Mike Kelly, CFA
Chief Strategy Officer
952-476-9800
ir@northernoil.com

Source: Northern Oil and Gas, Inc.