Northern Oil and Gas, Inc. Announces Fourth Quarter and Full Year 2019 Results

Northern Oil and Gas, Inc. (NYSE American: NOG) (“Northern”) today announced the company’s fourth quarter and full year 2019 results.

MANAGEMENT COMMENTS

“2019 was another transformational year in terms of scaling our business and the consummation of our plan driven to reduce interest expense and increase capital flexibility,” commented Nick O’Grady, Northern’s Chief Executive Officer. “We enter into 2020 already delivering on those goals regardless of current depressed commodity prices. Continued weak commodity pricing will create even more opportunity for Northern, given our strong oil price hedge book, balance sheet, and free cash flow profile.”

“As we move into 2020, we will adhere to our strict hurdle rates necessary to deploy capital,” commented Adam Dirlam, Northern’s Chief Operating Officer. “While the current macro environment is undoubtedly challenging, we are optimistic that it will also provide opportunities specific to Northern’s business model as a minority working interest owner to invest capital into value accretive projects for the benefit of our shareholders.”

FOURTH QUARTER AND FULL YEAR FINANCIAL RESULTS

FINANCIAL RESULTS

Fourth quarter net loss was $107.9 million or $0.27 per diluted share. Fourth quarter Adjusted Net Income was $21.5 million or $0.05 per diluted share, down from $94.8 million or $0.25 per diluted share in the prior year. Adjusted EBITDA in the fourth quarter was $114.2 million compared to $124.9 million in the fourth quarter of 2018, driven by 14% lower average realized prices and higher lease operating expense, offset partially by a 21% increase in production volumes.

Full year 2019 net loss was $76.3 million or $0.20 per diluted share. Full year 2019 Adjusted Net Income was $120.9 million or $0.31 per diluted share, down from $140.7 million or $0.59 per diluted share in 2018. Full year 2019 Adjusted EBITDA was $454.2 million compared to $349.3 million in 2018. Average realized prices were down approximately 9% year over year, offset by a 51% increase in production volumes. (See “Non-GAAP Financial Measures” below.)

PRODUCTION

Fourth quarter production increased 21% from the prior year and 8% from the prior quarter to 4.0 million Boe or 43,941 Boe per day, toward the middle of the guidance range. Shut-ins and curtailments, which Northern had forecasted would be approximately 2,400 barrels per day in the fourth quarter, were significantly higher at approximately 3,650 barrels per day. Strong fourth quarter well performance largely offset the negative impact from shut-ins. Full year 2019 production increased 51% from 2018 to 14.1 million Boe or 38,604 Boe per day.

PRICING

During the fourth quarter, NYMEX West Texas Intermediate (“WTI”) crude oil averaged $56.85 per Bbl, and NYMEX natural gas at Henry Hub averaged $2.40 per million cubic feet (“Mcf”). Northern’s unhedged net realized oil price in the fourth quarter was $49.20, representing a $7.65 differential to WTI prices. For the year, Northern’s realized oil differential was $6.28 per Bbl, within the stated guidance range. Northern’s fourth quarter unhedged net realized gas price was $0.47 per Mcf, representing approximately 20% realizations compared with Henry Hub pricing. For the year, Northern’s realized gas price was $1.60, which was 63% of the average Henry Hub price.

OPERATING AND G&A COSTS

Unit LOE costs came in slightly higher quarter over quarter, at $8.84 per Boe, which was driven by higher than expected curtailments as well as higher work over expense. Fourth quarter general and administrative (“G&A”) costs totaled $8.1 million, including stock-based compensation. Fourth quarter cash G&A expenses of $4.4 million included $0.8 million of costs related to the departure of Northern’s former chief executive officer. Excluding these amounts, cash G&A costs were approximately $3.6 million, or $0.91 per Boe.

CAPITAL EXPENDITURES

Capital spending for the fourth quarter was $134.6 million, made up of $85.6 million of organic D&C capital and $45.3 million of total acquisition and other spending, inclusive of ground game D&C spending. Northern added 14.6 net wells to production in the fourth quarter, approximately 2.0 net wells above guidance. These additional net well additions came online in late December and had a minimal impact on fourth quarter production. In addition, Northern’s wells in process rose to 25.8 net wells, up over 1.5 wells from the prior quarter. The accelerated development, driven by rising pricing in the fourth quarter, was the primary driver of Northern’s higher than forecast capital spending. On the ground game acquisition front, Northern closed on 14 transactions and committed to an additional nine during the fourth quarter. The majority of fourth quarter commitments that were not closed during 2019 will be closed in the first quarter, after which, Northern expects ground game activity to moderate significantly in 2020 as it moves to cash harvesting.

LIQUIDITY AND CAPITAL RESOURCES

As of December 31, 2019, Northern had $16.1 million in cash and $580.0 million outstanding on its revolving credit facility. Northern had total liquidity of $236.1 million as of December 31, 2019, consisting of cash and $220.0 million of borrowing availability under the revolving credit facility. Total debt net of cash was reduced by $31.9 during the fourth quarter.

As of December 31, 2019, Northern had additional debt outstanding consisting of a $130.0 million Senior Unsecured Note due 2022 and $417.7 million of Senior Secured Notes due 2023.

As previously announced, in the fourth quarter of 2019, Northern completed a consent solicitation, exchange, subscription, and partial tender process. Northern issued 1,500,000 shares of newly issued 6.50% Perpetual Cumulative Convertible Preferred Stock (“Preferred Stock”), and retired $270.8 million of its 8.5% Senior Secured Notes due 2023. Northern also expanded its senior secured revolving credit facility from $425 million to $800 million and extended the term one year to November 2024. The terms of these transactions served, among other things, to improve hedging flexibility, modify certain covenants in the Senior Secured Notes to allow for expanded restricted payments, and substantially reduce interest expense.

Also as previously announced, in January 2020, Northern executed on additional transactions to further reduce debt. In aggregate, Northern retired an additional $76.7 million of Senior Secured Notes for 794,702 shares of Preferred Stock and $2.5 million in cash. The current outstanding principal amount on the Senior Secured Notes as of March 10, 2020 is $341.0 million.

PROVED RESERVES AS OF DECEMBER 31, 2019
		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		71,276			109,503			89,527			55	%		$	1,251,429			69	%
PDNP Properties		5,884			7,342			7,107			4			109,093				6
PUD Properties		54,594			72,473			66,673			41			461,502				25
Total		131,754			189,318			163,307			100	%		$	1,822,024			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, 2019 based on average prices of $55.69 per barrel of oil and $2.58 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, 2019, after adjustment to reflect applicable transportation and quality differentials, was $50.53 per barrel of oil and $2.12 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 and is derived from the standardized measure of discounted future net cash flows, which is the most directly comparable GAAP measure. See “Non-GAAP Financial Measures” below.

2020 GUIDANCE COMMENTARY

Given the rapid deterioration and volatility in commodity prices, Northern has elected to defer its formal 2020 guidance. At the latest, Northern will provide this on its first quarter conference call. Assuming oil prices remain under $40 per Bbl for the majority of 2020, Northern anticipates a total capital budget of approximately $200 million, which represents more than a 55% decrease year-over-year. In this scenario Northern would expect to have more than 75% of its oil production hedged at an average price above $58 per Bbl. This capital plan, and the likely production range associated with it, would likely deliver even higher levels of free cash flow for 2020 than Northern’s previously anticipated $45-50 WTI base plan. Additionally, in an environment where uncertainty prevails and preserving capital is a priority, Northern is delaying its decision on commencing a common stock dividend and will reassess in the second quarter.

FOURTH QUARTER 2019 RESULTS

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

		Three Months Ended December 31,
		2019			2018			% Change
Net Production:
Oil (Bbl)		3,218,885			2,745,700			17	%
Natural Gas and NGLs (Mcf)		4,942,194			3,540,439			40	%
Total (Boe)		4,042,584			3,335,773			21	%
Average Daily Production:
Oil (Bbl)		34,988			29,845			17	%
Natural Gas and NGL (Mcf)		53,720			38,483			40	%
Total (Boe)		43,941			36,258			21	%
Average Sales Prices:
Oil (per Bbl)		$	49.20		$	49.15		—	%
Effect of Gain on Settled Derivatives on Average Price (per Bbl)		2.71			3.80
Oil Net of Settled Derivatives (per Bbl)		51.91			52.95			(2)	%
Natural Gas and NGLs (per Mcf)		0.47			4.97			(91)	%
Realized Price on a Boe Basis Including all Realized Derivative Settlements		41.91			48.86			(14)	%
Costs and Expenses (per Boe):
Production Expenses		$	8.84		$	6.43		37	%
Production Taxes		3.92			4.10			(4)	%
General and Administrative Expense		2.01			1.49			35	%
Depletion, Depreciation, Amortization and Accretion		15.69			14.48			8	%
Net Producing Wells at Period End		458.7			325.1			41	%

FULL YEAR 2019 RESULTS

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

		Years Ended December 31,
		2019			2018				% Change
Net Production:
Oil (Bbl)		11,325,418			7,790,182				45	%
Natural Gas and NGLs (Mcf)		16,590,774			9,224,766				80	%
Total (Boe)		14,090,547			9,327,643				51	%
Average Daily Production:
Oil (Bbl)		31,029			21,343				45	%
Natural Gas and NGL (Mcf)		45,454			25,273				80	%
Total (Boe)		38,604			25,555				51	%
Average Sales Prices:
Oil (per Bbl)		$	50.74		$	57.78			(12	)%
Effect of Gain (Loss) on Settled Derivatives on Average Price (per Bbl)		3.92			(2.94		)
Oil Net of Settled Derivatives (per Bbl)		54.66			54.84				—	%
Natural Gas and NGLs (per Mcf)		1.60			4.74				(66)	%
Realized Price on a Boe Basis Including all Realized Derivative Settlements		45.82			50.50				(9)	%
Costs and Expenses (per Boe):
Production Expenses		$	8.44		$	7.15			18	%
Production Taxes		4.10			4.86				(16)	%
General and Administrative Expenses		1.68			1.56				8	%
Depletion, Depreciation, Amortization and Accretion		14.92			12.84				16	%
Net Producing Wells at Period-End		458.7			325.1				41	%

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 derivative contracts scheduled to settle after December 31, 2019.

Crude Oil Derivative Price Swaps
Contract Period			Volume (Bbls)		Weighted Average Price (per Bbl)
2020:
	1Q		2,664,356		$57.93
	2Q		2,568,278		$57.67
	3Q		2,501,348		$58.47
	4Q		2,372,362		$58.03
2021(1):
	1Q		1,712,550		$56.74
	2Q		1,610,708		$57.24
	3Q		1,418,410		$54.35
	4Q		1,409,506		$54.37
2022(2):
	1Q		453,780		$53.07
	2Q		312,280		$52.30
	3Q		306,576		$52.33
	4Q		300,230		$52.35

_____________
(1)		We have entered into crude oil derivative contracts that give counterparties the option to extend certain current derivative contracts for additional periods. Options covering a notional volume of 0.3 million barrels for 2021 are exercisable on or about December 31, 2020. If the counterparties exercise all such options, the notional volume of our existing crude oil derivative contracts will increase as follows for 2021: (i) for the first quarter of 2021, by 112,500 barrels at a weighted average price of $57.78 per barrel, (ii) for the second quarter of 2021, by 113,750 barrels at a weighted average price of $57.78 per barrel, (iii) for the third quarter of 2021, by 46,000 barrels at a weighted average price of $58.00 per barrel, and (iv) for the fourth quarter of 2021, by 46,000 barrels at a weighted average price of $58.00 per barrel.
(2)		We have entered into crude oil derivative contracts that give counterparties the option to extend certain current derivative contracts for additional periods. Options covering a notional volume of 2.4 million barrels for 2022 are exercisable on or about December 31, 2021. If the counterparties exercise all such options, the notional volume of our existing crude oil derivative contracts will increase as follows for 2022: (i) for the first quarter of 2022, by 830,250 barrels at a weighted average price of $55.01 per barrel, (ii) for the second quarter of 2022, by 839,475 barrels at a weighted average price of $55.01 per barrel, (iii) for the third quarter of 2022, by 365,700 barrels at a weighted average price of $55.15 per barrel, and (iv) for the fourth quarter of 2022, by 365,700 barrels at a weighted average price of $55.15 per barrel.

CAPITAL EXPENDITURES & DRILLING ACTIVITY
		Fourth Quarter 2019		Full Year 2019
Capital Expenditures Incurred:
Organic Drilling and Development Capital Expenditures		$85.6 million		$313.6 million
Ground Game Drilling and Development Capital Expenditures		$40.5 million		$77.5 million
Ground Game Acquisition Capital Expenditures		$4.8 million		$29.8 million
Acquisition of Oil and Natural Gas Properties and Other		$3.7 million		$333.0 million
Net Organic Wells Added to Production		14.6		43.0
Net Producing Wells (Period-End)				458.7
Net Wells in Process (Period-End)				25.8
Increase in Wells in Process over Prior Period		1.5		3.0
Weighted Average AFE for Wells Elected to Year-to-Date		$8.1 million		$8.0 million

Capitalized costs are a function of the number of net well additions during the period as well as changes in wells in process from beginning to end of period. Capital expenditures attributable to the 1.5 and 3.0 increase in net wells in process for the fourth quarter and year, respectively, are reflected in the amounts included for “Drilling and Development Capital Expenditures” in the table above.

ACREAGE

As of December 31, 2019, Northern controlled leasehold of approximately 182,854 net acres targeting the Williston Basin Bakken and Three Forks formations, and approximately 91% of its total acreage position was developed, held by production or held by operations.

FOURTH QUARTER 2019 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 Thursday, March 12, 2020 at 10:00 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:

Dial-In Number: [phone] (US/Canada) and [phone] (International)
Conference ID: 13699346 - Northern Oil and Gas, Inc. Fourth Quarter and Year-End 2019 Earnings Call
Replay Dial-In Number: [phone] (US/Canada) and [phone] (International)
Replay Access Code: 13699346 - Replay will be available through March 19, 2020

UPCOMING CONFERENCE SCHEDULE

32nd Annual Roth Conference
March 15 - 17, 2020, Laguna Niquel, CA. (Now Virtual)

48th Annual Scotia Howard Weil Energy Conference
March 23 - 26, 2020, New Orleans, LA (Now Virtual)

IPAA OGIS New York
April 20-21, 2020, New York, NY

UBS Global Oil and Gas Conference
May 18-20, 2020, Dallas, TX

RBC Global Energy and Power Executive Conference
June 2-3, 2020, New York, NY

ABOUT NORTHERN OIL AND GAS

Northern Oil and Gas, Inc. is an exploration and production company with a core area of focus in the Williston Basin Bakken and Three Forks play in North Dakota and Montana.

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, 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 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 our company’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, Northern’s ability to acquire additional development opportunities, changes in Northern’s reserves estimates or the value thereof, 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, financial or political instability, acts of war or terrorism, and other economic, competitive, governmental, regulatory and technical factors affecting our company’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.

NORTHERN OIL AND GAS, INC.
STATEMENTS OF OPERATIONS
		Three Months Ended December 31,								Years Ended December 31,
(In thousands, except share and per share data)		2019			2018					2019				2018
REVENUES
Oil and Gas Sales		$	160,698			$	152,566			$	601,218			$	493,909
Gain (Loss) on Derivative Instruments, Net		(101,697		)		290,628				(128,837		)		185,006
Other Revenue		11				2				21				9
Total Revenues		59,012				443,196				472,402				678,924
OPERATING EXPENSES
Production Expenses		35,754				21,448				118,899				66,646
Production Taxes		15,827				13,669				57,771				45,302
General and Administrative Expenses		8,118				4,976				23,624				14,568
Depletion, Depreciation, Amortization and Accretion		63,411				48,295				210,201				119,780
Impairment of Other Current Assets		(1,571		)		—				6,398				—
Total Expenses		121,539				88,388				416,893				246,296
INCOME (LOSS) FROM OPERATIONS		(62,527		)		354,808				55,509				432,628
OTHER INCOME (EXPENSE)
Interest Expense, Net of Capitalization		(20,393		)		(20,057		)		(79,229		)		(86,005				)
Loss on the Extinguishment of Debt		(22,762		)		(73,055		)		(23,187		)		(173,430				)
Debt Exchange Derivative Gain (Loss)		—				(13,661		)		1,390				(598				)
Contingent Consideration Loss		(879		)		(28,968		)		(29,512		)		(28,968				)
Financing Expense		(1,447		)		(884		)		(1,447		)		(884				)
Other Income		69				53				158				891
Total Other Income (Expense)		(45,412		)		(136,572		)		(131,827		)		(288,994				)
INCOME (LOSS) BEFORE INCOME TAXES		(107,939		)		218,236				(76,318		)		143,634
INCOME TAX BENEFIT		—				(55		)		—				(55				)
NET INCOME (LOSS)		$	(107,939	)		$	218,291			(76,318		)		$	143,689
Net Income (Loss) Per Common Share – Basic		$	(0.27	)		$	0.58			$	(0.20	)		$	0.61
Net Income (Loss) Per Common Share – Diluted		$	(0.27	)		$	0.58			$	(0.20	)		$	0.61
Weighted Average Shares Outstanding – Basic		402,042,034				378,799,871				387,084,651				236,206,457
Weighted Average Shares Outstanding – Diluted		402,042,034				379,401,105				387,084,651				236,773,911

NORTHERN OIL AND GAS, INC.
BALANCE SHEETS
(In thousands, except par value and share data)		December 31, 2019				December 31, 2018
ASSETS
Current Assets:
Cash and Cash Equivalents		$	16,068			$	2,358
Accounts Receivable, Net		108,274				96,353
Advances to Operators		893				268
Prepaid Expenses and Other		1,964				12,361
Derivative Instruments		5,628				115,870
Income Tax Receivable		210				1,205
Total Current Assets		133,037				228,415
Property and Equipment:
Oil and Natural Gas Properties, Full Cost Method of Accounting
Proved		4,178,605				3,431,428
Unproved		11,047				4,307
Other Property and Equipment		2,157				997
Total Property and Equipment		4,191,809				3,436,732
Less – Accumulated Depreciation, Depletion and Impairment		(2,443,216		)		(2,233,987		)
Total Property and Equipment, Net		1,748,593				1,202,745
Derivative Instruments		8,554				61,843
Deferred Income Taxes		210				420
Other Noncurrent Assets, Net		15,071				10,222
Total Assets		$	1,905,465			$	1,503,645
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Accounts Payable		$	69,395			$	55,015
Accrued Liabilities		110,374				83,237
Accrued Interest		11,615				16,468
Debt Exchange Derivative		—				18,183
Derivative Instruments		11,298				—
Contingent Consideration		—				58,069
Asset Retirement Obligations		795				554
Total Current Liabilities		203,477				231,526
Long-term Debt, Net		1,118,161				830,203
Derivative Instruments		8,079				—
Asset Retirement Obligations		16,759				11,946
Other Noncurrent Liabilities		345				105
TOTAL LIABILITIES		1,346,822				1,073,780
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS’ EQUITY
Preferred Stock, Par Value $.001; 5,000,000 Authorized (12/31/2019 – 1,500,000 Shares Outstanding and 12/31/2018 – No Shares Outstanding)		2				—
Common Stock, Par Value $.001; 675,000,000 Authorized (12/31/2019 – 406,085,183 Shares Outstanding and 12/31/2018 – 378,333,070 Shares Outstanding)		406				378
Additional Paid-In Capital		1,431,438				1,226,371
Retained Deficit		(873,203		)		(796,884		)
Total Stockholders’ Equity		558,643				429,865
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY		$	1,905,465			$	1,503,645

Non-GAAP Financial Measures

Adjusted Net Income and Adjusted EBITDA are non-GAAP measures. Net income (loss) is the most directly comparable GAAP measure for both Adjusted Net Income and Adjusted EBITDA, and tabular reconciliations for these measures are included below. Northern defines Adjusted Net Income (Loss) as net income (loss) excluding (i) unrealized (gain) loss on derivatives, net of tax, (ii) financing expense, net of tax, (iii) impairment of other current assets, net of tax, (iv) loss on the extinguishment of debt, net of tax, (v) debt exchange derivative (gain) loss, net of tax, (vi) contingent consideration loss, net of tax, and (vii) acquisition transaction costs, net of tax. Northern defines Adjusted EBITDA as net income (loss) before (i) interest expense, (ii) income taxes, (iii) depreciation, depletion, amortization, and accretion, (iv) impairment of other current assets, (v) non-cash stock based compensation expense, (vi) loss on the extinguishment of debt, (vii) debt exchange derivative (gain) loss (viii) contingent consideration loss, (ix) cash severance expense, (x) financing expense, and (xi) unrealized (gain) loss on derivatives. 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 Northern’s core operating results. 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.

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 Northern’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 Northern’s oil and natural gas properties. Further, investors may utilize the measure as a basis for comparison of the relative size and value of Northern’s reserves to other companies. Management uses this measure when assessing the potential return on investment related to Northern’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)		2019				2018				2019				2018
Net Income (Loss)		$	(107,937	)		$	218,292			$	(76,318	)		$	143,689
Add:
Impact of Selected Items:
Unrealized (Gain) Loss on Derivatives		110,408				(280,195		)		173,214				(207,892		)
Financing Expense		1,447				884				1,447				884
Impairment of Other Current Assets		(1,571		)		—				6,398				—
Loss on the Extinguishment of Debt		22,762				73,055				23,187				173,430
Debt Exchange Derivative (Gain) Loss		—				13,661				(1,390		)		598
Contingent Consideration Loss		879				28,968				29,512				28,968
Acquisition Transaction Costs		—				—				1,763				—
Selected Items, Before Income Taxes		133,925				(163,627		)		234,130				(4,012		)
Income Tax of Selected Items(1)		(4,497		)		40,089				(36,898		)		983
Selected Items, Net of Income Taxes		129,429				(123,538		)		197,232				(3,029		)
Adjusted Net Income		$	21,492			$	94,754			$	120,914			$	140,660
Weighted Average Shares Outstanding – Basic		402,042,034				378,799,871				387,084,651				236,206,457
Weighted Average Shares Outstanding – Diluted		430,565,265				379,401,105				394,805,513				236,773,911
Net Income (Loss) Per Common Share – Basic		$	(0.27	)		$	0.58			$	(0.20	)		$	0.61
Add:
Impact of Selected Items, Net of Income Taxes		0.32				(0.33		)		0.51				(0.01		)
Adjusted Net Income Per Common Share – Basic		$	0.05			$	0.25			$	0.31			$	0.60
Net Income (Loss) Per Common Share – Diluted		$	(0.25	)		$	0.58			$	(0.19	)		$	0.61
Add:
Impact of Selected Items, Net of Income Taxes		0.30				(0.33		)		0.50				(0.02		)
Adjusted Net Income Per Common Share – Diluted		$	0.05			$	0.25			$	0.31			$	0.59

_______________
(1)		For the 2019 columns, this represents a tax impact using an estimated tax rate of 24.5% for the three and twelve months ended December 31, 2019 and includes an adjustment of $28.3 million and $20.5 million, respectively, for changes in our valuation allowance. For the 2018 columns, this represents a tax impact using an estimated tax rate of 24.5% for the three and twelve months ended December 31, 2018 and does not include any adjustments for changes in our valuation allowance.

Reconciliation of Adjusted EBITDA
		Three Months Ended December 31,								Years Ended December 31,
		2019				2018				2019				2018
		(in thousands)
Net Income (Loss)		$	(107,937	)		$	218,292			$	(76,318	)		$	143,689
Add:
Interest Expense		20,393				20,057				79,229				86,005
Income Tax Provision (Benefit)		—				(55		)		—				(55		)
Depreciation, Depletion, Amortization and Accretion		63,411				48,295				210,201				119,780
Impairment of Other Current Assets		(1,571		)		—				6,398				—
Non-Cash Stock-Based Compensation		3,674				1,903				7,955				3,876
Loss on the Extinguishment of Debt		22,762				73,055				23,187				173,430
Debt Exchange Derivative (Gain) Loss		—				13,661				(1,390		)		598
Contingent Consideration Loss		879				28,968				29,512				28,968
Financing Expense		1,447				884				1,447				884
Cash Severance Expense		759				—				759				—
Unrealized (Gain) Loss on Derivatives		110,408				(280,195		)		173,214				(207,892		)
Adjusted EBITDA		$	114,225			$	124,865			$	454,193			$	349,283

Reconciliation of PV-10

The following table reconciles the PV-10 value of our SEC Pricing Proved Reserves as of December 31, 2019 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%)		$	1,822,024
Future Income Taxes, Discounted at 10%(1)		(143,964		)
Standardized Measure of Discounted Future Net Cash Flows		$	1,678,060

____________
(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, 2019, our future income taxes were reduced.

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