Northern Oil and Gas, Inc. Announces 2014 Third Quarter Results and Raises 2014 Production Guidance

WAYZATA, Minn., Nov. 6, 2014 /PRNewswire/ -- Northern Oil and Gas, Inc. (NYSE MKT: NOG) today announced 2014 third quarter results.

2014 THIRD QUARTER HIGHLIGHTS

• Third quarter 2014 production increased 8% sequentially and 26% year over year to 1,513,205 barrels of oil equivalent ("Boe"), or 16,448 average Boe per day
• Oil and gas sales totaled $119.2 million during the third quarter
• Northern added 167 gross (13.8 net) wells to production during the third quarter
• The company raised full year 2014 production guidance to an expected 25% year over year increase
• Northern has approximately 4.0 million barrels of oil hedged for 2015 at an average price of $89.43 per barrel

Northern's GAAP net income for the third quarter of 2014 was $58.0 million, or $0.95 per diluted share.  Adjusted Net Income for the third quarter of 2014 was $15.6 million, or $0.26 per diluted share.  Adjusted EBITDA for the third quarter of 2014 was $81.4 million, an increase of 9% when compared to the third quarter of 2013.  See "Non-GAAP Financial Measures" below for additional information on these measures.

MANAGEMENT COMMENT

"Northern had another strong quarter of drilling and completion activity, resulting in continued sequential production growth and a record 359 gross (25.0 net) wells in process at the end of the quarter," commented Northern Oil Chairman and Chief Executive Officer Michael Reger.  "Our well productivity continued to improve as our new well additions were again heavily concentrated in the core counties of Mountrail, McKenzie, Williams and Dunn.  In addition, given market volatility our non-operated business model allowed us to quickly tighten our internal capital allocation process to incorporate the recent changes in oil prices.  We intend to monitor and adjust our capital allocation decisions as conditions merit.  Our capital discipline and liquidity position, coupled with our extensive hedge book, puts us in a strong position as we plan for 2015."

2014 GUIDANCE

Northern now expects full year 2014 production to increase 25% over 2013, which is the top end of our prior guidance of a 20% to 25% increase. Net well additions remain on pace for Northern to add approximately 44 net wells for the full year. 

DRILLING AND COMPLETIONS UPDATE

Field conditions in the third quarter were as expected, allowing Northern to add 167 gross (13.8 net) wells to production, which brought Northern's total producing well count to 2,197 gross (177.5 net) as of September 30, 2014.  The strong pace of drilling activity continued, and as a result, Northern's number of wells drilling or awaiting completion hit a new record of 359 gross (25.0 net) as of September 30, 2014.

The following table provides county detail for wells in process as of September 30, 2014.

OCTOBER ACTIVITY UPDATE

Northern completed and placed into production approximately 39 gross (2.3 net) wells during the month of October and Northern was participating in approximately 377 gross (28.3 net) wells that were drilling or awaiting completion as of October 31, 2014.

CAPITAL EXPENDITURES AND LIQUIDITY UPDATE

During the third quarter of 2014, Northern incurred $110.1 million of capital expenditures on drilling and completion and capitalized workover costs.  This amount includes percentage of completion accrual amounts that are attributable to the current wells in process.  In addition, during the third quarter Northern spent $11.6 million on acreage and other acquisition activities in the Williston Basin, and incurred $2.3 million of other capitalized costs. 

At September 30, 2014, Northern had $228 million in outstanding borrowings under its revolving credit facility, which has a total borrowing base of $550 million. The remaining borrowing capacity under the revolving credit facility, together with an additional $8.0 million in cash, left the company with available liquidity of approximately $330 million at quarter-end.

ACREAGE UPDATE

As of September 30, 2014, Northern controlled approximately 184,747 net acres targeting the Williston Basin Bakken and Three Forks formations.  During the third quarter of 2014, Northern acquired leasehold interests covering an aggregate of approximately 5,369 net mineral acres at an average cost of $1,402 per net acre.

As of September 30, 2014, approximately 76% of Northern's North Dakota acreage position, and 64% of Northern's total acreage position, was developed, held by production or held by operations.

HEDGING UPDATE

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 oil derivative contracts as of September 30, 2014, by fiscal quarter:

THIRD QUARTER 2014 OPERATING AND FINANCIAL RESULTS

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

Oil and Natural Gas Sales

In the third quarter of 2014, oil, natural gas and NGL sales, excluding the effect of settled derivatives, were $119.2 million, an increase of 11% as compared to the third quarter of 2013, driven by a 26% increase in production that was partially offset by a 12% decrease in realized prices, excluding the effect of settled derivatives.  The lower average realized price in the third quarter of 2014 as compared to the same period in 2013 was driven by lower average NYMEX oil prices and a higher oil price differential.  Northern's oil price differential during the third quarter of 2014 was $12.92 per barrel, as compared to $9.04 per barrel in the third quarter of 2013.

Derivative Instruments

For the third quarter of 2014, Northern incurred a loss on settled derivatives of $7.0 million, compared to an $8.1 million loss for the third quarter of 2013.  Northern had a non-cash mark-to-market derivative gain of $68.6 million in the third quarter of 2014, compared to a $29.4 million loss in the third quarter of 2013.

Production Expenses

Production expenses were $14.7 million in the third quarter of 2014 compared to $11.5 million in the third quarter of 2013.  On a per unit basis, production expenses increased from $9.56 per Boe in the third quarter of 2013 to $9.73 per Boe in the third quarter of 2014.  The higher cost on a per unit basis in 2014 is primarily due to higher workover costs and water hauling and disposal expenses.

Production Taxes

Northern pays production tax as a percentage of total oil and gas sales, before the effect of settled derivatives.  These costs were $12.1 million in the third quarter of 2014 compared to $9.9 million in the third quarter of 2013.  As a percentage of oil and gas sales, our production taxes were 10.1% and 9.3% in the third quarter of 2014 and 2013, respectively.  This increase in production tax rates as a percentage of oil and gas sales in the third quarter of 2014 is due to a declining proportion of Northern's production that qualifies for lower initial tax rates.

General and Administrative Expense

General and administrative expense was $4.7 million for the third quarter of 2014 compared to $4.2 million for the third quarter of 2013.  On a per unit basis, third quarter 2014 general and administrative expenses were $3.11 per Boe, a 10% reduction when compared with the $3.47 per Boe for the third quarter of 2013. 

Depletion, Depreciation, Amortization and Accretion

Depletion, depreciation, amortization and accretion ("DD&A") was $45.6 million in the third quarter of 2014 compared to $32.1 million in the third quarter of 2013.  Depletion expense, the largest component of DD&A, was $30.02 per Boe in the third quarter of 2014 compared to $26.66 per Boe in the third quarter of 2013.  The aggregate increase in depletion expense in the third quarter of 2014 compared to the third quarter of 2013 was driven by a 26% increase in production and a 13% increase in the depletion rate per Boe. 

Interest Expense

Interest expense, net of capitalized interest, was $10.6 million in the third quarter of 2014 compared to $9.2 million in the third quarter of 2013.  The increase in interest expense was primarily due to increased borrowings on our revolving credit facility.

Income Tax Provision

The provision for income taxes was $35.1 million in the third quarter of 2014 compared to $1.0 million in the third quarter of 2013.  The effective tax rate in the third quarter of 2014 was 37.7% compared to an effective tax rate of 37.6% in the third quarter of 2013. 

Net Income

Net income was a gain of $58.0 million, or approximately $0.95 per diluted share, for the third quarter of 2014, compared to net income of $1.7 million, or approximately $0.03 per diluted share, for the third quarter of 2013.  Net income in the third quarter of 2014 was impacted by a non-cash gain on the mark-to-market of derivative instruments, net of tax, totaling $42.7 million, compared to a $18.3 million loss, net of tax, in the third quarter of 2013. 

Non-GAAP Financial Measures

Adjusted Net Income for the third quarter of 2014 was $15.6 million (representing approximately $0.26 per diluted share), compared to $20.0 million (representing approximately $0.32 per diluted share) for the third quarter of 2013.  The decrease in non-GAAP Adjusted Net Income is primarily due to lower realized commodity prices as well as higher interest, operating and depletion expenses, which were partially offset by the continued addition of crude oil and natural gas production.  Northern defines Adjusted Net Income as net income excluding (i) (gain) loss on the mark-to-market of derivative instruments, net of tax and (ii) certain legal settlements, net of tax.

Adjusted EBITDA for the third quarter of 2014 was $81.4 million, compared to Adjusted EBITDA of $74.6 million for the third quarter of 2013.  The increase in Adjusted EBITDA is primarily due to our continued addition of crude oil and natural gas production from new wells, which was partially offset by lower realized commodity prices in 2014 compared to 2013. Northern defines Adjusted EBITDA as net income before (i) interest expense, (ii) income taxes, (iii) depreciation, depletion, amortization, and accretion, (iv) (gain) loss on the mark-to-market of derivative instruments and (v) non-cash share based compensation expense. 

Adjusted Net Income and Adjusted EBITDA are non-GAAP measures.  A reconciliation of these measures to the most directly comparable GAAP measure is included in the accompanying financial tables found later in this release.  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 results included herein provide useful information to both management and investors by excluding certain expenses and unrealized derivatives gains and losses 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.

THIRD QUARTER 2014 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 7, 2014 at 9:00 a.m. Central Time.  Details for the conference call are as follows:

Dial-In Number:  (888) 715-1402 (US/Canada) and (913) 312-1427 (International)
Conference ID:  6969791 - Northern Oil and Gas, Inc. Third Quarter 2014 Earnings Call
Replay Dial-In Number: (888) 203-1112 (US/Canada) and (719) 457-0820 (International)
Replay Access Code:  6969791 - Replay will be available through November 21, 2014

UPCOMING CONFERENCE SCHEDULE

Jefferies 2014 Global Energy Conference 
          November 11-12, 2014 in Houston, TX
Global Hunter Securities 1x1 Series Boston Energy Day 
          December 4, 2014 in Boston, MA
Capital One Securities 9^th Annual Energy Conference
          December 9-12, 2014 in New Orleans, LA

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," "anticipate," "target," "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 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, Northern's ability to acquire additional development opportunities, 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 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 Northern's operations, products, services 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. 

CONTACT:

Brandon Elliott 
EVP, Corporate Development and Strategy
952-476-9800
belliott@northernoil.com

Erik Nerhus
VP, Business Development
952-476-9800
enerhus@northernoil.com

SOURCE Northern Oil and Gas, Inc.