Exploration & Production | Drilling / Well Results | Quarterly / Earnings Reports | Second Quarter (2Q) Update
Northern O&G Brings 190 Bakken Wells to Production in 2Q
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Northern Oil and Gas, Inc. announced 2014 second quarter results.
Highlights:
- Second quarter 2014 production increased 17% sequentially and 41% year over year to 1,401,023 barrels of oil equivalent, or 15,396 average Boe per day
- Oil and gas sales were $121.2 million, a 52% increase over the second quarter of 2013
- Northern added 190 gross (14.4 net) wells to production during the second quarter
- Northern is raising full year 2014 production guidance to an increase of 20% to 25% over 2013
Northern's Adjusted Net Income for the second quarter of 2014 was $17.3 million, or $0.29 per diluted share. Adjusted Net Income excludes the impact of non-cash gains and losses on the mark-to-market of derivative instruments. GAAP net loss for the second quarter of 2014, including the impact of non-cash gains and losses on the mark-to-market of derivative instruments, was a loss of $4.4 million, or a loss of $0.07 per diluted share. Adjusted EBITDA for the second quarter of 2014 was $81.4 million, an increase of 40% when compared to the second quarter of 2013 and up 25% when compared to the first quarter of 2014.
Drilling & Completions Update
Field conditions in the second quarter were better than expected, allowing Northern to add 190 gross (14.4 net) wells to production during the quarter, which brought Northern's total producing well count to 2,037 gross (165.2 net) as of June 30, 2014. The strong pace of drilling activity continued as Northern spud 190 gross (13.4 net) wells during the quarter. As a result, Northern's number of wells drilling or awaiting completion was 298 gross (23.5 net) as of June 30, 2014.
The following table provides county detail for wells in process as of June 30, 2014.
July Activity Update
Northern completed and placed into production approximately 46 gross (4.0 net) wells during the month of July, and spud 61 gross (4.4 net) wells during the month. As of July 31, 2014, Northern was participating in approximately 313 gross (23.9 net) wells that were drilling or awaiting completion.
Revised 2014 Guidance
Net well additions remain on pace for Northern to add approximately 44 net wells for the full year. However, Northern now expects full year 2014 production to increase between 20% and 25% over 2013, versus prior guidance of a 15% increase. This improved outlook is driven in part by the excellent field conditions during the second quarter, as well as new completion designs. These new completion designs also appear to be driving a moderate increase in completed well costs, as the weighted average AFE cost of Northern's 23.5 net wells in process as of June 30, 2014 was $9.2 million. If the AFE cost trend continues, Northern would expect its full year 2014 drilling and completion capital expenditures to increase by approximately 5% over prior guidance.
Northern's Chairman and Chief Executive Officer Michael Reger, commented: "Northern's exposure to the core of the Williston Basin resulted in increased well productivity and strong sequential production growth for the quarter. Drilling activity remains robust and continues to be dominated by our exposure to the core counties of Mountrail, Williams, McKenzie and Dunn. Our inventory of in process wells remains at near record levels. The positive momentum we built in the second quarter allowed us to raise our full year production guidance for 2014."
CapEx & Liquidity Update
During the second quarter of 2014, Northern incurred $137.3 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 second quarter Northern spent $16.5 million on acreage and other acquisition activities in the Williston Basin, and incurred $1.8 million of other capitalized costs.
At June 30, 2014, Northern had $198 million in outstanding borrowings under its revolving credit facility, which has a total borrowing base of $500 million. The remaining borrowing capacity under the revolving credit facility, together with an additional $14.3 million in cash, left the company with available liquidity of approximately $316.3 million at quarter-end.
Acreage Update
As of June 30, 2014, Northern controlled approximately 186,695 net acres targeting the Williston Basin Bakken and Three Forks formations. During the second quarter of 2014, Northern acquired leasehold interests covering an aggregate of approximately 6,822 net mineral acres at an average cost of $1,759 per net acre.
As of June 30, 2014, approximately 75% of Northern's North Dakota acreage position, and 64% of Northern's total acreage position, was developed, held by production or held by operations.
Second Quarter 2014 Financials
Oil and Natural Gas Sales
In the second quarter of 2014, oil, natural gas and NGL sales, excluding the effect of settled derivatives, increased 52% as compared to the second quarter of 2013, driven by a 41% increase in production and a 9% increase in realized prices, excluding the effect of settled derivatives. The higher average realized price in the second quarter of 2014 as compared to the same period in 2013 was driven by higher average NYMEX oil prices. Northern's oil price differential to the NYMEX WTI benchmark during the second quarter of 2014 was $12.25 per barrel. This compares to differentials of $13.42 and $5.32 per barrel for the first quarter of 2014 and the second quarter of 2013, respectively.
Derivative Instruments
For the second quarter of 2014, Northern incurred a loss on settled derivatives of $11.2 million, compared to a $0.5 million loss for the second quarter of 2013. Northern had a non-cash mark-to-market derivative loss of $35.3 million in the second quarter of 2014, compared to a $17.0 million gain in the second quarter of 2013.
Production Expenses
Production expenses were $13.0 million in the second quarter of 2014 compared to $10.4 million in the second quarter of 2013. Northern experiences increases in aggregate operating expenses as it adds new wells and maintains production from existing properties. On a per unit basis, production expenses decreased from $10.49 per Boe in the second quarter of 2013 to $9.30 in the second quarter of 2014. The lower cost on a per unit basis in 2014 is primarily due to better operating conditions in the field, as well as the larger production base in 2014 over which the fixed cost components are spread.
Production Taxes
Northern pays production tax as a percentage of total oil and gas sales before the effect of settled derivatives. Average production tax rates on oil and gas sales were 10.1% and 9.5% in the second quarter of 2014 and 2013, respectively. Production tax expense was $12.2 million in the second quarter of 2014 compared to $7.6 million in the second quarter of 2013. The 2014 increase in the production tax rate as a percentage of oil and gas sales is due to a declining portion of Northern's production that qualifies for lower initial production tax rates.
General and Administrative Expense
General and administrative expense was $4.0 million for the second quarter of 2014 compared to $3.9 million for the second quarter of 2013. On a per unit basis, second quarter 2014 general and administrative expenses were $2.84 per Boe, a 28% reduction when compared with the $3.95 per Boe for the second quarter of 2013.
Depletion, Depreciation, Amortization and Accretion
Depletion, depreciation, amortization and accretion ("DD&A") was $42.2 million in the second quarter of 2014 compared to $26.6 million in the second quarter of 2013. Depletion expense, the largest component of DD&A, was $30.02 per Boe in the second quarter of 2014 compared to $26.66 per Boe in the second quarter of 2013. The aggregate increase in depletion expense in the second quarter of 2014 compared to the second quarter of 2013 was driven by a 41% increase in production and a 13% increase in the depletion rate per Boe.
Interest Expense
Interest expense, net of capitalized interest, was $10.3 million in the second quarter of 2014 compared to $7.8 million in the second quarter of 2013. The increase in interest expense was due to the increased borrowings on our revolving credit facility and the issuance of $200 million in 8% senior unsecured notes during the second quarter of 2013.
Income Tax Provision
The provision (benefit) for income taxes was a $2.8 million benefit in the second quarter of 2014 compared to $14.6 million provision in the second quarter of 2013. The effective tax rate in the second quarter of 2014 was 38.4% compared to an effective tax rate of 36.9% in the second quarter of 2013.
Net Income (Loss)
Net income (loss) was a net loss of $4.4 million, or approximately $0.07 per diluted share, for the second quarter of 2014, compared to net income of $25.0 million, or approximately $0.39 per diluted share, for the second quarter of 2013. Net income in the second period of 2014 was negatively impacted by a non-cash loss on the mark-to-market of derivative instruments, net of tax, totaling $21.7 million in the second quarter of 2014 compared to a $10.4 million gain in the second quarter of 2013.
