|Cabot Oil & Gas Corporation Announces Fourth Quarter and Full-Year 2013 Financial and Operating Results|
HOUSTON, Feb. 20, 2014 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today reported its financial and operating results for the fourth quarter and full year ended December 31, 2013. Highlights for the full year include:
Full-Year 2013 Financial Results
Equivalent production was 413.6 Bcfe in 2013, consisting of 394.2 billion cubic feet (Bcf) of natural gas and 3.2 million barrels of liquids production. These figures represent increases of 55 percent, 56 percent, and 34 percent, respectively, compared to 2012. "Our record production growth in 2013 was generated 100 percent organically through the drill-bit and results in a three-year compounded annual production growth rate of 47 percent," stated Dan O. Dinges, Chairman, President, and Chief Executive Officer.
Cash flow from operations in 2013 was $1.025 billion, compared to $652.1 million in 2012. Discretionary cash flow was $1.098 billion in 2013, compared to $680.1 million in 2012. Higher equivalent production drove the year's overall improvement, partially offset by lower realized natural gas and oil prices and increased absolute operating expenses associated with higher production. "Despite lower realized commodity prices, our cash flow growth in 2013 outpaced production growth as a result of continued decreases to our cost structure," explained Dinges.
Net income was $279.8 million in 2013, or $0.67 per share, compared to $131.7 million, or $0.31 per share, in 2012. Excluding the effect of selected items (detailed in the table below), net income was $298.1 million, or $0.71 per share, in 2013, compared to $138.9 million, or $0.33 per share, in 2012.
Natural gas price realizations, including the effect of hedges, were $3.56 per thousand cubic feet (Mcf) in 2013, down 3 percent compared to 2012. Oil price realizations, including the effect of hedges, were $101.13 per barrel (Bbl), down 1 percent compared to 2012.
Total per unit costs (including financing) decreased to $3.03 per Mcfe in 2013, down 18 percent from $3.69 per Mcfe in the 2012. All operating expense categories decreased on a per unit basis relative to last year except for transportation and gathering expense, which increased from $0.54 per Mcfe in 2012 to $0.55 per Mcfe in 2013, primarily as a result of increased Marcellus production volumes, slightly higher transportation rates and new transportation agreements in the Marcellus. Cash unit costs (including financing) decreased to $1.28 per Mcfe in 2013, down 26 percent from $1.74 per Mcfe in the 2012.
During 2013, the Company received approximately $324 million of gross proceeds from previously announced non-core asset sales in the Mid-Continent and West Texas. These proceeds were used, in conjunction with cash flow from operations, to fund the Company's $1.195 billion of capital expenditures and the Company's $165 million of share repurchases.
"This past year was a tale of two halves regarding the outlook for Cabot's natural gas price realizations, but in the end we met the challenge by delivering record-setting results for production, cash flow and reserves," said Dinges. "The key for 2014 is to continue to maximize operating efficiencies and manage our price risk, which will allow Cabot to further improve on the past year's record results."
Fourth Quarter 2013 Financial Results
Production in the fourth quarter of 2013 was 121.9 Bcfe, consisting of 116.7 Bcf of natural gas and 869,000 barrels of liquids. These figures represent increases of 55 percent, 56 percent, and 34 percent, respectively, compared to the fourth quarter of 2012. "As a result of an exceptional quarter operationally by our team that included a record number of completed stages in the Marcellus, we were able to achieve the high end of our production growth expectations," stated Dinges.
Cash flow from operations in the fourth quarter of 2013 was $257.9 million, compared to $197.0 million in the fourth quarter of 2012. Discretionary cash flow in the fourth quarter of 2013 was $284.5 million, compared to $223.7 million in the fourth quarter of 2012. Discretionary cash flow in the fourth quarter of 2013 included the impact of $34.2 million of current taxes associated with tax gains on the Mid-Continent and West Texas divestitures.
Net income in the fourth quarter of 2013 was $77.9 million, or $0.19 per share, compared to $40.9 million, or $0.10 per share, in the fourth quarter of 2012. Excluding the effect of selected items (detailed in the table below), net income was $74.4 million, or $0.18 per share, in the fourth quarter of 2013, compared to $57.1 million, or $0.14 per share, in the fourth quarter of 2012.
Natural gas price realizations, including the effect of hedges, were $3.44 per Mcf in the fourth quarter of 2013, down 12 percent compared to the fourth quarter of 2012. Oil price realizations, including the effect of hedges, were $95.57 per Bbl, down 9 percent compared to the fourth quarter of 2012.
Total per unit costs (including financing) decreased to $2.82 per Mcfe in the fourth quarter of 2013, down 13 percent from $3.25 per Mcfe in the fourth quarter of 2012. All operating expense categories decreased on a per unit basis relative to last year's comparable quarter except for depreciation, depletion and amortization expense, which increased from $1.47 per Mcfe in the fourth quarter of 2012 to $1.49 per Mcfe in the fourth quarter of 2013, due to slightly higher amortization on our unproved properties. Cash unit costs (including financing) decreased to $1.19 per Mcfe in the fourth quarter of 2013, down 23 percent from $1.55 per Mcfe in the fourth quarter of 2012.
Fourth Quarter 2013 Operational Highlights
Cabot continues to produce best-in-class results from its Marcellus Shale position in Susquehanna County, Pennsylvania. During the fourth quarter of 2013, the Company averaged 1,171 million cubic feet (Mmcf) per day of net Marcellus production, an increase of 67 percent over the prior year's comparable quarter. "Our production growth in the Marcellus was quite remarkable, especially when considering we operated only five rigs in the play for the majority of the year," commented Dinges. Marcellus cash unit costs in the fourth quarter of 2013 were $0.76 per Mcf, down 10 percent compared to the fourth quarter of 2012. A few highlighted well results from the quarter include:
"Our increase in EURs from 13.9 Bcf for our 2012 program to 16.9 Bcf for our 2013 program, along with continued cost improvements, results in a before-tax rate of return in excess of 100 percent at wellhead prices of $3.00," stated Dinges. "We anticipate drilling longer laterals on average in 2014 and look to continue to improve on our best-in-class well performance."
Eagle Ford Shale
Cabot's first four-well pad in the Eagle Ford came online during the fourth quarter and produced an average peak 24-hour rate per well of 885 barrels of oil equivalent (Boe) per day and an average 30-day rate per well of 582 Boe per day. Based on the realized cost savings of approximately $500,000 per well from pad-drilling efficiencies, the before-tax rate of return for the pad is over 50 percent.
The Company also recently turned-in-line its longest lateral well (8,708') in the Eagle Ford, which was completed with 31 frac stages. The well has produced a peak 24-hour rate of 1,344 Boe per day (92% oil) and an average 20-day rate of 1,010 Boe per day. Currently, the Company is completing its first six-well pad, which includes four wells with lateral lengths of approximately 8,000'. The six-well pad is expected to provide approximately $600,000 of cost savings per well.
Financial Position and Liquidity
As of December 31, 2013, the Company's net debt to adjusted capitalization ratio was 33.8 percent, compared to 33.2 percent at December 31, 2012 (detailed in the table below). The Company's total debt was $1,147 million, of which $460 million is outstanding under the Company's credit facility. Total lender commitments under the Company's credit facility are $1.4 billion, with $939 million of available credit under its facility at December 31, 2013.
The Company currently has approximately 1.2 Bcf per day of natural gas volumes hedged for 2014 at a weighted average floor of $4.11 per Mcf, including approximately 100 Mmcf per day on Dominion and approximately 100 Mmcf per day on Columbia. "By adding approximately 200 Mmcf per day of hedges on regional Marcellus indices for the balance of the year, we have locked in protection against volatility in regional basis differentials," explained Dinges. Additionally, the Company recently added hedges to cover 2,000 barrels of oil per day for the remainder of 2014 at a fixed price of $97.00 per barrel.
2014 Capital Budget and Production Guidance
The Company is maintaining its Marcellus rig count at six rigs for 2014 and will continue to monitor regional natural gas prices before making a decision on further acceleration in 2014. Maintaining the Marcellus rig count at six rigs will reduce the 2014 capital budget from $1.375 to $1.475 billion to $1.3 to $1.4 billion, without affecting the previously announced levels of absolute production for the year due to the Company's improved well performance and its current backlog of over 1,000 stages waiting to be placed on production. Production guidance for 2014 (originally issued on September 26, 2013) remains unchanged at 519 Bcfe to 598 Bcfe, which was predicated on 30 to 50 percent production growth on the mid-point of 2013 guidance at the time of issuance. Due to record production growth in 2013 that exceeded expectations and the impact of 2013 asset sales, the production guidance for the year now implies annual growth of 25 to 45 percent.
"We are well-positioned to navigate through this market in 2014 and provide another year of significant growth in production, cash flow and reserves, due to our increased hedge position and our increased well performance and improving cost structure, both of which result in higher rates of return despite lower realized prices," added Dinges.
First Quarter 2014 Outlook
During the first quarter of 2014, Cabot has seen its daily volumes fluctuate as a result of unscheduled downtime, which is primarily attributable to severe winter weather. "Due to these events, as well as our move to pad-drilling creating longer spud-to-sales durations for larger, multi-well pads, we anticipate relatively flat production levels for the first half of the year, similar to 2013," said Dinges. "On the pricing side, while we have experienced strong NYMEX prices this winter, regional differentials remain wider than originally expected. Through the first two months of the year, our Marcellus natural gas price realizations, before the effect of hedges, have been between $0.60 and $0.65 below NYMEX settlement prices. Despite these wider than anticipated differentials, based on the current NYMEX strip prices for the remainder of 2014, our implied rate of return on a typical Marcellus well would be over 200 percent."
A conference call is scheduled for Friday, February 21, 2014, at 9:30 a.m. Eastern Time to discuss fourth quarter and full-year 2013 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website. The latest financial guidance, including the Company's hedge positions, is also available in the Investor Relations section of the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
The statements regarding future financial performance and results and the other statements which are not historical facts contained in this release are forward-looking statements that involve risks and uncertainties, including, but not limited to, market factors, the market price (including regional basis differentials) of natural gas and oil, results of future drilling and marketing activity, future production and costs, and other factors detailed in the Company's Securities and Exchange Commission filings.
FOR MORE INFORMATION CONTACT Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas