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Investment Overview for ConocoPhillips (NYSE:COP)
Below are the key drivers for ConocoPhillips which present opportunities for upside or downside to the current Trefis price estimate for ConocoPhillips.
- Crude Oil Price: ConocoPhillips' stock price is highly sensitive to crude oil prices as the company derives more than 45% of its total value, by our estimates, from the sale of crude oil. We believe that the recent decline in oil prices could sustain for a longer period amid slower demand growth and the diminishing price-controlling power of the OPEC. According to our estimates, annual average crude oil prices (Brent) could bottom out around $80-85 per barrel by 2017 and rise back to a $100 per barrel by 2020. However, if oil prices remain depressed for longer than what we currently expect, and increase only to around $90 per barrel by the end of our forecast period, there could be almost 10% downside to our current price estimate for ConocoPhillips.
- Price of Natural Gas: ConocoPhillips' average selling price of natural gas increased from $5.06 per million cubic feet (Mcf) in 2010 to $5.64/Mcf in 2011 before plummeting in 2012 amidst an oversupply in the market due to the increased availability of shale gas. In 2001, approximately 1% of natural gas production came from shale sources. By 2013, this figure had increased to nearly 25%. Technological improvements have helped improve the ability of companies to discover these new resources. As a result of new discoveries of shale gas, there has been a decoupling between the prices of crude oil and natural gas. In 2013, the company's natural gas price realization increased on higher commodity prices in North America. We expect natural gas prices in North America to recover, albeit gradually, to the mid-$5 range by the end of the Trefis forecast period as additional demand comes from the power generation sector (which is switching to gas from coal) and other sources. However, if demand picks up further and prices rise above $10/Mcf there could be an upside of about 10% to our price estimate.
ConocoPhillips is the third largest oil producing company in the world. After the spin-off of its midstream and downstream businesses into an independent company, Phillips 66, ConocoPhillips has become a pure-play exploration & production company. The company conducts exploration activities in 19 countries and supplements its income with equity stakes in other oil & gas and chemical companies. About 55% of its production consists of liquids and about 45% consists of natural gas. Of the 55% that are liquids, about 30% is tied to Brent or international prices. The remaining 20% of liquids is tied to North American crude markers, NGL, or bitumen prices. On the natural gas side, about 45% of its portfolio, roughly 20%, consists of international gas. Price differentials between Brent and West Texas Intermediate (WTI), a widely used North American crude marker, have been narrowing of late. This has reduced the disparity in realized prices for crude oil in domestic and international markets. Price realized by the company on domestic and international sale of natural gas is also different.
Crude oil exploration and production is the most valuable segment for ConocoPhillips for the following reasons:
Large base of proven reserves
The amount of proved hydrocarbon reserves is an extremely critical metric for any oil and gas exploration and production company. It directly impacts the company’s production growth outlook, as it represents the total quantity of technically and economically recoverable oil and gas reserves owned by the company at a given point in time. ConocoPhillips’ total proved hydrocarbon reserves stood at 8,921 million barrels of oil equivalent at the end of 2013. This implies that the company held enough reserves at the end of 2013 to be able to produce oil and gas for the next 15 years at 2013 production rates.
More importantly, ConocoPhillips has reported a greater than 100% reserve replacement ratio for the last five years. This shows that the company has been able to consistently grow its reserve base through a successful exploration program. In 2013, ConocoPhillips’ reserve replacement ratio stood at 178.8% by our estimates, which implies that the company added 78.8% more proved hydrocarbons reserves to its reserve base than the amount of oil and gas it produced in the year. Its average reserve replacement ratio for the last five years has been over 143%.
Enviable acreage position in the Lower 48 states
ConocoPhillips holds 13.8 million net acres of onshore conventional and unconventional acreage in the Lower 48 states. The company’s unconventional holdings total 2.5 million net acres and include approximately 626,000 net acres in the Bakken, 227,000 net acres in the Eagle Ford, 194,000 net acres in Permian, 130,000 net acres in Niobrara, 900,000 net acres in the San Juan Basin, and nearly 430,000 net acres in other unconventional exploration plays. Currently, ConocoPhillips’ activities in this region are mostly centered on continued optimization and development of existing and emerging assets, with particular focus on areas with higher liquids production.
Improving drilling efficiencies
Most of the improvement in ConocoPhillips' price-adjusted cash operating margins over the last couple of years has come from better sales volume-mix, and continuous improvements in drilling and completion cost efficiencies. Over the last four years, the company has been able to achieve drilling and completion cost efficiency improvements of 37% and 41%, respectively, in the development of its acreage in the Eagle Ford tight oil play. A large part of this efficiency improvement can be attributed to the increased use of multi-pad well drilling. ConocoPhillips plans to further reduce its average total cost per well by using multi-well pad drilling techniques in 75% of all the wells drilled in the Eagle Ford play this year.
ConocoPhillips’ price-adjusted cash operating margins have also been helped over the past few years by the continuous improvement in its sales volume-mix, which is primarily being driven by the development of its assets in the Lower 48 states. Liquids (crude oil and natural gas liquids) now represent 54.4% of the total hydrocarbons produced by ConocoPhillips from the Lower 48 states, compared to just over 45% at the end of 2012, and their production has been growing rapidly over the last few quarters.
During the third quarter of 2014, the company’s crude oil production from the Lower 48 states grew by 25% y-o-y, while total hydrocarbon production from the region increased by just around 9%. This is significant because natural gas volumes are not as lucrative in the U.S. owing to lower commodity prices. In 2013, ConocoPhillips sold liquids at an average price of over $85 per barrel, while the company realized an average price of just around $37 per BOE of natural gas.
It is estimated that a large part of the world's oil reserves have already been discovered. Recent statistics have indicated that global consumption has been outpacing reserve additions. Peak oil is a commonly used term to describe the point at which world oil output will reach a maximum and decline afterward.
However, many institutions such as the International Energy Agency (IEA) believe that peak oil will not occur for another 25 years at the very least. Many governments across the world are promoting alternative energy measures to ensure that the supply and demand of energy will be met at all times to come.
How Does Trefis Modelling Work?
How do we get the historical numbers for this chart?
Trefis has a team of in-house Analysts who gather historical data from company filings and other verifiable sources. When historicals are available, we explain how we got them at the bottom of the Trefis analysis section below.
Who came up with the Trefis forecast for future years?
The Trefis team of in-house Analysts considers a variety of factors when projecting any forecast. The rationale for our projections is explained in the Trefis analysis section below.
How does my dragging the trendline on the chart impact the stock price?
- We use forecasts for business drivers to calculate forecasted Revenues and Profits for each division of the company.
- We then use forecasted Profits in a Discounted Cash Flow (DCF) model to obtain the Price Estimate for the company.
See more on: DCF Methodology
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