By Marin Katusa, Chief Energy Investment Strategist
Competition is supposed to make competitors stronger, but when it comes to the battle between coal and shale gas for supremacy as the United States’ power-generating fuel of choice, the rivalry instead has each commodity holding the other down.
Coal is the reigning champ is this competition, having provided at least 50% of the electricity consumed in the United States for many decades. Coal and nuclear plants have long worked together to provide the nation with its all-important baseload power; natural gas and renewables contribute to help meet peak-demand needs, but neither has come close to challenging coal’s grip on power.
But then horizontal drilling and multi-stage fracturing unlocked trillions of cubic feet of natural gas from shale formations across North America. Suddenly the continent was flooded with gas; and as supplies overwhelmed demand, a commodity that traded as high as $13 per MMBtu just four years ago saw its value drop as much as 85%.
At the same time, international demand kept coal prices pretty strong. Faced with a choice, utilities started to switch from coal to natural gas. Coal’s grip on US power-generation supremacy started to fade – from a high of 57% in 1985, coal’s contribution to US power needs slipped to 42% last year. Today coal is providing only 37% of US electricity.
As demand for coal dropped, coal prices started to lose ground. In the past 12 months, prices for Appalachian coal have fallen 24% while coal from the Powder River Basin in Montana and Wyoming has lost 45% of its value.
It’s become a race for the bottom. Ultracheap gas started to displace coal, coal prices fell to remain competitive, and now the two are fighting to simply tread water.
The Switch to Gas
As gas flooded the continent and prices plunged, it only made sense for US utilities to take advantage of this inexpensive alternative fuel. Southern Co., Xcel Energy, American Electric Power, and Dominion Resources are among the US power-generators that have taken advantage of low natural-gas prices to displace some of their coal-fired generation. Some of these companies simply started making more use of gas-fired plants that had previously only been used to serve peak-power demand. Others operate combined cycle coal-gas plants, which can burn either fuel. And some actually built new gas-fired units to replace older, less efficient facilities, some of which were being forced to close because of increasingly stringent environmental regulations.
Southern’s switch to gas makes for a good example. Southern ran its combined cycle gas turbine fleet at a near-record 70% of capacity during the first quarter of the year, doubling the plants’ typical use. This degree of transition has the utility on pace to consume more gas than coal this year for the first time in its 100-year history. As a result the company expects to derive 47% of its power from gas and only 35% from coal. Five years ago the company relied on coal for 70% of its generation; gas provided just 16% of its power.
No matter how you look at it, utilities are using a lot more gas than they used to. Barclays Capital estimates that 7 billion cubic feet of gas is being burned each by US utilities that used to burn coal to generate those watts. US Energy Information Administration data show power companies consuming 34% more gas this February than a year earlier. Credit Suisse estimates power plants ate up 5 billion cubic feet more gas each day in the first three months of the year compared to Q1 of 2011.
However, the switchover phase is almost complete. Utilities have transitioned their combined cycle plants, restarted their idled gas capacities, and committed as much to new gas plants as they are probably willing to commit, given natural gas’ tendency for extreme price volatility. And utilities will only start to make a dent in America’s massive stockpiles of natural gas if the trend to increased gas consumption can continue through this year. Credit Suisse figures the power industry will need to burn at least 4.5 billion cubic feet more per day above 2011 levels to create a notable drawdown in gas inventories, something that analysts peg as unprecedented but not out of the question.
So the switch is barely easing the gas-supply glut…but it is definitely hurting coal prices.
What Happens Next
As utilities switched to gas, demand for coal started to decline, and with declining demand comes falling prices. By January coal producers could no longer ignore the trend and started idling mines. Patriot Coal idled its Big Mountain mine, Alpha Natural Resources closed four mines, and many other companies cut back on production volumes.
Coal production in the United States is now down 8% compared to this time last year. Shares of Peabody Energy, the biggest coal producer in the United States, have dropped from $70 to $29. Arch Coal shares have fallen from $35 to less than $10. Several coal producers have announced losses in the hundreds of millions.
I like to say that the cure for low prices is low prices. Low commodity prices force production cuts, which reduce supplies and help to define a pricing floor based on the cost of production. Eventually, reduced supplies fall behind building demand, and prices are forced back up again.
The interesting thing about this situation is that there are two commodities competing to define the pricing floor. It’s like a manufacturing battle, where two companies keep undercutting each other’s prices until one goes under and the survivor gets all the business. In this case, neither fuel is going to go under – both will undoubtedly play important roles in electricity generation in the United States for many years. Instead, the competition will simply keep a tight lid on prices for years.
For example, in the last month natural gas prices posted an impressive rally, gaining as much as 40% after bottoming below $2 per MMBtu. That rally has now stalled, blocked from continued ascent by two serious obstacles: coal prices and shut-in gas production.
Coal prices matter because natural gas needs to remain competitive with coal. Utilities only switched to gas because it was cheaper, but with gas’ rally that economic edge is wearing thin. In fact, our calculations show that the two fuels are almost equivalent in terms of energy economics.
Since April 20 Central Appalachian coal has been priced at US$60.90 per ton. Each pound of Central Appalachian thermal coal generates 12,500 Btu, or 0.0125 MMBtu. With that information we can calculate that this mainstay US thermal coal is currently priced at US$2.436 per MMBtu. Natural gas is priced per MMBtu, so we can now compare our two fuels on a dollars-per-energy-produced basis: over the same time frame, the Henry Hub natural gas spot price has averaged US$2.188 per MMBtu.
So gas is cheaper than coal, but not by much. In fact, on May 25 the Henry Hub spot price was US$2.67 per MMBtu, making gas slightly more expensive than coal on an energy-equivalent basis.
And the price to generate each unit of energy is the only thing that matters to energy producers. We contend that gas’ price rally is over because if a rising gas price renders the two fuels economically equivalent, the shift to gas will end. Remember, coal was entrenched as America’s power-generation mainstay for many years, and that tenure leaves behind a legacy that favors a return to coal – if the economics allow it. For example, many US utilities are sitting on growing coal inventories. These utilities are being forced to continue buying the fuel under long-term take-or-pay contracts and will start burning it as soon as it makes sense to do so. And limited storage space is making these stockpiles problematic: GenOn Energy (NYSE:GEN), for instance, has declared force majeure on coal receipts due to a lack of storage space.
The other, longer-term barrier to a natural-gas price rally is the huge resources locked up in shut-in shales. As prices fell gas producers reduced output, starting with the fields that generated the lowest margins. The first on the chopping block: dry shales, which are formations that produce only dry natural gas (also known as straight methane), without much in the way of other byproduct fuels. Wet shales or liquids-rich shales, by contrast, produce significant volumes of heavier fossil fuels, like propane, butane, pentane, and even crude oil. Low natural gas prices have rendered many dry gas wells uneconomic, but the bonus production of natural gas liquids is keeping many wet gas wells in the black.
While producers may not be tapping into these dry shale resources right now, the resources themselves haven’t disappeared. Instead, these unloved dry shales have created a cap on natural gas prices. As soon as prices move up enough to render dry-gas production profitable, gas companies across the US will put their dry shales back into production, creating another glut of supply that will limit prices once again.
Coal is facing a similar situation. Coal prices have to remain depressed in order for coal to remain competitive. In short, the price of thermal coal in the United States is going to be constrained – perhaps even controlled – by the price of natural gas for the foreseeable future.
The Bottom Line
In the United States, shale gas production will keep gas prices low for years. Even a decline in stockpiles will do little to help – if prices climb, producers will return to their shut-in wells, and supplies will ramp up again. The massive volumes of natural gas sitting on reserve books across the continent simply will not let prices rise very much for a long time.
Constrained natural gas prices will keep a lid on thermal coal prices. Once the king of America’s power generation machine, coal now has to compete with natural gas at every turn; and to be competitive, it has to carry about the same price per MMBtu as gas.
Coal and natural gas are very different, but in fact the two fuels are more intertwined than one might think. The shale gas phenomenon has changed the natural gas world fundamentally; the result has been that coal and natural gas now compete for the same market. With abundant resources of both available in North America, instead of making each other stronger, coal and natural gas are holding each other down.
Even seemingly discouraging trends like the coal and natual gas price seesaw offer a savvy investor great profit potential. We’re so sure of this that we’ve started calling the energy sector the bull market of the 21st century.
Additional Links and Reads
Expanding Pipeline Capacity Won’t End Oil-Price Spread (Globe and Mail)
Experts are increasingly predicting that crude oil producers in Canada and the Bakken are facing a prolonged period of discounted pricing, despite moves to open new pipeline capacity to the US Gulf Coast. The newly reversed Seaway pipeline is now carrying oil from the Midwest to the Gulf Coast, and its southbound capacity will increase to 400,000 barrels per day by 2013; but analysts say that will not be enough to ease the glut of supply heading into Cushing from Canada’s oil sands and the Bakken shale.
WHO Releases Mixed Fukushima Radiation Report (Reuters)
In its first official statement about the event, the World Health Organization (WHO) says that spikes in radiation caused by the Fukushima nuclear disaster were below cancer-causing levels in almost all of Japan, though infants in one town appear to be at a higher risk of developing thyroid cancer. In a separate report, a UN scientific body said that several TEPCO-related workers have died since the accident, but none of the deaths were linked to irradiation.
Nigeria Oil Bill Waters Down Its Reforms (Reuters)
It looks increasingly likely that Nigeria’s long-awaited oil law will be a botched job that gives favorable tax terms to foreign oil companies while doing little to satisfy calls for transparency and reform of a corrupt and wasteful sector. A new draft of the bill is almost finalized, potentially ending years of uncertainty that has blocked billions of dollars of potential investment. However, those familiar with the bill predict that the oil industry will be happy with the bill, while Nigerians will be upset.
Chinese Coal, Iron Ore Defaults Prompt Mystery (Globe and Mail)
Over the last two weeks Chinese consumers of thermal coal and iron ore have been defaulting on their contracts, sending prices sharply down. The reason behind the cancellations is a hotly debated topic in the physical commodities market, with two main theories: Either Chinese buyers do not need the raw materials because of weak demand and high inventories (a bearish outlook), or they need the shipments but are defaulting to take advantage of falling prices (a neutral to bullish perspective).
Uranium Long-Term Price Finally Rises (Financial Post)
For the first time since the Fukshima nuclear disaster in March of last year, the long-term uranium price is showing signs of life. The term price – which covers material that will be delivered more than two years in the future – rose to US$61.50 a pound this week, up 2.5%. The boost was likely spurred by a decision by the local government of the Japanese town of Ohi to restart the town’s two reactors.