Stephen Maloney
Copyright 2009, Towers Perrin
All rights reserved
While crude oil markets are enjoying a breakout, why isn't natural gas keeping pace? Isn't there supposed to be some kind of multiplier relating the two commodities? Shouldn't rising hydrocarbon prices lift all boats? After all, the recession is over, right?
Maybe it's a storage problem so let's check the numbers.
As of October 9, 2009, US crude oil stocks were 337.8 million barrels, up from 309.2 million barrels a year ago. That's a 9.2% increase over last year and well outside the normal range for this time of year.
Natural gas stocks as of October 2, 2009 stood at 3,658 billion cubic feet (Bcf). That's up from 3,266 Bcf a year ago or a 14.6 % increase and also outside the normal range for this time of year.
So, we're not seeing an inordinate swing in storage volumes relative to normal ranges for this time of year.
Now, let's look at the prices.
WTI spot prices on October 9 were $71.75 a barrel, up from $69.80 the previous week. In contrast, spot prices for natty gas are around $3.82 per MMBtu and not showing much strength above the NYMEX $4 handle.
Let's put this in context. A barrel of oil is worth roughly 5.8 MMBtu. So, $71.75 per barrel of WTI crude prices a barrel's energy content at about $12.37 per MMBtu. On an energy content basis, oil prices are currently about 3.24 times higher than energy prices for an equivalent amount of natural gas. And, crude oil prices are in breakout.
By comparison, a year ago, WTI prices last year were $77.44 and heading south. Henry Hub prices were then around $8 per MMBtu. On an equivalent MMBtu basis, the conversion multiple last year was 1.67.
Natural gas prices are not keeping up with crude oil price increases.
Admittedly, a year-to-year comparison is not really fair. After all, US natural gas prices follow a cyclical pattern timed to the onset of winter. Prices tend to peak in late July-early August. That period also coincides with peak volatility reflecting the uncertain requirements of the upcoming
winter heating season and the uncertain potential for supply disruption associated with the beginning of hurricane season in the US Gulf Coast. So, there should be some risk premium to price into natural gas spot or prompt month prices. And, we should vary that premium through the year. As the winter heating season ends in late winter-early spring, the price topology can be as exciting as riding the "Rebel Yell" (ask Brian Hunter, formerly of Amaranth, to explain why Mar-Apr spreads are called the "widow maker").
Clearly, the evidence is "all hydrocarbons are the same" is NOT true on an equivalent heat rate basis. Maybe they once were, but not at this moment and not at certain times of the year.
What's changed?
First, crude oil is an international market while natural gas is currently dominated by pipelines.
In addition, we're seeing the increasing role natural gas is playing in domestic electric power generation. In contrast, crude oil has no role in electricity generation.
Utilities don't burn oil anymore to make electricity. Rather, they mostly burn US and Canadian produced natural gas and US coal. In fact, roughly a third of natural gas demand goes to generating electricity. And, over the past year, electric generation went down pretty hard due to the recession. When people talk about wind and solar reducing the dependency on foreign oil, they're wearing leisure suits and playing an 8-track tape from the 1970s.
Electricity generation directly taps into the real US economy (i.e., the one that employs working people - not NYSE). With US industrial capacity utilization running below 70%(!), it's not surprising that July net electric generation (a peak demand month) fell off the table some 7.6% this year. Coal was the big loser with its less liquid market taking a stomach churning 15% drop in generation. The (relative) big winner was natural gas demand for generation which was only down 0.4%.
The new dynamics of natural gas markets are breaking a lot of traditional notions. For example, while demand for generation softened, natural gas prices responded to market dynamics quicker than the coal market such that gas-fired generation actually stole market share from coal in many areas, including the Midwest. In effect, the higher spark spreads made gas-fired generators relative money makers this summer compared to coal generation while large segments of the US industrial sat idle. Wild.
We're still a long way from a US economy running at its normal 80% or so capacity utilization. The US economy will need a few years of white-knuckled growth combined with some serious capacity rationalizations to get there. Meanwhile, natural gas rigs are dropping off in an attempt to match supply to demand.
Shifting markets aren't the only change impacting natural gas markets. We also have seen a very quiet tropical storm season which has also moderated the volatility spikes we often see in the summer going into the fall.
All in all, while domestic supplies of natural gas heroically stole some domestic demand from coal it otherwise couldn't keep pace with crude oil's breakout driven by USD collapse and Chinese demand. Still, there may be some late inning hopes - despite threats (or promises - take your pick) of global warming, it may well be a colder winter this year. Cold temps can be beautiful music for natural gas producers.
Clearly, traditional market dynamics for natural gas were impacted by this recession and the "dog that didn't bark" (no headline-making hurricanes to speak of). And, so, the spreads between WTI crude oil and Henry Hub natural gas have widened beyond traditional bands.
What about the future? Will the US natural gas market continue to experience domestic dynamics? Or, will LNG expose the market to the trans-Atlantic spreads and transform US storage into a swing player not unlike the WTI-Brent spreads?
In my next blog, I'll talk about LNG.
Stephen Maloney
Managing Consultant, Risk and Financial Services
Towers Perrin
steve.maloney@towersperrin.comwww.towersperrin.com/energy