Sandy Fielden, RBN Energy
Two years ago in June 2011 the forward curve for NYMEX natural gas pointed to $5/MMBtu for gas in 2012 – rising to $8/MMBtu by 2022. This week (June 2013) the forward curve structure looks much the same except that expected prices in 2022 are down two bucks at $6/MMBtu. In between those forward curves, spot prices for natural gas plunged to less than $2/MMBtu in April 2012 and climbed back up to $4/MMBtu a few weeks ago. Today we consder how changing production and new patterns of demand look set to change gas market price structures for good.
This is the fifth and final episode in a series based on Rusty’s keynote presentation at Benposium on May 14, 2013 titled “Why What We Thought We Knew About the North American Hydrocarbon Market No Longer Matters”. Despite the complicated title, it boiled down to a simple premise. If we look back to see what folk were forecasting for North American energy markets two years ago in 2011 and then compare that to today’s actual data and forecast, what would that tell us about the changing pace of North American energy production?
Looking at the data from Bentek – produced as always at the time in good faith based on what the market was telling them – we see that the scale of change going on in North American energy production exceeded everyone’s expectations. We looked at crude oil production forecasts in the Williston Basin and the Eagle Ford, the natural gas production forecast in the Marcellus and the US NGL production forecast from Bentek around the time of the June 2011 Benposium. What we found was that in every case – crude oil, natural gas and NGLs - today’s forecast numbers for what we expect by 2016 are way higher than they were back in 2011. In the first episode in the series (see Too Wrong for Too Long? – How 2011 Bakken Crude Forecasts Compare to Today) we looked at surging crude production in the Bakken. In the second episode in the series we looked at how rapid growth in the Marcellus natural gas production forecast is going to have dramatic consequences for traditional natural gas flows into the northeast in the coming years (see How Marcellus Forecasts Changed the World Sooner Than We Thought). Episode 3 looked at how the Eagle Ford crude and condensate production forecast nearly doubled in just two years. Along the way a lot more of that crude production turned out to be condensate than anyone had guessed or planned for (see Too Wrong for Too Long – The Eagle Ford Crude Condensate Challenge). In Episode 4 we looked at the consequences of higher than expected NGL supplies on traditional demand for these products and the resultant increase in exports (see The NGL Surge We Didn’t Expect).
Today we finish up the series by reflecting on the impact of unexpected changes in natural gas pricing over the past two years.
We talked earlier in this series about the recent dramatic increase in US natural gas production. Dry gas production in the Lower 48 increased by 17 percent from 56 Bcf/d in January 2010 to 66 Bcf/d in December 2011 (data from the Energy Information Administration - EIA). Since then production has leveled off – except in the Marcellus where it continues to increase – reaching almost 12 Bcf/d this year. Back in June 2011 Bentek made a pretty accurate call on gas – projecting that the supercharged rate of natural gas growth happening two years ago would slow down to a crawl. What they didn’t see coming – and to be fair no-one else did- was the dramatic change in natural gas price outlook that came in early 2012.
The chart below shows the Bentek forecast in June 2011. Increased production was expected to dampen prices through the start of the winter season in October 2011. Then prices were expected to increase steadily through 2012 and 2013 to reach nearly $5/MMBtu in October 2013. For June 2013 – Bentek forecast prices at $4.35/MMBtu – about 50 cents above where the NYMEX settled today ($3.877 – June 20, 2013).
Source: CME Futures Data from Morningstar
The next chart (below) shows what actually happened to prices between June 2011 and today with futures prices added out to October 2013 (green box). Instead of drifting lower and then rising again in response to winter demand, prices dropped like a stone from June 2011 through April 2012. The price crash took the NYMEX Henry Hub futures price below $2/MMBtu for a short period. Since then low prices have steadily recovered although not quite to the levels anticipated back in 2011. You have hardly heard $5/MMBtu from any analysts in 2013 and the forward prices through the end of this year (NYMEX futures – in the green box) are currently flat at around $4/MMBtu. What threw everybody off and caused prices to nosedive in 2011 was the weather. Specifically warm weather – the mildest winter on record. The weather played havoc with the natural gas seasonal supply balance. As we explained recently in Eric Penner’s ongoing blog series about natural gas storage (see Come on Feel The Noise) the normal expectation is that higher demand for space heating in the winter increases natural gas consumption. That demand exceeds the capacity of pipelines to deliver the gas – hence most local gas delivery companies in consuming regions such as the northeast and the Midwest use storage to balance supplies. Storage is typically filled during the summer months when production exceeds demand. What happened in 2011-2012 was that it did not get cold enough to withdraw a whole lot of gas from storage. That left record storage levels at the end of the winter. With supplies piling up in storage and production still at record levels, prices went into free fall.
Source: CME Futures Data from Morningstar
Our lesson from this experience is that relying on the weather to behave in a predictable manner is not such a good idea. Although the US natural gas market uses storage as the balancing device to manage supply and demand, too much storage is a very visible indication of over supply and prices will respond accordingly. As we have seen in more recent analysis (see Bright Lights Big City) the seasonal nature of demand for natural gas is changing in the US as well as the geographic distribution of production. Going forward the traditional balancing role of storage is changing and new outlets for excess natural gas supplies are needed – whether from new domestic demand or in the form of liquefied natural gas (LNG) exports (see LNG Prices Shaky).
Which brings us neatly to one other thing that we can learn by looking back at prices in 2011 – about the way the futures market behaves. The next chart (below) shows the forward curve for Henry Hub, LA NYMEX natural gas futures prices in June 2011 (blue line) and this week (June 19, 2013 – red line). Looking first at 2011, at that time there was no indication in the futures market that prices would nosedive to $2/MMBtu by April 2012. The forward curve then surges up from $4.50/MMBtu in June 2011 to over $8/MMBtu in 2023. If you were a producer in 2011 it really would have been a good idea to hedge your production at that time. The point to note here is that everything we see in a forward curve reflects what the market is currently pricing in for the future – not what is actually going to happen (see A Bridge Too Far for more on forward curves).
Source: CME Futures Data from Morningstar
And forward curves are based largely on futures market sentiment where financial players who may not have the best handle on the fundamentals dominate the trading volume. For instance, if you look at the two forward curves in the chart above then you see that although the latest curve is a couple of bucks below the 2011 version – it basically has the same shape. In particular you still see the little blips in both curves that represent seasonality – higher prices in winter than summer. Looking at the red 2013 curve it is clear that the futures market believes that there will still be marked seasonality in natural gas prices – even 10 years from today in 2023. But the reality is that a seasonal pattern like that is very unlikely to be what we see if we look back even two years from now. That is because of the changes in northeast (Marcellus) production and their impact on seasonal demand. In fact it seems likely that sooner rather than later, the northeast will need less storage to meet winter demand because of local production. In addition summer demand for natural gas is expected to increase as more gas fired power generation comes online and we start to see exports of natural gas as LNG from the Gulf Coast. These trends should smooth out seasonality in natural gas prices.
So to sum up – in addition to the big changes in the volumes and geographic location of natural gas production, expect to see big changes in the price structure of the market going forward. Fears about the levels of storage in early 2012 caused prices to fall far lower than anyone expected in June 2011. Since then the storage glut has been reduced by new sources of demand (mainly encouraged by low prices). But looking forward the whole seasonal nature of the natural gas market is changing so that winter storage soon may not be the fixation it is today – even if the futures market still believes it will be.
This mini series looking back at energy markets over the past two years has reminded us just how much has changed in such a short period of time. Many of those changes have blind-sided industry pundits and seemed incredible. Yet from the changes have come a myriad of opportunities and investments that look set to make the next two years even more exciting.