US Oil Demand Returns to Growth

• Early estimates indicate that US oil demand grew by 2% last year, after several years of declining consumption.
• Although superficially consistent with recent GDP data, it's not yet clear whether this reflects a new trend or the results of non-recurring factors. 

After three straight years of declining oil consumption and a substantial net reduction since 2005, preliminary estimates suggest that US demand for petroleum and its products grew by 2% last year. In the estimation of the International Energy Agency (IEA) US demand growth in 2013 even outstripped that of China.  However, it strikes me as an exaggeration--or at least premature--to see signs, as a recent headline in the Financial Times suggested, that "America returns to gas-guzzling oil demand."  Is this a new trend, or just another blip?

The Energy Information Agency (EIA) of the US Department of Energy won't issue final figures on 2013 consumption for a few more weeks. In the interim, the American Petroleum Institute (API) released its estimates for December and the Fourth Quarter, showing a 5.8% year-on-year uptick for the month and a 4.6% increase for the quarter, compared to the final quarter of 2012. API's Chief Economist John Felmy cited "continued progress in domestic manufacturing as well as the broader economy."

The US economy has shown unexpected strength recently but continues to disappoint a sizable majority of Americans, based on recent polling. The economy added just under 200,000 jobs per month last year, while total employment remains  below its pre-recession peak. The government's first estimate at the end of January indicated that US gross domestic product grew by 3.2% in the fourth quarter of 2013, slower than the third quarter's relatively strong 4.1% pace. That puts full-year growth at 1.9%, or less than the 2.8% rate for the 2012 when US oil consumption shrank by 2% from the year before.

In any case, the  linkage between economic growth and oil demand has weakened over time, falling by more than 60% since the mid-1970s and by 20% just since 2000. In fact, following the peak in US oil demand in 2005, estimated oil and natural gas consumption per dollar of real GDP has declined by an average of 1.7% per year, only a little less than the average of post-recession US GDP growth. So annual efficiency gains come close to offsetting the impact of economic growth on US oil demand.

Some of this is the result of specific efficiency improvements, such as the 1.0 mile-per-gallon increase in the fuel economy of vehicles sold in 2013, compared to the previous year. Tracking data from the University of Michigan indicate a 16% improvement in the fuel economy of new cars since the 2008 model year. Of course it takes time for the impact of new higher-mpg vehicles to make a dent in the demand of a fleet of roughly 235 million cars and light trucks. That's even true of plug-in electric vehicles that use no liquid fuel at all. With cumulative US sales of around 160,000, EVs are displacing less than 5,000 barrels per day (bpd) of gasoline at this point, in a 9 million bpd market.

Because the primary use of oil in the US is in transportation, with less than 1% of it going to generate electricity, we should look at indicators of transportation activity for signals about changes in oil demand. The Federal Highway Administration's tally of US vehicle miles traveled (VMT) for 2013 was just 0.6% higher than 2012, through November, and remained more than 2% below its 2007 peak, only slightly more than a decade ago. If there's been a recent shift in driving habits, it's either well-hidden or involves a switch back to putting more miles on less-efficient vehicles--countering the anecdotal trend of the last few years. In the longer term, VMT growth will face headwinds from the changes in driver demographics I described last August.

In seeking explanations for last year's higher demand, we also can't ignore one-time factors like weather. Heating-degree-day data for the northeast during the fourth quarter shows a nearly 10% increase compared to 4Q2012. That indicates more days when the average temperature was farther below 65 F, and presumably more consumption of heating fuel as a result--a trend that seems to be continuing this quarter.

Scrutinizing EIA's detailed data on product supplied reveals that around two-thirds of the roughly 300,000 bpd annual increase in demand in 2013 (through October) was in the categories of liquefied petroleum gases (LPG) and low-sulfur distillate, both used for heating. For that matter, much of the growth in LPG demand is being met from the processing of shale gas, rather than crude oil refining, so its inclusion as part of "oil demand" is somewhat misleading. Nor do growing US net exports of refined products, at  around a million barrels per day last year according to API, have any bearing on this discussion, since they aren't included in the figures on which US consumption is gauged.

Another factor to consider when evaluating changes in oil demand is pricing. US retail gasoline prices averaged $0.11 per gallon less in 2013 than 2012, while retail diesel averaged around $0.05/gal. less. Those don't seem like big enough changes to affect demand, but the fourth quarter comparison is more dramatic, with gasoline and diesel $0.22 and $0.15/gal., respectively, less than a year earlier. That, together with a cooler fall, might help explain the fourth quarter bump in API's figures, which showed gasoline demand up by 3.7% year-on-year, and diesel up 5.3%.

Indications of a resurgence in US oil demand growth depend heavily on a single quarter's results, following a quarter of above-trend GDP growth--partially offset by efficiency gains that are expected to grow--and reinforced by cooler weather.  While I can easily imagine that a return to robust US economic growth, combined with persistently weaker fuel prices, could put US oil consumption on an ascending path again, I'd like to see a few more data points before discerning larger implications for global oil demand and prices.

A different version of this posting was previously published on the website of Pacific Energy Development Corporation.

The LPG Echo of the Shale Gas Boom

• Increased US production of LPG and natural gas liquids is an outgrowth of the shale gas revolution and a key ingredient for translating its benefits into industrial growth.
• The infrastructure investments, export opportunities and price relationships for these liquids represent a microcosm of the similar issues for shale gas and LNG.

An article in the Wall St. Journal last month on the impact of a Midwest propane shortage on farmers trying to dry their corn harvest caught my attention. How could propane be in short supply, when US production is soaring due to shale gas? While it turns out that the shortfall in question was localized and temporary, it prompted me to take a closer look at LPG supply and demand than I have in many years. I found yet another market that is being transformed by the shale gas revolution.

Like most Americans--except for those in the roughly 5% of US homes heated with it-- I normally think about LPG only when I have to change the tank on my barbecue grill. That wasn't always the case; early in my career I traded LPGs for Texaco's west coast refining system. I'm happy to see that some of my former colleagues from that period are still involved and frequently quoted as experts on it. Although the LPG market is obscure to many, it represents a microcosm of the issues of reindustrialization and product exports arising from the recent turnaround in US energy output trends.

In order to follow these developments, we first need to clarify some confusingly similar acronyms, starting with LPG. Although often used synonymously with propane, it actually stands for "liquefied petroleum gas" and covers mainly propane and butane, though some in the industry include ethane in this category. The term reflects the oil refinery source of much of their supply, both historically and to an important extent today.  LPG overlaps with natural gas liquid (NGL)--ethane, propane, butane, isobutane and "natural gasoline"-- that has been separated from "wet" ( liquids-rich) natural gas during processing. NGLs are entirely distinct from the anagrammatical LNG, or liquefied natural gas, which consists mainly of methane that has been chilled until it becomes a liquid. By contrast, NGLs and LPG are typically stored at or near ambient temperature but under pressure to keep them in the liquid state.

LPG and NGLs make up a distinct segment of US and global energy markets, falling between the markets for natural gas and refined petroleum products. They are also linked to these larger markets, both logistically and economically. For example, gas marketers vary the amount of liquids they leave in "dry gas" to meet pipeline natural gas specifications based on price and other factors, and oil refiners blend varying quantities of butane into gasoline, depending on seasonal requirements. Propane and butane are mainly used as fuels, while ethane and isobutane are chiefly chemical feedstocks.

The development of shale gas in the US and Canada has affected the supply of NGLs and LPG in several important ways. First, starting around 2007 increasing shale gas output helped to halt and then reverse the decline in US natural gas production from which US NGLs are sourced. Then, following the financial crisis, diverging natural gas and crude oil/liquids prices pushed shale drillers toward the liquids-rich portions of shale basins like the Eagle Ford in Texas, in order to maximize their revenue. The resulting surge of US NGL production in late 2009 reinforced the decline of US LPG imports that began with the recession. According to US Energy Information Administration data, the US became a fairly consistent net exporter of LPG in 2011.

The current US LPG surplus is around 100,000 bbl/day, out of total production of around 2.7 million bbl/day. That surplus and its expected growth provides the basis for a number of announced LPG  export projects, as well as the anticipated development of new domestic chemical facilities such as ethylene crackers that would consume substantial portions of new supply, particularly of ethane.

The success of those projects depends on significant investments in new infrastructure, including gas processing, NGL fractionators to split the raw NGL into its components, and pipelines to deliver NGL to fractionators and LPG to markets. This is particularly true for the Marcellus and Utica shale gas in the Northeast, from which little or no ethane has been extracted due to limited local demand. Not only is that a missed manufacturing opportunity, but it constitutes a potential constraint on further liquids-rich gas development, since leaving too much ethane in the marketed gas would cause it to exceed pipeline BTU specifications.

In the meantime we're left with a situation that's analogous to the growth of tight oil production from the Bakken  shale. New sources of production have come on-stream faster than the infrastructure necessary to deliver them efficiently to where they can be processed or consumed. That puts a growing US surplus of propane and other NGLs in tension with tight regional markets for these fuels in the Midwest and Northeast, where residential propane prices are running well ahead of last year's at this time.  The resolution of this apparent paradox will depend on which infrastructure and demand projects are eventually completed, and how soon.

A different version of this posting was previously published on the website of Pacific Energy Development Corporation.