A Free-Market Energy Blog

Pickens Plan II’s Natural Gas Trucks: Mel Brooks Meets Energy Policy

By Donald Hertzmark -- March 9, 2009

Mel Brooks, in his classic comedy The Producers, schemed to make money by over-subscribing shares in a sure-to-fail play. Unfortunately for his character, the play became a smash hit, and all the investors wanted their payouts. Since he had sold well over 100% of the interest in the play, he was in a bit of a pickle.

And so it is with natural gas. Clean, easy to use, abundant—natural gas is everyone’s choice for our energy transition away from oil and coal for power generation, industry, homes, and now transportation. Enter oilman-turned-wind-promoter T. Boone Pickens, with a proposal to move U.S. heavy trucks strongly toward natural gas fuel (as compressed natural gas, or CNG). And to enable the offset, the electricity that is currently generated by such gas (about a 21% market share of power generation, according to the Energy Information Administration’s Annuel Energy Outlook 2009, Table 8) would be supplied by new wind farms, built mostly in the Plains States.[1]

The argument is based on simple physical resource reallocation. Large trucks in the United States use roughly 2.8 million barrels of diesel oil per day. If these trucks were converted to natural gas engines over the next few years as the existing stock of trucks turns over, then domestic oil demand would fall by 14% (US DOE-EIA, Petroleum Navigator).[2] Without support or justification, however, this revamped Pickens Plan assumes that all of this demand reduction would come out of imported crude or refined products. The Plan also assumes that CNG will replace diesel on a 1:1 energy equivalence.

Right now, all that gas, and more, is used elsewhere in the economy, especially to generate electricity. Electricity accounts for nearly 30% of gas consumed in the United States. In their base-case projection, the DOE’s Energy Information Administration expects a slight increase in gas use for power generation through 2030, although the fuel declines in importance to about 18% of total electricity production (EIA, Annual Energy Outlook 2009, Table 13).

It seems simple: if wind can supply 20% of U.S. electricity by 2030, then all of that natural gas can be released to fuel large trucks. Supporters also assert that truckers will save (a lot) of money by switching to natural gas. Just recently economist Lawrence Lindsay, writing in the Weekly Standard extolled the virtues of a gas-fueled long distance truck fleet.

At current pump prices of $2.50/gal., diesel for trucks costs about $17.85 per million BTUs. Gas at the Henry Hub in Louisiana is less than one third of that price. In the view of the Pickens Plan proponents, this cost differential is compelling, saving literally billions of dollars annually.

But apples are not being compared to apples, and the conversion argument leaves out important things–like transportation of the gas to market, taxes, compression to fill the trucks, and the station to hold the compressors–factors that are all included in today’s diesel prices. In fact, if one leaves out all of the non-fuel costs and taxes listed above, then at current crude prices, oil costs just $6-7 per million BTUs, not much different from natural gas.

The rub is getting the gas to market. In its recent Annual Energy Outlook, DOE estimated that transmission of gas to market, compression, and taxes equivalent to those levied on diesel will add at least $7 per million BTUs to the price of gas for trucks and other transport users (AEO 2008, Table A13). One more thing, a dedicated large gas truck costs about $75,000 more than a diesel one, with more complex fuel storage. These trucks will also pay some penalty in payload capability since CNG cylinders are heavy. UPS found that an optimized engine used about 10-15% more energy per mile than did a similar diesel vehicle, vitiating most of the remaining fuel price advantage. Overall, operating costs for UPS fleets in Connecticut ranged from about the same as for diesel trucks to 20-30% more.

So if CNG presents no special financial advantage to operators (and this was without equalizing fuel taxes), then reducing oil imports must carry a very large externality to make the Pickens Plan a sensible one. But the externalities do not all move in one direction. If the demand for diesel in the United States falls, then so will its price relative to other refined products, thereby diminishing the putative savings from the fuel switch.

There is an even larger issue, though. The United States currently imports about 15–16 percent of its natural gas, mostly from Canada. About 2–3 percent of our gas supply arrives as LNG. Over the next 20–25 years the DOE expects that gas use in the United States will remain about constant, and that imports will also stay roughly constant. However, most U.S. imports will be LNG by the middle of the next decade. By 2030, the DOE expects that almost 90 percent of gas imports will be LNG (Energy Information, Administration, Annual Energy Outlook 2009, Table 13).

With a growing population and economy, and even with an expectation of no increase in power generation from natural gas, any new gas that goes for large trucks will have to come from somewhere. A full substitution for the diesel used by heavy trucks would require at least 6 tcf/year, more than is used in any other sector of the U.S. economy.

Mel Brooks and LNG

This is where Mel Brooks comes in. Natural gas use is expected to rise only negligibly among residential users due to efficiency improvements—and ditto for industry. And we know that gas molecules cannot be reused, so to meet transportation demand for gas without increasing imports will require that all gas-fired generation be shut down by 2030 and that an additional 1–2 Tcf/d of gas be taken from other end users.[3] But if climate concerns are to reduce the new coal plants currently in the DOE forecast of U.S. generation capacity, and if older coal and nuclear plants reach the ends of their lifetimes and must be retired, then how will the lights stay on?

Easy, they say—just build more gas-fired generation. Everyone is for fast, clean and reliable Plan B for the power sector. But where will the gas come from? LNG, where else. The LNG imports sufficient to replace diesel in large trucks will sum to about 140 million tonnes annually.[4] Apparently, all we will be doing is exchanging gas imports for oil imports. To attract additional LNG supplies the United States will have to start paying more for gas—right now, the production from the various shale formations keeps gas prices relatively low in the United States, making LNG a true marginal fuel. Once LNG becomes a major necessary element in supply (30% to meet the demands of the Pickens Plan), then gas prices will need to rise in order to pull in supplies in a world market where many LNG importers lack domestic supply alternatives. Such a scenario does not sound remotely like the story told by proponents of The Plan.


There is absolutely nothing wrong with CNG vehicles. They are clean, safe and use well-understood technology. Anyone stuck in a Washington, D.C., traffic jam behind a bus certainly appreciates the difference between diesel and CNG exhaust. Moreover, urban fleets may actually be reasonably cost effective conversion targets compared with long distance trucks—the vehicles return to a central garage each night and can use “trickle” compression rather than more costly fast compression, gas infrastructure is already in place—and no government funds are needed. But forcing CNG into inappropriate end uses, using government funds to build pipeline infrastructure in sparsely populated regions of the country, and basing the whole program on vast increases in LNG imports seems to fail the reasonableness test.

[1] As has been argued on this site repeatedly, a kWh from wind cannot replace one from a central station source on anything approximating a 1:1 basis. Even then, the wind system requires generation backup for a substantial proportion of its operable capacity.

[2] Total diesel use in the US is currently about 4.5 million b/d, of which about 125,000-300,000 b/d are imported as finished products. The remainder comes from domestic refineries, which use about 65% imported crude oil and feedstocks.

[3] In the DOE’s Base Case there is substantially increased output from shale formations in the US, which just about covers the fall in output from other sources.

[4] 140 million tonnes of LNG is equivalent to 2.8 million b/d. Currently, the United States imports 12 million tonnes/year and the DOE projects 2030 imports of ~66 million tonnes/year.


  1. bottomofthe9th  

    The main source of additional gas is greater domestic production–this year rigs are being laid off left and right because prices don’t support marginal production, but even at $6/mmbtu development would be quite robust.

    Indeed, the latest LNG developments are for exporting, not importing–one in BC, one on the Gulf Coast, etc.

    With Haynesville, Marcellus, and Fayetteville already in the fold and Horn River and Montney on the horizon, US supply is more than robust enough to support additional CNG demand.

    In general I find this blog to be much more informed on global oil issues than domestic gas ones. One important thing to remember is that there’s much greater supply elasticity for domestic gas–drilling can be ramped up quickly due to market incentives–versus global oil, where the most nimble players (IOCs) don’t have access to the best reserves and the NOCs, which do, are plagued by under-investment and as such can’t respond when prices increase. So while oil and gas prices are somewhat competitive now, oil is likely to be back at $70+/bbl ($12/mmbtu) by the end of next year, while gas stays in the $5-6/mmbtu range for a long while.


  2. Donald Hertzmark  

    Like you I wish for a healthy and robust domestic upstream industry. However, given the evident of hostility of the Obama administration toward oil and gas production, expecting the “rational actor” response of our textbooks to increased demand for gas may be hoping for too much. In addition, if you notice the demand volumes that are at stake here, the full Pickens plan is basically like a doubling of industrial demand for natural gas. Even without political sandbagging such increases would be difficult to sustain over many years. The output from the shales is expected to just about make up for declines elsewhere, and with offshore out of bounds for a few years, it is not reasonable to forecast significant increases in domestic gas output.

    You final paragraph raises a troubling point. How could US gas prices stay at half the energy price of crude for any sustained period? We are not in the 1970s any more and the energy markets are linked all over. But if we admit your assertion and assume that the US gas market can be maintained indefinitely at a price that is just half of the crude price, then doesn’t this create a great opportunity for US heavy industry? With LNG importers elsewhere paying prices linked to refined products, typical for such contracts, our industrial competitors will pay more than twice for their gas what US users pay near the source. Gas exporters, seeing netback values at home higher than Henry Hub gas prices will have little incentive to invest in other, less remunerative gas conversion schemes. It will then make sense for heavy gas users – methanol, ammonia, GTL, petrochemicals – to move to the US to take advantage of the very low prices. Such an outcome is not likely and neither are such pricing differentials.

    Back to the main point, gas is everyone’s Plan B for energy supply, but there is no desire on the part of those issuing drilling permits to assure its availability through domestic production. Hence the increased reliance on LNG. Your suggested large price differentials are only possible if the increases in domestic output that can be achieved without federal government approvals are truly massive and sustained. There is nothing to suggest that this is the case. Without downplaying the importance of these shale structures, I suggest that we look closely at the overall supply picture before committing to a future that merely substitutes gas imports for oil imports.


  3. bottomofthe9th  

    Gas prices can “decouple” from oil prices because of the transportation economics–being a liquid, oil is quite inexpensive to ship, leading to more or less equal prices worldwide. Gas, on the other hand, costs something like $2.50/mmbtu to get from Qatar to the United States in transportation costs alone, to say nothing of the huge capex associated with a liquefaction train there and a regasification terminal here.

    So the point is, US gas prices can be $3-4/mmbtu higher than those in the primary gas-producing regions (Australia, Russia, Qatar, etc.) and have the market still be in equilibrium. And by the same token, prices in Japan/Europe can be near oil parity and also be in equilibrium, because while the differential is large, it is not large enough to support building a train here and shipping the gas there. So the ammonia capacity goes to Qatar/Saudi Arabia/Russia, because that’s where gas is cheap (indeed, almost free), but US gas is still quite cheap relative to oil. And just because gas is somewhat inexpensive in the US does not necessarily lead to a concentration of heavy industry–labor costs, for one, are much higher here than in developing, energy-exporting countries.

    And shales have much, much more upside than there is downside to conventional production. Indeed, throughout 2008, domestic production increased roughly 8% (net of hurricane effects)–meaning that unconventionals production increased faster than that and much more than offset conventionals decline. Given that shale exploration is a pretty recent phenomenon, there will be similar production upside (that is, increasing by a billion cubic feet per day every quarter) once the rigs come back.


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    […] “Pickens Plan II’s Natural Gas Trucks (Don Hertzmark: March 9, 2009) […]


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  7. Lev  

    The futures market price of natural gas for delivery in 2018 is about $8 per million BTU. At the same time the price of crude oil for delivery in 2018 is about $100. So given that crude oil provides about 6 million BTU per barrel a BTU for delivery in 2018 ( a good proxy for the long term) then crude oil is about twice as expensive as natural gas in 2018. If Mr. Hertzmark does not believe that divergence in the price of energy between oil and natural gas is viable he has a good speculation available. Short oil and be long natural gas. As of Friday Nov. 27, 2009 from the CME website.


  8. Lev  

    That natural gas prices not only can but must decouple from those of oil at some location is implicit in what Bottomof the 9th’s post at least as long as some natural gas is transported as liquid. Since natural gas costs over $2.5 per 1000 btu to transport natural gas MUST in equilibrium cost at least $2.5 more in the places in which it is imported by tanker than in the places where it is liqyufied. So at either its export point or its import point BTU from natural gas must have a substantially different price than BTU from oil.


  9. Lev  

    For natural gas in the coming decades the continental US is likely to be neither an exporter nor an importer.


  10. Levis Kochin  

    The production of natural gas in the US is looking more like LEV’s predictions and less like those of Hertzmark. In consequence the futures price of oil for Dec. 2016 is now $90 per barrel and the futures price of natural gas is now $6.3 for Dec. 2016 So the price of natural gas per energy equivilent barrel of crude is about $40 or less than half the cost of crude.


  11. Levis Kochin  

    Natural Gas Trucks withOUT subsidy. I know this is not in the Pickins Plan as he specializes his efforts at producing politically viable but economically senseless plans. What puzzles me is that Obama has not taken Pickins up on his proposal.


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    […] Pickens Plan II’s Natural Gas Trucks: Mel Brooks Meets Energy Policy (Donald Hertzmark: March 9, 2009) […]


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