• Climate Change
    Climate Change in Obama’s Second Term
    President Obama surprised pretty much everyone when he spent a considerable part of his inaugural address talking about the need to confront climate change. It suggests a willingness to tackle the issue in ways that go beyond what was accomplished in his first term. I’ll be watching three big areas on the domestic front. The first, and the most politically challenging test, will be how he uses existing Clean Air Act authority to go after carbon dioxide emissions from existing power plants. Some creative plans have been surfacing – you’d be well served to read Dan Lashof and his NRDC colleagues’ recent paper, which outlines one of those, here – that could allow the EPA to make substantial cuts to emissions in ways that are flexible enough to pass a serious cost-benefit test. Figuring out how to advance such a plan amidst significant energy-sector uncertainty remains a real hurdle. Indeed facts on the ground have changed so quickly enough that the emissions that NRDC projects will occur in 2020 as a result of its proposed policies are now very close considerably closer to what the EIA projects will happen without any policy at all. (Update: The NRDC study uses a two year old baseline that projected power sector emissions of 2301 tons in 2020; the EIA 2013 AEO now projects 2081 tons; and the NRDC policy case projects 1796 tons.) This particular change, of course, argues in favor of more aggressive standards, and reinforces the fact that rigid regulation can result in lost opportunities. But the prospect of equally large changes in the other direction (i.e. changes that make cuts more difficult) will undoubtedly be on policymakers’ minds as they work through various options. The president will also need to be prepared to fend off congressional attacks on EPA authority if he decides to go down this road in a strong way. The second area I’ll be watching is spending on energy innovation. This may be the most promising area for near-term bipartisan compromise, however limited, on Capitol Hill. But success in attracting support on this front is far from a given, particularly given continuing focus on the budget deficit. The fact that some new innovation spending seems possibly doable with enough political muscle, but unlikely to move forward without some sort of White House push, makes it a useful test for whether the administration has the ability to move anything climate-related forward in Congress. The last area to watch is much broader. While pressing forward on near-term initiatives, President Obama will need to lay the groundwork for longer-term action. The reality is that none of the front-burner decisions – on EPA regulations, innovation spending, or the Keystone XL pipeline – will get the United States on the sort of long term path that it needs to be on. And some potential near-term decisions – particularly on oil and gas infrastructure, including Keystone and other issues – could make it more difficult to forge a broad enough coalition to curb U.S. emissions down the line. What President Obama did yesterday, by weaving action on climate into a history of how Americans have tackled big problems in the past, and talking at some length about the problem, was an important start in trying to build the broad understanding of climate risks that could help support a future push for more substantial action. It will become easy in the next few years to focus only on tangible wins that have near-term payoffs. But to fully evaluate whether Obama succeeds in his second term agenda, it will be essential to keep an eye on the long haul.
  • Fossil Fuels
    Chavez’s Troubled Legacy for Venezuela’s Oil Industry
    The failure of ailing Venezuelan president Hugo Chavez to return from Cuba, where he is recovering from another round of surgery, to Caracas for his inauguration underscores the uncertainty of the South American country’s future as a critical oil supplier. Chavez, first elected in 1998 and inaugurated in 1999, rode ultra-low oil prices to power, promising a tougher stance against the majors and a more hawkish voice within OPEC. So how’s the country’s oil industry faring today versus when he entered office? Venezuela was the third-largest producer in OPEC when Chavez took office, its roughly 3.5 million barrels per day (mb/d) surpassed only by Saudi Arabia and Iran (see Figure 1). Output was on the upswing, +1 mb/d since the start of the decade. But the country’s production has trended steadily downward under Chavez—now 30 percent lower than it was in 1998—falling victim to the mismanagement of PDVSA (Venezuela’s national oil company) to finance other state projects, hostility toward foreign investment, and a mature production base where decline rates at existing fields are as high as 25 percent, according to the U.S. Energy Information Administration (EIA). Figure 1. Oil Production Among Select OPEC Suppliers (1998-3Q2012) Source: EIA. Includes crude, NGLs, and other liquids. The woeful production record under Chavez isn’t for lack of oil in the ground. Venezuela sits on more proved reserves, according to BP’s estimate, than any other, at 297 billion barrels (Figure 2). Saudi Arabia comes closest, at 265 billion barrels, though the kingdom is also less heavily explored and has a generally higher-quality resource base. Of Venezuela’s proved reserves, most (some 220 billion barrels, per BP) are extra-heavy crude and bitumen in the Orinoco Belt, but industry estimates suggest that even this low-quality oil can be produced at as low as one-third the cost of its Canadian cousin, due to favorable fluid and reservoir conditions that make for better per-well production rates. Figure 2. Proved Oil Reserves by Country Source: BP Statistical Review of World Energy 2012 While production has fallen under Chavez, consumption has risen (Figure 3)—up from about 490 thousand barrels per day (kb/d) in 1998 to 850 kb/d today—biting into net exports, which poses a problem for the country’s future fiscal health. Crude exports have collapsed since Chavez took power, down nearly 40 percent to roughly 1.5 mb/d (Figure 4). Refined product export patterns are looking increasingly shaky as well. Last September saw a sharp jump in U.S. gasoline and other refined product exports to the South American country, some 196 kb/d, and some industry sources estimate a reliance on net product imports as high as 300 kb/d. The proximate causes of the September jump were accidents at the Amuay and El Palito refineries, which knocked out a substantial portion of the country’s refining capacity. But the more troublesome underlying factor is the slow deterioration of the country’s refining complex and oil-specific technical prowess, causing a string of outages and unplanned stoppages in recent years. Figure 3. Venezuelan Oil Consumption by Major Product Category Figure 4. Venezuela Crude Oil and Natural Gas Liquids Exports (1998-2011) Source: IEA Part of what underpins the climb in Venezuela’s consumption is deeply subsidized oil; drivers there enjoy the cheapest gasoline in the world (Figure 5). Figure 5. Price per Gallon of Premium Gasoline Ranked by Country Price per gallon of premium gasoline, Aug. 12 Country Rank, most expensive (out of 60) $10.12 Norway 1 $9.41 Turkey 2 $9.28 Israel 3 $8.61 Hong Kong 4 $8.20 Denmark 6 $7.87 United Kingdom 10 $3.75 United States 49 $1.89 United Arab Emirates 56 $1.73 Egypt 57 $0.89 Kuwait 58 $0.61 Saudi Arabia 59 $0.09 Venezuela 60 Source: Bloomberg News, Aug. 13, 2012 Whoever takes over for Chavez will face unenviable challenges: righting an industry that accounts for 95 percent of the country’s export earnings and 40 percent of government revenue after years of mismanagement; restoring the once-venerable PDVSA, whose debt as a percentage of GDP rose from 7 percent to 11 percent between 2000 and 2012; taming inflation running at 26 percent; and dealing with a host of other economic woes. It’s a full inbox.
  • China
    China: Dirty Air, Dirtier Water?
    In recent weeks, the Chinese and western media have been all atwitter over the shocking levels of air pollution in Beijing and a number of other Chinese cities. But it really shouldn’t be all that shocking. After all, in 2007, the World Bank and China’s own State Environmental Protection Administration (now the Ministry of Environmental Protection) found that that as many as 700,000 people die prematurely annually from respiratory disease related to air pollution. And more recently, Greenpeace Beijing reported that in 2011 in four major cities, more than 8,000 people died prematurely as a result of just one pollutant, PM 2.5. Anyone who spends any time in Beijing knows that the city has not yet found a way to tackle the myriad sources of air pollution from construction to cars to coal. As frightening as the country’s smog-filled skies might be, the country’s water pollution is easily as alarming.  According to one 2011 report, in 2010, “up to 40 percent of China’s rivers were seriously polluted” and “20 percent were so polluted their water quality was rated too toxic even to come into contact with.” Part of the explanation may rest in the “estimated 10,000 petrochemical plants along the Yangtze and 4000 along the Yellow rivers.” (And the Yellow and Yangtze are not even the most polluted of China’s seven major rivers.) On top of whatever polluted wastewater might be leaching or simply dumped into China’s rivers from these factories, the Ministry of Supervision reports that there are almost 1,700 water pollution accidents annually. The total cost in terms of human life: 60,000 premature deaths annually. While the macro picture is concerning, even more worrying is that individual Chinese don’t know whether their water is safe to drink or not. A Chinese newspaper, the Southern Weekly, recently featured an interview with a married couple, both of whom are water experts in Beijing (available in English here). They stated that they hadn’t drunk from the tap in twenty years, and have watched the water quality deteriorate significantly over just the past few years, even while state officials claim that more than 80 percent of water leaving treatment facilities met government standards in 2011. It is difficult to get the straight story. According to one report by Century Weekly, there are a number of reasons for differing assessments of the country’s water quality: 1) the frequency of testing at treatment plants is too low, and only 40 percent of the treatment plants in China’s thirty-five major cities have the capacity to test for all 106 indicators in any case; 2) there are only a few independent water-quality monitoring bureaus, and most water testing is done in-house by the same water-treatment plant being evaluated; 3) there is weak transparency from local governments as to the results of the tests; and 4) no water testing accounts for the contamination that occurs from the aging and degraded pipes through which the water is transmitted to Chinese households. China’s environmental challenges are long in the making, not simply a function of the past thirty years of reform. As one reporter has noted, Beijing in the 1950s transformed from a city that “did not produce even pencils” to one that boasted “700 factories and 2000 blast furnaces belching soot in the air.” In his 1991 book Environmental Management in China, Qu Geping, China’s first director of the country’s National Environmental Protection Agency, further commented about that time: “The environmental situation quickly deteriorated. A lot of places were polluted by either smog, sewage waters or rubbish. Biological resources, forests in particular, were seriously damaged, causing several losses to the ecosystem. There was extensive destruction of the natural environment of our country.” In the 1950s, China, like other countries, neither understood well nor had the capacity to deal effectively with the environmental and health challenges its rapid development was creating. Today, however, China has both the knowledge and the capability. In the midst of the recent air pollution crisis, Premier-elect Li Keqiang said it would take time to address the air pollution problem: “There has been a long-term buildup to this problem, and the resolution will require a long-term process. But we must act.”  In the meantime, the Chinese people can only wear their masks, buy their bottled water, and hope they are not in this year’s batch of pollution-related casualties.
  • Food and Water Security
    Food Price Volatility and Insecurity
    Global food prices are being driven up by a number of factors including bad weather, low stocks, and unstable commodities markets. Combating price volatility and protecting food security will take increased agriculture production and better food distribution, experts say.
  • Energy and Environment
    New From CFR: Joshua Kurlantzick on Indonesia’s Infrastructure and Growth
    Yesterday on CFR’s Asia Unbound blog, CFR fellow Joshua Kurlantzick suggested that resource nationalism could threaten Indonesia’s economic development. As he argues: There is certainly nothing wrong with Indonesians, and Indonesian ministers, wanting to control how their infrastructure is developed, and how their abundant resources are extracted and used; too often in the past, before the devolution process of the 2000s, Indonesians in many parts of the country felt that they saw little benefit from the natural resources extracted from Indonesian waters and soils. Still, Indonesia has enormous deficits in physical infrastructure, and if it is to retain the 6-7 percent annual growth rates it expects over the next decade, taking its place among the highest-powered developing economies, this huge infrastructure gap must be addressed. You can read the full post here.
  • China
    Five Critical Questions About the U.S. Strategic Petroleum Reserve
    Constant chatter about an impending oil release from the U.S. Strategic Petroleum Reserve (SPR) was a prominent feature of the oil market last year. Much of the speculation was driven by the ongoing loss of crude from Iran, due to sanctions, and the possibility of a confrontation with Tehran over its nuclear program, which could have cut off traffic through the vital Strait of Hormuz. The market’s SPR talk has died down, but Washington is likely to face some important questions in the near future about the country’s emergency oil reserves, driven by evolving domestic supply-demand conditions. Here are five: -- Size Some analysts are calling for the SPR to be downsized in light of the country’s declining net import levels, thanks to growing domestic production and declining consumption. The 695 million barrels of crude oil in the SPR are currently around 80 days’ worth of net imports (at 2012 net petroleum imports of 8.72 mb/d). If current trends hold, net imports could fall to roughly 6 mb/d within 3-4 years. That would mean that trimming down the SPR to the International Energy Agency (IEA)-mandated 90-days of net imports (using government stocks alone) could free up around 155 million barrels of SPR oil, which could be sold on the open market to generate substantial public revenue. -- Location It may make sense to consider adding or transferring emergency inventories to the East and West coasts, rather than having them confined to the U.S. Gulf Coast. Locating the SPR in the Gulf was a natural decision when the SPR was first created. But the turnaround in light sweet crude production in the greater Gulf region and the Upper Mississippi Valley, where SPR oil was designed to be shipped via pipeline, point to a declining need for that grade in that part of the country. In the case of a disruption in imports, the East and West coasts may benefit much more from extra oil on hand (and potentially in the form of refined products like gasoline and diesel). -- Composition As it stands, 38 percent of the SPR is made up of sweet crude oil, much medium API in gravity. But with imports of light sweet crude into the Gulf Coast in what may be a terminal decline, displaced by indigenously-produced tight oil, and ongoing pipeline reconfigurations, the region’s crude mix is quickly changing. It may be worth considering the types of crude held in the SPR to better reflect refiners’ needs in that part of the country, which is home to roughly half of U.S. operable refining capacity. Moreover, adding refined products may be worthwhile. Hurricanes Katrina and Rita in 2005 crippled refineries in the Gulf (Katrina alone shut in 8 percent of total U.S. refinery output), and crude isn’t any good for drivers if it can’t be turned into gasoline when they need it. -- Criteria for release Only broad criteria govern when the president can release oil from the SPR. When the White House should pull the trigger is a highly subjective decision as a result, which has caused (usually partisan) bickering in the past. Presidents Clinton and Obama both took heat for their SPR decisions, justified or not. The 2011 IEA-coordinated release seemed to up the intensity of calls for greater transparency and predictability in the agency’s decisions, which some energy experts support. Criteria could be based on a variety of variables, including the absolute or relative physical supply shortage or price increase. Estabilishing strict criteria would have trade-offs, though. If the market knows that an SPR release will be triggered at X dollars, for instance, traders may try to test Washington’s commitment, leading to suboptimal auto-releases. -- Inclusion of newer oil heavyweights China is now one of the world’s largest strategic stockpilers of oil, not to mention the second largest consumer, and is actively growing its emergency crude holdings. Yet it remains outside of the IEA. That leaves open the risk that, in a future release, Washington could sell oil in the open market only to be absorbed into Chinese public stocks. In that scenario, the net effect on global oil supply would still be better than if the United States hadn’t released anything, but not as good as if Beijing had held off on bidding for its own account—or better yet, released its own stocks simultaneously. Finding a reliable way to bring China into future talks about coordinated stockpile drawdowns could benefit Washington and Beijing alike. The IEA and China have discussed impending releases before, as they did prior to the 2011 Libya-related release. But establishing a system for joint action, even if China remains outside IEA membership, could be a worthwhile goal, partly because the story won’t end with China. The growth of India’s strategic stocks, as well as those of other non-IEA countries,  are sure to raise similar questions down the road.
  • Fossil Fuels
    How Far Have U.S. Oil Imports Fallen?
    There’s a lot of buzz today about new projections for U.S. oil imports showing that imports are poised to continue diving. The Financial Times captures the essence well with the headline “U.S. oil imports to fall to 25-year low”, referring to projections through 2014. I’ve written before about the risks of focusing on imports rather than consumption. If you want to focus on imports, though, the number to drill down on isn’t the volume of imports – it’s spending on imports as a fraction of GDP. Alas, by that measure, despite a positive trend and strong improvements over the last decade, the United States will remain in worse shape next year than in any year between 1983 and 2003. Let’s start by taking a quick step back. To the extent that U.S. dependence on imported oil is consequential, that’s either because spending on imports bleeds the U.S. economy, or because volatile import bills hurt the United States. The first problem is measured directly by U.S. spending on imported oil relative to U.S. GDP. The second problem can be measured indirectly by the same figure: everything else being equal, the higher the baseline for U.S. import spending is, the greater the economic impact of a given oil shock will be. The chart below shows U.S. spending on oil imports as a fraction of U.S. GDP. It incorporates the new projections for next two years by assuming that one-quarter of U.S. imports (i.e. imports from Canada) are priced at WTI and the rest are priced at Brent, and assumes 2.2 percent GDP growth (the results aren’t sensitive to this choice). The underlying data comes from the EIA and FRED. The result is clear: imports measured in value relative to the size of the economy aren’t anywhere close to their 25-year lows. (This is because lower import volumes have been substantially offset by higher oil prices.) The result is that projected import spending as a fraction of the economy is higher than import spending was in 1973, the year of the first modern oil crisis. It isn’t far below the figure for 1978, the year before the second crisis hit. And it is double its level in 1988, the year before Saddam Hussein invaded Kuwait and touched off an oil-centered crisis. Reaching the low mark for the past 25-five hears, achieved in 1998 at 0.45 percent of GDP, would require U.S. imports or prices to be slashed by a factor of four from their 2012 levels. There should be no question that the decline in U.S. imports – and, more fundamentally, the production gains and consumption curbs behind it – is good news. But, with oil prices appearing fairly steady at historic highs, it’s important to keep that in perspective. [Note: This post has been updated to include projections for 2014; its qualitative conclusions are unchanged.]
  • Fossil Fuels
    Drilling into the American Energy Boom, in Four Charts
    One interesting feature of the U.S. hydrocarbon boom is the widening gap between the industry’s interest in drilling for oil and other liquids versus dry natural gas. It’s all about economics: the disparity in prevailing market prices and outlook between these commodities is dictating companies’ willingness to sink money into, and bear the risk of, trying to produce them. The two graphs below show industry expenditures on exploration and production (E&P) in North America relative to crude oil and natural gas prices, courtesy of the U.S. oil services and drilling equity research team at Barclays Capital. Surging prices for both goods starting around 2003 sparked a boom in spending, which roughly tripled between 2002 and 2012. Figures 1 and 2: North American E&P spending vs. benchmark U.S. crude oil and natural gas prices As the two figures show, the surge in gas production from the investment boom helped swamp benchmark natural gas prices at Henry Hub, Louisiana, reflecting a glutted market. Benchmark West Texas Intermediate (WTI) oil prices, in contrast, quickly rebounded to around triple-digits after their epic collapse in 2008-9, and remain far above long-term inflation-adjusted historical averages (despite having to contend with a glut of their own at the WTI pricing hub of Cushing, Oklahoma). Looking at oil- versus gas-directed rotary rig counts in the United States makes it clear just how much more drilling activity is occurring here right now relative to the 1990s (Figure 3). There are about twice as many rigs deployed today as there were a decade ago. In absolute terms, drillers favored gas between 2002 and 2009, moving hundreds of rigs into production. But with natural gas prices down for the count, and with the rapid resurgence of the price of oil, North American operators are overwhelmingly choosing to channel their investment into the hunt for liquids. Figure 3. Rotary rigs in operation in the United States since 1989 (including oil- vs. gas-directed) The substitution of gas for oil-directed drilling activity has been a defining reversal in U.S. hydrocarbon production over the last three years. Whereas just a few years ago nearly 90 percent of rigs were looking for dry gas, that figure’s plummeted to 24 percent—and oil-directed rigs now make up three-quarters of the total. Figure 4. Percentage of oil- versus gas-directed rotary rigs in operation in the United States This picture could change if gas prices were to move high enough to justify companies increasing their budgets for gas drilling again, which could set off a scramble for those contractors able to quickly get rigs back into gas plays. But for the time being, it’s oil, not dry gas, that operators are interested in, not surprisingly, given the price differential. Either way, the aggregate picture is of a country where drilling is at full tilt. Even Hollywood wants in on the action.
  • Climate Change
    A New Paper on Natural Gas as a Bridge Fuel
    I have a new paper (PDF) in Climatic Change that explores the climate consequences of natural gas as a bridge fuel. [Update: The article is now behind a paywall. If you don’t have access, you can download an unformatted pre-print version here.] Here’s the abstract (followed by a discussion): Many have recently speculated that natural gas might become a “bridge fuel”, smoothing a transition of the global energy system from fossil fuels to zero carbon energy by temporarily offsetting the decline in coal use. Others have contended that such a bridge is incompatible with oft-discussed climate objectives and that methane leakage from natural gas system may eliminate any advantage that natural gas has over coal. Yet global climate stabilization scenarios where natural gas provides a substantial bridge are generally absent from the literature, making study of gas as a bridge fuel difficult. Here we construct a family of such scenarios and study some of their properties. In the context of the most ambitious stabilization objectives (450 ppm CO2), and absent carbon capture and sequestration, a natural gas bridge is of limited direct emissions-reducing value, since that bridge must be short. Natural gas can, however, play a more important role in the context of more modest but still stringent objectives (550 ppm CO2), which are compatible with longer natural gas bridges. Further, contrary to recent claims, methane leakage from natural gas operations is unlikely to strongly undermine the climate benefits of substituting gas for coal in the context of bridge fuel scenarios. I’m not going to go through the details of the paper, but I want to discuss some of the physical intuition that underlies it, and add some explicit comparisons with a couple other papers that have garnered a lot of attention (and that motivated this work). The underlying explanation for the results on methane is intuitively straightforward. When one models mitigation scenarios, peak temperatures are typically realized many decades after greenhouse gas emissions (and intensive natural gas use) have fallen deeply. That’s because the climate system has a lot of inertia. This means that it’s the long-term impact of methane -- known to be much smaller than its short-term impact -- that really influences peak temperatures. That weakens the ultimate impact of methane. In particular, gas is never worse than coal for peak temperatures, even with 5 percent leakage, regardless of the choice of emissions target. I explore a wide range of scenario pairs that differ only in their relative use of coal and gas. In every pair, peak temperatures are higher in the cases that feature coal than in those that feature gas. This is a consequence of the phenomenon that I just mentioned: because peak temperatures lag the decline of conventional fossil fuel combustion by several decades, the effect of methane leakage largely dies out (loosely speaking) before it can influence peak temperatures much. All of this is compounded by the fact that, if one wants to keep to an aggressive emissions target, a natural gas bridge can’t last long. A short bridge means relatively little in the way of methane leakage, and a relatively small impact on peak temperatures as a result. This corollary of this result, though, is that using gas as a bridge instead of keeping coal around a bit longer (assuming the same path for zero-carbon energy in both cases) doesn’t make much of a difference to carbon dioxide emissions if you’re trying to stabilize concentrations near 450 ppm. The bridge is simply too short for the distinction to be large. Some of these results change a bit when you’re looking at scenarios that stabilize carbon dioxide concentrations around 550 parts per million. Extreme methane leakage can now be more consequential for peak temperatures, because the natural gas bridge is longer, allowing for more methane to be emitted. (Lower leakage rates of 1-2 percent, consistent with mainstream estimates, are still of only minor consequence.) At least as important is that substituting gas for coal in the context of such targets can be far more consequential (because fossil fuels without CCS can stick around longer). The upshot is that, even with an aspiration to keep carbon dioxide concentrations below 450 parts per million, transitioning from coal to gas may be valuable as hedge in case an ultimate transition to zero-carbon energy occurs late. Comparisons with Howarth et al. and Wigley These results differ from those in two papers on natural gas and methane that have garnered particularly widespread attention for their alarming results. Robert Howarth and colleagues combined high estimates of methane leakage with a focus on 20-year warming potentials to conclude that natural gas is worse for climate change than coal. The new Climatic Change paper shows that the 20-year horizon is completely inappropriate for discerning the impact of methane leaks on peak temperatures. Tom Wigley raised a similar concern about Howarth et al. in a paper published in 2011. (He kindly helped me replicate the results in his paper.) To avoid Howarth’s reliance on global warming potentials, he constructed a scenario in which natural gas use rises strongly through 2100 and then declines through 2200, ultimately ending at approximately present levels. He then estimated the impact of methane emissions on temperature profiles over the course of his scenario, rather than on a particular time horizon, finding that methane negated any warming benefits for many decades. But there is an important limitation to that paper: natural gas use is never phased out in its scenarios. (They are not stabilization scenarios.) That makes it impossible for that paper to discern the impact of methane leakage on peak temperatures. (Temperatures never peak in the paper’s scenarios.) My new paper was originally motivated by a desire to address this issue. The result should cool down some of the alarm that the earlier paper generated. Limits and Directions for Future Work My new paper looks strictly at the climate consequences of bridge fuel scenarios. It does not dive into two other critical questions: Are such scenarios technologically, economically, or politically plausible? And what are their economic, security, and environmental costs and benefits? Both questions are massive and are essential to address. The paper says nothing about whether pushing into natural gas in the short run would make it more or less likely for the world to make a timely transition to zero-carbon energy after that; in-depth study of the plausibility of different pathways is essential to addressing that. Moreover, peak temperatures are only one criterion by which scenarios should be judged. Comprehensive assessments need to take issues like economic cost and local environmental consequences into account. I can’t stress this strongly enough: My paper does not say that any particular pathway is "better" or "worse" or "preferable". It explores some important properties of theoretical paths that have been widely discussed but poorly investigated. In doing that, it shows that recent studies have tended to overestimate the importance of methane, but that, at the same time, some commentators have given too much credit to the potential value of natural gas as a bridge fuel for achieving stringent climate goals. Taking things to the next level, and understanding how a near-term shift to gas might affect long-term trends and outcomes, will require considerably more in-depth work on how gas fits into economic and political systems.
  • Rule of Law
    Emerging Voices: Amanda Richardson on Land Rights for Women
    Emerging Voices features contributions from scholars and practitioners highlighting new research, thinking, and approaches to development challenges. This article is from Amanda Richardson, an attorney and land tenure specialist with Landesa. She discusses the benefits that secure land rights can bring to women and their communities. The Council on Foreign Relations Development Channel recently posted an exciting article by Stephanie Hanson of the One Acre Fund on empowering female smallholder farmers. The article highlighted four obstacles women farmers in the developing world face: poor quality seed and no fertilizer, no access to credit, limited education and training, and no access to markets. We at Landesa agree strongly with this assessment. However, we would add one fundamental obstacle that presents a significant burden for women across the developing world: their lack of secure land rights to the land they rely on. The fact is that women make up only a fraction of the agricultural landholders in most developing regions. In fact, the number is often less than 5 percent and generally less than 20 percent. This means the overwhelming majority of women farmers in the developing world don’t have secure rights to the land they till. As Hanson’s article points out, women are often unable to access credit in rural communities because they do not have a formal title to their land. In fact, studies have shown that women with land rights are more likely to receive credit. However, secure land rights mean more than just access to credit. When women have secure rights to the land they use, they have incentives to make the land more productive with, for instance, better seeds and fertilizer. In Rwanda, a study found that women are the primary farmers but are granted only temporary, insecure use rights to the land they farm. These weak land rights contribute to a lack of investment in land that has led to severe problems with soil erosion. Furthermore, women with secure rights tend to practice traditional conservation methods, such as mulching and intercropping. In many countries government services cannot be accessed without a title deed. In India, for example, the government provides many agricultural extension services, from education to seeds to fertilizer, but only if the recipient has a land title. And as we know, the vast majority of women don’t have a title and therefore can’t access these services. In fact, in India, women own less than 10 percent of the land. When women have secure rights to land, it also improves their status in both their households and their communities. This enhanced status can empower women to participate more effectively and fully in community-level organizations, such as collectives that negotiate with traders, making those institutions more responsive to women’s needs. Improved status can also render women less vulnerable to domestic violence. A study in India indicates that women who own land or a house face a significantly lower risk of marital violence. Furthermore, these benefits accrue to the next generation. Women with land rights contribute a greater proportion of their own income to the household and exercise greater control over the household’s agricultural income in general, according to a study in Nicaragua and Honduras. They are also more likely to spend these funds on food for the family, leading to better nutrition for children. In fact, a study in Nepal found that the odds that a child is severely underweight are reduced by half if the mother owns land. Furthermore, when women in the household have land rights, as the Nicaragua and Honduras study found, children are more likely to go to school and have higher levels of educational attainment. Organizations must recognize the importance of targeting women and tailor their programs to meet their needs, as the One Acre Fund does so admirably. However, secure rights to land are of fundamental importance to women smallholders. In many ways they are a foundational first step. Organizations looking to help women farmers would enhance their impact by incorporating this issue.
  • Fossil Fuels
    The (Possible) Problem With Methanol
    People looking for a way that natural gas could break oil’s stranglehold on the U.S. transport system typically run into forbidding limits. Gas could be used to run power plants that would charge electric cars, but those cars are currently too expensive for most drivers. Gas could be compressed and used directly in automobiles, but limited range and fueling infrastructure are big barriers. Natural gas could also be converted into gasoline or diesel, but the costs and risks of building plants can scare investors. A dedicated band of analysts, advocates, and former policymakers has been pushing another solution: methanol. Methanol is a liquid fuel can be produced from natural gas using technology that is already widely utilized in the chemicals industry. Its advocates claim that it costs a mere $100 to alter a car so that it can use the fuel. And, using current cost estimates, advocates argue that methanol could be produced at a price that would make it a highly cost-effective competitor for gasoline and diesel. Advocates acknowledge, though, that methanol isn’t going anywhere with the current transport system. They argue that legislators should require that all cars be built to take methanol as a fuel – a so-called tri-fuel mandate. That, they claim, would allow methanol to compete on a level playing field, and potentially help replace oil. It’s an intriguing idea, but it needs more flesh on the bones. Introducing a tri-fuel mandate would be politically challenging. Current fuel economy regulations give automakers special credit against their fuel economy obligations when they sell flex-fuel vehicles. If a new tri-fuel mandate replaced this approach, automakers would be forced to take other steps to boost fuel economy instead, possibly threatening margins, and prompting political opposition. At the same time, creating a new market for methanol (the transport sector) would raise the price of methanol and hurt chemicals producers who already use it as a feedstock. They would be reliable opponents of any tri-fuel mandate. Policymakers faced with these sorts of obstacles aren’t going to be swayed by the simple claim that a tri-fuel mandate would “increase competition” and possibly help displace oil. They’re going to want some stronger analysis that persuades them that the energy payoff would be worth the political price. Doing that requires three pieces of analysis that I haven’t seen: What would the all-in cost of marginal methanol supplies be in a world that featured rapidly growing U.S. methanol production for transportation? That cost estimate would need to include not only production costs for new facilities, but also new distribution and storage infrastructure. Simply pointing to the current market price of methanol doesn’t answer that question – that price does not necessarily reflect the cost of new capital investments. How much risk would investors in methanol production face – and what would that mean for likely investment and production? It’s all well and good to claim that, at current natural gas and oil prices, methanol production looks like a good bet. A real-world investor will need to consider the potential risks of lower oil prices and higher natural gas prices. Is it reasonable to expect large investments once one considers how real investors will behave? If not, a tri-fuel standard would probably do little, and policymakers are unlikely to want to pursue one. What would the national benefits of an oil-to-methanol shift be? Or, put a different way, is a shift to methanol similar to increasing oil production, or to cutting oil use? Increasing U.S. production lowers world prices by increasing supply relative to demand, but doesn’t protect the country from volatile oil prices (or reduce greenhouse gas emissions). Reducing U.S. oil demand generally does all of these. My instinct is that, at least for modest volumes, methanol prices are likely to follow gasoline and diesel prices, failing to insulate the U.S. economy from oil price volatility. For larger volumes, I’m less certain. Moreover, different fuel options can have different consequences for vulnerability to short- and long-run price increases. My sense is that methanol would do more to address long-run price increases, but those happens to be a smaller economic vulnerability in the first place. The answers to these questions are particularly important if there’s a chance that a focus on boosting methanol production might substitute for other measures to reduce oil dependence. With advocacy for methanol on the rise, it’s all the more important that these questions be answered. If methanol really is as promising as its supporters claim, then solid answers here might prompt some policy progress. Absent that, I’m skeptical that we’ll see much action on this front.
  • Global Governance
    Through the Glass Darkly: What U.S. Intelligence Predicts for 2030
    Mathew Burrows, counselor to the National Intelligence Council, may have the most fascinating job in Washington. Every four to five years he coordinates the U.S. intelligence community’s crystal-ball gazing exercise, which imagines what the future will bring fifteen to twenty years hence. The sixth and most recent installment, Global Trends 2030: Alternative Worlds, offers an eye-opening  glimpse into the turbulent world we will inherit as middle classes grow, power shifts to developing countries, demographics change, and humanity confronts daunting ecological constraints. The NIC report  identifies four “megatrends”—or drivers—shaping the world of 2030. The first is a dramatic expansion of the global middle class. From antiquity poverty has been humanity’s dominant condition. That is poised to change. Not only will extreme poverty (defined as earning less than $1.25 per day) drop by up to fifty percent, but the proportion of individuals moving into the middle class will explode in the developing world, and particularly in Asia. Individual empowerment—driven by advances in education, health, and communications technology,including social media—will have dramatic social, economic, ecological and political impacts. Consumers will demand new lifestyles, generating economic growth but placing strains on the global environment. Wealthier, more educated citizens will demand open, accountable and democratic governments. Closed regimes will attempt to fight back, but the future of authoritarianism looks dim. The second major trend is a dramatic diffusion of state power from the West to the “Rest.” While some commentators have questioned this reality,Global Trends illustrates just how profoundly—and abruptly—it is occurring. By 2030 China will pass the United States as the world’s largest economy while other economies continue to grow. Goldman Sachs predicts that the so-called “Next Eleven”—Bangladesh, Egypt, Indonesia, Iran, Mexico, Nigeria, Pakistan, the Philippines, South Korea, Turkey and Vietnam— will overtake the collective global power of twenty-seven members of the European Union by 2030. The world has experienced earlier power transitions, of course. But historically “only one or two countries have been rising at the same time, shaking the international system rather than reordering it wholesale in a compressed time frame.” Now, the world faces the unprecedented emergence of multiple power centers at once. This shift, at a time of relative U.S. decline and European and Japanese stagnation, will place intense stress on regional orders, particularly in Asia, and embolden rising power demands that multilateral institutions—from the UN Security Council to the IMF—be transformed to reflect their preferences and weight.  The United States, accustomed to global leadership, will need to adjust to its new status as primus inter pares. This crowded geopolitical landscape will complicate multilateral cooperation, given the proliferation of actors able to block progress. It may also encourage more informal forms of collective action through ad hoc coalitions and public-private networks. The third driver is demographic change. The world is aging—not only in advanced industrial democracies, but also in China and much of the developing world. With its working age population set to peak in 2015, China faces the challenge of getting rich before it gets old. In wealthy countries, meanwhile, a growing “pensioner bulge” will strain creaky welfare states, particulary in Europe and Japan. (The U.S. dilemma is less acute, given continued high immigration and a near-replacement birthrate). Strikingly, declining fertility will allow most developing countries, provided they are decently governed, to reap a demographic dividend: As youth bulges recede and working age populations rise, including in the Arab world, growth prospects will increase and political instability will decline. India is especially well positioned for sustained growth in this scenario. By contrast, Russia’s population will contract sharply from 143 to 130 million, accelerating its geopolitical decline. To be sure, the world’s population will continue to grow—reaching 8.3 billion in 2030. But it will be increasingly urbanized with more than sixty percent of people (up from fifty percent today and thirty percent in 1950) living in cities. Thanks largely to migration from rural areas, the global urban population will swell by a 1.4 billion by 2030. A third of this increase will occur in China and India, but another quarter will occur in just nine countries: Bangladesh, Brazil, DRC, Indonesia, Mexico, Nigeria, Pakistan, the Philippines, and the United States itself. Worryingly, these surging urban populations are likely to create huge demands on fragile infrastructure, stressed ecosystems, and often corrupt municipal governments. At the same time, urban centers will become the motor of economic growth, and, in some cases, powerful international actors in their own right. The final megatrend—exacerbated by the other three—is growing competition for food, water, and energy, particularly in the context of global climate change.  Global Trends predicts that demand for food will rise by more than thirty-five percent by 2030, thanks to population growth and changing dietary preferences, but productivity gains will continue to lag. The result could be disastrous shortages and persistent price volatility. Already, the report notes, “the world has consumed more food than it has produced in seven of the last eight years.” Likewise, the world’s annual water requirements are predicted to climb forty percent by 2030, when the OECD predicts that “nearly half of the world’s population will live in areas with severe water stress”—thanks in part to accelerating global warming. The dual challenge before humanity, as I have written, is to feed the world without killing the planet  and to fashion sustainable strategies for using—and sharing—increasingly scarce fresh water resources. If there is a bright spot in this resource picture, particularly for the United States, it is in the energy field. Although global demand for energy may rise fifty percent by 2030, technological breakthroughs in unconventional oil and gas extraction offer extraordinary opportunities, particularly for the United States. (The downside of this revolution, of course, is in reducing market incentives for investment in clean, alternative energy sources like hydropower, wind, and solar). How these four powerful megatrends will interact in practice depends, the NIC argues, on six “game-changers”—or uncertainties. These include whether the global economy remains crisis-prone or stabilizes; whether domestic and global governance arrangements wither or adapt; whether number of interstate conflicts rise or decline; whether the world’s regions become more stable or unstable; whether new information, manufacturing, resource and health technologies advance peace and prosperity or prove disruptive; and whether  the United States retreats from the world or remains committed to global engagement. One frustration of the NIC report is that rather than offering probabilities on each of its “game-changers,” it outlines several plausible scenarios, or “alternative worlds.” But we shouldn’t be too judgmental. As astute observers from Niels Bohr to Yogi Berra have noted, “predictions are difficult, particularly about the future.” The NIC’s own history bears this out. In a commendable gesture, the Global Trends 2030 actually begins with a candid assessment of biases and blind spots that marrred previous editions. These shortcomings include focusing on gradual change rather than abrupt discontinuities, ignoring ideology, failing to analyze the shifting influence of state versus non-state actors, focusing too little on the U.S. global role and its impact on others’ behavior, and, finally, neglecting to discuss second- and third-order consequences of major trends. For all its uncertainties, Global Trends 2030 confirms another of Yogi Berra’s pearls of wisdom: “The future ain’t what it used to be.”    
  • Fossil Fuels
    The Five Most Influential Energy and Climate Studies of 2012
    Ideas matter. Or at least Council on Foreign Relations fellows like to believe that: otherwise, we’d be wasting a lot of our time. With that in mind, I canvassed some of the smartest observers of the energy and climate worlds – scholars, advocates, journalists, businesspeople, and policymakers – for their picks for the most influential studies, reports, in-depth articles, or books of the year in the field. Then I threw my own judgement into the mix. Without further ado, here are my picks for the five most influential energy or climate publications of 2012. This isn’t a list of “the best” analyses of the year – it’s a collection of those that have had the most impact. Read them if you haven’t yet. You’re already feeling their consequences in any case. Ed Morse et al., “Energy 2020: North America, the New Middle East?”. There’s little doubt in my mind that this study, released by Citigroup in March, was the most influential item published on energy or climate this year. Sure, there had been diffuse buzz about “energy independence” earlier, but this report was the first to put hard numbers to the discussion, not just for oil production, but for macroeconomic consequences too, helping vault the discussion onto a new plane. It should go without saying that changes on the ground are the fundamental root of renewed enthusiasm for U.S. oil production. But whether you’re thrilled or appalled by all the energy independence talk, give this paper a lot of credit for bringing it to the fore. Energy Information Administration (EIA), “The Availability and Price of Petroleum and Petroleum Products Produced in Countries Other Than Iran”. Part of me wanted to list this dry report as the most influential energy publication of the year. When Congress passed a tough set of new Iran sanctions in late 2011, it gave the president a way out: the EIA was to issue a report on the price and availability of oil from outside Iran; the president could then decide that the oil market was too tight for sanctions to go ahead. The EIA report, published in late February, could have teed up such a judgment, but instead helped pave the way for Iran sanctions to go ahead. Those sanctions have had more bite than many initially expected. Yes, the report primarily described existing market conditions, but it had considerable leeway in interpreting them. Its real-world impact may have been large. Bill McKibben, “Global Warming’s Terrifying New Math”. How often does an article about climate change get 121,000 likes on Facebook and merit 13,600 tweets? Those are the stats that this Rolling Stone piece, published in July, has racked up. The article, which juxtaposed numbers for fossil fuel reserves (large) with estimates of how much carbon can safely be released into the atmosphere (smaller), has spawned a speaking tour that reportedly has drawn as many as two thousand people to individual events, and a fossil fuel divestment movement on college campuses across the nation that is attracting considerable attention. It has also helped crystallize thinking in some important quarters that U.S. oil and gas gains are incompatible with climate safety. This one is a lot like “Energy 2020” in one important way: love or hate its analysis, it’s getting a lot of traction, in this case particularly among students who will become political leaders some day. This one is a toss up between “Effect of Increased Natural Gas Exports on Domestic Energy Markets” (EIA) and “Macroeconomic Impacts of LNG Exports from the United States” (NERA Economic Consulting for DOE). The first, published in January, forecasted large potential price spikes if natural gas exports went ahead; the second, published this month, concluded that price impacts would be limited and that macroeconomic gains would be had. These are basically the two poles in the ongoing debate over whether to allow liquefied natural gas (LNG) exports. They currently rate a tie. The Obama administration will probably announce its LNG export policy early next year. Then we’ll know which study was really the most influential. Alvarez, Pacala, Winebrake, Chameides, and Hamburg, “Greater focus needed on methane leakage from natural gas infrastructure,” Proceedings of the National Academy of Sciences. Bob Howarth and two of his colleagues threw much of the climate world into intense confusion when they published a paper in early 2011 claiming that natural gas was worse for climate change than coal. The February 2012 paper from Alvarez et al., which looked at how the impact of a shift from coal to gas would affect temperatures over time, seems to have helped people put methane in perspective, and has moved the debate onto considerably firmer ground. There’s still much to contest in the PNAS paper – and much more data to be collected – but it appears to have shifted policy-related discussion from “is gas worse than coal?” to “how do we make gas better for the climate?” That’s a change that can have big real-world consequences. Honorable mentions include Richard Muller’s “BEST” study that confirmed global warming trends, which made a big splash but seems to have since faded; the IHS study that estimated a gain of 600,000 jobs from shale gas (technically ineligible because it was published in December 2011) – its estimates made it into the president’s State of the Union address this year, and seem to have influenced White House thinking on natural gas more broadly; the Breakthrough Institute’s work establishing the federal government’s historical role in promoting shale gas technology, which also made it into the State of the Union, and has helped remind many that federal support remains vital to energy innovation; and the “Darkest Before Dawn” study from three McKinsey consultants that projected widespread grid-parity for solar power within five years, influencing opinion among an important segment of people who think about where clean energy is heading. And finally an invitation to chime in in the comments section: What did this list miss?
  • Fossil Fuels
    A New Study on Oil Trade and International Relations
    Policymakers, analysts, and pundits regularly argue over whether countries should care about who they buy their oil from. Economist usually insist that, because markets are flexible, the precise patterns of oil trade don’t matter. Security strategists often insist that they must. It’s long bothered me that despite voluminous writings that explore whether oil trade patterns should affect international relationships, there’s basically nothing out there on whether they actually do affect international relationships in practice. To address that gap, Blake and I brought together a great group of scholars, practitioners, and businesspeople earlier this year. The group prepared case studies of a dozen pairs of countries in advance. Then the collected participants discussed their implications. Blake and I have now published an article in Survival that draws lessons from the studies. (An ungated pre-publication version is available here.) We’ve also collected most of the case studies at a special CFR website here. We learned a lot in the course of researching and writing it, and hope that the case studies and the final article help others do the same. I won’t step through the whole thing, but I do want to highlight one lesson that stood out for me: the details of oil trade often influence political relationships because leaders think that they do. If, for example, U.S. leaders believe that they should afford special treatment to the countries that supply their oil, that will have consequences for international relations, no matter what their economic advisers tell them about fungible commodities and liquid markets. This lesson, along with the others in the paper, is worth keeping in mind as analysts and policymakers try to sort through the upheavals currently underway in the world of oil.
  • Fossil Fuels
    Oil Boom... And Risk Management
    A story on NPR yesterday morning, “The Downsides of Living in an Oil Boomtown,” had an interesting portrait of the economic effects of high oil prices and booming oil production on Williston, North Dakota. The frenzied pace of job creation has led to high wages but also high turnover. A leap in demand for local goods like housing has caused massive inflation in housing prices and day care services. A similar story could be told of many other rural communities in states like Pennsylvania and Texas where the ramp up in oil and gas drilling activity has been a sudden shock on an otherwise rather static business scene. The underlying message of the NPR piece is straightforward: Every economic change has its tradeoffs. Taking into account the massive joblessness problem in the United States right now—what Fed Chairman Ben Bernanke recently called “an enormous waste of human and economic potential”—there’s some irony in a news story focused on the downside of too much hiring happening too fast and too much money flowing into the hands of a local workforce. But the report is right to get people thinking about the economic tradeoffs involved anytime local economic growth is tied closely to the extractive sector. I was interested to see that Carmen Reinhart and Kenneth Rogoff’s This Time is Different singles out commodity price fluctuations as having played “major role in precipitating sovereign debt crises” over the last two centuries. Analyzing the co-movement between defaults and real global commodity prices, they write: Peaks and troughs in commodity price cycles appear to be leading indicators of peaks and troughs in the capital flow cycle, with troughs typically resulting in multiple defaults… Emerging market borrowing tends to be extremely procyclical. Favorable trends in countries’ terms of trade (meaning high prices for primary commodities) typically lead to a ramping up of borrowing. When commodity prices drop, borrowing collapses and defaults step up. So what’s the link to the NPR story? The extractive industry is a cyclical business; and so, too, will be the economic fortunes of the those local, or even state, economies that depend heavily on it. Unforeseen fluctuations in commodity prices can carry local consequences  entirely different from, and at times much stronger than, what a country as a whole experiences, if a particular local economy is insufficiently diversified and unhedged. Typically, discussion of what the American energy boom could mean for the U.S. economy has focused on aggregate outcomes in areas like domestic output or employment. But what about for smaller slices of the country, which may be more exposed? Yes, the good times can be pretty heady—but the bad times can be especially tough. Texas, for instance, went into recession when oil prices collapsed in 1986, though lower prices were a net economic benefit to the rest of the country, which breathed a sigh of relief after the oil crises of the 1970s. The state’s economy is more diversified now, making it less sensitive to oil prices. But the link’s still there, as it is in other producing regions. Energy economists in major hydrocarbon-producing states like Texas have known this for a long time, so they’ve devoted lots of attention to understanding how a change in prices affects their part of the country. Mine Yücel at the Dallas Fed is among those who have done years of excellent research on these localized oil-related macroeconomic dynamics. Policymakers in states less accustomed to these levels of hydrocarbon-driven economic activity will now need to follow suit, and those in the oil patch may need to re-learn old lessons.