Note: this post is part of a series highlighting PEC’s upcoming conference, Achieving Deep Carbon Reductions: Paths for Pennsylvania’s Energy Future, March 15-16 at the David L. Lawrence Convention center in downtown Pittsburgh. This piece was contributed by guest blogger Aimee Curtright, Ph.D., and Sara Turner of RAND.
Read other pieces in the series and learn more about deep decarbonization on the PEC Blog. Register for the conference at pec-climate.org.
Wood and other forms of solid biomass were, for millennia of human history, the dominant fuels for cooking, heating, and lighting. More recently, the industrial revolution was enabled by a transition away from the use of wood to coal, and since that time, people in some regions of the world—like the United States and Europe—have reaped dramatic benefits from the use of fossil fuels like coal, oil, and natural gas. At the same time, water and conventional air pollution directly resulting from extracting and burning fossil fuels have taken a toll on human health. And global climate change—which is being driven largely by the greenhouse gas (GHG) carbon dioxide (CO2) produced when burning fossil fuels—threatens uncertain but likely very substantial economic and social costs, including adverse impacts for many who have yet to experience the full benefit of the use of fossil fuels. Today only 1.1% of the Commonwealth of Pennsylvania’s electricity is generated from biomass, and while biomass will almost certainly never become the dominant fuel for the electricity sector in the United States, it is still worth including as part of a menu of GHG mitigation strategies.
Biomass… doesn’t suffer from intermittency like solar and wind and is inherently amenable to storage.
There are a few compelling reasons to consider biomass. While climate change mitigation efforts for the electricity sector have generally focused on incrementally curbing CO2 emissions, very deep reductions in carbon emissions will ultimately be necessary. If net negative GHG emissions are required, one approach would be burning biomass in conjunction with capturing CO2 emissions in a process referred to as bioenergy with carbon capture and storage or BECCS.  Another reason to consider “going back” to biomass is that it that doesn’t suffer from intermittency like solar and wind and is inherently amenable to storage. It also hybridizes logically—if not always seamlessly—with the burning of fossil fuels. But unlike solar and, to a lesser extent, wind, biomass-based fuel is not a virtually infinite and “free” resource. This is because biomass also has value as food for humans and animals and, of course, as both the framework and substance of natural ecosystems. Which leads this discussion to the inherent factors that will ultimately limit the widespread use of biomass for deep carbon reductions.
One major drawback to using biomass is that accurately estimating the carbon footprint of biomass-based electricity is extremely complex and depends dramatically on the specific choice of fuel and how it is used, not to mention how you attribute and account for emissions. In and of itself this makes biomass a politically unappealing fuel – what decision maker wants to deal with complexity, variability, and uncertainty?
In addition to needing to ensure that the bioenergy has a net GHG benefit over its full lifecycle relative to alternative fuel choices, biomass fuel for electricity at large scale would need to:
- Be non-competitive with food crops;
- Not compromise valuable ecosystem services and wildlife habitat; and
- Require scant irrigation, fertilizer, and pesticide.
These constraints imply the relative value of utilizing waste biomass, and the relative importance of niche applications for burning biomass like combined heat and power (CHP). Biomass co-firing with fossil fuels is one such niche example for the electricity sector.
Unfortunately, for this renewable electricity source more than any other, the devil is in the details.
RAND spent several years thinking about the potential to co-fire biomass fuels in existing coal-fired power plants, in work supported by and in collaboration with the Department of Energy’s National Energy Technology Lab (NETL). We found that this approach is a potentially cost-effective, near-term way to take the edge off of CO2 emissions for the electricity sector. More recently, an analysis of 60 scenarios of co-firing biomass with coal and natural gas found CO2 abatement costs around $30-40 per metric ton of CO2, values which compare favorably with other options for CO2 abatement. However, this approach has limits, including the fact that co-firing the “low-hanging fruit” biomass would lead to rising costs of the next unit of available fuel.
But while biomass is clearly not a deep decarbonization silver bullet, decision makers shouldn’t simply write off its potential to help us on our path to deep carbon emission reductions for the electricity sector. Unfortunately, for this renewable electricity source more than any other, the devil is in the details, and in order to make sure we are actually realizing the climate mitigation benefits of biomass fuels, we’ll have to find ways to appropriately and consistently account for associated GHG emissions. This means we will need decision makers who are comfortable with uncertainty and willing to tackle complexity, and who will roll up their sleeves and work with experts in government agencies and the broader scientific community to sort through the best overall portfolio of solutions for mitigating climate change.
Aimee Curtright is a senior physical scientist at the RAND Corporation and a professor at the Pardee RAND Graduate School. She works primarily in the areas of energy policy and technology assessment.
Her recent and ongoing projects include a life-cycle assessment of the greenhouse gas emissions of biomass energy feedstocks, a study on the technical and logistical barriers to co-firing biomass in existing coal-fired power plants, and an analysis of the costs and benefits of imposing a 25 percent renewable energy mandate.
Curtright’s past experience includes postdoctoral research at Carnegie Mellon University in the department of engineering and public policy, a fellowship at the National Academies with the Board on Energy and Environmental Systems, and research in microbattery fabrication at the U.S. Naval Research Lab. Curtright received her Ph.D. in physical chemistry from the University of California, Berkeley.
Sara Turner is a doctoral candidate at the Pardee RAND Graduate School and an assistant policy analyst at RAND. She has an M.A. in international studies, specializing in international political economy, from the Josef Korbel School of International Studies at the University of Denver, and dual B.A. degrees in economics and international relations from Gonzaga University.
Prior to joining Pardee RAND, Turner was a research associate at the Frederick S. Pardee Center for International Futures at the University of Denver, where she worked on a project to forecast potential futures for fisheries and aquaculture development and another to collect and analyze new data on the structure of the international system. She also served as a consultant for the Institute for Security Studies in Pretoria, South Africa, developing forecasts for poverty reduction in Africa in light of proposed sustainable development goals. Her research interests include climate change, food security, poverty, human development, and disaster risk reduction.
 For an introductory overview, see this explainer from EIA.
 1.6% of U.S. electricity overall comes from biomass. Both values were calculated from EIA data on net generation by source (thousand megawatts), available here.
 See Williams, J. H., et al. (2012). “The Technology Path to Deep Greenhouse Gas Emissions Cuts by 2050: The Pivotal Role of Electricity.” Science 335(6064): 53-59.
 Other approaches to net negative emissions include direct air capture of CO2 with CCS and chemically or biologically enhanced ocean uptake. See, for example, Smith, P., et al. (2016). “Biophysical and economic limits to negative CO2 emissions.” Nature Clim. Change 6(1): 42-50.
 Carbon capture and storage, or CCS, is discussed in another post in this series.
 Other renewables—notably non-dispatchable wind and solar—are discussed in another post in this series.
 For an “in the weeds” but concise overview of the complexity of carbon accounting for biofuels, see this recent post by B. Paulos.
 Some of the other downsides and complexities—from logistics and costs to concerns from the environmental advocacy community—are discussed by B. Paulos here. Some “facts and myths” about bioenergy are discussed in the companion piece here.
 A recent economic research study at USDA found that expanding production of switchgrass by enough to produce 250 TWh of electricity per year would require an area of land approximately equal to half of U.S. wheat production and could reduce crop production by 0.6-4.0 percent.
 CHP and district heating, backup or augmentation for intermittent renewables, and liquid aviation fuels are all examples where biomass could arguably be a more dominant solution than for the case of utility-scale electricity generation.
 Publications from this body of work, including links to download RAND’s publicly available “Calculating Uncertainty in Biomass Emissions” (CUBE) model, can be found here.
 See specifically http://www.rand.org/pubs/technical_reports/TR984.html.
 Originally reported as 2014 CAD$27 to 38 per tCO2 and converted to 2014 USD$31.0-$43.70 using an exchange rate of 1.15 CAD:1 USD.
 Estimating marginal abatement cost for different energy technologies involves many assumptions (e.g., geographic location, fuel mix of existing electricity supply, technological progress of competing technologies) and is a field of study in its own right. However, for some ballpark numbers of abatement costs for a range of low-carbon technologies, see Figure 4.6 in this EIA report.
 The National Renewable Energy Lab (NREL) estimated both the technical and economic potential of biopower in the United States and concluded that Pennsylvania had the technical potential to support approximately 2 GW of biopower and supply 13.4 TWh per year, where biopower includes both solid biomass potential and biogas such as methane. Including economic factors, the potential dropped considerably to 0.8 GW of potential capacity and 6.6 TWh of electricity generation per year.