Policy Implications of Allocation Methods in the Life Cycle Analysis of Integrated Corn and Corn Stover Ethanol Production
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A biorefinery may produce multiple fuels from more than one feedstock. The ability of these fuels to qualify as one of the four types of biofuels under the US Renewable Fuel Standard and to achieve a low carbon intensity score under California’s Low Carbon Fuel Standard can be strongly influenced by the approach taken to their life cycle analysis (LCA). For example, in facilities that may co-produce corn grain and corn stover ethanol, the ethanol production processes can share the combined heat and power (CHP) that is produced from the lignin and liquid residues from stover ethanol production. We examine different LCA approaches to corn grain and stover ethanol production considering different approaches to CHP treatment. In the baseline scenario, CHP meets the energy demands of stover ethanol production first, with additional heat and electricity generated sent to grain ethanol production. The resulting greenhouse gas (GHG) emissions for grain and stover ethanol are 57 and 25 g-CO2eq/MJ, respectively, corresponding to a 40 and 74 % reduction compared to the GHG emissions of gasoline. We illustrate that emissions depend on allocation of burdens of CHP production and corn farming, along with the facility capacities. Co-product handling techniques can strongly influence LCA results and should therefore be transparently documented.
KeywordsEthanol Corn Corn stover GHG emissions Integrated facility Life cycle analysis
In 2014, the USA produced 54 billion liters of ethanol . The country exported 3.0 billion liters and imported 2.7 billion liters. Two hundred ten ethanol biorefineries in 28 states contributed to ethanol production . Iowa has the largest ethanol production capacity at over 15 billion liters per year (BLY), followed by Nebraska at almost 7.6 BLY . Production occurs as far west as California and as far south as Louisiana. The predominant feedstock is corn grain, but some ethanol plants use a corn/sorghum blend, sugar cane bagasse, cheese whey, and various waste biomass as feedstocks. Plants have been built in the past few years to convert corn stover to ethanol. Since 2012, 1.4 million gallons of cellulosic ethanol has come onto the US market . This volume is expected to increase as two cellulosic ethanol projects move towards capacity-level production. Construction is nearly complete at a DuPont facility in Iowa projected to use 340,000 tonnes of corn stover a year to produce 100 million liters per year (MLY) of ethanol . An operational Abengoa plant that converts cellulosic biomass to ethanol in Hugoton, Kansas, has a capacity of 95 MLY . Approximately 80 % of the biomass will be corn stover . The remaining 20 % will come from wheat straw, milo stubble, and switchgrass . Another facility in Iowa, built by POET, was completed in the late 2014 and uses approximately 250,000 tonnes of corn stover per year to produce 75 MLY of ethanol [3, 8].
One interesting aspect that POET has pursued is to co-locate production of cellulosic ethanol next to a corn grain ethanol plant. One objective of this strategy is to increase total ethanol output from the biorefinery to 3.8 BLY . Another advantage of the co-location of ethanol production from the two feedstocks is that the heat and power available from combustion of the lignin fraction of the stover and other liquid residues could be shared between the two ethanol production trains . While this co-location and subsequent heat integration could save energy and reduce costs (besides cost savings from sharing ethanol storage and transportation logistics), it raises interesting life cycle analysis (LCA) questions as to how to allocate conversion process greenhouse gas (GHG) intensities to the corn grain ethanol and corn stover ethanol. Furthermore, the feedstock production stage of ethanol’s life cycle can be revisited with an eye towards viewing corn grain and stover harvest as an integrated system rather than as two independent systems. Decisions about how to treat feedstock production stage and conversion stage GHG emissions will influence corn grain and corn stover ethanol’s life cycle GHG emissions.
The Renewable Fuel Standard (the so-called RFS2), included in the Energy Policy Act of 2007, defined four types of biofuels and outlined the volume of renewable fuels that would be used in the country [10, 11]. This legislation set volumetric targets for four biofuel categories with associated life cycle greenhouse gas (GHG) reduction thresholds when compared with a 2005 petroleum fuel baseline. RFS2 mandates that by 2022, 136 BLY of biofuels should be produced, with a maximum of 57 BLY coming from corn grain ethanol . Corn ethanol must have life cycle greenhouse gas (GHG) emissions at least 20 % below that of conventional gasoline. The RFS2 also mandates production of another biofuel category, called advanced biofuels, which must achieve a 50 % reduction in GHG emissions compared to baseline fossil fuels. By 2022, 80 BLY of advanced biofuels should be produced. Cellulosic biofuels, another biofuel category, must have a 60 % reduction in GHG emissions. Their target production by 2022 is 61 BLY. Cellulosic biofuels are made from cellulose, hemicellulose, or lignin. Ethanol produced from the fermentation of corn stover falls in this category . Another biofuel category is biomass-based diesel. By 2022, 4 BLY of fuel that is 50 % less GHG intensive that conventional diesel is the volumetric target and it has already been met .
The US Environmental Protection Agency (EPA) determines whether a given biofuel falls into any of the four categories established in the RFS2. To determine life cycle GHG emissions of biofuel pathways, which include GHG emissions from feedstock production and transportation, land-use change (LUC), feedstock conversion to fuel, fuel transportation, and fuel combustion, the EPA conducts life cycle analyses (LCA) that are specific to a certain feedstock (e.g., corn stover) and final fuel (e.g., ethanol) . The EPA requires that each pathway subject to analysis has a single feedstock and single final fuel.
The estimation of life cycle GHG emissions of biofuel pathways also affects their attractiveness under California’s Low Carbon Fuel Standard (LCFS), a performance-based standard that aims for a 10 % reduction in GHG emission intensity of transportation fuels by 2020 relative to the 2010 level . Similar to the EPA’s approach, biofuel LCAs conducted to establish eligibility for the LCFS must consider a single feedstock’s conversion to a single final fuel . Oregon has recently adopted an LCFS that targets a 10 % reduction in transportation fuel GHG intensity by 2025 . Washington is also looking to adopt similar legislation . Another piece of legislation in development for 11 other states is the Northeast and Mid-Atlantic LCFS.
In the case of the RFS2, each feedstock (or feedstock blend) must be converted to a single fuel product that would qualify as either a conventional, renewable, advanced, or cellulosic biofuel. (Corn ethanol is considered a “conventional” biofuel, essentially a subcategory within the renewable category because production of corn ethanol is capped at 15 billion gallons per year whereas production of other biofuels that could be classified as renewable is not capped.) This requirement forces allocation of GHG emissions from a single conversion facility processing more than one feedstock among the final fuel products and has significant implications for integrated production scenarios such as those pursued by POET. These biorefineries could produce a single biofuel stream containing some fuel molecules that could qualify as cellulosic biofuels and some that could qualify only as renewable (in the case of corn ethanol, conventional) biofuels. In the case of the LCFS, these different fuel molecules would contribute differing levels of emission reductions. It is an open question as to how to treat this blended fuel stream in biofuel LCA for regulation purposes, especially with the RFS2 biofuel categories.
Some previous studies have considered one or both of the life cycle GHG emissions and techno-economic aspects of combined processing of corn stover and corn grain. Murphy and Kendal , for example, examined the influence of different co-product handling techniques on the GHG intensity of co-produced corn and corn stover but did not examine the full life cycle of biofuels produced from these feedstocks combined. Several studies [20, 21, 22] examined how corn stover might be integrated as a source of biopower at corn ethanol plants, but two of these studies were limited to a techno-economic perspective and did not consider life cycle GHG emissions. In addition, Ou et al.  examined the economic performance of co-located corn grain and stover ethanol plants. Finally, Kauffman et al.  consider converting corn grain and corn stover produced on the same hectare of land to ethanol and gasoline (via pyrolysis), respectively, and calculate the life cycle GHG emissions of these fuels. The analysis does not consider co-location of the pyrolysis and ethanol plants and how they might share utilities. None of these studies consider the sensitivity of life cycle GHG emissions of co-produced fuels to co-product handling techniques and the ensuing renewable fuel policy (RFS, LCFS) implications.
In this paper, we examine the implications of different approaches to estimating life cycle GHG emissions of corn grain ethanol and corn stover ethanol produced at an integrated biorefinery. We develop results for a single ethanol stream and for separate ethanol streams produced either from corn grain or corn stover. In the latter case, we examine the influence of treatment of feedstock production as separate or integrated and of the treatment of combined heat and power (CHP)-produced energy at the conversion facility. The objective of this analysis is to illuminate challenges in applying the RFS2 and LCFS frameworks to biorefineries integrating corn grain and corn stover ethanol production. Conclusions of this work could also apply to integrated biorefineries that use multiple feedstocks to produce other biofuels besides ethanol.
The life cycle GHG emissions of biofuels can be estimated through LCA using a model such as Argonne National Laboratory’s Greenhouse gases, Regulated Emissions and Energy use in Transportation (GREET™). The US EPA used GREET, along with several other models, in developing life cycle GHG estimates for biofuels addressed in the RFS2 . CARB uses a California-specific version of GREET (CA-GREET) to develop estimates of the life cycle GHG intensity of biofuel pathways for its LCFS legislation . In this analysis, we use the GREET version released in October 2014.
Goal and Scope
The functional unit for this analysis is 1 MJ of ethanol. Life cycle GHG emissions were calculated for corn grain and stover ethanol separately and for a single ethanol stream produced from both feedstocks. Figure 1 shows the boundary diagram for the integrated scenario. We treat CO2 emissions from ethanol combustion during vehicle operation as offset by carbon uptake during feedstock growth, which in the case of corn grain and corn stover occurred in the recent past. The net GHG emissions from ethanol combustion and carbon uptake are minimal and are estimated to be about 0.4 g-CO2eq/MJ depending on the CH4 and N2O emission factors of ethanol combustion. We include land-use change (LUC) GHG emissions. We describe our development of LUC GHG emissions that are used in this analysis in a separate publication .
Materials and energy consumed during corn farming, corn transportation and the production of ethanol from corn grain for the baseline scenario (Argonne National Laboratory, 2014)
Grain harvest energy
Corn grain transportation
Grain ethanol yield
L ethanol/dry tonne
Dry DGS produced
Materials and energy consumed during corn stover collection, corn stover transportation, and the production of ethanol from corn stover (Argonne National Laboratory, 2014)
Stover removal rate
Stover harvest energy
Stover transportation energy
kg/dry tonne stover
kg/dry tonne stover
kg/dry tonne stover
Stover ethanol yield
L ethanol/dry tonne
Energy and materials consumed and energy produced during ethanol production at an integrated corn grain and corn stover plant. Amounts are presented for 1 L of grain, stover, and total ethanol production (from both feedstocks)
Stover ethanol yield (L/dry tonne)
Grain ethanol yield (L ethanol/tonne grain)
Natural gas (MJ/L)
CHP electricity generated (MJ/L)
CHP heat generated (MJ/L)
Alpha amylase (g/L)
Gluco amylase (g/L)
Sulfuric acid (g/L)
Corn steep liquor (g/L)
When corn stover ethanol is considered to be produced at an isolated facility, surplus electricity could be available from the CHP plant and exported to the grid [9, 31]. In that case, the corn stover ethanol receives a fairly large GHG emission reduction credit (as much as 18 g-CO2eq/MJ) for displacing conventional electricity. At an integrated facility, both corn grain and corn stover ethanol production could rely on the heat and electricity CHP produces, which reduces electricity and NG consumption in corn ethanol production. The impact of the internal displacement could be addressed properly by a process-level allocation. With a process-level allocation, the heat and electricity from CHP is considered a co-product of stover ethanol since they are derived from stover ethanol residues. Thus, the energy use and GHG emissions from corn stover harvesting, conversion, and LUC are allocated between stover ethanol and generated electricity and heat by their energy content.
In the baseline scenario, the energy demands for stover ethanol production are met first; and any additional energy from CHP is applied to grain ethanol production. The DGS co-product of corn ethanol displaces conventional animal feed (corn and soybean meal); corn ethanol is assigned as the corresponding displacement credit 15 g-CO2eq/MJ-corn ethanol . It would also be possible to treat the corn grain ethanol and its dry DGS (DDGS) co-product with energy or market value allocation techniques , but those methods were not evaluated in this analysis.
Alternative Allocation Scenarios
Within an LCA of integrated corn grain and corn stover ethanol production, options exist as to how to allocate energy and environmental burdens among products and co-products of both the farming stage and the conversion stage. Certainly, it is worthwhile to examine these options because co-product allocation choices can influence LCA results . Decisions about co-product allocation must be clearly documented so that LCA results are transparent. In the base case farming scenario, we apply an attributional approach to allocation and the only energy consumption and emission burdens tied to corn stover are those associated with stover collection and supplemental fertilizer application. Alternatively, energy and emission burdens of corn agriculture (including LUC) could be allocated between the grain and stover on a mass or energy basis (or market revenue based). In the case of mass allocation, GHG emissions are allocated based on the total mass of feedstock harvested from each unit area. The approach to allocating burdens on an energy basis is similar but replaces the mass of feedstock with its energy content. We investigated each of these alternative allocation scenarios.
CHP allocation scenarios as compared to the baseline. The demands for external energy are given for 1 L of grain, stover, and combined ethanol (from both feedstocks) after CHP heat and electricity are applied. The electricity demand for both feedstocks is met by CHP, so no additional electricity is required
Corn farming allocation
CHP energy share
Natural gas (MJ/L)
Natural gas (MJ/L)
Natural gas (MJ/L)
Fulfill corn stover demand
Ethanol production allocationa
Fulfill corn grain demand
Results and Discussion
Baseline GHG Emissions
Also presented in Fig. 2 are the combined ethanol GHG emissions, which are the total emissions of a single ethanol stream coming out of the integrated plant. Results are presented as a combined liter of ethanol, of which 73 and 27 % come from corn grain and corn stover, respectively. The total GHG emissions of ethanol produced at the integrated plant are 48 g-CO2eq/MJ, with the largest portion of the emissions coming from corn farming and transportation at 26 g-CO2eq/MJ, then ethanol production at 23 g-CO2eq/MJ. When the integrated scenario results are compared to gasoline, the combined ethanol liter achieves a 49 % reduction assuming the GHG intensity of gasoline is 94 g-CO2eq/MJ . When corn grain and corn stover ethanol are treated in isolation, the associated GHG emission reductions are 40 and 74 %, respectively. The result of corn stover ethanol when based on integrated ethanol production is similar to previous studies with the GHG emissions of this fuel showing a marked emission reduction as compared to gasoline (>60 %)[13, 26, 34].
Alternative Allocation Scenarios
For the baseline, farming energy is allocated based on attribution, meaning the only operations assigned to the corn stover are the energy to collect and transport the stover to the biorefinery and burdens associated with supplemental fertilizer production, application, and fugitive N2O emissions. Allocating the total farming emissions based on the energy content of the feedstocks results in a decrease of the grain ethanol GHG emissions from 57 to 55 g-CO2eq/MJ and an increase in the stover emissions from 25 to 40 g-CO2eq/MJ. The change in the emissions for each feedstock stems from a change in the farming emissions. When energy allocation is applied to corn farming with stover harvest, the GHG intensity of corn grain ethanol decreases by 9 %, while it increases by 140 % for corn stover ethanol. With the energy allocation scenario, both fuels provided a life cycle GHG emission reduction compared to gasoline of 42 and 57 % for grain and stover ethanol, respectively. If mass rather than energy allocation is applied to feedstock production, similar values, 55 and 38 g-CO2eq/MJ, result for grain and stover ethanol, respectively. It is important to note, however, that this treatment of the collection of corn grain and corn stover as an integrated system may not accurately represent the feedstock production stage. At present, farmers may view stover harvest less as a means to produce an additional product from their land, but rather as a technique to manage rising crop residue levels as corn yields increase. This viewpoint is likely more prevalent in areas with high corn yields with a corresponding substantial stover resource.
Treating CHP-Produced Heat and Electricity by Displacement
In this paper, CHP-produced heat and electricity are considered as a co-product of corn stover ethanol production with associated energy and emission burdens. When corn stover ethanol is produced in an individual plant, a common approach to handle CHP-produced heat and electricity is a displacement method where all GHG emissions are allocated to the ethanol and additional electricity is exported to the grid with the ethanol receiving a displacement credit [9, 33]. This methodology can also be applied to the integrated scenario.
When CHP-produced electricity and heat are treated with the displacement method, no GHG emissions are associated with the CHP-produced heat and electricity that is used internally in corn ethanol and corn stover ethanol production. As a result, when corn grain ethanol production consumes the CHP-produced energy, the ethanol receives the benefit of an emission-free energy source. All of the GHG emission burden associated with corn stover that serves as the CHP energy feedstock are assigned to corn stover ethanol production, regardless of the final fate of the CHP energy. In our analysis, we assume that the displaced electricity is produced from the national average grid mix, which is 0.5, 26.1, 41.5, 19.5, 0.3, and 12.2 % from residual oil, natural gas, coal, nuclear power, biomass, and others (e.g., hydro, geothermal), respectively . The displacement credits are assigned to corn stover ethanol. We generated results for when this displacement method along with the attributional approach to corn grain and stover agriculture is applied to calculation of the GHG emissions for the baseline scenario. Corn stover receives the CHP-produced energy first. Compared to a scenario with the same assumptions except the energy allocation method applied to co-produced CHP, the GHG emissions for stover ethanol increase from 25 to 27 g-CO2eq/MJ, while those for grain ethanol decrease from 57 to 54 g-CO2eq/MJ. The change in emissions is relatively small because 88 % of the heat and electricity is utilized by corn stover ethanol, meaning most of the emissions of the CHP co-product are assigned to the stover ethanol production in the baseline scenario. For this scenario, the GHG emission reduction is increased for corn grain from 40 to 42 % but decreased for stover from 74 to 71 %. These results would leave the status of corn grain ethanol and corn stover ethanol as conventional and cellulosic biofuels, respectively. The GHG emissions for the combined liter decrease when CHP is considered a byproduct from 48 to 47 g-CO2eq/MJ. Unlike when CHP-generated electricity is considered a co-product, a displacement credit can be taken for the generated electricity that goes unused at the biorefinery.
The effects of treating CHP as a co-product rather than a byproduct have a greater effect when we consider scenario 1, in which CHP energy is allocated based on ethanol production. It is important to note that burdening corn stover ethanol production with the energy consumption and emissions associated with converting corn stover to CHP-produced energy that is subsequently used by the corn grain ethanol process is likely not an appropriate allocation method for an integrated plant. We present this scenario, however, to highlight the pronounced effect on results that these types of choices in LCA can have. In this case, which essentially ties the burden associated with CHP-produced energy to corn stover ethanol, the GHG emissions in this scenario decrease for grain ethanol from 48 to 40 g-CO2eq/MJ, while they increase for stover ethanol from 48 to 69 g-CO2eq/MJ. The effect of the assumption about CHP energy is much greater because, in this scenario, stover ethanol only utilizes 57 % of the heat and electricity produced by CHP. Under these conditions, corn grain ethanol achieves a GHG emission reduction of 17 %. On the other hand, stover ethanol would only offer a 25 % GHG reduction compared to gasoline and would only qualify as a renewable fuel under RFS2.
Effect of Plant Size on GHG Emissions
Comparison of Life Cycle GHG Emissions from Integrated Versus Separate Analysis of Co-Produced Corn Grain and Corn Stover Ethanol
It is clear that regardless of whether analysis of corn ethanol considers it apart from or together with corn stover ethanol as an integrated liter of ethanol or as a separate liter of ethanol, this biofuel can achieve a 20 % reduction in GHG emissions as compared to baseline gasoline and qualify as a conventional biofuel under the RFS2. (Corn ethanol is not eligible for classification as an advanced or cellulosic biofuel, even if it achieves the GHG emission targets for these fuel categories.) Decisions about LCA methodology, however, strongly affect life cycle GHG results for corn stover ethanol, currently considered to be one of the most promising cellulosic biofuels in the USA. For the alternative CHP scenarios, created solely from changes in accounting technique rather than any physical, on-the-ground change in the life cycle of this biofuel, it no longer offers GHG emissions at a 50 or 60 % GHG reduction compared to gasoline to be classified as an advanced or cellulosic biofuel, respectively.
Conclusions and Policy Implications
One objective of biofuel policies like the RFS2 and LCFS is to increase production volumes of biofuels with large reductions in life cycle GHG emissions as compared to baseline fossil fuels (gasoline, diesel). In this analysis, we examine different LCA scenarios that could influence the volume of high-GHG reduction fuels that integrated corn grain-corn stover ethanol facilities produce. The LCA methodology applied to these facilities can have a direct bearing on the success of biofuel policies. On the one hand, if corn grain ethanol and corn stover ethanol continue to be treated separately as required by RFS2 although they are produced at one facility, LCA methodology choices could increase or decrease volumes of conventional (20 % GHG reduction), advanced (50 % GHG reduction), and cellulosic (60 % GHG reduction) ethanol the facility produces. While the treatment we adopted as the baseline scenario maintains corn stover ethanol as a biofuel that achieves a greater than 60 % reduction as compared to gasoline, the treatments we adopted for scenarios 1 and 2 cause corn stover ethanol to qualify only as a renewable fuel or maybe an advanced biofuel under RFS2 if certain process improvements were realized. Just a 3 % reduction in the ethanol facility energy requirement for scenario 1 and a 10 % reduction for scenario 2 allow stover ethanol to qualify as an advanced biofuel. Under all scenarios, corn grain ethanol remains in the category of conventional biofuel, but the GHG emission reductions are very close to advanced biofuel emission levels (50 % GHG reduction). However, RFS2 prohibits grain ethanol from consideration as an advanced biofuel, even if it meets the GHG emission reduction target.
Even though corn grain ethanol is excluded from the advanced biofuel classification, the integrated scenario still produces ethanol with lower GHG emissions than from an individual plant. In theory, the integrated ethanol pathway is allowed in LCFS certification. Thus, this reduction can help states implementing an LCFS to meet their GHG emission reduction targets for transportation fuels. It is important to note that co-product handling techniques applied to corn grain and stover harvest and CHP-produced energy have a strong influence on results. These techniques raise allocation and crediting issues and can cause LCA to become convoluted and out of touch with the physical system under analysis. Co-product handling techniques that are adopted in biofuel LCA must be documented transparently for the results to be interpreted, especially if they will be applied in a policy context.
In conclusion, as biorefineries expand and mature, they may well use more than one feedstock and produce more than one product. LCAs of these products could adopt many different approaches that will influence the output of different categories of biofuels from these refineries. LCA methodology choices should reflect to the extent possible the physical system subject to analysis and should be transparent. Currently, biofuel policies force separate treatment of fuels that may be co-produced at integrated facilities, which moves the analysis away from this desired reflection of the physical reality of the biorefinery. This construct influences the ability of policies to meet their intended outcomes, and an open dialogue is necessary to examine the influence of LCA requirements of these policies and the application of these policies in the broader community.
This work was supported by the Bioenergy Technologies Office (BETO) of the Office of Energy Efficiency and Renewable Energy of the United States Department of Energy, under Contract DE-AC02-06CH11357. The authors thank Alicia Lindauer, Kristen Johnson, and Zia Haq of the Bioenergy Technologies Office for their support and guidance.
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