Bibliography - H. Jin

1. Jin, H., Eric Larson, and F. E. Celik, 2009: Performance and Cost Analysis of Future, Commercially-Mature Gasification-Based Electric Power Generation from Switchgrass. Biofuels, Bioproducts, Biorefining, 3(2), doi:10.1002/bbb.138 142-173
   [ Abstract ]

   Detailed process designs and mass/energy balances are developed using a consistent modeling framework and input parameter assumptions for biomass-based power generation at large scale (4536 dry metric tonnes per day switchgrass input), assuming future commercially mature component equipment performance levels. The simulated systems include two gasifi cation-based gas turbine combined cycles (B-IGCC) designed around different gasifi er technologies, one gasifi cation-based solid oxide fuel cell cycle (B-IGSOFC), and a steam-Rankine cycle. The simulated design-point effi ciency of the B-IGSOFC is the highest among all systems (51.8%, LHV basis), with modestly lower effi ciencies for the B-IGCC design using a pressurized, oxygen-blown gasifi er (49.5% LHV) and for the B-IGCC design using a low-pressure indirectly heated gasifi er (48.6%, LHV). The steam-Rankine system has a simulated effi ciency of 33.0% (LHV). Detailed capital costs are estimated assuming commercially mature (‘N^th plant’) technologies for the two B-IGCC and the steam-Rankine systems. B-IGCC systems are more capital-intensive than the steam-Rankine system, but discounted cash fl ow rate of return calculations highlight the total cost advantage of the B-IGCC systems when biomass prices are higher. Uncertainties regarding prospective mature-technology costs for solid oxide fuel cells and hot gas sulfur clean-up technologies assumed for the B-IGSOFC performance analysis make it diffi cult to evaluate the prospective electricity generating costs for B-IGSOFC relative to B-IGCC. The rough analysis here suggests that B-IGSOFC will not show improved economics relative to B-IGCC at the large scale considered here.

2. Larson, Eric, H. Jin, and F. E. Celik, 2009: Large-Scale Gasification-Based Co-Production of Fuels and Electricity from Switchgrass. Biofuels, Bioproducts, Biorefining, 3(2), doi:10.1002/bbb.137 174-194
   [ Abstract ]

   Large-scale gasifi cation-based systems for producing Fischer-Tropsch (F-T) fuels (diesel and gasoline blendstocks), dimethyl ether (DME), or hydrogen from switchgrass – with electricity as a coproduct in each case – are assessed using a self-consistent design, simulation, and cost analysis framework. We provide an overview of alternative process designs for coproducing these fuels and power assuming commercially mature technology performance and discuss the commercial status of key component technologies. Overall effi ciencies (lower-heatingvalue basis) of producing fuels plus electricity in these designs ranges from 57% for F-T fuels, 55–61% for DME, and 58–64% for hydrogen. Detailed capital cost estimates for each design are developed, on the basis of which prospective commercial economics of future large-scale facilities that coproduce fuels and power are evaluated.

3. Larson, Eric, Robert H. Williams, and H. Jin, June 2006: Fuels and electricity from biomass with CO₂ capture and storage. Proceedings of the 8th International Conference on Greenhouse Gas Control Technologies (GHGT-8), Trondheim, Norway, http://www.princeton.edu/pei/energy/publications/texts/IK-Larson-et-al-GHGT8-FI,
   [ Abstract ]

   Mass/energy balances and financial analysis are presented for (1) plants co-producing Fischer- Tropsch diesel and gasoline blendstocks plus electricity from biomass and (2) biomass integrated gasification combined cycle power plants. Plant designs with and without carbon capture and storage are analyzed. The feedstock is switchgrass. For plants with CO₂ capture, we assume that the CO₂ is stored in deep saline aquifers or used for enhanced oil recovery.

4. Williams, Robert H., Eric Larson, and H. Jin, May 2006: Comparing climate - change mitigating potentials of alternative synthetic liquid fuel technologies using biomass and coal. Proceedings of the 5th Annual Conference on Carbon Capture and Sequestration, http://www.netl.doe.gov/publications/proceedings/06/carbon-seq/Tech%20Session%20178.pdf,
   [ Abstract ]

   The climate-change mitigation potentials of alternative options for making synthetic liquid fuel from coal and biomass without and with CO₂ capture and storage are explored. The emphasis is on making Fischer-Tropsch liquids, with comparisons to cellulosic ethanol. Particular attention is given to exploitation of the negative CO₂ emissions potential of CO₂ capture and storage for bioenergy systems. One Fischer-Tropsch option involves coprocessing biomass and coal. All liquid fuel production options involve production of electricity as a net coproduct. Both CO₂ aquifer storage and CO₂ enhanced oil recovery options are analyzed. The metrics by which the alternatives are compared are: (i) the net greenhouse gas emission rate associated with liquid fuel production and use, (ii) the specific capital cost of liquid fuel production, (iii) the lifecycle cost calculated for a fixed capital charge rate, and (iv) the internal rate of return on equity as a function of both the crude oil price and the price of greenhouse gas emissions. In addition, for options that involve biomass, liquid fuel yields per tonne of biomass are compared. And for enhanced oil recovery applications of the captured CO₂, the relative profitability of using CO₂ from synfuel plants and integrated gasifier combined cycle power plants is explored.

5. Williams, Robert H., Eric Larson, and H. Jin, June 2006: Synthetic fuels in a world with high oil and carbon prices. Proceedings of the 8th International Conference on Greenhouse Gas Control Technologies (GHGT-8), http://www.futurecoalfuels.org/documents/032007_williams.pdf,
   [ Abstract ]

   Four carbon management options are investigated for making Fischer-Tropsch fuels plus electricity: three processing coal and one co-processing coal and biomass. Energy and carbon balances are estimated. Economic analyses are carried out for carbon prices of $0 and $100 per tonne of carbon. Both levelized costs and internal rates of return on equity are estimated with CO₂ vented, and with CO₂ captured and stored in saline aquifers, and with CO₂ captured and used for enhanced oil recovery. Comparisons are made with coal integrated gasifier combined cycle power plants. When the carbon price is $100 per tonne of carbon, the co-processing option is the most economically attractive option for making Fischer-Tropsch liquids. Even at zero carbon price enhanced oil recovery applications of captured CO₂ will often be economically attractive where such opportunities exist. Enhanced oil recovery is a sufficiently large and economically interesting niche in the USA (and perhaps elsewhere) that it could enable wide near-term experience with gasification-based energy and carbon capture and storage technologies.

6. Larson, Eric, H. Jin, and F. E. Celik, October 2005: Gasification-Based Fuels and Electricity Production from Biomass, without and with Carbon Capture and Storage. Princeton Environmental Institute, Princeton University, http://www.hydrogen.energy.gov/analysis_repository/project.cfm/PID=226,
   [ Abstract ]

   We report here on design, mass-and-energy-balance calculations, and production cost estimates for gasification-based thermochemical conversion of switchgrass into Fischer-Tropsch (F-T) fuels, dimethyl ether (DME), and hydrogen, in all cases with some level of co-production of electricity. Also, some process designs are developed and analyzed that include capture of byproduct CO₂ for underground storage. Additionally, we present results for stand-alone electricity production using integrated gasification combined-cycle technology, both with and without carbon capture and storage (CCS). The feedstock considered in all cases is switchgrass, and the reference production scale is an “as received” input of 5,670 metric tons per day (tpd) of switchgrass having a moisture content of 20%. This corresponds to a dry matter flow of 4,536 tpd (or 5000 dry short tons per day). The 20% moisture level is sufficiently low that active drying of the feed material is not necessary before gasification. This saves considerable capital cost by avoiding a dryer, while imposing little if any efficiency penalty relative to systems with active drying utilizing low-grade waste heat. The physical and chemical characteristics of the assumed switchgrass are given in Table 1. The energy flow corresponding to 5,670 tpd of 20% moisture switchgrass is 983 MW higher heating value or 893 MW lower heating value.

7. Larson, Eric, and H. Jin, et al., 2004: Thermochemical Fuels Production from Switchgrass. , Princeton, NJ, Princeton Environmental Institute, Unpublished

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