The following are reports documenting system studies performed for gasification technologies:

• Alaska Coal Gasification Feasibility Studies - Healy Coal-to-Liquids Plant [PDF-3.6MB] (July 2007)
  This study evaluates the feasibility of building a relatively small coal-to-liquids plant in central Alaska to provide a clean diesel product to Alaska’s refineries. The study concludes that the establishment of a 14,640 barrel per day F-T plant, using 4 million tons per year of coal, could be economic provided the price per barrel of the F-T product is at least $64 per barrel.
• Beluga Coal Gasification Feasibility Study - Phase I Final Report [PDF-4MB] (July 2006)
  This report summarizes the investigation of an IGCC system for a potential  industrial setting on the Cook Inlet, in Nikiski, Alaska. Faced with an increase in natural gas price and a decrease in supply, local industry is investigating alternatives to natural gas as a feed stock for their process plants. This study evaluated a gasification plant that would supply syn-gas to meet the chemical needs of a local application and would also co-produce power to meet on-site demand, and possibly other by-products for local use. The results of the study verified that conversion of a plant from natural gas to syn-gas is technically and economically feasible.
• Comparison of Pratt and Whitney Rocketdyne IGCC and Commercial IGCC Performance [PDF-2.5MB] (June 2006)
  This report compares the performance and cost of commercial Integrated Gasification Combined Cycle (IGCC) plants using General Electric Energy (GEE) and Shell gasifiers with conceptual IGCC plant designs using the Pratt & Whitney Rocketdyne (PWR) compact gasifier. The PWR gasifier is also compared with the GEE gasifier in hydrogen production and carbon capture mode. With the exception of the PWR gasifier, the plants are designed with commercially available equipment to be operational in approximately 2010. All results should be considered preliminary and dictated in large part by the selected design basis.
• Polygeneration of SNG, Hydrogen, Power, and Carbon Dioxide from Texas Lignite [PDF-333KB] (Dec 2004)
  The intent of this study is to investigate the feasibility of siting a lignite conversion plant in Texas at the mine mouth of the Wilcox lignite deposit. The concept is to coproduce at least three products: electric power, hydrogen or substitute natural gas (SNG), and carbon dioxide. The electric power would be sold to the grid, the hydrogen would be sent by pipeline to the Gulf Coast petroleum refineries, the SNG would be sold as a natural gas supplement, and the carbon dioxide would be pipelined to the West Texas oil fields for enhanced oil recovery.
• Potential Application of Coal-Derived Fuel Gases for the Glass Industry: A Scoping Analysis [PDF-254KB] (Dec 2004)
  The objective of this study is to explore the economic viability of producing coal-derived fuel gases for use in the glass manufacturing industry as an alternative to natural gas. In this study small-size gasification systems that suffer adversely from economics of scale were not considered. Instead, full-scale commercial gasification systems were analyzed that could produce enough fuel gas and electric power for several manufacturing plants. The possibility exists to gather a number of large manufacturers in a geographically centralized location in an Industrial Gasification Island (IGI) complex so that a central coal gasification plant could economically provide fuel and power to all of these industries.
• Current and Future IGCC Technologies: Bituminous Coal to Power [PDF-1.3MB] (August 2004)
  In order to evaluate the benefits of the ongoing R&D, fifteen (15) IGCC configurations that produce electric power from bituminous coal were analyzed in this report. Twelve cases do not have carbon capture, and 3 cases capture carbon. The results show that there are potentially significant improvements that could result from continuing research development and demonstration (RD&D) in advanced IGCC systems with and without sequestration, provided that the RD&D achieves the performance and cost levels assumed in this analysis. These improvements include reduced capital costs and improved plant efficiency resulting in about 35 percent reduction in COE compared to current IGCC and sequestration technologies.
• Destec Gasifier IGCC Base Cases [PDF-278KB] (June 2000)
  Two IGCC Base Cases have been developed based on the Destec gasification process. The cases differ primarily in how the generated fuel syngas is cooled and in the gas cleanup sections. The Destec process uses a two stage, oxygen-blown, entrained flow, slagging gasifier. Both cases use a raw gas cooler (which is integrated with the gasifier and other heat exchangers) to generate high pressure superheated steam and a cyclone to remove particulates, which are recycled to the gasifier. The syngas leaves the cyclone at 650^oF for Case 1 and at 1004^oF for Case 2. For Case 1, the fuel gas is further cooled and scrubbed before entering a cold gas cleanup unit (CGCU) using the MDEA/Claus/Scot process for sulfur removal and recovery. For Case 2, fuel gas enters a chloride guard bed that is followed by a hot gas cleanup unit (HGCU) using a transport absorber/regenerator process. The sulfur dioxide generated from the transport regenerator is sent to an acid plant for producing sulfuric acid. Power is recovered for both cases using a modified W501G gas turbine and a three-pressure level reheat steam cycle.
• KRW Gasifier IGCC Base Cases [PDF- 335KB] (June 2000)
  Three IGCC Base Cases have been developed based on the KRW gasification process. The primary differences are dependent on the approach for removing sulfur. Case 1 uses in-bed sulfur capture and a polishing hot gas cleanup section to provide clean fuel gas. Cases 2 and 3 use no in-bed sulfur capture. All cases use a raw gas cooler (which is integrated with the gasifier and other heat exchangers) to generate high pressure superheated steam and cyclones to remove particulates, which are recycled to the gasifier. Gas filters are then used for further cleaning with the fuel gas stream exiting at 1004^oF for all cases. For Case 2, the fuel gas is further cooled and scrubbed before entering a cold gas cleanup unit (CGCU) using the MDEA/Claus/Scot process for sulfur removal and recovery. For Cases 1 and 3, fuel gas enters a chloride guard bed that is followed by a hot gas cleanup unit (HGCU) using a transport absorber/regenerator process. For Case 1, the HGCU section is a polishing process with the sulfur dioxide rich waste stream from the regenerator being combined with the solid waste stream from the gasifier and sent to a sulfator. For Case 3, the sulfur dioxide generated from the transport regenerator is sent to an acid plant for producing sulfuric acid. Power is recovered for all cases using a modified W501G gas turbine and a three-pressure level reheat steam cycle.
• Shell Gasifier IGCC Base Cases [PDF-275KB] (June 2000)
  Two IGCC Base Cases have been developed based on the Shell gasification process. The cases differ primarily in how the generated fuel syngas is cooled and in the gas cleanup sections. The Shell process uses an oxygen-blown, entrained flow, slagging gasifier. Both cases use a raw gas cooler (which is integrated with the gasifier and other heat exchangers) to generate high pressure superheated steam and a ceramic filter to remove particulates, which are recycled to the gasifier. The syngas leaves the ceramic filter at 640^oF for Case 1 and at 1004^oF for Case 2. For Case 1, the fuel gas is further cooled and scrubbed before entering a cold gas cleanup unit (CGCU) using the MDEA/Claus/Scot process for sulfur removal and recovery. For Case 2, fuel gas enters a chloride guard bed, which is followed by a hot gas cleanup unit (HGCU) using a transport absorber/regenerator process. The sulfur dioxide generated from the transport regenerator is sent to an acid plant for producing sulfuric acid. Power is recovered for both cases using a modified W501G gas turbine and a three-pressure level reheat steam cycle.
• Texaco Gasifier IGCC Base Cases [PDF-349KB] (June 2000)
  IGCC Base Cases have been developed for three Texaco Gasifier cases that differ primarily in how the generated fuel syngas is cooled and in the gas cleanup sections. For Case 1, the gasifier system includes a high-pressure water quench section that rapidly reduces the solid/gas mixture to approximately 425^oF (605 psia). The Texaco Radiant/Convective design is used in Cases 2 and 3. In this design, the mix of gas/solids from the gasifier enters a radiant syngas cooling (RSC) system, (perhaps larger in size than the gasifier vessel), where cooling to approximately 1500^oF is accomplished by generating high-pressure steam. For Case 2, a convective syngas cooling (CSC) /gas scrubbing system cools the raw fuel stream to about 305^oF (400 psia) by generating additional steam and by reheating the clean fuel gas from the CGCU section. For Case 3, the CSC is used only to generate steam and cools the syngas to approximately 1004^oF. Cases 1 and 2 use a gas scrubber and a low temperature gas cooling/heat recovery section to reduce the raw fuel gas stream to 103^oF prior to entering a CGCU section for sulfur removal. In Case 3, the raw fuel gas is cleaned for particulates using cyclones and gas filters before entering a chloride guard bed. The sulfur removal is accomplished in a HGCU section and sulfur is recovered using a sulfuric acid plant.
• Transport Gasifier IGCC Base Cases [PDF-256KB] (June 2000)
  Two IGCC Base Cases have been developed based on the Transport gasification process. The cases differ primarily in the oxidant used for the gasification section. Both cases use a raw gas cooler (which is integrated with the gasifier and other heat exchangers) to generate high pressure superheated steam and a ceramic filter to remove particulates, which are recycled to the gasifier. The syngas leaves the gas cooler at 1004^oF for both Cases. The fuel gas enters a chloride guard bed that is followed by a hot gas cleanup unit (HGCU) using a transport absorber/regenerator process. The sulfur dioxide rich waste stream from the HGCU is sent to a sulfator. Power is recovered for both cases using a modified W501G gas turbine and a three-pressure level reheat steam cycle.
• British Gas / Lurgi Gasifier IGCC Base Cases [PDF-273KB] (June 2000)
  Two IGCC Base Cases have been developed based on the BGL gasification process. The BGL process uses an oxygen-blown, moving-bed, slagging gasifier. The Illinois #6 Coal is fed to the gasifier as a mixture of coarse coal (i.e. above 1/4"), fines, and coal briquettes. The oxygen is supplied from a cryogenic air separation plant (ASU) that is integrated with the gas turbine compressor. The steam requirements are furnished from the bottoming steam cycle. In Case 1, the raw fuel gas produced is cooled to remove the heavy hydrocarbon components (tars, oils, naphtha) which are recirculated to the gasifier. After additional cooling, the fuel gas then enters a cold gas cleanup unit (CGCU) using the MDEA/Claus/Scot process for sulfur removal and recovery. The cleaned fuel gas is reheated, resaturated and combined with recirculated nitrogen from the ASU and sent to the gas turbine section. In Case 2, the raw fuel gas is sent through a filter, to remove any particulates, and then through a chloride guard bed before being sent to the transport desulfurization unit. The sulfur dioxide generated from the transport regenerator is sent to an acid plant for producing sulfur dioxide. The cleaned hot fuel gas is combined with recirculated nitrogen from the ASU and sent to the gas turbine section. Power is recovered for both cases using a modified W501G gas turbine and a three-pressure level reheat steam cycle.