COAL TO LIQUIDS NEWS
China coal giant Shenhua plans to invest some $58.5 billion in various coal gasification projects over the next decade, according to a Xinhua news agency report. The schemes would convert coal to fuels, synthetic natural gas (SNG) and methanol. Shenhua already began trial runs at its direct coal liquefaction plant in Inner Mongolia earlier this year and has a second, indirect coal-to-liquids (CTL) project in the works. A Shenhua official was quoted by Xinhua as saying the company plans to start more trial runs at the direct liquefaction plant in July. That plant aims to convert 3.5 million tons/year of coal to 1.08 million tons of diesel and naphtha. In total, Shenhua aims to create CTL capacity for production of some 30 million tons/year of chemicals and fuels by 2020, said Zhang Diankui, vice president, Project Planning, of Shenhua Coal Liquefaction Corp (Beijing). Shenhua plans to invest “400 billion yuan to build seven coal chemical production bases in regions, including Inner Mongolia, Ningxia, Xinjiang, Shaanxi and Shanxi,” he added.
Australia’s Syntech Resources, a subsidiary of German investor group, Direct Invest, announced this month that it aims to put $500 million into a Surat Basin coal mine as part of a planned $1.5 billion coal-to-liquids (CTL) project. According to an announcement from Australia’s trade minister Simon Crean, obtained by Gasification News, Direct Invest has already invested $250 million in the Surat Basin coal project and will invest a further $250 million to make the mine operational. “Construction on the [first phase of the project] will start in July, creating 100 jobs, while a further 100 jobs will be created once the mine opens,” Crean said. “Initial [coal] shipments are expected to start in the second half of 2010 with an annual capacity of 1.5 million tons.” Phase 2 of the Surat Basin project is expected to commence in 2013 with total employment expected to expand up to 600 jobs, he said. “Direct Invest also announced that it will significantly increase its investment in Australian clean coal projects, including coal-to-liquid (CTL), gas-to-liquid (GTL), as well as carbon capture and storage,” Crean added. “Direct Invest says that its investment in Australian clean coal technology projects is likely to rise to more than $1.5 billion over the next 5 years. The first project is the Sunstate CTL/GTL project, also located in the Surat Basin, and the second project to be located in New South Wales is in the preparatory stages. “Direct Invest received support from the Australian Government’s trade and investment development agency, Austrade, and from the Queensland government . . . “Direct Invest has interests in clean coal technologies – coal to liquid, gas to liquid and developments in CCTL (Clean Coal to Liquids) that enables carbon capture and storage [with] more than $7 million investments to date with the potential to invest more than $1.5 billion dollars in this technology development over next 5 years,” he added. In a separate report from Business Day (Australia), Direct Invest director, Erik Schaefer, was quoted as saying that the schemes would be “viable in a carbon-constrained economy with no need for government subsidies.” Sunstate GTL has been touted by Australia’s Pacific GTL Ltd. as an (A)$1.5 billion coal-seam methane conversion scheme, aiming to produce 17,000 barrels/day of Fischer-Tropsch liquids (mostly diesel). The proposed plant would be located in the Darling Downs area west of Brisbane and, according to Pacific GTL, would employ Syntroleum FT technology. – Jack Peckham
Linc Energy announced June 24 that it has appointed UBS Investment Bank to advise on divestment of an estimated 5 billion tons of company coal tenements in mining areas at Emerald (Teresa), Galilee and Pentland, all in Queensland, Australia. Funds from an eventual sale would support Linc’s planned underground coal gasification (UCG) and coal-to-liquids (CTL) projects. “Linc Energy will duly discontinue its current exclusive negotiation with Chinese coal group Yanzhou Coal and related entities,” Linc announced. “Linc has decided that, though negotiations have been ongoing, the buyer's timetable to complete a purchase is no longer in the best interests of Linc Energy and its shareholders. “With interest from potential bidders increasing and the overall confidence in the coal sector improving significantly, Linc Energy views the best mechanism for delivering value to shareholders for these assets would be via a competitive sales process conducted by UBS instead of continuing the existing negotiation. “The divestment of any of these Queensland assets will not delay or adversely impact Linc's UCG/GTL commercialization strategy in South Australia or overseas.” – Jack Peckham
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CARBON STORAGE
Foster Wheeler on June 17 inked a technical services agreement for a pre-front-end engineering design (pre-FEED) for a proposed flue-gas CO2 capture project in the UK. CO2 capture would be part of E.ON’s proposed supercritical-technology conversion of a coal-fired power station in Kent, England. Consortium partner for the project is Mitsubishi Heavy Industries (MHI), which is supplying its “KM CDR” amine solvent-based CO2 capture technology. MHI says this scheme offers “low energy consumption, low solvent degradation, and reduced corrosion within the equipment.” E.ON is asking the UK government for CO2 capture & storage (CCS) funding as part of its Kingsnorth Power Station conversion project. Some 2 million tons/year of CO2 from the retrofitted plant would be stored within a depleted North Sea gas reservoir. – Jack Peckham
U.S. power producer Tenasaka announced June 18 that it chose Fluor for engineering, procurement & construction (EPC) on its proposed 600-MW (net) “Trailblazer” supercritical pulverized-coal power plant in Nolan County, Texas. The plant would include up to 90% CO2 capture & storage (CCS). Tenaska told Gasification News that it hasn’t yet selected a CO2 capture technology. A final decision whether to move ahead with Trailblazer will be made next year. New Texas legislation offers financial incentives for clean-coal plants that involve CO2 capture & storage (CCS), Tenaska pointed out. The new legislation also includes grant funds to help pay for front-end engineering & design (FEED) studies for CCS. The $3.5 billion plant, if built, “is expected to be the first conventional commercial coal-fueled power plant in the United States, and possibly worldwide, to produce electricity while designed to capture 85 to 90% of the CO2 emissions and providing for its use in enhanced oil recovery (EOR) and geologic storage,” Tenaska said. Trailblazer has already received a draft air permit from the Texas Commission on Environmental Quality (TCEQ) and has received a “screening study” from the Electric Reliability Council of Texas (ERCOT). Plant construction could begin as early as 2010, with operation in 2015, Tenaska said. -- Jack Peckham
U.S. Dept. of Energy (DOE) on June 11 announced selection of nine CO2 capture schemes for future integrated gasification combined cycle (IGCC) plants. The selected schemes include high-temperature membranes, with the following universities and a commercial producer:
·University of Minnesota, Minneapolis, Minn.—This project aims to develop defect-free, contaminant-resistant, hydrothermally stable molecular sieve membrane films with minimally tortuous path for diffusion of the preferred hydrogen molecules from the shifted synthesis gas mixtures (DOE share: $793,775; recipient share: $199,997; duration: 48 months). ·Pall Corp., Cortland, N.Y.—Pall Corporation will leverage its proprietary combinatorial membrane fabrication technology to screen a large number of potential ternary palladium (Pd)-alloys for sulfur-tolerant, phase-stabilized hydrogen transport membrane candidates for separating hydrogen from shifted synthesis gas mixtures (DOE share: $1,207,289; recipient share: $310,000; duration: 36 months). ·Arizona State University, Tempe, Ariz.—Researchers at Arizona State will integrate the water gas shift reaction with a CO2 selective membrane to separate CO2 from shifted synthesis gas (DOE share: $656,316; recipient share: $164,088; duration: 48 months). Another selected scheme is for high-efficiency solvents: ·SRI International, Menlo Park, Calif.—SRI will use aqueous NH4CO3 based solvents to capture high-pressure CO2 at lower solvent cost and with an efficient regeneration process (DOE share: $1,998,455; recipient share: $399,691 [will be increased to $499,613 to meet the 20% requirement]; duration: 24 months). A third scheme is for solid sorbents, involving two companies: ·TDA Research, Inc., Wheat Ridge, Colo.—TDA will develop novel mesoporous carbon with Lewis base functionalized groups that remove CO2 via physical adsorption (DOE share: $2,000,000; recipient share: $500,000; duration: 24 months). ·URS Group, Austin, Texas—Using a molecular computational approach to formulate and then fabricate superior sorbent material, URS Group will combine modeling and experiments to tailor sorbents properties for optimum CO2 capture (DOE share: $1,999,934; recipient share: $684,462; duration: 36 months). DOE also solicited “novel ideas” on CO2 capture. Winning grantees include: ·Gas Technology Institute, Des Plaines, Ill.—GTI will couple an engineered plastic contactor with an appropriate solvent to potentially achieve 60% operating cost and 70% capital cost reduction (DOE share: $999,607; recipient share: $273,846; duration: 24 months). ·Membrane Technology and Research, Inc., Menlo Park, Calif.—Membrane Technology and Research will develop a novel polymer membrane(s) for the separation of hydrogen from shifted synthesis gas (DOE share: $952,764; recipient share: $240,061; duration: 24 months). ·New Jersey Institute of Technology, Newark, N.J.—Researchers propose a pressure swing absorption approach to capture CO2 using an ionic liquid incorporated in either a ceramic hollow tube or polytetrafluoroethylene (PTFE) fiber membrane (DOE share: $805,819; recipient share: $206,017; duration: 36 months).
U.S. Dept. of Energy on June 15 unveiled an amended “round 3” funding opportunities announcement (FOA) for CO2 capture & storage (CCS) under the “Clean Coal Power Initiative” program. “DOE anticipates making multiple awards under this FOA and may be able to provide up to $1.4 billion to be distributed among projects selected under both the previous closing date of January 20, 2009 and the new closing date of August 24, 2009,” DOE said. “Of the total amount, approximately $800 million in DOE funding is being made available under the Recovery Act. The projects will be cost-shared, with the award recipient(s) providing at least 50% of funds for the project. . . . “Notable modifications made under this amendment include the following: Carbon capture technologies must operate at 50% carbon capture efficiency and make progress toward a target CO2 capture efficiency of 90%t in a gas stream containing at least 10% CO2 by volume. “Projects must use domestic mined coal or coal refuse for at least 55% of energy input. . . . “Per a legislative change contained in the Omnibus Appropriations Act of 2009, 70% of program funds are no longer required to be used to fund projects on coal-based gasification technologies. “Applicants, including those who wish to re-submit or modify their submission from the January 20, 2009 closing date, must apply under the August 24, 2009 closing date. Selection announcements are anticipated for October 2009.”
-- Industrial CO2 FOA
Meantime, DOE unveiled yet another CO2 “FOA,” this time including projects that would use captured CO2 for “beneficial use.” “DOE anticipates making multiple awards under this FOA,” the agency said. “The projects will be cost-shared, with the award recipients providing at least 20% of the total funding required for each project. DOE expects to provide more than $1.4 billion to the selected projects . . . “Projects will be selected in two technology areas: ·Large-scale industrial carbon capture and sequestration projects from industrial sources ($1.3 billion)—The objective of this technology area is to demonstrate advanced technologies that capture CO2 emissions from industrial sources—such as cement plants, chemical plants, refineries, steel and aluminum plants, and manufacturing facilities—and store the CO2 in deep saline formations and deep geologic systems including basalts, operating or depleted oil and gas fields, and unmineable coal seams. In the evaluation process, greater weight will be given to projects that propose to capture and sequester 1 million tons of CO2 per plant per year by 2015 as an integral component of commercial operation. ·Innovative concepts for beneficial CO2 use ($100 million)—The objective of this technology area is to demonstrate innovative concepts for beneficial CO2 use, where ‘use’ is defined as the permanent conversion of CO2 from flue gas into another form such as solid carbonates, plastics, and fuels. These breakthrough concepts have the potential to mitigate CO2 emission in areas of the country where geologic storage may not be an optimal solution.” The closing date for applications is August 7, 2009. Selection announcements are anticipated in September 2009, DOE said.
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In Other Sectors
Los Angeles based synthetic fuels developer Rentech announced June 24 that it just bought 100% of biomass gasification technology SilvaGas and 25% of bioenergy project developer ClearFuels. “These agreements represent major steps forward in Rentech’s strategy of offering integrated solutions for the conversion of various types of urban and rural biomass feedstocks into high-value energy products such as renewable synthetic jet fuel, diesel fuel and electric power,” Rentech said. “With the SilvaGas acquisition, Rentech acquires a biomass gasification technology that has operated at commercial scale and is planned for deployment at Rentech’s Rialto Renewable Energy Center under a licensing agreement with SilvaGas,” Rentech said. “The SilvaGas gasifier can handle urban waste streams that are more varied than the virgin biomass streams that the ClearFuels gasifier has been optimized to convert.” ClearFuels’ technology, in contrast, “can convert rural virgin biomass feedstocks into syngas that is cleaner and requires less conditioning, leading to highly efficient conversion into synthetic liquid fuels,” Rentech said. “Commercial deployment of the ClearFuels technology first requires the construction and operation of a demonstration scale facility, on which Rentech and ClearFuels will collaborate by placing a ClearFuels gasifier at Rentech’s PDU [process development unit] in Colorado.” Integration of the gasification technologies with Rentech’s syngas conditioning and cleanup technology and its Fischer-Tropsch fuels technology “will enable Rentech to offer integrated packages for renewable fuels and power production. These offerings can be tailored to optimize the conversion of a variety of renewable feedstock types into ultra-clean diesel fuel, jet fuel and electric power,” the company said. Recent U.S. federal “renewable fuel standard-2” rules mandating 21 billion gallons of “advanced” biofuels open opportunities for biomass-to-liquids (BTL) fuels schemes, the company pointed out. Meantime, parallel U.S. legislation expected to create a Renewable Portfolio Standard (RPS) for electric power also would favor biomass gasification power, Rentech said. Hunt Ramsbottom, Rentech CEO, said: “With the acquisition of SilvaGas’ biomass gasification process, Rentech will own a complete technology offering for the production of renewable fuels and power. This biomass gasification technology provides us with the flexibility to choose from multiple low-value urban feedstocks to produce any of several high-value products such as jet and diesel fuels and power, depending on the market we are in.” – Jack Peckham
Atlanta-based Global Energy Holdings Group announced June 9 that it received notice from the NYSE Amex stock exchange that Global Energy is not in compliance with the continued listing standards. Reason for the listing: it has sustained losses or its financial condition has become so impaired that it appears questionable, in the opinion of NYSE Amex, as to whether Global Energy will be able to continue operations or meet its obligations as they mature. Global Energy has until July 3, 2009 to submit a plan to achieve compliance with the Amex rules. If Global Energy does not submit a plan, or if the plan is not accepted by NYSE Amex, or if Global Energy does not achieve compliance by December 3, 2009, then Global Energy’s common stock will be subject to delisting procedures. NYSE Amex further notified Global Energy that due to the continued low trading price of its common stock, NYSE Amex deems it appropriate for Global Energy to effect a reverse stock split. “If Global Energy does not complete the reverse stock split within a reasonable amount of time, NYSE Amex may suspend dealings in Global Energy’s common stock or initiate delisting procedures,” Global Energy Holdings said. Global Energy Holdings describes itself as a developer of renewable energy projects, including biomass gasification and landfill-gas-to-energy projects. – Jack Peckham
Sasol announced June 19 that it expects to report earnings declines of between 40-50% for the fiscal 2009 year ending June 30. “The expected decrease in earnings is mainly due to the lower crude oil and chemical prices . . . together with a considerable reduction in refining margins and a further deterioration in chemical markets,” Sasol said. “This earnings guidance includes the impact of the non-cash charges relating to the Sasol Inzalo BEE transaction and the administrative penalties paid to the European Commission and the South African Competition Commission” over price-fixing charges. “Overall group production volumes are up mainly due to increased production volumes at the Oryx GTL plant and the additional production volumes at the Arya Sasol Polymers plant,” Sasol said. “The Synfuels operations in Secunda, South Africa, are expecting production volumes to be about 4% lower than last year. “The overall deterioration in market conditions will also result in negative stock effects, net realizable value stock write-downs and impairments.” Meantime, “growth plans remain unchanged” but “we have reprioritized our planned capital expenditure to R16 billion for 2009 in light of the changed market conditions,” the company said. Official FY 2009 results will announced on September 14, Sasol said. – Jack Peckham
Woodlands, Texas-based SeprOx announced June 10 that it won a $250,000 grant from Texas Emerging Technology Fund (ETF) for its version of a proposed ion transport membrane (ITM) oxygen-production technology. The SeprOx scheme effectively would aim to compete with the existing Air Products ITM oxygen scheme for various types of gasification plants. SeprOx said it potentially could win another $750,000 grant for a total $1 million from the ETF. SeprOx was established in 2008 as a wholly owned subsidiary of Trans Ionics Corporation (TIC) to “scale up and commercialize groundbreaking technology capable of separating virtually pure oxygen from air using a proprietary membrane material under exclusive license from the University of Houston,” SeprOx said. “Applications of the technology range from small medical oxygen generators to large industrial oxygen systems for clean coal combustion and gasification. The company expects to complete fabrication of a working prototype of its five-liter-per-minute portable medical oxygen generator.” The company points out that existing ITMs selectively separate pure oxygen from air at temperatures between 900°C and 1,000°C. “In these membrane systems, oxygen from the air is reduced to oxygen anions which diffuse across the non-porous film under the influence of a pressure gradient and are oxidized to reform pure oxygen and electrons on the downstream side,” SeprOx said. “Electrons formed in this oxidation step diffuse in the reverse direction through the film thus eliminating the need for wires. These mixed ionic electronic conducting (MIEC) membranes have been shown to have high oxygen production rates and produce >99.95% pure oxygen; and the use of ITMs is expected to reduce the cost of oxygen production by 30-50% versus cryogenic distillation “One of the debits of existing ITM systems, however, is their high operating temperatures, which result in higher manufacturing costs (because of more exotic materials of construction, etc). Like solid oxide fuel cells, the goal for these oxygen separation systems for some time has been the development of a membrane that operates effectively in the 400-700 °C range. Until now, however, such materials have not been available. “A recent discovery by researchers at the University of Houston’s Texas Center for Superconductivity (TcSUH) has resulted in a paradigm shift in MIEC materials and ushered in the age of low temperature oxygen separation. Research has shown that certain layered mixed metal oxides called ‘A-site-ordered double perovskites’ have unusually high oxygen mobility because the oxygen atoms in the lattice are arranged in planes. “More importantly, this high oxygen mobility occurs at temperatures between 400 and 700°C or up to 600°C lower than in similar membranes currently under development by other companies. Operation at these ‘moderate’ temperatures allows for the first-time the use of standard materials of construction like stainless steel and nickel for the housings and other non-membrane construction thus further reducing the cost of manufacturing.” – Jack Peckham
Hydrotreating vegetable oils into “bio-derived synthetic paraffinic kerosene” (Bio-SPK) yields a fuel that is chemically near-identical to Fischer-Tropsch kero-jet fuel. Except for aromatics, both “Bio-SPK” and FT-jet likewise are near-identical to petroleum-based kero-jet fuel. Now, 50% “Bio-SPK” blends have just won huge industry endorsements from last week’s annual Paris Air Show. There’s historical precedent supporting Bio-SPK: For years, Fischer-Tropsch jet fuel (also very low in aromatics and highly paraffinic) has been blended at 50% ratio into petroleum kero-jet for commercial airlines traveling to and from South Africa. The 50% blend limit is to ensure that there’s enough aromatics in the blended jet fuel to maintain seal swell in aircraft fuel systems, as “green jet fuel” technology developer UOP told us. Another boost to Bio-SPK blend: Its potential to slash CO2 emissions from aircraft by roughly 40%, according to a new study endorsed by major aircraft industries. The “Bio-SPK” aviation industry study (“Evaluation of Bio-Derived Synthetic Paraffinic Kerosene”), released June 17, just won endorsement from Boeing, refinery technology provider UOP, GE Aviation, CFM International, Pratt & Whitney, Rolls-Royce, Air New Zealand, Continental Airlines, Japan Airlines and Virgin Atlantic. Bio-SPK is NOT biodiesel, contrary to what some uninformed press reports have suggested. Rather, it’s an all-hydrocarbon, refinery hydrotreated vegetable oil (HVO), virtually identical (except for ultra-low aromatics) to normal, petroleum-based kero-jet fuel, according to the joint industry report obtained by Hart Energy Publishing. Bio-oils from jatropha, algae or camelina are among the potential source feedstocks for Bio-SPK, the report points out. But the resulting jet fuel is nothing like the fatty acid methyl esters (FAME) of conventional biodiesel. At the Paris Air Show last week, Bill Glover, Boeing commercial airplane managing director of environmental strategy, said that the industry study showed the Bio-SPK fuel blends used in the test flight program “met or exceeded all technical parameters for commercial jet aviation fuel. Those standards include freezing point, flash point, fuel density and viscosity, among others. “The tests revealed that using the Bio-SPK fuel blends had no adverse effects on the engines or their components. They also showed that the fuels have greater energy content by mass than typical petroleum-derived jet fuel - which potentially could lower fuel consumption per mile. Renewable jet fuels from bio-derived sources are being considered because of their ability to reduce carbon dioxide (CO2) emissions.” Glover revealed the key fuel properties of several types of Bio-SPK versus conventional petroleum kero-jet: 
Source: Boeing Glover pointed out that while these bio-based jet fuels can meet commercial jet fuel operating requirements, they still have several problems to overcome. Algae-based jet biofuel, for example, isn’t expected to be commercially ready until 8-10 years from now, he said. “Technological innovation is needed for processing” algae into bio-jet-fuel, he explained. Meantime, jatropha-oil jet-biofuel might be ready for commercial output in two to four years. But production is “limited to warm climates only and mechanical harvesting isn’t mature,” he said. As for camelina-based Bio-SPK, this oilseed-based feedstock is “ready now” but challenges include “a limited total potential owing to yield” plus the economic problem of being “somewhat tied to grain market swings,” he said. To further the case for Bio-SPK, the aircraft industry partners “are preparing a comprehensive report for submittal to ASTM International fuel approval process” and they’re “anticipating ASTM approval in 2010 in support of industry goal to accelerate availability and use,” he said. This would involve 50-50 blends of Bio-SPK and ordinary kero-jet. Meantime, Bio-SPK advocates are “working across the industry on regional biofuel commercialization projects” and “continuing lifecycle analysis to verify sustainability of feedstocks and methods,” he added. Jet-engine maker Pratt & Whitney, and Continental Airlines, separately announced last week that they’re also endorsing the Bio-SPK study results. Flight tests with Boeing and Japan Airlines “generated valuable data to support certification of Bio-SPK at a 50 percent blend ratio," said Alan Epstein, Pratt & Whitney’s VP-technology & environment. According to the study, a series of laboratory, ground and flight tests conducted between 2006 and 2009 indicated the test fuels performed as well as or better than typical petroleum-based Jet A. The testing included several commercial airplane engine types using blends of up to 50% petroleum-based Jet A/Jet A-1 fuel and 50% biofuels. -- Jack Peckham
Topsoe Wins Research Grant for Di-Ethyl Ether Diesel Substitute Haldor Topsoe and Danish Technology Institute announced June 10 that they have jointly won a €1 million research grant from Danish Energy Agency for a project aiming to turn bioethanol into di-ethyl ether (DEE). The funding is part of the “Energy Development and Demonstration Program” aimed at the development and demonstration of energy technologies. “Diesel engines cannot run on bioethanol, because the cetane number is too low, meaning that the motor cannot start,” Topsoe noted in a press announcement. “The project goal is to uncover how bioethanol can be converted into diethyl ether using a catalytic process: The diethyl ether may subsequently be applied as diesel fuel.” “We expect to draw on our experience from diesel catalysis as well as industrial production of dimethyl ether [DME],” said Pär Gabrielsson, Project Manager in Topsoe’s Research and Development department. Topsoe said a DEE scheme would be 30-40% more efficient than running an engine on gasoline. DEE also would be a cheaper type of biofuel, Topsoe figures. However, DEE, like DME, is a volatile fuel requiring an LPG-like vehicle fueling system as well as a completely new refueling infrastructure, since it’s not compatible with diesel fuel. Mitsubishi to Build $1.5 Billion Coal-to-Chemicals Plant in Indonesia According to an Asia Pulse report quoting local newspaper Investor Daily, Mitsubishi aims to build a coal gasification chemical plant in East Kalimantan. The U.S. $1.5 billion plant would produce some 500,000 tons/year of chemical products from coal gasification, the report said. Quoting chemicals association (FIKI) chairman Hidayat Nyakman, the report said Mitsubishi “has already completed feasibility study and is now seeking land around 37 hectares needed to build the factory.” East Kalimantan was selected “probably as it is one of the largest coal producing areas in the country,” the report said. Marion County, Fla. Sets July 22 Deadline for Gasification WTE Proposals Marion County and the city of Ocala, Fla., want potential bidders on a gasification-based waste-to-energy (WTE) scheme to get their proposals in before July 22. According to a report from the Ocala (Fla.) Star-Banner, the county is trying to come up with alternatives to trash landfilling. City Council Pro-Tem Kent Guinn was quoted as saying that he’s interested in “how the city and county could work together to address solid waste issues, or even regionally with, perhaps, Alachua, Levy and Citrus counties. The city's contract for trash hauling is up in three years and the county's landfill reportedly has capacity for six years,” the report noted. The county's “request for proposals for waste energy and gasification technology is due July 22,” the report said. “City Manager Ricky Horst said the city has been working with Florida Municipal Power Agency and Progress Energy to see if they would be interested in buying any power that might be generated from the waste energy process.” Westralian Drilling Program Aims to Support Coal-Gasification Projects Australia’s Westralian Gas and Power announced June 11 that it has inked a drilling contract with Wallis Drilling to explore what it called the “coal-rich Boyup Basin,” in a run-up to a possible coal-gasification project. The drilling program “is operated by the Oswest Energy Pty Ltd Joint Venture which is 75% owned by Oswal Resources Pty Ltd and 25% owned by Westralian Gas and Power Limited,” Westralian said. “The joint venture intends to develop shallow coal for export to India or to feed a large scale ammonia/urea/fertilizer plant, utilizing coal gasification technology as an energy source.” Europlasma Appoints 1st-Ever Board of Advisors France-based gasification waste-to-energy (WTE) project developer Europlasma announced June 14 that it has appointed its first-ever Board of Advisors to guide company strategy. “The first three members appointed to serve on the Advisory Board – Pierre Catlin, François Marchal and Bernard Virton – have experienced profiles that fit together effectively in a number of relevant areas for Europlasma: waste processing, setting up and development of commercial and industrial real estate projects, financial markets and specific issues related to listed companies,” Europlasma said. Catlin brings some 25 years experience in executive management positions within the Suez Group’s European subsidiaries, while Marchal spent more than 10 years as chief commercial officer and head of sales for French equities at Société Générale. Virton meantime has decades of experience in commercial real estate and large-scale projects, Europlasma said U-Wyoming OK’s ‘High Plains Gasification Advanced Technology Center’ The University of Wyoming (UW) Board of Trustees on June 15 approved the final step in a site selection process for the High Plains Gasification-Advanced Technology Center (HPG-ATC) to be built in the Cheyenne Business Parkway in east Cheyenne. The real estate transfer agreement details a property transfer from Cheyenne LEADS, the economic development corporation for Cheyenne, and Laramie County, to the University of Wyoming. “The HPG-ATC will consist of a small-scale gasification system that would allow UW and GE Energy researchers to develop and validate advanced coal gasification technology solutions for Powder River Basin and other Wyoming coals,” UW said. “The plant is expected to allow engineers to gain experience in advanced coal gasification processes, which offer a method to generate electricity from coal with fewer emissions and the ability to capture carbon for future sequestration. It also will provide students an opportunity to learn about coal gasification.” Construction on the $100 million project is expected to take about 2-1/2 years, UW said. Chemrec Boasts of Naming to ‘European Tech Tour’ Sweden’s Chemrec, developer of a pulp-mill black-liquor gasification scheme focused on dimethyl ether (DME) production, announced last week it was named among Europe’s most innovative and promising technology companies at for the “European Tech Tour Cleantech Summit.” “The European Tech Tour organizes conferences to bring together growth companies like Chemrec and key European, U.S. and Asian investors and professionals who can assist in their global expansion,” Chemrec said. “From a pool of more than 300 applicants, Chemrec was one of just 24 firms invited to present its technology to a delegation of clean-tech investors and professionals from across Europe at the June 17-18 event in Geneva, Switzerland. Chemrec was chosen due to the maturity of its technology, attractive niche focus, flexible bioproducts output and its seasoned management team.” Technip Wins LNG EPC Contract for China Technip announced June 22 that it won a lump-sum contract from Ningxia Hanas Natural Gas Company for an 800,000 tons/year liquefied natural gas (LNG) plant to be built in Yinchuan, China, for start-up in second-half 2011. The contract covers the engineering, supply of main equipment, procurement and construction management services for facilities for natural gas pre-treatment, liquefaction, LNG storage and loading, utilities, offsites, buildings and other infrastructure. “This LNG plant will be the largest facility of its kind in China,” Technip said. “It will have two trains with a capacity of 400,000 tons per year each, based on an Air Products liquefaction process. The LNG will be distributed to the Chinese market to help meet the growing demand for clean energy.”
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