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01130 Improved gas-in-place determination for coal gas reservoirs
03
Gaseous
fuels (sources,
properties,
recovery,
99101122 Characteristics and controlling accumulation belts in Songliao basin
treatment)
factors of gas
Hong, F. and Song, Y. Shiyou Kanfan Yu Kaifa, 1997, 24, (3), 5-9. (In Chinese) The paper details a study of the characteristics and controlling factors of gas accumulation belts in the Songliao basin. Based on distribution, structure, source-reservoir-cap assemblage and genetic type of gas pools, four gas accumulation belts were delineated: (1) the western gas accumulation belt mainly contains biogas and low-mature oil-type gas pools with source and reservoir in the same bed; (2) the Wangjiatun gas accumulation belt consists of coal-formed and abiogenetic gas pools, with abundant gas source and developed faults; (3) the ChaoyanggouChangchunling gas accumulation belt is dominated by coal-formed gas pools, with less low-mature oil-type gas pools; (4) the south-eastern uplift gas accumulation belt possesses chiefly coal-formed gas pools with old source and young reservoir belt, or with source and reservoir totally in the Jurassic system and abiogenetic gas pools. These gas accumulation belts are mainly controlled by source sag, sand body location and deep seated faults.
99101123 Correlation of gas-chromatographic retention indexes and structural characteristics of polycyclic hydrocarbons
Nabivach, V. M. Kokr Khim., 1998, (2), 24-29. (In Russian) Structural characteristics of polycyclic hydrocarbons and correlation of gaschromatography retention indexes are given and implications for environmental analysis are discussed.
99101124 Distribution and accumulation regularity for coal bed methane in China
Zhao, Q. et al. Shiyou Xuebao, 1997, 18, (4). l-6. (In Chinese) The distribution and accumulation regularities for coal-bed methane resources in China were studied. Coal bed methane resources were estimated at 25-35 x lOI* m’, distributed in eight coal-forming sets of 39 coal-bearing basins or 68 coal-bearing units. The exploration of coal bed methane was different either from conventional oil/gas or coal. The traps of coal-bed methane can be classified into 4 types: gas pressure sealing trap, confined water sealing trap, micro-penetration sealing trap from top waterhearing bed and structural trap. The accumulation regularities of coal-bed methane on regional thermodynamic metamorphism, regional compaction metamorphism and structure dynamic metamorphism was discussed. The areas of high-productivity are located in: (1) gas pressure or confined water sealing area with thermodynamic metamorphism, (2) confined water sealing area with structure dynamic and thermodynamic metamorphism and (3) confined water sealing area with light-compaction and elevation.
Effect of reservoir parameters on production of coal-bed methane
99101125
Wang, L. and Cai, Y. Shiyou Kantan Yu Kaifa, 1997, 24, (3), 74-77. (In Chinese) By using coal-bed gas numerical simulation to make sensitivity analyses of parameters, the effect of reservoir parameters on the production of coalbed methane was studied. The study showed that the key reservoir factors controlling the recovery of coal-bed methane are the absolute permeability, relative permeability, initial gas content and the isothermal absorption. In addition, a discussion took place on the effects of well-spacing and the fracture half-length on the production of coal-bed methane.
Gaseous fuels (derived from oil shale) for heavyduty gas turbines and combined-cycle power generators
99101126
Jabera, J. 0. et al. Applied Energy, 1998, 60, (l), l-20. Design-point performance predictions, relating to efficiency, net specific work and fuel flow, when a low-calorific-value fuel gas instead of natural gas is employed are presented. TURBOMATCH and GATE/CYCLE computational thermal-models were used. With slight modifications in the fuel supply, combustor and turbomachinery of the engine, in order to accommodate the increase in the mass flow rate across the turbine’s expander, such a fuel could be burnt in the industrial gas turbine’s combustor, which had originally been designed for use with natural gas. The results of this study agree with those for nominally-similar electric power generators, that are already operating world-wide using coal-or-biomass derived gaseous fuels with relatively low energy densities. 99101127 Gasification of biomass and biomass-coal tures in a pressurized fluidized bed gasifier
mix-
Andries, J. er al. Greenhouse Gas Mitigation, Proc. Technol. Act. Implemented Joinrly, 1997 (Pub. 1998), 537-543. Edited by Riemer, P. W. F. et al., Elsevier, Oxford, UK. Experimental research and modelling concerning co-gasification of biomass and coal in a bubbling pressurized fluidized bed reactor was performed in the framework of a multi-national European JOULE project. The performance of the gasifier in terms of carbon conversion, fuel gas composition and non-steady state behaviour was studied in order to determine the impact of feeding characteristics (biomass type, mixing ratio) and process conditions (temperature, air-fuel ratio and air-steam ratio). Pelletized straw and miscanthus were used as biomass components. The process development unit used is operated at pressures up to 10 bar and temperatures in the range of 650-900°C and has a maximum thermal capacity of 1.5 MW. Time-averaged and time-dependent performance characteristics of the fuel gas were experimentally determined. The results obtained are presented and analysed. They will be compared with an
116 Fuel and Energy Abstracts
March 1999
acceptable operating range with regard to the dynamic behaviour concerning gas turbine combustors. This will be provided by one of the other partners in the project, Nuovo Pignone. The evaluation of the results will ultimately be applied to implement and test an optimized control strategy for operating the pressurized fluidized bed gasifier integrated with a gas turbine combustion chamber. 99101126 Gasification of oil sand coke: review Furimsky, E. Fuel Process. Technol., 1998, 56, (3). 263-290. Gasification of oil sand coke is discussed concentrating on its production, properties and suitability, especially as a fuel source for integrated gasification-combined cycle power generation. Emphasis was placed on coke from the Suncore and Syncrude Canada operations. Database on the chemical and physical properties of the oil sand coke were established including the composition and fusion properties of the mineral matter. The coke reactivities were determined by 02 chemisorption, fixed-bed and fluidized-bed bench-scale gasification and pilot-plant gasification. The reactivity of the oil sand coke for gasification was low and comparable to that of high-rank coals such as anthracite, which required high-severity conditions (e.g. entrained-bed gasifiers, with both dry and slurry feeding systems) to achieve high conversion. Approximately a 70 wt% solids concentration in water can be achieved. Gasification is the leader among clean technologies for the conversion of carbonaceous solids to useful products because of its high efficiency, low SO, and NO, emissions, as well as a low solid waste production, when compared with the competing technologies. When compared with natural gas-based power generation gasification of oil sands coke was not competitive. The potential for transportation of the oil sand coke to the USA for electricity generation using the integrated gasification combined-cycle (IGCC) technology was evaluated.
99101129 Helium isotopic characteristics of natural gas pools in the Jiyang Depression Zheng, L. and Liao, Y. Kuangwu Xuebao, 1998, 18, (I), 52-54. (In Chinese) The Jiyang depression is an intercontinental extensional basin and contains a number of hydrocarbon and non-hydrocarbon natural gas pools. Helium isotopic compositions have three types showing that the helium is different in origin: 2.50cR/R,<3.20, 1.40
Improved gas-in-place determination for coal gas
reservoirs
Mavor, M. J. et al. Proc. Gas Technol. Symp., 1996, 439450. In recent years the Upper Cretaceous Fruitland Formation of the San Juan Basin of Colorado and New Mexico has been a very active natural gas play. Case studies of coal gas-in-place volume reassessments have revealed that gains of up to 74% are possible based upon the use of improved analytical methods. The greater gas-in-place estimates were consistent with production history and provide a new perspective upon the producible coal-gas resources. Coal gas-in-place volume is proportional to the reservoir drainage area and three petrophysical parameters: gross reservoir rock thickness, average reservoir rock density and average in-situ sorbed gas content. The procedure evaluates each of these parameters with a combination of core and density log data for specific reservoirs. Quantifiable errors and causes of errors in these petrophysical parameters have been determined. Errors in coal gas-in-place volume estimates are caused by: (a) geological structural and stratigraphic variations that disrupt the lateral continuity of coal beds; (b) using a too low maximum density cut-off limit value when determining gross reservoir rock thickness with density log data (c) by basing average reservoir rock density estimates upon ‘rules of thumb’ or bounding rock densities; (d) by performing gas desorption measurements at ambient surface temperature; and (e) by using gas desorption data collected from drill cuttings rather than whole core samples and basing in-situ sorbed gas content estimates on it.
99101131 ment tests
Improving the reliability of Ifg-generation assess-
99101132
Low cost adsorbents for low-temperature cleaning
Price, T. J. er al. Applied Energy, 1998, 60, (l), 41-63. Pumping-trials with less than four weeks duration were used to indicate the economic and scientific suitabilities of landfills for landfill-gas (Ifg) harnessing. Some of the challenges and proposed solutions are discussed. The methodology employed, results measured and conclusions drawn, based upon brief pumping-trials conducted at 12 different UK landfill sites, are presented.
of flue aases Rubio, g and Izquierdo, M. T. Fuel, 1998, 77, (6), 631-637. Prepared from a low-grade coal, the adsorption capacity with regard to SOz of chars has been evaluated at typical conditions of flue gas (presence of oxygen and water vapour and linear gas velocity of 0.12 m s-‘) at an inlet concentration of 2 g SO2 me3. The flue gases have been simulated, varying the water vapour and oxygen contents as well as the adsorption temperature which was varied between 80°C and 150°C. The study has focused on the influence of several process variables as well as the intrinsic features of the chars, such as their porous texture, on the SO2 adsorption capacity of the chars. The positive effect of water vapour in the absence of oxygen, under the conditions studied has been observed. This effect can be explained by the intervention of oxygen functionalities in chars. Here two effects overlap:
Gaseous
fuels (sources,
properties,
recovery,
99101122 Characteristics and controlling accumulation belts in Songliao basin
treatment)
factors of gas
Hong, F. and Song, Y. Shiyou Kanfan Yu Kaifa, 1997, 24, (3), 5-9. (In Chinese) The paper details a study of the characteristics and controlling factors of gas accumulation belts in the Songliao basin. Based on distribution, structure, source-reservoir-cap assemblage and genetic type of gas pools, four gas accumulation belts were delineated: (1) the western gas accumulation belt mainly contains biogas and low-mature oil-type gas pools with source and reservoir in the same bed; (2) the Wangjiatun gas accumulation belt consists of coal-formed and abiogenetic gas pools, with abundant gas source and developed faults; (3) the ChaoyanggouChangchunling gas accumulation belt is dominated by coal-formed gas pools, with less low-mature oil-type gas pools; (4) the south-eastern uplift gas accumulation belt possesses chiefly coal-formed gas pools with old source and young reservoir belt, or with source and reservoir totally in the Jurassic system and abiogenetic gas pools. These gas accumulation belts are mainly controlled by source sag, sand body location and deep seated faults.
99101123 Correlation of gas-chromatographic retention indexes and structural characteristics of polycyclic hydrocarbons
Nabivach, V. M. Kokr Khim., 1998, (2), 24-29. (In Russian) Structural characteristics of polycyclic hydrocarbons and correlation of gaschromatography retention indexes are given and implications for environmental analysis are discussed.
99101124 Distribution and accumulation regularity for coal bed methane in China
Zhao, Q. et al. Shiyou Xuebao, 1997, 18, (4). l-6. (In Chinese) The distribution and accumulation regularities for coal-bed methane resources in China were studied. Coal bed methane resources were estimated at 25-35 x lOI* m’, distributed in eight coal-forming sets of 39 coal-bearing basins or 68 coal-bearing units. The exploration of coal bed methane was different either from conventional oil/gas or coal. The traps of coal-bed methane can be classified into 4 types: gas pressure sealing trap, confined water sealing trap, micro-penetration sealing trap from top waterhearing bed and structural trap. The accumulation regularities of coal-bed methane on regional thermodynamic metamorphism, regional compaction metamorphism and structure dynamic metamorphism was discussed. The areas of high-productivity are located in: (1) gas pressure or confined water sealing area with thermodynamic metamorphism, (2) confined water sealing area with structure dynamic and thermodynamic metamorphism and (3) confined water sealing area with light-compaction and elevation.
Effect of reservoir parameters on production of coal-bed methane
99101125
Wang, L. and Cai, Y. Shiyou Kantan Yu Kaifa, 1997, 24, (3), 74-77. (In Chinese) By using coal-bed gas numerical simulation to make sensitivity analyses of parameters, the effect of reservoir parameters on the production of coalbed methane was studied. The study showed that the key reservoir factors controlling the recovery of coal-bed methane are the absolute permeability, relative permeability, initial gas content and the isothermal absorption. In addition, a discussion took place on the effects of well-spacing and the fracture half-length on the production of coal-bed methane.
Gaseous fuels (derived from oil shale) for heavyduty gas turbines and combined-cycle power generators
99101126
Jabera, J. 0. et al. Applied Energy, 1998, 60, (l), l-20. Design-point performance predictions, relating to efficiency, net specific work and fuel flow, when a low-calorific-value fuel gas instead of natural gas is employed are presented. TURBOMATCH and GATE/CYCLE computational thermal-models were used. With slight modifications in the fuel supply, combustor and turbomachinery of the engine, in order to accommodate the increase in the mass flow rate across the turbine’s expander, such a fuel could be burnt in the industrial gas turbine’s combustor, which had originally been designed for use with natural gas. The results of this study agree with those for nominally-similar electric power generators, that are already operating world-wide using coal-or-biomass derived gaseous fuels with relatively low energy densities. 99101127 Gasification of biomass and biomass-coal tures in a pressurized fluidized bed gasifier
mix-
Andries, J. er al. Greenhouse Gas Mitigation, Proc. Technol. Act. Implemented Joinrly, 1997 (Pub. 1998), 537-543. Edited by Riemer, P. W. F. et al., Elsevier, Oxford, UK. Experimental research and modelling concerning co-gasification of biomass and coal in a bubbling pressurized fluidized bed reactor was performed in the framework of a multi-national European JOULE project. The performance of the gasifier in terms of carbon conversion, fuel gas composition and non-steady state behaviour was studied in order to determine the impact of feeding characteristics (biomass type, mixing ratio) and process conditions (temperature, air-fuel ratio and air-steam ratio). Pelletized straw and miscanthus were used as biomass components. The process development unit used is operated at pressures up to 10 bar and temperatures in the range of 650-900°C and has a maximum thermal capacity of 1.5 MW. Time-averaged and time-dependent performance characteristics of the fuel gas were experimentally determined. The results obtained are presented and analysed. They will be compared with an
116 Fuel and Energy Abstracts
March 1999
acceptable operating range with regard to the dynamic behaviour concerning gas turbine combustors. This will be provided by one of the other partners in the project, Nuovo Pignone. The evaluation of the results will ultimately be applied to implement and test an optimized control strategy for operating the pressurized fluidized bed gasifier integrated with a gas turbine combustion chamber. 99101126 Gasification of oil sand coke: review Furimsky, E. Fuel Process. Technol., 1998, 56, (3). 263-290. Gasification of oil sand coke is discussed concentrating on its production, properties and suitability, especially as a fuel source for integrated gasification-combined cycle power generation. Emphasis was placed on coke from the Suncore and Syncrude Canada operations. Database on the chemical and physical properties of the oil sand coke were established including the composition and fusion properties of the mineral matter. The coke reactivities were determined by 02 chemisorption, fixed-bed and fluidized-bed bench-scale gasification and pilot-plant gasification. The reactivity of the oil sand coke for gasification was low and comparable to that of high-rank coals such as anthracite, which required high-severity conditions (e.g. entrained-bed gasifiers, with both dry and slurry feeding systems) to achieve high conversion. Approximately a 70 wt% solids concentration in water can be achieved. Gasification is the leader among clean technologies for the conversion of carbonaceous solids to useful products because of its high efficiency, low SO, and NO, emissions, as well as a low solid waste production, when compared with the competing technologies. When compared with natural gas-based power generation gasification of oil sands coke was not competitive. The potential for transportation of the oil sand coke to the USA for electricity generation using the integrated gasification combined-cycle (IGCC) technology was evaluated.
99101129 Helium isotopic characteristics of natural gas pools in the Jiyang Depression Zheng, L. and Liao, Y. Kuangwu Xuebao, 1998, 18, (I), 52-54. (In Chinese) The Jiyang depression is an intercontinental extensional basin and contains a number of hydrocarbon and non-hydrocarbon natural gas pools. Helium isotopic compositions have three types showing that the helium is different in origin: 2.50cR/R,<3.20, 1.40
Improved gas-in-place determination for coal gas
reservoirs
Mavor, M. J. et al. Proc. Gas Technol. Symp., 1996, 439450. In recent years the Upper Cretaceous Fruitland Formation of the San Juan Basin of Colorado and New Mexico has been a very active natural gas play. Case studies of coal gas-in-place volume reassessments have revealed that gains of up to 74% are possible based upon the use of improved analytical methods. The greater gas-in-place estimates were consistent with production history and provide a new perspective upon the producible coal-gas resources. Coal gas-in-place volume is proportional to the reservoir drainage area and three petrophysical parameters: gross reservoir rock thickness, average reservoir rock density and average in-situ sorbed gas content. The procedure evaluates each of these parameters with a combination of core and density log data for specific reservoirs. Quantifiable errors and causes of errors in these petrophysical parameters have been determined. Errors in coal gas-in-place volume estimates are caused by: (a) geological structural and stratigraphic variations that disrupt the lateral continuity of coal beds; (b) using a too low maximum density cut-off limit value when determining gross reservoir rock thickness with density log data (c) by basing average reservoir rock density estimates upon ‘rules of thumb’ or bounding rock densities; (d) by performing gas desorption measurements at ambient surface temperature; and (e) by using gas desorption data collected from drill cuttings rather than whole core samples and basing in-situ sorbed gas content estimates on it.
99101131 ment tests
Improving the reliability of Ifg-generation assess-
99101132
Low cost adsorbents for low-temperature cleaning
Price, T. J. er al. Applied Energy, 1998, 60, (l), 41-63. Pumping-trials with less than four weeks duration were used to indicate the economic and scientific suitabilities of landfills for landfill-gas (Ifg) harnessing. Some of the challenges and proposed solutions are discussed. The methodology employed, results measured and conclusions drawn, based upon brief pumping-trials conducted at 12 different UK landfill sites, are presented.
of flue aases Rubio, g and Izquierdo, M. T. Fuel, 1998, 77, (6), 631-637. Prepared from a low-grade coal, the adsorption capacity with regard to SOz of chars has been evaluated at typical conditions of flue gas (presence of oxygen and water vapour and linear gas velocity of 0.12 m s-‘) at an inlet concentration of 2 g SO2 me3. The flue gases have been simulated, varying the water vapour and oxygen contents as well as the adsorption temperature which was varied between 80°C and 150°C. The study has focused on the influence of several process variables as well as the intrinsic features of the chars, such as their porous texture, on the SO2 adsorption capacity of the chars. The positive effect of water vapour in the absence of oxygen, under the conditions studied has been observed. This effect can be explained by the intervention of oxygen functionalities in chars. Here two effects overlap: