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Sour gas

About: Sour gas is a research topic. Over the lifetime, 1553 publications have been published within this topic receiving 18307 citations.


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Journal ArticleDOI
TL;DR: The most reliable approach for discriminating bacterial versus thermochemical sulfate reduction is to combine as many of these criteria as possible as mentioned in this paper, which can be used in exploration or deposits of hydrocarbons, sour gas, elemental sulfur, and certain metal sulfides.

741 citations

BookDOI
21 Jun 2006
TL;DR: In this paper, the authors present an overview of the role of gas plants in the process of natural gas processing, including contractual agreements and economics, as well as safety and environmental aspects.
Abstract: OVERVIEW OF NATURAL GAS INDUSTRY Sources of Natural Gas Natural Gas Compositions Classification Processing and Principal Products Product Specifications Combustion Characteristics OVERVIEW OF GAS PLANT PROCESSING Roles of Gas Plants Plant Processes Important Support Components Contractual Agreements and Economics FIELD OPERATIONS AND INLET RECEIVING Field Operations Gas Hydrates Inlet Receiving Safety and Environmental Considerations COMPRESSION Fundamentals Compressor Types Capacity and Power Calculations Comparison of Reciprocating and Centrifugal Compressors Safety and Environmental Considerations GAS TREATING Solvent Absorption Processes Physical Absorption Adsorption Cryogenic Fractionation Membranes Nonregenerable Hydrogen Sulfide Scavengers Biological Processes Safety and Environmental Considerations GAS DEHYDRATION Water Content of Hydrocarbons Gas Dehydration Processes Safety and Environmental Considerations HYDROCARBON RECOVERY Process Components Recovery Processes Safety and Environmental Considerations NITROGEN REJECTION Nitrogen Rejection for Gas Upgrading Nitrogen Rejection for Enhanced Oil Recovery Safety and Environmental Considerations TRACE-COMPONENT RECOVERY OR REMOVAL Helium Mercury (BTEX) Benzene, Toluene, Ethylbenzene, and Xylene LIQUIDS PROCESSING Condensate Processing NGL Processing Safety and Environmental Considerations SULFUR RECOVERY Properties of Sulfur Sulfur Recovery Processes Sulfur Storage Safety and Environmental Considerations TRANSPORTATION AND STORAGE Gas Liquids LIQUEFIED NATURAL GAS Gas Treating before Liquefaction Liquefaction Cycles Storage of LNG Transportation Regasification and Cold Utilization of LNG Economics Plant Efficiency Safety and Environmental Considerations CAPITAL COSTS OF GAS PROCESSING FACILITIES Introduction Basic Premises for Cost Data Amine Treating Glycol Dehydration NGL Recovery with Straight Refrigeration (Low Ethane Recovery) NGL Recovery with Cryogenic Processing (High Ethane Recovery) Sulfur Recovery and Tail Gas Cleanup NGL Extraction Plant Costs for Larger Facilities Corrections to Cost Data NATURAL GAS PROCESSING PLANTS Plant with Sweet Gas Feed and 98% Ethane Recovery Plant with Sour Gas Feed, NGL, and Sulfur Recovery Plant with Sour Gas Feed NGL Recovery and Nitrogen Rejection NOTATION Appendix A: Glossary of Gas Process Terminology Appendix B: Physical Constants and Physical Properties References Index *Each chapter contains Introduction and Reference sections

509 citations

Journal ArticleDOI
TL;DR: This Review attempts to exhaustively compile the existing literature on sour gas sweetening and to identify promising areas for future developments in the field.
Abstract: Hydrogen sulfide removal is a long-standing economic and environmental challenge faced by the oil and gas industries. H2S separation processes using reactive and non-reactive absorption and adsorption, membranes, and cryogenic distillation are reviewed. A detailed discussion is presented on new developments in adsorbents, such as ionic liquids, metal oxides, metals, metal–organic frameworks, zeolites, carbon-based materials, and composite materials; and membrane technologies for H2S removal. This Review attempts to exhaustively compile the existing literature on sour gas sweetening and to identify promising areas for future developments in the field.

384 citations

Journal ArticleDOI
TL;DR: In this paper, the authors show that the temperature required for in-situ thermochemical sulfate reduction to produce the high H2S concentrations encountered in deep carbonate gas reservoirs is greater than 140°C.
Abstract: Natural gas in the Permian-Triassic Khuff Formation of Abu Dhabi contains variable amounts of H2S. Gas souring occurred through thermochemical sulfate reduction of anhydrite by hydrocarbon gases. Sour gas is observed only in reservoirs hotter than a critical reaction temperature: 140°C. Petrographic examination of core from a wide depth range showed that the anhydrite reactant has been replaced by calcite reaction product only in samples deeper than 4300 m. Gas composition data show that only reservoirs deeper than 4300 m contain large quantities of H2S (i.e., >10%). At present-day geothermal gradients, 4300 m is equivalent to 140°C. Fluid inclusion analysis of calcite reaction product has shown that calcite growth only became significan at temperatures greater than 140°C. Thus, three independent indicators all show that 140°C is the critical temperature above which gas souring by thermochemical sulfate reduction begins. The previously suggested lower temperature thresholds for other sour gas provinces (80-130°C) derive from gas composition data that may not allow adequately either for the reservoir temperature history or for the migration of gas generated at higher temperatures into present traps. Conversely, published proposals for higher threshold temperature (180-200°C) derive from short duration experimental data that are not easily extrapolated to geologically realistic temperatures and time scales. Therefore, the temperature of 140°C derived from our study of the Khuff Formation may be th best estimate of temperature required for in-situ thermochemical sulfate reduction to produce the high H2S concentrations encountered in deep carbonate gas reservoirs.

251 citations

Journal ArticleDOI
TL;DR: In this paper, a process design study and an economic assessment were made of a hybrid process for the removal of up to 40 mole% CO2 and up to 1 mole% H2S from crude natural gas.

193 citations


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Performance
Metrics
No. of papers in the topic in previous years
YearPapers
202332
202291
202150
202078
201956
201860