75.060 (Natural gas) 标准查询与下载

ASTM D3246-14 采用氧化微库仑法测定石油气中硫含量的标准试验方法

4.1 Trace quantities of sulfur compounds in hydrocarbon products can be harmful to many catalytic chemical processes in which these products are used. Maximum permissible levels of total sulfur are normally included in specifications for such hydrocarbons. It is recommended that this test method be used to provide a basis for agreement between two laboratories when the determination of sulfur in hydrocarbon gases is important. 4.2 On liquefied petroleum gas, total volatile sulfur is measured on an injected gas sample. For such material a liquid sample must be used to measure total sulfur. 1.1 This test method covers determination of sulfur in the range from 1.5 to 100 mg/kg (ppm by mass) by weight in hydrocarbon products that are gaseous at normal room temperature and pressure. Note 1—The test method has been tested cooperatively only on high-purity ethylene gas. Precision data have not been developed for other products. 1.2 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard. 1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry

ASTM D7940-14 使用光纤耦合拉曼光谱法分析液化天然气(LNG)的标准实施规程

5.1 The composition of liquefied gas fuels (LNG, LPG) is important for custody transfer and production. Compositional determination is used to calculate the heating value, and it is important to ensure regulatory compliance. Compositional determination is also used to optimize the efficiency of liquefied hydrocarbon gas production and ensure the quality of the processed fluids. 5.2 Alternatives to compositional measurement using Raman spectroscopy are described in Test Method D1945, Practice D1946, and Test Method D7833. 5.3 The advantage of this standard over existing standards mentioned in 5.2 above, is that Raman spectroscopy can determine composition by directly measuring the liquefied natural gas. Unlike chromatography, no vaporization step is necessary. Since incorrect operation of on-line vaporizers can lead to poor precision and accuracy, elimination of the vaporization step offers a significant improvement in the analysis of LNG. 1.1 This standard practice is for both on-line and laboratory instrument-based determination of composition for liquefied natural gas (LNG) using Raman spectroscopy. The basic methodology can also be applied to other light hydrocarbon mixtures in either liquid or gaseous states, if the needs of the application are met, although the rest of this practice refers specifically to liquids. From the composition, gas properties such as heating value and the Wobbe index may be calculated. The components commonly determined according to this test method are CH4, C2H6, C3H8, i-C4H10, n-C4H10, iC5H12, n-C5H12, neo-C5H12, N2, O2. The applicable range of this standard is 200 ppmv to 100 mol %. Components heavier than C5 are not measured as part of this practice. Note 1: Raman spectroscopy does not directly quantify the component percentages of noble gases, however, inerts can be calculated indirectly by subtracting the sum of the other species from 100 %. 1.2 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard. 1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to e......

Standard Practice for Analysis of Liquefied Natural Gas 40;LNG41; by Fiber-Coupled Raman Spectroscopy

ASTM D6273-14 天然气气味强度的标准试验方法

4.1 Federal regulations (49 CFR Part 192.625) state: “A combustible gas in a distribution line must contain a natural odorant or be odorized so that at a concentration in air of one-fifth of the lower explosive limit, the gas is readily detectable by a person with a normal sense of smell.” These regulations state further that “To assure the proper concentration of odorant with this section, each operator must conduct periodic sampling of combustible gases using an instrument capable of determining the percentage of gas in air at which the odor becomes readily detectable.” Additionally, a number of states have enacted legislation that requires natural gas to be odorized so that it is detectable at concentrations less than one fifth of the lower explosive limit. See Note 1. While regulations do not specify the exact method for determining compliance, it has been documented that compliance testing must be olfactory in nature.4Note 1—For example, Massachusetts Section 192.625 MFS Standards requires that “... a concentration of fifteen hundredths of one percent gas in the air is readily perceptible to the normal or average olfactory senses of a person...” 4.2 These test methods cover procedures to measure the odor level of natural gas by way of olfactory determination. No direct correlation may be ascertained between these test methods and those methods available or under development that quantitatively measure the concentration of sulfur compounds in natural gas. 4.3 These test methods outline general procedures to measure the odor detection levels of natural gas. It is the responsibility of persons using these test methods to develop and maintain equipment and specific operating procedures to ensure public safety and compliance with all appropriate regulations. 1.1 These test methods cover the procedures for determining the odor intensity of natural gas through the use of instruments that dilute and mix the sampled natural gas with air. The mixed gas stream is then sniffed by the operator for the purpose of determining the threshold detection level or the readily detection level, or both, for odorant in the natural gas stream. 1.2 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Methods for Natural Gas Odor Intensity

ASTM D7648-12 直接推动或手动驱动的人工取样设备对活性土壤气体取样的标准操作规程

Soil gas is simply the gas phase (air) that exists in the open spaces between soil particles in the unsaturated portion of the vadose zone. Normally comprised of nitrogen and oxygen, soil gas becomes contaminated when volatile organic compounds (VOCs) are released in the subsurface due to spills or leaks, and they begin to evaporate from a fluid phase and become part of the soil gas. Over time, VOCs can potentially migrate through the soil or groundwater or both and present a problem to the environment and human health. Application of Soil Gas Surveys8212;Soil gas surveying offers an effective, quick and cost-effective method of detecting volatile contaminants in the vadose zone. Soil gas surveying has been demonstrated to be effective for selection of suitable and representative samples for other more costly and definitive investigative methods. This method is highly useful at the initiation of an investigation into the preliminary site investigation of determining the existence and extent of volatile or semivolatile organic contamination, and determination of location of highest concetrations, as well as, monitoring the effectiveness of on-going remedial activities. Samples are collected by inserting a sampling device into a borehole with hydraulically-driven direct push drilling technology or manually-driven driven hand sampling equipment. Soil gas surveys can be performed over a wide range of spatial designs. Spatial designs include soil gas sampling in profiles or grid patterns at a single depth or multiple depths. Multiple depth sampling is particularly useful for contaminant determinations in cases with complex soil type distribution and multiple sources. Depth profiling can also be useful in the determination of the most appropriate depth(s) at which to monitor soil gas, as well as the demonstration of migration and degradation processes in the vadose zone. Soil gas surveys are used extensively in preliminary site investigations and monitoring of effectiveness of on-going site remediation efforts. Project objectives must be known and the limitation of this method considered. Limitations include: Data generated from soil gas surveying is relative and not of the quality necessary for a single data set; and Soil gas surveys need to be done quickly, so this method is for active soil-gas sampling devices only.1.1 This practice details the collection of active soil gas samples using a variety of sample collection techniques with tooling associated with direct push drilling technology (DPT) or manual-driven hand-sampling equipment, for the express purpose of conducting soil gas surveys. 1.2 This practice proceeds on the premise that soil gas surveys are primarily used for two (2) purposes, 1) as a preliminary site investigative tool and 2) for the monitoring of ongoing remediation activities. 1.3 The practicality of field use demands that soil gas surveys are relatively accurate, as well as being simple, quick, and inexpensive. This guide suggests that the objective of soil gas surveys is linked to three factors: 1.3.1 VOC detection and quantitation, including determination of depth of VOC contamination. 1.3.2 Sample retrieval ease and time. 1.3.3 Cost. 1.4 This practice will likely increase the awareness of a fundamental difference between soil gas sampling for the purpose of soil gas surveys versus sub-slab or vapor intrusion investigations or both. Specifically, the purpose of a soil gas survey is to provide quick and inexpensive data to the investigator that will allow the investigator to 1) develop a site investigation plan that is strategic in its efforts, 2) determine success or progress of on-going remedial activities, or 3) select the most suitable subsequent investigation equi......

Standard Practice for Active Soil Gas Sampling for Direct Push or Manual-Driven Hand-Sampling Equipment

ASTM D7663-12 包气带中活性土壤气体抽样以评估蒸汽入侵的标准操作规程

Soil-gas sampling results can be dependent on numerous factors both within and outside the control of the sampling personnel. Key variables are identified and briefly discussed below. Please see the documents listed in the Bibliography for more detailed information on the effect of various variables. Application8212;The techniques described in this standard practice are suitable for collecting samples for subsequent analysis for VOCs by US EPA Method TO-15, US EPA Method TO-17, Test Method D5466, Practice D6196, or other VOC methods (for example, ISO 16017-1, US EPA Methods TO-3 and TO-12). In general, off-site analysis is employed when data are needed for input to a human health risk assessment and low- or sub-ppbv analytical sensitivity is required. On-site analysis typically has lesser analytical sensitivity and tends to be employed for screening level studies. The techniques also may prove useful for analytical categories other than VOCs, such as methane, ammonia, mercury, or hydrogen sulfide (See Test Method D5504). Limitations: This method only addresses collection of gas-phase species. Less volatile compounds, such as SVOCs, may be present in the environment both in the gas phase and sorbed onto particulate matter, as well as in liquid phase. In soil gas, the gas-phase fraction is the primary concern. In other potential sampling locations (for example, ambient or indoor air), however, sampling for the particulate phase fraction may also be of interest. The data produced using this method should be representative of the soil gas concentrations in the geological materials in the immediate vicinity of the sample probe or well at the time of sample collection (that is, they represent a point-in-time and point-in-space measurement). The degree to which these data are representative of any larger areas or different times depends on numerous site-specific factors. Effect of Purging of Dead Space8212;If a soil gas probe is to be sampled soon after installation, the gas within the probe and any sand pack will consist mostly of atmospheric air. This air must be purged before soil gas that is representative of the geologic materials can be obtained. If the probe has previously been sampled, it may be possible to collect a representative sample after a smaller volume of gas is purged, but the volume of gas in the probe tubing or pipe must be purged at a minimum. It is recommended that a minimum of three (3) dead volumes be purged from the sampling system immediately prior to sample collection. Larger purge volumes typically are not necessary to achieve stable readings and should be avoided for shallower probes or if the potential exists that the additional purging will affect the partitioning of the VOCs in the subsurface. Larger purge (and sample collection) volumes can result in migration of soil gas from locations some distance from the sampling probe. Preferential pathways within the soil may exist and so the uncertainty associated with the origin of the soil gas will tend to increase with increasing purge (and sample) volumes. The data, however, should still be representative of how VOCs will migrate in these subsurface conditions. Effect of Sampling Rate8212;The faster the rate of sampling, the larger the pressure differential (that is, vacuum) that is induced at the point(s) where soil gas enters the sampling system. The relationship between the flow rate and the vacuum is primarily.........

Standard Practice for Active Soil Gas Sampling in the Vadose Zone for Vapor Intrusion Evaluations

ASTM D7663-11 渗流区活性土壤气体抽样以评估蒸汽入侵的标准操作规程

Soil-gas sampling results can be dependent on numerous factors both within and outside the control of the sampling personnel. Key variables are identified and briefly discussed below. Please see the documents listed in the Bibliography for more detailed information on the effect of various variables. Application8212;The techniques described in this standard practice are suitable for collecting samples for subsequent analysis for VOCs by US EPA Method TO-15, US EPA Method TO-17, Test Method D5466, Practice D6196, or other VOC methods (for example, ISO 16017-1, US EPA Methods TO-3 and TO-12). In general, off-site analysis is employed when data are needed for input to a human health risk assessment and low- or sub-ppbv analytical sensitivity is required. On-site analysis typically has lesser analytical sensitivity and tends to be employed for screening level studies. The techniques also may prove useful for analytical categories other than VOCs, such as methane, ammonia, mercury, or hydrogen sulfide (See Test Method D5504). Limitations: This method only addresses collection of gas-phase species. Less volatile compounds, such as SVOCs, may be present in the environment both in the gas phase and sorbed onto particulate matter. In soil gas, the gas-phase fraction is the primary concern. In other potential sampling locations (for example, ambient or indoor air), however, sampling for the particulate phase fraction may also be of interest. The data produced using this method should be representative of the soil gas concentrations in the geological materials in the immediate vicinity of the sample probe or well at the time of sample collection (that is, they represent a point-in-time and point-in-space measurement). The degree to which these data are representative of any larger areas or different times depends on numerous site-specific factors. Effect of Purging of Dead Space8212;If a soil gas probe is to be sampled soon after installation, the gas within the probe and any sand pack will consist mostly of atmospheric air. This air must be purged before soil gas that is representative of the geologic materials can be obtained. If the probe has previously been sampled, it may be possible to collect a representative sample after a smaller volume of gas is purged, but the volume of gas in the probe tubing or pipe must be purged at a minimum. It is recommended that a minimum of three (3) dead volumes be purged from the sampling system immediately prior to sample collection. Larger purge volumes typically are not necessary and should be avoided, especially for shallower probes or if the potential exists that the additional purging will affect the partitioning of the VOCs in the subsurface. Larger purge (and sample collection) volumes can result in migration of soil gas from locations some distance from the sampling probe. Preferential pathways within the soil may exist and so the uncertainty associated with the origin of the soil gas will tend to increase with increasing purge (and sample) volumes. Effect of Sampling Rate8212;The faster the rate of sampling, the larger the pressure differential (that is, vacuum) that is induced at the point(s) where soil gas enters the sampling system. The relationship between the flow rate and the vacuum is primarily dependent on the gas-permeability of the subsurface materials. This pressure differential has the potential to affect the partitioning of the VOCs in.........

Standard Practice for Active Soil Gas Sampling in the Vadose Zone for Vapor Intrusion Evaluations

ASTM D3246-11 氧化微库仑法测定石油气中硫的标准试验方法

Trace quantities of sulfur compounds in hydrocarbon products can be harmful to many catalytic chemical processes in which these products are used. Maximum permissible levels of total sulfur are normally included in specifications for such hydrocarbons. It is recommended that this test method be used to provide a basis for agreement between two laboratories when the determination of sulfur in hydrocarbon gases is important. On liquefied petroleum gas, total volatile sulfur is measured on an injected gas sample. For such material a liquid sample must be used to measure total sulfur.1.1 This test method covers determination of sulfur in the range from 1.5 to 100 mg/kg (ppm by mass) by weight in hydrocarbon products that are gaseous at normal room temperature and pressure.Note 18212; The test method has been tested cooperatively only on high-purity ethylene gas. Precision data have not been developed for other products.1.2 The values stated in Si units are to be regarded as the standard. The values given n parentheses are for information only1.3This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry

ASTM D6273-08 天然气气味强度的标准试验方法

Federal regulations (49 CFR Part 192.625) state: “A combustible gas in a distribution line must contain a natural odorant or be odorized so that at a concentration in air of one-fifth of the lower explosive limit, the gas is readily detectable by a person with a normal sense of smell.” These regulations state further that “each operator shall conduct periodic sampling of combustible gases to assure the proper concentration of odorant in accordance with this section.” Additionally, a number of states have enacted legislation that requires natural gas to be odorized so that it is detectable at concentrations less than one fifth of the lower explosive limit. See note Note 1. While regulations do not specify the exact method for determining compliance, it has been documented that compliance testing must be olfactory in nature. Note 18212;For example, Massachusetts Section 192.625 MFS Standards requires that “... a concentration of fifteen hundredths of one percent gas in the air is readily perceptible to the normal or average olfactory senses of a person ... .” These test methods cover procedures to measure the odor level of natural gas by way of olfactory determination. No direct correlation may be ascertained between these test methods and those methods available or under development that quantitatively measure the concentration of sulfur compounds in natural gas. These test methods outline general procedures to measure the odor detection levels of natural gas. It is the responsibility of persons using these test methods to develop and maintain equipment and specific operating procedures to ensure public safety and compliance with all appropriate regulations.1.1 These test methods cover the procedures for determining the odor intensity of natural gas through the use of instruments that dilute and mix the sampled natural gas with air. The mixed gas stream is then sniffed by the operator for the purpose of determining the threshold detection level or the readily detection level, or both, for odorant in the natural gas stream. 1.2 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Methods for Natural Gas Odor Intensity

ASTM D1988-06(2011) 用色斑长度检测管测定天然气中的硫醇的标准试验方法

The measurement of mercaptans in natural gas is important, because mercaptans are often added as odorants to natural gas to provide a warning property. The odor provided by the mercaptan serves to warn consumers (for example, residential use) of natural gas leaks at levels that are well below the flammable or suffocating concentration levels of natural gas in air. Field determinations of mercaptans in natural gas are important because of the tendency of the mercaptan concentration to fade over time. This test method provides inexpensive field screening of mercaptans. The system design is such that it may be used by nontechnical personnel, with a minimum of proper training.1.1 This test method covers a rapid and simple field determination of mercaptans in natural gas pipelines. Available detector tubes provide a total measuring range of 0.5 to 160 ppm by volume of mercaptans, although the majority of applications will be on the lower end of this range (that is, under 20 ppm). Besides total mercaptans, detector tubes are also available for methyl mercaptan (0.5 to 100 ppm), ethyl mercaptan (0.5 to 120 ppm), and butyl mercaptan (0.5 to 30 mg/M3 or 0.1 to 8 ppm). Note 18212;Certain detector tubes are calibrated in terms of milligrams per cubic metre (mg/M3) instead of parts per million by volume. The conversion is as follows for 25°C (77°F) and 760 mm Hg. 1.2 Detector tubes are usually subject to interferences from gases and vapors other than the target substance. Such interferences may vary among brands because of the use of different detection principles. Many detector tubes will have a precleanse layer designed to remove interferences up to some maximum level. Consult manufacturer's instructions for specific interference information. Hydrogen sulfide and other mercaptans are usually interferences on mercaptan detector tubes. See Section 5 for interferences of various methods of detection. 1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use. For specific hazard statements, see 7.3.

Standard Test Method for Mercaptans in Natural Gas Using Length-of-Stain Detector Tubes

ASTM D4888-06(2011) 使用着色长度检测管对天然气中水蒸气的试验方法

The measurement of water vapor in natural gas is important because of the gas quality specifications, the corrosive nature of water vapor on pipeline materials, and the effects of water vapor on utilization equipment. This test method provides inexpensive field screening of water vapor. The system design is such that it may be used by nontechnical personnel with a minimum of proper training.1.1 This test method covers a procedure for rapid and simple field determination of water vapor in natural gas pipelines. Availabel detector tubes provide a total measuring range of 0.1 to 40 mg/L, although the majority of applications will be on the lower end of this range (that is, under 0.5 mg/L). At least one manufacturer provides tubes that read directly in pounds of water per million cubic feet of gas. See Note 1. 1.2 Detector tubes are usually subject to interferences from gases and vapors other than the target substance. Such interferences may vary among brands because of the use of different detection methods. Consult manufacturer's instructions for specific interference information. Alcohols and glycols will cause interferences on some water vapor tubes because of the presence of the hydroxyl group on those molecules. 1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Water Vapor in Natural Gas Using Length-of-Stain Detector Tubes

ASTM D4810-06(2011) 使用着色长度检测管对天然气中硫化氢的标准试验方法

The measurement of hydrogen sulfide in natural gas is important because of the gas quality specifications, the corrosive nature of H2S on pipeline materials, and the effects of H2S on utilization equipment. This test method provides inexpensive field screening of hydrogen sulfide. The system design is such that it may be used by nontechnical personnel with a minimum of proper training.1.1 This test method covers a procedure for a rapid and simple field determination of hydrogen sulfide in natural gas pipelines. Available detector tubes provide a total measuring range of 0.5 ppm by volume up to 40 % by volume, although the majority of applications will be on the lower end of this range (that is, under 120 ppm). 1.2 Typically, sulfur dioxide and mercaptans may cause positive interferences. In some cases, nitrogen dioxide can cause a negative interference. Most detector tubes will have a “precleanse” layer designed to remove certain interferences up to some maximum interferent level. Consult manufacturers' instructions for specific interference information. 1.3 The values stated in SI units are to be regarded as the standard. 1.4 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes

ASTM D1988-06 用色斑长度检测管测定天然气中的硫醇的标准试验方法

The measurement of mercaptans in natural gas is important, because mercaptans are often added as odorants to natural gas to provide a warning property. The odor provided by the mercaptan serves to warn consumers (for example, residential use) of natural gas leaks at levels that are well below the flammable or suffocating concentration levels of natural gas in air. Field determinations of mercaptans in natural gas are important because of the tendency of the mercaptan concentration to fade over time. This test method provides inexpensive field screening of mercaptans. The system design is such that it may be used by nontechnical personnel, with a minimum of proper training.1.1 This test method covers a rapid and simple field determination of mercaptans in natural gas pipelines. Available detector tubes provide a total measuring range of 0.5 to 160 ppm by volume of mercaptans, although the majority of applications will be on the lower end of this range (that is, under 20 ppm). Besides total mercaptans, detector tubes are also available for methyl mercaptan (0.5 to 100 ppm), ethyl mercaptan (0.5 to 120 ppm), and butyl mercaptan (0.5 to 30 mg/M179; or 0.1 to 8 ppm).Note 18212;Certain detector tubes are calibrated in terms of milligrams per cubic metre (mg/M179;) instead of parts per million by volume. The conversion is as follows for 25176;C (77176;F) and 760 mm Hg.Equation 1 - mg/M179; = ppm X molecular weight/24.451.2 Detector tubes are usually subject to interferences from gases and vapors other than the target substance. Such interferences may vary among brands because of the use of different detection principles. Many detector tubes will have a precleanse layer designed to remove interferences up to some maximum level. Consult manufacturer's instructions for specific interference information. Hydrogen sulfide and other mercaptans are usually interferences on mercaptan detector tubes. See Section 5 for interferences of various methods of detection.1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use. For specific hazard statements, see 7.3.

Standard Test Method for Mercaptans in Natural Gas Using Length-of-Stain Detector Tubes

ASTM D4888-06 使用着色长度检测管对天然气中水蒸气的试验方法

The measurement of water vapor in natural gas is important because of the gas quality specifications, the corrosive nature of water vapor on pipeline materials, and the effects of water vapor on utilization equipment. This test method provides inexpensive field screening of water vapor. The system design is such that it may be used by nontechnical personnel with a minimum of proper training.1.1 This test method covers a procedure for rapid and simple field determination of water vapor in natural gas pipelines. Availabel detector tubes provide a total measuring range of 0.1 to 40 mg/L, although the majority of applications will be on the lower end of this range (that is, under 0.5 mg/L). At least one manufacturer provides tubes that read directly in pounds of water per million cubic feet of gas. See Note 1.1.2 Detector tubes are usually subject to interferences from gases and vapors other than the target substance. Such interferences may vary among brands because of the use of different detection methods. Consult manufacturer's instructions for specific interference information. Alcohols and glycols will cause interferences on some water vapor tubes because of the presence of the hydroxyl group on those molecules.1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Water Vapor in Natural Gas Using Length-of-Stain Detector Tubes

ASTM D3246-05 用氧化微库仑法测定石油气中硫含量的标准试验方法

Trace quantities of sulfur compounds in hydrocarbon products can be harmful to many catalytic chemical processes in which these products are used. Maximum permissible levels of total sulfur are normally included in specifications for such hydrocarbons. It is recommended that this test method be used to provide a basis for agreement between two laboratories when the determination of sulfur in hydrocarbon gases is important. On liquefied petroleum gas, total volatile sulfur is measured on an injected gas sample. For such material a liquid sample must be used to measure total sulfur.1.1 This test method covers determination of sulfur in the range from 1.5 to 100 mg/kg (ppm by mass) by weight in hydrocarbon products that are gaseous at normal room temperature and pressure.Note 18212; The test method has been tested cooperatively only on high-purity ethylene gas. Precision data have not been developed for other products.1.2 The values stated in Si units are to be regarded as the standard. The values given n parentheses are for information only1.3This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry

ASTM D1945-03(2010) 气相色谱法分析天然气的标准试验方法

This test method is of significance for providing data for calculating physical properties of the sample, such as heating value and relative density, or for monitoring the concentrations of one or more of the components in a mixture.1.1 This test method covers the determination of the chemical composition of natural gases and similar gaseous mixtures within the range of composition shown in Table 1. This test method may be abbreviated for the analysis of lean natural gases containing negligible amounts of hexanes and higher hydrocarbons, or for the determination of one or more components, as required. 1.2 The values stated in inch-pound units are to be regarded as standard. The values given in parentheses are mathematical conversions to SI units that are provided for information only and are not considered standard. 1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Analysis of Natural Gas by Gas Chromatography

ASTM D1945-03 气相色谱法分析天然气的标准试验方法

This test method is of significance for providing data for calculating physical properties of the sample, such as heating value and relative density, or for monitoring the concentrations of one or more of the components in a mixture.1.1 This test method covers the determination of the chemical composition of natural gases and similar gaseous mixtures within the range of composition shown in Table 1. This test method may be abbreviated for the analysis of lean natural gases containing negligible amounts of hexanes and higher hydrocarbons, or for the determination of one or more components, as required.1.2 The values stated in SI units are to be regarded as the standard. The values given in parentheses are for information only.1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Analysis of Natural Gas by Gas Chromatography

ASTM D6273-98(2003) 天然气气味强度的标准试验方法

Federal regulations4 state: “A combustible gas in a distribution line must contain a natural odorant or be odorized so that at a concentration in air of one-fifth of the lower explosive limit, the gas is readily detectable by a person with a normal sense of smell.” These regulations state further that “each operator shall conduct periodic sampling of combustible gases to assure the proper concentration of odorant in accordance with this section.” Additionally, a number of states have enacted legislation that requires natural gas to be odorized so that it is detectable at concentrations less than one fifth of the lower explosive limit.5 While regulations do not specify the exact method for determining compliance, it has been documented that compliance testing must be olfactory in nature.6 These test methods cover procedures to measure the odor level of natural gas by way of olfactory determination. No direct correlation may be ascertained between these test methods and those methods available or under development that quantitatively measure the concentration of sulfur compounds in natural gas. These test methods outline general procedures to measure the odor detection levels of natural gas. It is the responsibility of persons using these test methods to develop and maintain equipment and specific operating procedures to ensure public safety and compliance with all appropriate regulations.1.1 These test methods cover the procedures for determining the odor intensity of natural gas through the use of instruments that dilute and mix the sampled natural gas with air. The mixed gas stream is then sniffed by the operator for the purpose of determining the threshold detection level or the readily detection level, or both, for odorant in the natural gas stream. 1.2 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Methods for Natural Gas Odor Intensity

ASTM D6273-98 天然气气味强度的标准试验方法

1.1 These test methods cover the procedures for determining the odor intensity of natural gas through the use of instruments that dilute and mix the sampled natural gas with air. The mixed gas stream is then sniffed by the operator for the purpose of determining the threshold detection level or the readily detection level, or both, for odorant in the natural gas stream. 1.2 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Methods for Natural Gas Odor Intensity

ASTM D1945-96(2001) 使用气相色谱法分析天然气的标准试验方法

1.1 This test method covers the determination of the chemical composition of natural gases and similar gaseous mixtures within the range of composition shown in Table 1. This test method may be abbreviated for the analysis of lean natural gases containing negligible amounts of hexanes and higher hydrocarbons, or for the determination of one or more components, as required. 1.2 The values stated in SI units are to be regarded as the standard. The values given in parentheses are for information only. 1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Analysis of Natural Gas by Gas Chromatography

ASTM D3246-96 氧化微库仑法测定石油气中硫的标准试验方法

1.1 This test method covers determination of sulfur in the range from 1.5 to 100 mg/kg (ppm by mass) by weight in hydrocarbon products that are gaseous at normal room temperature and pressure. Note 1-The test method has been tested cooperatively only on high-purity ethylene gas. Precision data have not been developed for other products. 1.2 The values stated in SI units are to be regarded as the standard. 1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry