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ASTM D8488-22

(Test Method)

Standard Test Method for Determination of Hydrogen Sulfide (H2S) in Natural Gas by Tunable Diode Laser Spectroscopy (TDLAS)

Standard Test Method for Determination of Hydrogen Sulfide (H<inf>2</inf>S) in Natural Gas by Tunable Diode Laser Spectroscopy (TDLAS)

SIGNIFICANCE AND USE
5.1 H2S measurements in natural gas are performed to ensure concentrations satisfy gas purchase contract criteria and to prevent pipeline and associated component corrosion.  
5.2 Using TDLAS for the measurement of H2S in natural gas enables a high degree of selectivity with minimal interference from common constituents in natural gas streams. The TDLAS analyzer can detect changes in concentration with a relatively rapid response compared to other methods so that operators may take swift action when designated H2S concentrations are exceeded.  
5.3 Primary applications covered in this test method are listed in 5.3.1 and 5.3.2. Each application may have differing requirements and methods for gas sampling. Additionally, different natural gas applications may require unique spectroscopic considerations.  
5.3.1 Raw natural gas is found in production, gathering sites, and inlets to gas-processing plants characterized by potentially high levels of water (H2O), carbon dioxide (CO2), H2S, and heavy hydrocarbons. Gas-conditioning plants and skids are normally used to remove H2O, CO2, H2S, and other contaminants.  
5.3.2 High-quality “sales gas” is found in transportation pipelines, natural gas distribution (utilities), and natural gas power plant inlets. The gas is characterized by a very high percentage of methane (90 to 100 %) with small quantities of other hydrocarbons and trace levels of contaminants.
SCOPE
1.1 This test method is for the online determination of hydrogen sulfide (H2S) in natural gas using tunable diode laser absorption spectroscopy (TDLAS) analyzers also known as a “TDL analyzers.” The particular wavelength for H2S measurement varies by manufacturer, typically between 1000 and 10 000 nm with an individual laser having a tunable range of less than 10 nm. The H2S concentration ranges can be anywhere from 0-5 ppm(v) to 0-90 % by volume.  
1.2 Units—The values stated in SI units are to be regarded as the standard. No other units of measurement are included in this standard. TDLAS analyzers inherently output concentrations in unitless molar ratios such as ppm(v).
Note 1: Weight-per-volume units such as milligrams or grains of H2S per cubic foot or cubic meter can be derived from ppm(v) at “standard conditions” or standard temperature and pressure.  
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, health, and environmental practices and determine the applicability of regulatory limitations prior to use.  
1.4 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

General Information

Status
Published
Publication Date
31-Oct-2022
ICS
75.060 - Natural gas
Technical Committee
D03 - Gaseous Fuels
Drafting Committee
D03.12 - On-Line/At-Line Analysis of Gaseous Fuels
Current Stage
Ref Project

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ASTM D8488-22 - Standard Test Method for Determination of Hydrogen Sulfide (H<inf>2</inf>S) in Natural Gas by Tunable Diode Laser Spectroscopy (TDLAS)ASTM D8488-22 - Standard Test Method for Determination of Hydrogen Sulfide (H<inf>2</inf>S) in Natural Gas by Tunable Diode Laser Spectroscopy (TDLAS)
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ASTM D8488-22 - Standard Test Method for Determination of Hydrogen Sulfide (H<inf>2</inf>S) in Natural Gas by Tunable Diode Laser Spectroscopy (TDLAS)
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This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the
Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.
Designation:D8488 −22
Standard Test Method for
Determination of Hydrogen Sulfide (H S) in Natural Gas by
2
1
Tunable Diode Laser Spectroscopy (TDLAS)
This standard is issued under the fixed designation D8488; the number immediately following the designation indicates the year of
original adoption or, in the case of revision, the year of last revision. A number in parentheses indicates the year of last reapproval. A
superscript epsilon (´) indicates an editorial change since the last revision or reapproval.
1. Scope D5503 Practice for Natural Gas Sample-Handling and Con-
ditioning Systems for Pipeline Instrumentation (With-
1.1 This test method is for the online determination of
3
drawn 2017)
hydrogen sulfide (H S) in natural gas using tunable diode laser
2
D5504 TestMethodforDeterminationofSulfurCompounds
absorption spectroscopy (TDLAS) analyzers also known as a
in Natural Gas and Gaseous Fuels by Gas Chromatogra-
“TDLanalyzers.” The particular wavelength for H S measure-
2
phy and Chemiluminescence
ment varies by manufacturer, typically between 1000 and
D6228 TestMethodforDeterminationofSulfurCompounds
10 000 nm with an individual laser having a tunable range of
in Natural Gas and Gaseous Fuels by Gas Chromatogra-
less than 10 nm. The H S concentration ranges can be any-
2
phy and Flame Photometric Detection
where from 0-5 ppm(v) to 0-90 % by volume.
D6968 Test Method for Simultaneous Measurement of Sul-
1.2 Units—The values stated in SI units are to be regarded
fur Compounds and Minor Hydrocarbons in Natural Gas
as the standard. No other units of measurement are included in
and Gaseous Fuels by Gas Chromatography and Atomic
this standard. TDLAS analyzers inherently output concentra-
Emission Detection
tions in unitless molar ratios such as ppm(v).
D7551 Test Method for Determination of Total Volatile
Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum
NOTE 1—Weight-per-volume units such as milligrams or grains of H S
2
per cubic foot or cubic meter can be derived from ppm(v) at “standard Gases and Natural Gas by Ultraviolet Fluorescence
conditions” or standard temperature and pressure.
D7833 Test Method for Determination of Hydrocarbons and
1.3 This standard does not purport to address all of the Non-Hydrocarbon Gases in Gaseous Mixtures by Gas
safety concerns, if any, associated with its use. It is the
Chromatography
responsibility of the user of this standard to establish appro-
priate safety, health, and environmental practices and deter-
3. Terminology
mine the applicability of regulatory limitations prior to use.
3.1 Definitions—For definitions of general terms used in
1.4 This international standard was developed in accor-
D03 Gaseous Fuels standards, refer to Terminology D4150.
dance with internationally recognized principles on standard-
3.2 Definitions of Terms Specific to This Standard:
ization established in the Decision on Principles for the
3.2.1 absorption spectroscopy, n—refers to spectroscopic
Development of International Standards, Guides and Recom-
techniques that measure the absorption of electromagnetic
mendations issued by the World Trade Organization Technical
radiation as a function of frequency or wavelength because of
Barriers to Trade (TBT) Committee.
its interaction with a sample.
2. Referenced Documents
3.2.2 adsorption, n—adhesion of molecules to a solid sur-
2
face forming a molecular or atomic film.
2.1 ASTM Standards:
D1945 Test Method for Analysis of Natural Gas by Gas
3.2.3 chemometrics, n—field of science relating measure-
Chromatography
ments made on a chemical system or process to the state of the
D4150 Terminology Relating to Gaseous Fuels
system via application of mathematical or statistical methods.
3.2.4 desorption, n—phenomenon whereby a substance is
1 released from a surface (the opposite of adsorption).
ThistestmethodisunderthejurisdictionofASTMCommitteeD03onGaseous
Fuels and is the direct responsibility of Subcommittee D03.12 on On-Line/At-Line
3.2.5 heat trace, n—ribbon-shaped tape that uses electrical
Analysis of Gaseous Fuels.
resistance or tubing carrying steam to generate heat.
Current edition approved Nov. 1, 2022. Published November 2022. DOI:
10.1520/D8488-22.
2
For referenced ASTM standards, visit the ASTM website, www.astm.org, or
contact ASTM Customer Service at service@astm.org. For Annual Book of ASTM
3
Standards volume information, refer to the standard’s Document Summary page on The last approved version of this historical standard is referenced on
the ASTM website. www.astm.org.
Copyright © ASTM International, 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA 19428-2959. United States
1

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5.1 Elemental sulfur impacts the quality of pipeline natural gas and deposits on pipeline flanges, fittings and valves, thereby impacting their performance. Natural gas suppliers and distributers require a standardized test method for measuring elemental sulfur. Some government regulators are also interested in measuring elemental sulfur since it would provide a means for assessing the contribution of elemental sulfur in pipelines to the SOx emission inventory from burning of gaseous fuels. Use of this method in concert with sulfur gas laboratory test methods such as Test Methods D4084, D4468, D5504, and D6228 or on-line methods such as D7165 or D7166 can provide users with a comprehensive sulfur compound profile for natural gas or other gaseous fuels. Other applications may include elemental sulfur in particulate deposits such as diesel exhausts.
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1.1 This standard practice is intended for gravimetric determination of compressor oil carryover as aerosols using either a coalescing filter method or sorbent tube method.  
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This specification covers LNG density calculation models for use in the calculation or prediction of the densities of saturated liquefied natural gas (LNG) mixtures at a specified temperature range given the pressure, temperature, and composition of the mixture. Composition restrictions for the LNGs are given for methane, nitrogen, n-butane, i-butane, and pentanes. It is assumed that hydrocarbons with carbon numbers of six or greater are not present in the LNG solution. The mathematical models presented here are the extended corresponding states model, hard sphere model, revised Klosek and McKinley model, and the cell model.
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ASTM D7904-21(Test Method)
Standard Test Method for Determination of Water Vapor (Moisture Concentration) in Natural Gas by Tunable Diode Laser Spectroscopy (TDLAS)

SIGNIFICANCE AND USE
5.1 Moisture measurement in natural gas is performed to ensure sufficiently low levels for gas purchase contracts and to prevent corrosion. Moisture may also contribute to the formation of hydrates.  
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SCOPE
1.1 This test method covers online determination of vapor phase moisture concentration in natural gas using a tunable diode laser absorption spectroscopy (TDLAS) analyzer also known as a “TDL analyzer.” The particular wavelength for moisture measurement varies by manufacturer; typically between 1000 and 10 000 nm with an individual laser having a tunable range of less than 10 nm.  
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1.4 The moisture concentration range is 1 to 10 000 parts per million by volume (ppmv). It is unlikely that one spectrometer cell will be used to measure this entire range. For example, a TDL spectrometer may have a maximum measurement of 1 ppmv, 100 ppmv, 1000 ppmv, or 10 000 ppmv with varying degrees of accuracy and different lower detection limits.  
1.5 TDL absorption spectroscopy measures molar ratios such as ppmv or mole percentage. Volumetric ratios (ppmv and %) are not pressure d...

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5.1 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.  
5.2 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.
SCOPE
1.1 This test method covers a procedure for rapid and simple field determination of water vapor in natural gas pipelines. Available 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.  
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ASTM D1988-20(Test Method)
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SIGNIFICANCE AND USE
5.1 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 decline over time.  
5.2 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 training.
SCOPE
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 1: 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 6 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, health, and environmental practices and determine the applicability of regulatory limitations prior to use. For specific hazard statements, see 8.3.  
1.4 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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

SIGNIFICANCE AND USE
5.1 The measurement of hydrogen sulfide in natural gas is important because of gas quality specifications, the corrosive nature of H2S on pipeline materials, and the effects of H2S on utilization equipment.  
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Standard Test Method for Natural Gas Odor Intensity

SIGNIFICANCE AND USE
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.4
Note 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 This test method covers procedures to measure the odor level of natural gas by way of olfactory determination. No direct correlation may be ascertained between this test method and those methods available or under development that quantitatively measure the concentration of sulfur compounds in natural gas.  
4.3 This test method outlines general procedures to measure the odor detection levels of natural gas. It is the responsibility of persons using this test method to develop and maintain equipment and specific operating procedures to ensure public safety and compliance with all appropriate regulations.
SCOPE
1.1 This test method covers the procedures for determining the threshold detection level, readily detectable level, and odor intensity of natural gas using 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 any of these parameters for odorant in a 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, health, and environmental practices and determine the applicability of regulatory limitations prior to use.  
1.3 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

  • Standard
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    English language
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  • Standard
    3 pages
    English language
    sale 15% off