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ASTM D4810-06

(Test Method)

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

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

SIGNIFICANCE AND USE
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.
SCOPE
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.

General Information

Status
Historical
Publication Date
31-May-2006
ICS
75.060 - Natural gas
Technical Committee
D03 - Gaseous Fuels
Current Stage
Ref Project

Relations

Replaces
ASTM D4810-88(1999) - Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes
Effective Date
01-Jun-2006
Referred By
ASTM D7165-22 - Standard Practice for Gas Chromatograph Based On-line/At-line Analysis for Sulfur Content of Gaseous Fuels
Effective Date
01-Jun-2006

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ASTM D4810-06 - Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector TubesASTM D4810-06 - Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes
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ASTM D4810-06 - Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length-of-Stain Detector Tubes
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NOTICE: This standard has either been superseded and replaced by a new version or withdrawn.
Contact ASTM International (www.astm.org) for the latest information
Designation: D4810 – 06
Standard Test Method for
Hydrogen Sulfide in Natural Gas Using Length-of-Stain
1
Detector Tubes
This standard is issued under the fixed designation D4810; 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 a controlled rate of flow. The length of stain produced is
converted to ppm (by volume) hydrogen sulfide (H S), by
2
1.1 This test method covers a procedure for a rapid and
comparison to a calibration scale supplied by the manufacturer
simple field determination of hydrogen sulfide in natural gas
for each box of detection tubes (higher range tubes have units
pipelines. Available detector tubes provide a total measuring
of percent by volume). The system is direct reading, easily
range of 0.5 ppm by volume up to 40 % by volume, although
portable,andcompletelysuitedtomakingrapidspotchecksfor
the majority of applications will be on the lower end of this
hydrogen sulfide under field conditions.
range (that is, under 120 ppm).
1.2 Typically, sulfur dioxide and mercaptans may cause
4. Significance and Use
positive interferences. In some cases, nitrogen dioxide can
4.1 The measurement of hydrogen sulfide in natural gas is
cause a negative interference. Most detector tubes will have a
important because of the gas quality specifications, the corro-
“precleanse” layer designed to remove certain interferences up
sive nature of H S on pipeline materials, and the effects of H S
2 2
to some maximum interferent level. Consult manufacturers’
on utilization equipment.
instructions for specific interference information.
4.2 This test method provides inexpensive field screening of
1.3 The values stated in SI units are to be regarded as the
hydrogensulfide.Thesystemdesignissuchthatitmaybeused
standard.
by nontechnical personnel with a minimum of proper training.
1.4 This standard does not purport to address all of the
safety concerns, if any, associated with its use. It is the
5. Apparatus
responsibility of the user of this standard to establish appro-
5.1 Length-of-Stain Detector Tube and Calibration
priate safety and health practices and determine the applica-
Scale—A sealed glass tube with breakoff tips sized to fit the
bility of regulatory limitations prior to use.
tube holder of the pump. The reagent layer inside the tube,
typically a silica gel substrate coated with the active chemicals,
2. Referenced Documents
must be specific for hydrogen sulfide and must produce a
2.1 Gas Processors Association Standard:
distinct color change when exposed to a sample of gas
No. 2377-86 Test for Hydrogen Sulfide in Natural Gas
2 containing hydrogen sulfide. Any substances known to inter-
Using Length of Stain Tubes
fere must be listed in the instructions accompanying the tubes.
3. Summary of Test Method A calibration scale should be marked directly on the tube or
other markings which provide for easy interpretation of hydro-
3.1 The sample is drawn through a detector tube filled with
gen sulfide content from a separate calibration scale supplied
a specially prepared chemical.Any hydrogen sulfide present in
with the tubes. The calibration scale shall correlate hydrogen
the sampling reacts with the chemical to produce a color
sulfide concentration to the length of the color stain. Shelf life
changeorstain.Thelengthofthestainproducedinthedetector
of the detector tubes must be a minimum of two years from
tube, when exposed to a measured volume of sample, is
date of manufacture when stored according to manufacturers’
directly proportional to the amount of hydrogen sulfide present
recommendations.
in the sample.Ahand-operated piston or bellows-type pump is
5.2 Detector Tube Pump—A hand-operated pump of a
used to draw a measured volume of sample through the tube at
3
piston or bellows type. It must be capable of drawing 100 cm
per stroke of sample through the detector tube with a volume
3
3
1
tolerance of 65cm . It must be specifically designed for use
ThistestmethodisunderthejurisdictionofASTMCommitteeD03onGaseous
Fuels and is the direct responsibility of Subcommittee D03.07 on Analysis of with detector tubes.
Chemical Composition of Gaseous Fuels.
NOTE 1—A detector tube and pump together form a unit and must be
Current edition approved June 1, 2006. Published June 2006. Originally
approved in 1988. Last previous edition approved in 1999 as D4810 - 98 (1999).
DOI: 10.1520/D4810-06.
2 3
Available from Gas Processors Association, 1812 First National Bank Bldg., Direct Reading Colorimetric Indicator Tubes Manual , 1st ed., American
Tulsa, OK 74103. Industrial Hygiene Association, Akron, OH 44311, 1976.
Copyright © ASTM Internati
...

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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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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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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.  
5.2 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.
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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).  
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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, health, and environmental practices and determine the applicability of regulatory limitations prior to use.  
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Standard Test Method for Water Vapor in Natural Gas Using Length-of-Stain Detector Tubes

SIGNIFICANCE AND USE
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.  
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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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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, health, and environmental practices and determine the applicability of regulatory limitations prior to use.  
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Standard Test Method for Mercaptans in Natural Gas Using Length-of-Stain Detector Tubes

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.
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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.  
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