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ASTM D3588-98(2003)

(Practice)

Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels

Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels

SIGNIFICANCE AND USE
The heating value is a measure of the suitability of a pure gas or a gas mixture for use as a fuel; it indicates the amount of energy that can be obtained as heat by burning a unit of gas. For use as heating agents, the relative merits of gases from different sources and having different compositions can be compared readily on the basis of their heating values. Therefore, the heating value is used as a parameter for determining the price of gas in custody transfer. It is also an essential factor in calculating the efficiencies of energy conversion devices such as gas-fired turbines. The heating values of a gas depend not only upon the temperature and pressure, but also upon the degree of saturation with water vapor. However, some calorimetric methods for measuring heating values are based upon the gas being saturated with water at the specified conditions.
The relative density (specific gravity) of a gas quantifies the density of the gas as compared with that of air under the same conditions.
SCOPE
1.1 This practice covers procedures for calculating heating value, relative density, and compressibility factor at base conditions (14.696 psia and 60°F (15.6°C)) for natural gas mixtures from compositional analysis. It applies to all common types of utility gaseous fuels, for example, dry natural gas, reformed gas, oil gas (both high and low Btu), propane-air, carbureted water gas, coke oven gas, and retort coal gas, for which suitable methods of analysis as described in Section 6 are available. Calculation procedures for other base conditions are given.
1.2 The values stated in inch-pound units are to be regarded as the standard. The SI units 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.

General Information

Status
Historical
Publication Date
09-May-2003
ICS
75.160.30 - Gaseous fuels
Technical Committee
D03 - Gaseous Fuels
Drafting Committee
D03.03 - Determination of Heating Value and Relative Density of Gaseous Fuels
Current Stage
Ref Project

Relations

Replaces
ASTM D3588-98 - Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels
Effective Date
10-May-2003
Replaced By
ASTM D3588-98(2011) - Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels
Effective Date
01-Nov-2011
Referred By
ASTM F2239-10(2021) - Standard Test Method for Performance of Conveyor Broilers
Effective Date
10-May-2003
Referred By
ASTM D7551-10(2015) - Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases and Natural Gas by Ultraviolet Fluorescence
Effective Date
10-May-2003
Referred By
ASTM F1484-18(2023) - Standard Test Methods for Performance of Steam Cookers
Effective Date
10-May-2003
Referred By
ASTM F2861-20 - Standard Test Method for Enhanced Performance of Combination Oven in Various Modes
Effective Date
10-May-2003
Referred By
ASTM F1496-13(2019) - Standard Test Method for Performance of Convection Ovens
Effective Date
10-May-2003
Referred By
ASTM F1991-99(2021) - Standard Test Method for Performance of Chinese (Wok) Ranges
Effective Date
10-May-2003
Referred By
ASTM D7164-21 - Standard Practice for On-line/At-line Heating Value Determination of Gaseous Fuels by Gas Chromatography
Effective Date
10-May-2003
Referred By
ASTM D8251-23 - Standard Practice for Determining Compressor Oil Carryover in Compressed Natural Gas Used as a Natural Gas Motor Vehicle Fuel
Effective Date
10-May-2003
Referred By
ASTM F2379-04(2021) - Standard Test Method for Energy Performance of Powered Open Warewashing Sinks
Effective Date
10-May-2003
Referred By
ASTM D7940-21 - Standard Practice for Analysis of Liquefied Natural Gas (LNG) by Fiber-Coupled Raman Spectroscopy
Effective Date
10-May-2003
Referred By
ASTM D7314-21 - Standard Practice for Determination of the Heating Value of Gaseous Fuels using Calorimetry and On-line/At-line Sampling
Effective Date
10-May-2003
Referred By
ASTM F1605-14(2019) - Standard Test Method for Performance of Double-Sided Griddles
Effective Date
10-May-2003
Referred By
ASTM F2238-20 - Standard Test Method for Performance of Rapid Cook Ovens
Effective Date
10-May-2003

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ASTM D3588-98(2003) - Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous FuelsASTM D3588-98(2003) - Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels
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ASTM D3588-98(2003) - Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density of Gaseous Fuels
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Standards Content (Sample)

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:D3588–98 (Reapproved 2003)
Standard Practice for
Calculating Heat Value, Compressibility Factor, and Relative
1
Density of Gaseous Fuels
This standard is issued under the fixed designation D3588; 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 (LP) Gases and Propene Concentrates by Gas Chromatog-
raphy
1.1 This practice covers procedures for calculating heating
D2650 Test Method for Chemical Composition of Gases by
value, relative density, and compressibility factor at base
Mass Spectrometry
conditions (14.696 psia and 60°F (15.6°C)) for natural gas
2
2.2 GPA Standards:
mixtures from compositional analysis. It applies to all com-
GPA2145 PhysicalConstantsfortheParaffinHydrocarbons
montypesofutilitygaseousfuels,forexample,drynaturalgas,
4
and Other Components in Natural Gas
reformed gas, oil gas (both high and low Btu), propane-air,
GPA Standard 2166 Methods of Obtaining Natural Gas
carbureted water gas, coke oven gas, and retort coal gas, for
4
Samples for Analysis by Gas Chromatography
which suitable methods of analysis as described in Section 6
GPA 2172 Calculation of Gross Heating Value, Relative
are available. Calculation procedures for other base conditions
Density, and Compressibility Factor for Natural Gas
are given.
,
4 5
Mixtures from Compositional Analysis
1.2 The values stated in inch-pound units are to be regarded
GPAStandard2261 MethodofAnalysisforNaturalGasand
as the standard. The SI units given in parentheses are for
4
Similar Gaseous Mixtures by Gas Chromatography
information only.
GPA Technical Publication TP-17 Table of Physical Prop-
1.3 This standard does not purport to address all of the
erties of Hydrocarbons for Extended Analysis of Natural
safety concerns, if any, associated with its use. It is the
4
Gases
responsibility of the user of this standard to establish appro-
4
GPSA Data Book, Fig. 23-2, Physical Constants
priate safety and health practices and determine the applica-
2.3 TRC Document:
bility of regulatory limitations prior to use.
6
TRC Thermodynamic Tables—Hydrocarbons
2. Referenced Documents
2.4 ANSI Standard:
3
ANSI Z 132.1-1969: Base Conditions of Pressure and
2.1 ASTM Standards:
Temperature for the Volumetric Measurement of Natural
D1717 Method for Analysis of Commercial Butane-Butene
7,8
Gas
Mixtures and Isobutylene by Gas Chromatography
D1945 Test Method for Analysis of Natural Gas by Gas
3. Terminology
Chromatography
3.1 Definitions:
D1946 Practice for Analysis of Reformed Gas by Gas
3.1.1 British thermal unit—the defined International Tables
Chromatography
British thermal unit (Btu).
D2163 Test Method for Analysis of Liquefied Petroleum
3.1.1.1 Discussion—The defining relationships are:
–1 –1
1 Btu•lb = 2.326 J•g (exact)
1
This practice is under the jurisdiction of ASTM Committee D03 on Gaseous
4
Fuels and is the direct responsibility of Subcommittee D03.03 on Determination of
Available from Gas ProcessorsAssociation (GPA), 6526 E. 60th St.,Tulsa, OK
Heating Value and Relative Density of Gaseous Fuels. 74145, http://www.gasprocessors.com.
5
Current edition approved May 10, 2003. Published May 2003. Originally The sole source of supply of the program in either BASIC or FORTRAN
approved in 1998. Last previous edition approved in 1998 as D3588 – 98. DOI: suitable for running on computers known to the committee at this time is the Gas
10.1520/D3588-98R03. ProcessorsAssociation. If you are aware of alternative suppliers, please provide this
2
A more rigorous calculation of Z(T,P) at both base conditions and higher information to ASTM International Headquarters. Your comments will receive
1
pressures can be made using the calculation procedures in “Compressibility and careful consideration at a meeting of the responsible technical committee , which
Super Compressibility for Natural Gas and Other Hydrocarbon Gases,” American you may attend.
6
Gas Association Transmission Measurement Committee Report 8, AGA Cat. No. AvailablefromThermodynamicsResearchCenter,TheTexasA&MUniversity,
XQ1285, 1985, AGA, 1515 Wilson Blvd., Arlington, VA 22209. College Station, TX 77843-3111.
3 7
For referenced ASTM standards, visit the ASTM website, www.astm.org, or Available fromAmerican National Standards Institute (ANSI), 25 W. 43rd St.,
contact ASTM Customer Service at service@astm.org. For Annual Book of ASTM 4th Floor, New York, NY 10036, http://www.ansi.org.
8
Standards volume information, refer to the standard’s Document Summary page on Supporting data have been filed at ASTM International Headquarters and may
the ASTM website. be obtained by requesting Research
...

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1.1 This terminology standard covers the compilation of terminology developed by Committee D03 on Gaseous Fuels. It does not include terms, definitions, abbreviations, acronyms, and symbols specific to only a single D03 standard in which they appear. These terms, definitions, abbreviations, acronyms, and symbols are used in:  
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Standard Test Method for Determination of Elemental Sulfur in Natural Gas

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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 test method is primarily for the determination of elemental sulfur in natural gas pipelines, but it may be applied to other gaseous fuel pipelines and applications provided the user has validated its suitability for use. The detection range for elemental sulfur, reported as sulfur, is 0.0018 mg/L to 30 mg/L. The results may also be reported in units of mg/kg or ppm.  
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Standard Test Method for Analysis of Hydrogen Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method)

SIGNIFICANCE AND USE
5.1 This test method is useful in determining the concentration of hydrogen sulfide in gaseous samples and in verifying compliance with operational needs and/or environmental limitations for H2S content. The automated performance operation of this method allows unattended measurement of H2S concentration. The user is referred to Practice D7166 for unattended on-line use of instrumentation based upon the lead acetate reaction rate method.
SCOPE
1.1 This test method covers the determination of hydrogen sulfide (H2S) in gaseous fuels. It is applicable to the measurement of H2S in natural gas, liquefied petroleum gas (LPG), substitute natural gas, landfill gas, sewage treatment off gasses, recycle gas, flare gasses, and mixtures of fuel gases. This method can also be used to measure the hydrogen sulfide concentration in carbon dioxide. Air does not interfere. The applicable range is 0.1 to 16 parts per million by volume (ppm/v) (approximately 0.1 to 22 mg/m3) and may be extended to 100 % H2S by manual or automatic volumetric dilution.  
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ASTM D1072-23(Test Method)
Standard Test Method for Total Sulfur in Fuel Gases by Combustion and Barium Chloride Titration

ABSTRACT
This test method is for the determination of total sulfur in combustible fuel gases and is applicable to natural gases, manufactured gases, mixed gases, and other miscellaneous gaseous fuels. For the use of barium chloride titration following collection of sulfur dioxide by alternative procedures, ammonia, amines, substances producing water soluble cations, and fluorides will interfere with the titration. The apparatus includes the following: (1) burner, (2) chimneys, absorbers, and spray traps, (3) flow meter, (4) vacuum system, (5) air-purifying system, and (6) monometer. The schematic diagrams of the gas burner, combustion and absorption apparatus, suction system, and purified air system are provided. Reagent grade chemicals shall be used in all tests and include: (1) water, (2) denatured ethyl or isopropyl alcohol, (3) barium chloride, standard solution, (4) hydrochloric acid, (5) hydrogen peroxide, (6) iso-propanol, (7) potassium hydrogen phthalate, (8) phenolphthalein, (9) methyl orange indicator solution, (10) silver nitrate solution, (11) sodium carbonate solution, (12) sodium hydroxide solution, (13) sulfuric acid, (14) tetrahydroxyquinone indicator, and (15) thorin indicator. The procedure for the following are detailed: (1) calibration and standardization of sodium hydroxide, sulfuric acid, and barium chloride solutions, (2) preparation of apparatus, (3) sulfur determination, (4) analysis of absorbent, and (5) quality assurance. The formula of calculating the volume of gas in standard cubic feet burned during the determination and the concentration of sulfur from the results of titration are given.
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5.1 The methane number (MN) is a measure of the resistance of the gaseous fuel to autoignition (knock) when used in an internal combustion engine. The relative merits of gaseous fuels from different sources and having different compositions can be compared readily on the basis of their methane numbers. Therefore, the calculated methane number (MNC) is used as a parameter for determining the suitability of a gaseous fuel for internal combustion engines in both mobile and stationary applications.
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1.5 Units—The values stated in SI units are to be regarded as standard. Other units of measurement included in this standard are provided for information only and are not considered standard.  
1.6 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 Hydrogen Purity Analysis Using a Continuous Wave Cavity Ring-Down Spectroscopy Analyzer

SIGNIFICANCE AND USE
5.1 Proton exchange membranes (PEM) used in fuel cells are susceptible to contamination from a number of species that can be found in hydrogen. It is critical that these contaminants be measured and verified to be present at or below the amounts stated in SAE J2719 and ISO 14687 to ensure both fuel cell longevity and optimum efficiency. Contaminant concentrations as low as single-figure ppb(v) for some species can seriously compromise the life span and efficiency of PEM fuel cells. The presence of contaminants in fuel-cell-grade hydrogen can, in some cases, have a permanent adverse impact on fuel cell efficiency and usability. It is critical to monitor the concentration of key contaminants in hydrogen during the production phase through to delivery of the fuel to a fuel cell vehicle or other PEM fuel cell application. In ISO 14687, the upper limits for the contaminants are specified. Refer to SAE J2719 (see 2.3) for specific national and regional requirements. For hydrogen fuel that is transported and delivered as a cryogenic liquid, there is additional risk of introducing impurities during transport and delivery operations. For instance, moisture can build up over time in liquid transfer lines, critical control components, and long-term storage facilities, which can lead to ice buildup within the system and subsequent blockages that pose a safety risk or the introduction of contaminants into the gas stream upon evaporation of the liquid. Users are reminded to consult Practice D7265 for critical thermophysical properties such as the ortho/para hydrogen spin isomer inversion that can lead to additional hazards in liquid hydrogen usage.
SCOPE
1.1 This test method describes contaminant determination in fuel cell grade hydrogen as specified in relevant ASTM and ISO standards using cavity ring-down spectroscopy (CRDS). This standard test method is for the measurement of one or multiple contaminants including, but not limited to, water (H2O), oxygen (O2), methane (CH4), carbon dioxide (CO2), carbon monoxide (CO), ammonia (NH3), and formaldehyde (H2CO), henceforth referred to as “analyte.”  
1.2 This test method applies to CRDS analyzers with one or multiple sensor modules (see 6.2 for definition). This test method describes sampling apparatus design, operating procedures, and quality control procedures required to obtain the stated levels of precision and accuracy.  
1.3 The values stated in either SI units or inch-pound units are to be regarded separately as standard. The values stated in each system are not necessarily exact equivalents; therefore, to ensure conformance with the standard, each system shall be used independently of the other, and values from the two systems shall not be combined.  
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.  
1.5 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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ASTM D7493-22(Test Method)
Standard Test Method for Online Measurement of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatograph and Electrochemical Detection

SIGNIFICANCE AND USE
5.1 Gaseous fuels, such as natural gas, petroleum gases and bio-gases, contain sulfur compounds that are naturally occurring or that are added as odorants for safety purposes. These sulfur compounds are odorous, toxic, corrosive to equipment, and can inhibit or destroy catalysts employed in gas processing and other end uses. Their accurate continuous measurement is important to gas processing, operation and use, and is frequently of regulatory interest.  
5.2 Small amounts (typically, total of 4 to 6 ppm(v)) of sulfur odorants are added to natural gas and other fuel gases for safety purposes. Some sulfur odorants are reactive and may be oxidized to form more stable sulfur compounds having higher odor thresholds which adversely impact the potential safety of the gas delivery systems and gas users. Gaseous fuels are analyzed for sulfur compounds and odorant levels to assist in pipeline integrity surveillance and to ensure appropriate odorant levels for public safety.  
5.3 This method offers an on-line method to continuously identify and quantify individual target sulfur species in gaseous fuel with automatic calibration and validation.
SCOPE
1.1 This test method is for on-line measurement of gas phase sulfur-containing compounds in gaseous fuels by gas chromatography (GC) and electrochemical (EC) detection. This test method is applicable to hydrogen sulfide, C1 to C4 mercaptans, sulfides, and tetrahydrothiophene (THT).  
1.1.1 Carbonyl sulfide (COS) is not measured according to this test method.  
1.1.2 The detection range for sulfur compounds is approximately from 0.1 to 100 ppm(v) (mL/m3) or 0.1 to 100 mg/m3 at 25 °C, 101.3 kPa. The detection range will vary depending on the sample injection volume, chromatographic peak separation, and the sensitivity of the specific EC detector.  
1.2 This test method describes a GC-EC method using capillary GC columns and a specific detector for natural gas and other gaseous fuels composed of mainly light (C4 and smaller) hydrocarbons. Alternative GC columns including packed columns, detector designs, and instrument parameters may be used, provided that chromatographic separation, quality control, and measurement objectives needed to comply with user or regulator needs, or both, are achieved.  
1.3 This test method does not intend to identify and measure all individual sulfur species and is mainly employed for monitoring naturally occurring reduced sulfur compounds commonly found in natural gas and fuel gases or employed as an odorant in these gases.  
1.4 This test method is typically employed in repetitive or continuous on-line monitoring of sulfur components in natural gas and fuel gases using a single sulfur calibration standard. Guidance for producing calibration curves specific to particular analytes or enhanced quality control procedures can be found in Test Methods D5504, D5623, D6228, D6968, ISO 19739, or GPA 2199.  
1.5 The test method can be used for measuring sulfur compounds listed in Table 1 in air or other gaseous matrices, provided that compounds that can interfere with the GC separation and electrochemical detection are not present.  
1.6 This test method is written as a companion to Practices D5287, D7165 and D7166.  
1.7 Units—The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.  
1.8 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.  
1.9 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 Tec...

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  • Standard
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    English language
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