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ASTM D1657-22e1

(Test Method)

Standard Test Method for Density or Relative Density of Light Hydrocarbons by Pressure Hydrometer

Standard Test Method for Density or Relative Density of Light Hydrocarbons by Pressure Hydrometer

SIGNIFICANCE AND USE
5.1 The density or relative density of light hydrocarbons and liquefied petroleum gases is used in custody transfer quantity calculations or to satisfy transportation, storage, and regulatory requirements.
SCOPE
1.1 This test method covers the determination of the density or relative density of light hydrocarbons including liquefied petroleum gases (LPG) having Reid vapor pressures exceeding 101.325 kPa (14.696 psi).  
1.2 The prescribed apparatus should not be used for materials having vapor pressures higher than 1.4 MPa (200 psi) at the test temperature. This pressure limit is dictated by the type of equipment. Higher pressures can apply to other equipment designs.  
1.3 The initial pressure hydrometer readings obtained are uncorrected hydrometer readings and not density measurements. Readings are measured on a hydrometer at either the reference temperature or at another convenient temperature, and readings are corrected for the meniscus effect, the thermal glass expansion effect, alternate calibration temperature effects and to the reference temperature by means of calculations and Adjunct to D1250 Guide for Petroleum Measurement Tables (API MPMS Chapter 11.1) or API MPMS Chapter 11.2.4 (GPA TP-27), as applicable.  
1.4 Values determined as density or relative density can be converted to equivalent values in the other units or alternative reference temperatures by means of Interconversion Procedures API MPMS  Chapter 11.5, or Adjunct to D1250 Guide for Petroleum Measurement Tables (API MPMS Chapter 11.1) or API MPMS Chapter 11.2.4 (GPA TP-27), as applicable.  
1.5 The calculations required in Section 11 shall be applied to the initial pressure hydrometer reading with observations and results reported as required by Section 11 prior to use in a subsequent calculation procedure (measurement ticket calculation, meter factor calculation, or base prover volume determination).  
1.6 Annex A1 contains a procedure for verifying or certifying the equipment for this test method.  
1.7 The values in SI units are to be regarded as the standard. US Customary values shown in adjacent parentheses are for information only and may not be exactly equivalent. Both SI and customary units have been rounded so that they may not be exactly equivalent.  
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 Technical Barriers to Trade (TBT) Committee.

General Information

Status
Published
Publication Date
30-Jun-2022
ICS
75.080 - Petroleum products in general
Technical Committee
D02 - Petroleum Products, Liquid Fuels, and Lubricants
Drafting Committee
D02.02 - Hydrocarbon Measurement for Custody Transfer (Joint ASTM-API)
Current Stage
Ref Project

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ASTM D1657-22e1 - Standard Test Method for Density or Relative Density of Light Hydrocarbons by Pressure HydrometerASTM D1657-22e1 - Standard Test Method for Density or Relative Density of Light Hydrocarbons by Pressure Hydrometer
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ASTM D1657-22e1 - Standard Test Method for Density or Relative Density of Light Hydrocarbons by Pressure Hydrometer
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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.
´1
Designation: D1657 − 22
Manual of Petroleum Measurement Standards (MPMS), Chapter 9.2
Standard Test Method for
Density or Relative Density of Light Hydrocarbons by
1
Pressure Hydrometer
This standard is issued under the fixed designation D1657; 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
ε NOTE—Editorially corrected adjunct information in March 2023.
1. Scope* and results reported as required by Section 11 prior to use in a
subsequent calculation procedure (measurement ticket
1.1 This test method covers the determination of the density
calculation, meter factor calculation, or base prover volume
or relative density of light hydrocarbons including liquefied
determination).
petroleum gases (LPG) having Reid vapor pressures exceeding
101.325 kPa (14.696 psi). 1.6 Annex A1 contains a procedure for verifying or certify-
ing the equipment for this test method.
1.2 The prescribed apparatus should not be used for mate-
rials having vapor pressures higher than 1.4 MPa (200 psi) at 1.7 The values in SI units are to be regarded as the standard.
the test temperature. This pressure limit is dictated by the type US Customary values shown in adjacent parentheses are for
of equipment. Higher pressures can apply to other equipment information only and may not be exactly equivalent. Both SI
designs. and customary units have been rounded so that they may not be
exactly equivalent.
1.3 The initial pressure hydrometer readings obtained are
1.8 This standard does not purport to address all of the
uncorrected hydrometer readings and not density measure-
safety concerns, if any, associated with its use. It is the
ments. Readings are measured on a hydrometer at either the
responsibility of the user of this standard to establish appro-
reference temperature or at another convenient temperature,
priate safety, health, and environmental practices and deter-
and readings are corrected for the meniscus effect, the thermal
mine the applicability of regulatory limitations prior to use.
glass expansion effect, alternate calibration temperature effects
1.9 This international standard was developed in accor-
and to the reference temperature by means of calculations and
dance with internationally recognized principles on standard-
Adjunct to D1250 Guide for Petroleum Measurement Tables
ization established in the Decision on Principles for the
(API MPMS Chapter 11.1) or API MPMS Chapter 11.2.4 (GPA
Development of International Standards, Guides and Recom-
TP-27), as applicable.
mendations issued by the World Trade Organization Technical
1.4 Values determined as density or relative density can be
Barriers to Trade (TBT) Committee.
converted to equivalent values in the other units or alternative
reference temperatures by means of Interconversion Proce-
2. Referenced Documents
dures API MPMS Chapter 11.5, or Adjunct to D1250 Guide for
2
2.1 ASTM Standards:
Petroleum Measurement Tables (API MPMS Chapter 11.1) or
D1250 Guide for the Use of the Joint API and ASTM
API MPMS Chapter 11.2.4 (GPA TP-27), as applicable.
Adjunct for Temperature and Pressure Volume Correction
1.5 The calculations required in Section 11 shall be applied
Factors for Generalized Crude Oils, Refined Products, and
to the initial pressure hydrometer reading with observations
Lubricating Oils: API MPMS Chapter 11.1
D1265 Practice for Sampling Liquefied Petroleum (LP)
Gases, Manual Method
1
This test method is under the jurisdiction of ASTM Committee D02 on
D1298 Test Method for Density, Relative Density, and API
Petroleum Products, Liquid Fuels, and Lubricants and the API Committee on
Petroleum Measurement, and is the direct responsibility of Subcommittee D02.02
Gravity of Crude Petroleum and Liquid Petroleum Prod-
/COMQ, the joint ASTM-API Committee on Hydrocarbon Measurement for
ucts by Hydrometer Method (API MPMS Chapter 9.1)
Custody Transfer (Joint ASTM-API). This test method has been approved by the
sponsoring committees and accepted by the Cooperating Societies in accordance
2
with established procedures. For referenced ASTM standards, visit the ASTM website, www.astm.org, or
Current edition approved July 1, 2022. Published July 2022. Originally approved contact ASTM Customer Service at service@astm.org. For Annual Book of ASTM
in 1939. Last previous edition approved in 2017 as D1657 – 12 (2017). DOI: Standards volume information, refer to the standard’s Document Summary page on
10.1520/D1657-22E01. the AS
...

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5.1 Some petroleum products are treated with mineral acid as part of the refining procedure. Obviously, any residual mineral acid in a petroleum product is undesirable. The absence of a positive indication in the test for acidity of the distillation residue or aqueous extract of a hydrocarbon liquid is an assurance of the care used in refining the fuel or solvent.
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5.1 Sulfur present as mercaptans or as hydrogen sulfide in distillate fuels and solvents can attack many metallic and non-metallic materials in fuel and other distribution systems. A negative result in the doctor test ensures that the concentration of these compounds is insufficient to cause such problems in normal use.
SCOPE
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4.1 This test method provides a means of monitoring the sulfur level of various petroleum products and additives. This knowledge can be used to predict performance, handling, or processing properties. In some cases the presence of sulfur compounds is beneficial to the product and monitoring the depletion of sulfur can provide useful information. In other cases the presence of sulfur compounds is detrimental to the processing or use of the product.
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1.1 This practice covers the establishment and maintenance of the essentials of a quality management system in laboratories engaged in the analysis of petroleum products, liquid fuels, and lubricants. It is designed to be used in conjunction with Practice D6299.
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SCOPE
1.1 This test method covers the atmospheric distillation of petroleum products and liquid fuels using a laboratory batch distillation unit to determine quantitatively the boiling range characteristics of such products as light and middle distillates, automotive spark-ignition engine fuels with or without oxygenates (see Note 1), aviation gasolines, aviation turbine fuels, diesel fuels, biodiesel blends up to 30 % volume, marine fuels, special petroleum spirits, naphthas, white spirits, kerosines, and Grades 1 and 2 burner fuels.
Note 1: An interlaboratory study was conducted in 2008 involving 11 different laboratories submitting 15 data sets and 15 different samples of ethanol-fuel blends containing 25 % volume, 50 % volume, and 75 % volume ethanol. The results indicate that the repeatability limits of these samples are comparable or within the published repeatability of the method (with the exception of FBP of 75 % ethanol-fuel blends). On this basis, it can be concluded that Test Method D86 is applicable to ethanol-fuel blends such as Ed75 and Ed85 (Specification D5798) or other ethanol-fuel blends with greater than 10 % volume ethanol. See ASTM RR:D02-1694 for supporting data.2  
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1.5 WARNING—Mercury has been designated by many regulatory agencies as a hazardous substance that can cause serious medical issues. Mercury, or its vapor, has been demonstrated to be hazardous to health and corrosive to materials. Use Caution when handling mercury and mercury-containing products. See the applicable product Safety Data Sheet (SDS) for additional information. The potential exists that selling mercury or mercury-containing products, or both, is prohibited by local or national law. Users must determine legality of sales in their location.  
1.6 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibilit...

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5.1 Knowledge of the boiling point distribution of stabilized crude oils is important for the marketing, scheduling, and processing of crude oil in the petroleum industry. Test Method D7169 and IP 545 purport to give such a distribution in crude oils, but are susceptible to significant errors in the light ends portion of the distribution as well as in the mass recovery of the whole crude oil due to the interference imposed by the diluent solvent. This test method allows for more accurate determination of the front end of the boiling point distribution curve, in addition to providing important C1 to C9 (nonane) component level information, and more accurate mass recovery at C9 (nonane).
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1.1 This test method specifies a method to determine the boiling range distribution of hydrocarbons in stabilized crude oil up to and including n-nonane. A stabilized crude oil is defined as having a Reid Vapor Pressure equivalent to or less than 82.7 kPa. The results of this test method can be combined with those from Test Method D7169 and IP 545 to give a full boiling point distribution of a crude oil (see Appendix X3).  
1.2 The values stated in SI units are to be regarded as the standard. The values given in parentheses are provided for information purposes only.  
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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 Paraffin, Naphthene, and Aromatic Hydrocarbon Type Analysis in Petroleum Distillates Through 200 °C by Multi-Dimensional Gas Chromatography

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5.1 A knowledge of the composition of hydrocarbon refinery streams is useful for process control and quality assurance.  
5.2 Aromatics in gasoline are soon to be limited by federal mandate. This test method can be used to provide such information.
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1.1 This test method covers the determination of paraffins, naphthenes, and aromatics by carbon number in low olefinic hydrocarbon streams having final boiling points of 200 °C or less. Hydrocarbons with boiling points greater than 200 °C and less than 270 °C are reported as a single group. Olefins, if present, are hydrogenated and the resultant saturates are included in the paraffin and naphthene distribution. Aromatics boiling at C9 and above are reported as a single aromatic group.  
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1.4.1 The abbreviation for SI unit “coulomb” is “C”.  
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