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ASTM D5002-22

(Test Method)

Standard Test Method for Density, Relative Density, and API Gravity of Crude Oils by Digital Density Analyzer

Standard Test Method for Density, Relative Density, and API Gravity of Crude Oils by Digital Density Analyzer

SIGNIFICANCE AND USE
5.1 Density is a fundamental physical property that may be used in conjunction with other properties to characterize the quality of crude oils.  
5.2 The density or relative density of crude oils is used for the conversion of measured volumes to volumes at the standard temperatures of 15 °C or 60 °F and for the conversion of crude mass measurements into volume units.  
5.3 The application of the density result obtained from this test method, for fiscal or custody transfer accounting calculations, may require measurements of the water and sediment contents obtained on similar specimens of the crude oil parcel.
SCOPE
1.1 This test method covers the determination of the density, relative density, and API gravity of crude oils that may be handled in a normal fashion as liquids at test temperatures between 15 °C and 35 °C utilizing either manual or automated sample injection equipment. This test method applies to crude oils with high vapor pressures provided appropriate precautions are taken to prevent vapor loss during transfer of the sample to the density analyzer.  
1.2 This test method was evaluated in interlaboratory study testing using crude oils in the 0.75 g/mL to 0.95 g/mL range. Lighter crude oil may require special handling to prevent vapor losses.  
1.3 The values stated in SI units are to be regarded as standard. Other units of measurement are included in this standard. The accepted units of measurement of density are grams per millilitre and kilograms per cubic metre.  
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. Specific warning statements are given in 7.4, 7.5, and 7.6.  
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.

General Information

Status
Published
Publication Date
30-Jun-2022
ICS
75.040 - Crude petroleum
Technical Committee
D02 - Petroleum Products, Liquid Fuels, and Lubricants
Drafting Committee
D02.04.0D - Physical and Chemical Methods
Current Stage
Ref Project

Relations

Refers
ASTM D1217-20 - Standard Test Method for Density and Relative Density (Specific Gravity) of Liquids by Bingham Pycnometer
Effective Date
01-May-2020

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Standards Content (Sample)

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: D5002 − 22
Standard Test Method for
Density, Relative Density, and API Gravity of Crude Oils by
1
Digital Density Analyzer
This standard is issued under the fixed designation D5002; the number immediately following the designation indicates the year of
original adoption or, in the case of revision, the year of last revision.Anumber in parentheses indicates the year of last reapproval.A
superscript epsilon (´) indicates an editorial change since the last revision or reapproval.
1. Scope* D287Test Method forAPI Gravity of Crude Petroleum and
Petroleum Products (Hydrometer Method)
1.1 Thistestmethodcoversthedeterminationofthedensity,
D941Test Method for Density and Relative Density (Spe-
relative density, and API gravity of crude oils that may be
cific Gravity) of Liquids by Lipkin Bicapillary Pycnom-
handled in a normal fashion as liquids at test temperatures
3
eter (Withdrawn 1993)
between 15°C and 35°C utilizing either manual or automated
D1193Specification for Reagent Water
sample injection equipment. This test method applies to crude
D1217Test Method for Density and Relative Density (Spe-
oils with high vapor pressures provided appropriate precau-
cific Gravity) of Liquids by Bingham Pycnometer
tions are taken to prevent vapor loss during transfer of the
D1250Guide for the Use of the Joint API and ASTM
sample to the density analyzer.
Adjunct for Temperature and Pressure Volume Correction
1.2 This test method was evaluated in interlaboratory study
FactorsforGeneralizedCrudeOils,RefinedProducts,and
testing using crude oils in the 0.75g⁄mL to 0.95g⁄mL range.
Lubricating Oils: API MPMS Chapter 11.1
Lightercrudeoilmayrequirespecialhandlingtopreventvapor
D1298Test Method for Density, Relative Density, or API
losses.
Gravity of Crude Petroleum and Liquid Petroleum Prod-
1.3 The values stated in SI units are to be regarded as ucts by Hydrometer Method
D4052Test Method for Density, Relative Density, and API
standard. Other units of measurement are included in this
standard. The accepted units of measurement of density are Gravity of Liquids by Digital Density Meter
D4057Practice for Manual Sampling of Petroleum and
grams per millilitre and kilograms per cubic metre.
Petroleum Products
1.4 This standard does not purport to address all of the
D4177Practice for Automatic Sampling of Petroleum and
safety concerns, if any, associated with its use. It is the
Petroleum Products
responsibility of the user of this standard to establish appro-
D4377TestMethodforWaterinCrudeOilsbyPotentiomet-
priate safety, health, and environmental practices and deter-
3
ric Karl Fischer Titration (Withdrawn 2020)
mine the applicability of regulatory limitations prior to use.
Specific warning statements are given in 7.4, 7.5, and 7.6.
3. Terminology
1.5 This international standard was developed in accor-
3.1 Definitions:
dance with internationally recognized principles on standard-
3.1.1 density, n—mass per unit volume at a specified tem-
ization established in the Decision on Principles for the
perature.
Development of International Standards, Guides and Recom-
3
mendations issued by the World Trade Organization Technical
3.1.1.1 Discussion—TheSIunitofdensityiskg/m ;theunit
3
Barriers to Trade (TBT) Committee.
ofmeasureg/cm iscommonlyusedinindustry.Lesspreferred
units, for example, kg/L or g/mL, are still in use.
2. Referenced Documents
3.1.2 relative density, n—the ratio of the density of a
2
2.1 ASTM Standards:
material at a stated temperature to the density of water at a
stated temperature.
1
This test method is under the jurisdiction of ASTM Committee D02 on
3.1.2.1 Discussion—Relative density is also commonly
Petroleum Products, Liquid Fuels, and Lubricants and is the direct responsibility of
knownasspecificgravity.Commonlyusedstatedtemperatures
Subcommittee D02.04.0D on Physical and Chemical Methods.
are 20°C⁄20°C, 15°C⁄15°C, 20°C⁄4°C and 60°F⁄60°F.
Current edition approved July 1, 2022. Published August 2022. Originally
approved in 1989. Last previous edition approved in 2019 as D5002–19. DOI: “Relative density” was historically known as the deprecated
10.1520/D5002-22.
term “specific gravity”.
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.
*A Summary of Changes section appears at the end of this standard
Copyright © ASTM International, 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA 19428-2959. United States
1

-----------
...

This document is not an ASTM standard and is intended only to provide the user of an ASTM standard an indication of what changes have been made to the previous version. Because
it may not be technically possible to adequately depict all changes accurately, ASTM recommends that users consult prior editions as appropriate. In all cases only the current version
of the standard as published by ASTM is to be considered the official document.
Designation: D5002 − 19 D5002 − 22
Standard Test Method for
Density, Relative Density, and API Gravity of Crude Oils by
1
Digital Density Analyzer
This standard is issued under the fixed designation D5002; 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*
1.1 This test method covers the determination of the density, relative density, and API gravity of crude oils that may be handled
in a normal fashion as liquids at test temperatures between 15 °C and 35 °C utilizing either manual or automated sample injection
equipment. This test method applies to crude oils with high vapor pressures provided appropriate precautions are taken to prevent
vapor loss during transfer of the sample to the density analyzer.
1.2 This test method was evaluated in interlaboratory study testing using crude oils in the 0.75 g ⁄mL to 0.95 g ⁄mL range. Lighter
crude oil may require special handling to prevent vapor losses.
1.3 The values stated in SI units are to be regarded as standard. Other units of measurement are included in this standard. The
accepted units of measurement of density are grams per millilitre and kilograms per cubic metre.
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. Specific warning statements are given in 7.4, 7.5, and 7.6.
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.
2. Referenced Documents
2
2.1 ASTM Standards:
D287 Test Method for API Gravity of Crude Petroleum and Petroleum Products (Hydrometer Method)
D941 Test Method for Density and Relative Density (Specific Gravity) of Liquids by Lipkin Bicapillary Pycnometer (Withdrawn
3
1993)
D1193 Specification for Reagent Water
D1217 Test Method for Density and Relative Density (Specific Gravity) of Liquids by Bingham Pycnometer
D1250 Guide for the Use of the Joint API and ASTM Adjunct for Temperature and Pressure Volume Correction Factors for
Generalized Crude Oils, Refined Products, and Lubricating Oils: API MPMS Chapter 11.1
1
This test method is under the jurisdiction of ASTM Committee D02 on Petroleum Products, Liquid Fuels, and Lubricants and is the direct responsibility of Subcommittee
D02.04.0D on Physical and Chemical Methods.
Current edition approved Dec. 1, 2019July 1, 2022. Published January 2020August 2022. Originally approved in 1989. Last previous edition approved in 20182019 as
ɛ1
D5002 – 18D5002 – 19. . DOI: 10.1520/D5002-19.10.1520/D5002-22.
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 Standards
volume information, refer to the standard’s Document Summary page on the ASTM website.
3
The last approved version of this historical standard is referenced on www.astm.org.
*A Summary of Changes section appears at the end of this standard
Copyright © ASTM International, 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA 19428-2959. United States
1

---------------------- Page: 1 ----------------------
D5002 − 22
D1298 Test Method for Density, Relative Density, or API Gravity of Crude Petroleum and Liquid Petroleum Products by
Hydrometer Method
D4052 Test Method for Density, Relative Density, and API Gravity of Liquids by Digital Density Meter
D4057 Practice for Manual Sampling of Petroleum and Petroleum Products
D4177 Practice for Automatic Sampling of Petroleum and Petroleum Products
3
D4377 Test Method for Water in Crude Oils by Potentiometric Karl Fischer Titration (Withdrawn 2020)
3. Terminology
3.1 Definitions:
3.1.1 density, n—mass per unit volume at a specified temperature.
3.1.1.1 Discussion—
3 3
The SI unit of density is kg/m ; the unit of measure g/cm is commonly used in industry. Less preferred units, for example, kg/L
or g/mL, are still in use.
3.1.2 relative density, n—the ratio of the density of a material at a stated temper
...

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SIGNIFICANCE AND USE
5.1 Most often determined trace elements in crude oils are nickel and vanadium, which are usually the most abundant; however, as many as 45 elements in crude oils have been reported. Knowledge of trace elements in crude oil is important because they can have an adverse effect on petroleum refining and product quality. These effects can include catalyst poisoning in the refinery and excessive atmospheric emission in combustion of fuels. Trace element concentrations are also useful in correlating production from different wells and horizons in a field. Elements such as iron, arsenic, and lead are catalyst poisons. Vanadium compounds can cause refractory damage in furnaces, and sodium compounds have been found to cause superficial fusion on fire brick. Some organometallic compounds are volatile which can lead to the contamination of distillate fractions, and a reduction in their stability or malfunctions of equipment when they are combusted.  
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ASTM
ASTM D4007-22(Test Method)
Standard Test Method for Water and Sediment in Crude Oil by the Centrifuge Method (Laboratory Procedure)

SIGNIFICANCE AND USE
5.1 The water and sediment content of crude oil is significant because it can cause corrosion of equipment and problems in processing. A determination of water and sediment content is required to measure accurately net volumes of actual oil in sales, taxation, exchanges, and custody transfers. It is not anticipated that this test method, which is written with a dedicated laboratory facility in mind, is likely to be used in field test rooms or sample rooms due to safety concerns for proper ventilation and handling.  
5.2 This test method may not be suitable for crude oils that contain alcohols that are soluble in water. In cases where the impact on the results may be significant, the user is advised to consider using another test method, such as Test Method D4928 (API MPMS Chapter 10.9).
SCOPE
1.1 This test method describes the laboratory determination of water and sediment in crude oils by means of the centrifuge procedure. This centrifuge method for determining water and sediment in crude oils is not entirely satisfactory. The amount of water detected is almost always lower than the actual water content. When a highly accurate value is required, the revised procedures for water by distillation, Test Method D4006 (API MPMS Chapter 10.2) (Note 1), and sediment by extraction, Test Method D473 (API MPMS Chapter 10.1), shall be used.  
Note 1: Test Method D4006 (API MPMS Chapter 10.2) has been determined to be the preferred and most accurate method for the determination of water.  
1.2 The values stated in SI units are to be regarded as standard.  
1.2.1 Exception—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, health, and environmental practices and determine the applicability of regulatory limitations prior to use. Specific warning statements appear in 7.1, 9.3, and A1.5.4.  
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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ASTM
ASTM D8150-22(Test Method)
Standard Test Method for Determination of Organic Chloride Content in Crude Oil by Distillation Followed by Detection Using Combustion Ion Chromatography

SIGNIFICANCE AND USE
5.1 Organic chlorides do not occur naturally in crude oil. When present, they result from contamination in some manner, such as disposal of chlorinated solvent used in many dewaxing pipeline or other equipment operations.  
5.1.1 Uncontaminated crude oil will contain no detectable organic chloride, and most refineries can handle very small amounts without deleterious effects.
5.1.1.1 Most trade contracts specify that no organic chloride is present in the crude oil.  
5.1.2 Several pipelines have set specification limits less than 1 μg/g organic chlorides in the whole crude, and less than 5 μg/g in the light naphtha, based on the yield of naphtha being 20 % of the original sample.
5.1.2.1 To ensure less than 1 μg/g organic chloride in the crude oil, the amount measured in the naphtha fraction shall be less than 1/f (where f is the naphtha fraction calculated with Eq 1). For example, a crude oil sample with 1 μg/g of organic chloride but a 10 % yield of naphtha would create a naphtha containing 10 μg/g organic chloride. Further, a crude containing 1 μg/g of organic chloride but a 40 % yield of naphtha would create a naphtha containing 2.5 μg/g organic chloride. Due to the difference in naphtha yields, the impact on refining operations can be significantly different.
5.1.2.2 Since crude oil deposits worldwide exhibit different yields of naphtha, the working range of detection for this method shall cover a broad range, possibly as high as 50 μg/g in a naphtha fraction.  
5.1.3 Organic chloride present in the crude oil (for example, methylene chloride, perchloroethylene, etc.) is usually distilled into the naphtha fraction. Some compounds break down during fractionation and produce hydrochloric acid, which has a corrosive effect. Some compounds survive fractionation and are destroyed during hydro-treating (desulfurization of the naphtha).  
5.2 Other halides can also be used for dewaxing crude oil; in such cases, any organic halides will have similar impact on ...
SCOPE
1.1 This test method covers the determination of organic chloride (above 1 μg/g organically-bound chlorine) in crude oils, using distillation and combustion ion chromatography.  
1.2 This test method involves the distillation of crude oil test specimens to obtain a naphtha fraction prior to chloride determination. The chloride content of the naphtha fraction of the whole crude oil can thereby be obtained. See Section 6 regarding potential interferences.  
1.3 The test procedure covers the determination of organic chloride in the washed naphtha fraction of crude oil by combustion ion chromatography. Other halides can be determined but are not included in the precision statement of the test method.  
1.4 The values stated in SI units are to be regarded as standard. The preferred concentration units are micrograms of chloride per gram of sample.  
1.4.1 Exception—The values given in parentheses are for information only.  
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 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.  
1.7 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision ...

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ASTM
ASTM D4929-22(Test Method)
Standard Test Method for Determination of Organic Chloride Content in Crude Oil

SIGNIFICANCE AND USE
5.1 Organic chlorides do not occur naturally in crude oil. When present, they result from contamination in some manner, such as disposal of chlorinated solvent used in many dewaxing pipeline or other equipment operations.  
5.1.1 Uncontaminated crude oil will contain no detectable organic chloride, and most refineries can handle very small amounts without deleterious effects.
5.1.1.1 Most trade contracts specify that no organic chloride is present in the crude oil.  
5.1.2 Several pipelines have set specification limits at  
5.1.2.1 To ensure Eq 3).  
5.1.3 Organic chloride present in the crude oil (for example, methylene chloride, perchloroethylene, etc.) is usually distilled into the naphtha fraction. Some compounds break down during fractionation and produce hydrochloric acid, which has a corrosive effect. Some compounds survive fractionation and are destroyed during hydro-treating (desulfurization of the naphtha).  
5.2 Other halides can also be used for dewaxing crude oil; in such cases, any organic halides will have similar impact on the refining operations as the organic chlorides.  
5.3 Organic chloride species are potentially damaging to refinery processes. Hydrochloric acid can be produced in hydrotreating or reforming reactors and the acid accumulates in condensing regions of the refinery. Unexpected concentrations of organic chlorides cannot be effectively neutralized and damage can result. Organic chlorides are not known to be naturally present in crude oils and usually result from cleaning operations at producing sites, pipelines, or tanks. It is important for the oil industry to have common methods available for the determination of organic chlorides in crude oil, particularly when transfer of custody is involved.
SCOPE
1.1 The procedures in this test method cover the determination of organic chloride (above 1 μg/g organically-bound chlorine) in crude oils, using either distillation and sodium biphenyl reduction, distillation and microcoulometry, or distillation and X-ray fluorescence (XRF) spectrometry.  
1.2 The procedures in this test method involve the distillation of crude oil test specimens to obtain a naphtha fraction prior to chloride determination. The chloride content of the naphtha fraction of the whole crude oil can thereby be obtained. See Section 6 regarding potential interferences.  
1.3 Procedure A covers the determination of organic chloride in the washed naphtha fraction of crude oil by sodium biphenyl reduction followed by potentiometric titration.  
1.4 Procedure B covers the determination of organic chloride in the washed naphtha fraction of crude oil by oxidative combustion followed by microcoulometric titration.  
1.5 Procedure C covers the determination of organic chloride in the washed naphtha fraction of crude oil by X-ray fluorescence spectrometry.  
1.6 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.  
1.6.1 The preferred concentration units are micrograms of chloride per gram of sample, though milligrams of chloride per kilogram of sample is commonly used for Procedure C.  
1.7 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.  
1.8 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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