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ASTM D3827-92(2002)

(Test Method)

Standard Test Method for Estimation of Solubility of Gases in Petroleum and Other Organic Liquids

Standard Test Method for Estimation of Solubility of Gases in Petroleum and Other Organic Liquids

SCOPE
1.1 This test method covers a procedure for estimating the equilibrium solubility of several common gases in petroleum and synthetic lubricants, fuels, and solvents, at temperatures between 0 and 488 K.
1.2 This test method is limited to systems in which polarity and hydrogen bonding are not strong enough to cause serious deviations from regularity. Specifically excluded are such gases as HCl, NH3, and SO2, and hydroxy liquids such as alcohols, glycols, and water. Estimating the solubility of CO2 in nonhydrocarbons is also specifically excluded.  
1.3 Highly aromatic oils such as diphenoxy phenylene ethers violate the stated accuracy above 363 K, at which point the estimate for nitrogen solubility is 43% higher than the observation.  
1.4 Lubricants are given preference in this test method to the extent that certain empirical factors were adjusted to the lubricant data. Estimates for distillate fuels are made from the lubricant estimates by a further set of empirical factors, and are less accurate. Estimates for halogenated solvents are made as if they were hydrocarbons, and are the least accurate of the three.  
1.5 The values stated in SI units are to be regarded as the standard. The values in parentheses are for information only.
1.6 This standard does not purport to address all of the safety problems, 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
14-Oct-1992
ICS
75.040 - Crude petroleum
Technical Committee
D02 - Petroleum Products, Liquid Fuels, and Lubricants
Drafting Committee
D02.L0.07 - Engineering Sciences of High Performance Fluids and Solids (Formally D02.1100)
Current Stage
Ref Project

Relations

Replaces
ASTM D3827-92(1997) - Standard Test Method for Estimation of Solubility of Gases in Petroleum and Other Organic Liquids
Effective Date
15-Oct-1992
Replaced By
ASTM D3827-92(2007) - Standard Test Method for Estimation of Solubility of Gases in Petroleum and Other Organic Liquids
Effective Date
01-May-2007

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ASTM D3827-92(2002) - Standard Test Method for Estimation of Solubility of Gases in Petroleum and Other Organic LiquidsASTM D3827-92(2002) - Standard Test Method for Estimation of Solubility of Gases in Petroleum and Other Organic Liquids
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ASTM D3827-92(2002) - Standard Test Method for Estimation of Solubility of Gases in Petroleum and Other Organic Liquids
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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
An American National Standard
Designation:D3827–92(Reapproved 2002)
Standard Test Method for
Estimation of Solubility of Gases in Petroleum and Other
1
Organic Liquids
This standard is issued under the fixed designation D3827; 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 (e) indicates an editorial change since the last revision or reapproval.
TABLE 1 Solubility Parameters of Gaseous Solutes
1. Scope
Gas M d at 298 K Fuel Factor
2 2
1.1 This test method covers a procedure for estimating the
He 4 3.35 1.27
equilibrium solubility of several common gases in petroleum
Ne 20 3.87 1.37
and synthetic lubricants, fuels, and solvents, at temperatures
H 2 5.52 1.27
2
between 0 and 488 K.
N 28 6.04 1.70
2
Air 29 6.67 1.44
1.2 This test method is limited to systems in which polarity
CO 28 7.47 1.37
and hydrogen bonding are not strong enough to cause serious
O 32 7.75 1.28
2
deviations from regularity. Specifically excluded are such
Ar 40 7.71 1.37
CH 16 9.10 1.42
gases as HCl, NH , and SO , and hydroxy liquids such as 4
3 2
Kr 84 10.34 1.37
alcohols, glycols, and water. Estimating the solubility of CO
2
CO 44 14.81 1.14
2
in nonhydrocarbons is also specifically excluded.
1.3 Highly aromatic oils such as diphenoxy phenylene
Gravity) or API Gravity of Crude Petroleum and Liquid
ethers violate the stated accuracy above 363 K, at which point
2
Petroleum Products by Hydrometer Method
the estimate for nitrogen solubility is 43% higher than the
D2502 Test Method for Estimation of Molecular Weight
observation.
(RelativeMolecularMass)ofPetroleumOilsfromViscos-
1.4 Lubricants are given preference in this test method to
2
ity Measurements
the extent that certain empirical factors were adjusted to the
D2503 Test Method for Molecular Weight (Relative Mo-
lubricant data. Estimates for distillate fuels are made from the
lecular Mass) of Hydrocarbons by Thermoelectric Mea-
lubricantestimatesbyafurthersetofempiricalfactors,andare
2
surement of Vapor Pressure
lessaccurate.Estimatesforhalogenatedsolventsaremadeasif
theywerehydrocarbons,andaretheleastaccurateofthethree.
3. Terminology
1.5 The values stated in SI units are to be regarded as the
3.1 Definitions:
standard. The values in parentheses are for information only.
3.1.1 Bunsen coeffıcient—the solubility of a gas, expressed
1.6 This standard does not purport to address all of the
as the gas volume reduced to 273 K (32°F) and 0.10 MPa (1
safety concerns, if any, associated with its use. It is the
atm), dissolved by one volume of liquid at the specified
responsibility of the user of this standard to establish appro-
temperature and 0.10 MPa.
priate safety and health practices and determine the applica-
3.1.2 Ostwald coeffıcient—the solubility of a gas, expressed
bility of regulatory limitations prior to use.
as the volume of gas dissolved per volume of liquid when both
2. Referenced Documents
are in equilibrium at the specified partial pressure of gas and at
the specified temperature.
2.1 ASTM Standards:
3.2 Definitions of Terms Specific to This Standard:
D1218 Test Method for Refractive Index and Refractive
2
3.2.1 distillate fuel—a petroleum product having a molecu-
Dispersion of Hydrocarbon Liquids
2
lar weight below 300 g/mol.
D1250 Guide for Petroleum Measurement Tables
3.2.2 halogenated solvent—a partially or fully halogenated
D1298 TestMethodforDensity,RelativeDensity(Specific
hydrocarbon having a molar volume below 300 mL/mol.
3.2.3 solubility parameter—the square root of the internal
1
energy change (heat absorbed minus work done) of vaporiza-
This test method is under the jurisdiction of ASTM Committee D02 on
Petroleum Products and Lubricants and is the direct responsibility of Subcommittee
tion per unit volume of liquid, at 298 K.
D02.11 on Engineering Sciences of High Performance Fluids and Solids.
3.2.3.1 Discussion—For gases in Table 1, the liquid is
Current edition approved Oct. 15, 1992. Published December 1992. Originally
hypothetical and the values were calculated from actual solu-
approved in 1979. Last previous edition approved in 1986 as D3827–86.
2
Annual Book of ASTM Standards, Vol 05.01. bility data.
Copyright © ASTM International, 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA 19428-2959, United States.
1

---------------------- Page: 1 ----------------------
D3827–92 (2002)
TABLE 2 Constants for Synthetic Nonhydrocarbons
Compound d M r dr/dT
1 1
Di-2-ethylhexyl adipate 18.05 370 0.928 0.00075
Di-2-ethylhexyl sebacate 17.94 427 0.916 0.00073
Trimetholylpropane pelargonate 18.48 459 0.962 0.00070
Pentaerythritol caprylate 18.95 540 1.002 0.00065
Di-2-ethylhexyl phthalate 18.97 390 0.986 0.00075
Diphenoxy diphenylene eth
...

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1.1 This test method covers the procedure for the distillation of stabilized crude petroleum (see Note 1) to a final cut temperature of 400 °C Atmospheric Equivalent Temperature (AET). This test method employs a fractionating column having an efficiency of 14 to 18 theoretical plates operated at a reflux ratio of 5:1. Performance criteria for the necessary equipment is specified. Some typical examples of acceptable apparatus are presented in schematic form. This test method offers a compromise between efficiency and time in order to facilitate the comparison of distillation data between laboratories.
Note 1: Defined as having a Reid vapor pressure less than 82.7 kPa (12 psi).  
1.2 This test method details procedures for the production of a liquefied gas, distillate fractions, and residuum of standardized quality on which analytical data can be obtained, and the determination of yields of the above fractions by both mass and volume. From the preceding information, a graph of temperature versus mass % distilled can be produced. This distillation curve corresponds to a laboratory technique, which is defined at 15/5 (15 theoretical plate column, 5:1 reflux ratio) or TBP (true boiling point).  
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1.1 This guide covers a summary of the water and sediment determination methods from the API MPMS Chapter 10 for crude oils. The purpose of this guide is to provide a quick reference to these methodologies such that the reader can make the appropriate decision regarding which method to use based on the associated benefits, uses, drawbacks and limitations.  
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5.1 This test method describes a sensitive method for estimating the intrinsic stability of an oil. The intrinsic stability is expressed as S-value. An oil with a low S-value is likely to undergo flocculation of asphaltenes when stressed (for example, extended heated storage) or blended with a range of other oils. Two oils each with a high S-value are likely to maintain asphaltenes in a peptized state and not lead to asphaltene flocculation when blended together.  
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5.1 Crude oils and oil sands bitumen contain naturally occurring acidic species. Acidity of crude oil has been implicated in corrosion of distribution and process systems. The relative amount of these materials can be determined by titrating with bases. The acid number is a measure of this amount of acidic substance in the oil under the conditions of the test.  
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1.1 This test method covers the determination of acidic components in crude oil and petroleum products including waxes, bitumen, base stocks, and asphalts that are soluble in mixtures of xylenes and propan-2-ol. It is applicable for the determination of acids whose dissociation constants in water are larger than 10–9; extremely weak acids whose dissociation constants are smaller than 10–9 do not interfere. The values obtained by this test method may not be numerically equivalent to other acid value measurements. The range of KOH acid numbers included in the precision statement is 0.1 mg/g to 16 mg/g.  
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ASTM D5863-22(Test Method)
Standard Test Methods for Determination of Nickel, Vanadium, Iron, and Sodium in Crude Oils and Residual Fuels by Flame Atomic Absorption Spectrometry

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5.1 When fuels are combusted, metals present in the fuels can form low melting compounds that are corrosive to metal parts. Metals present at trace levels in petroleum can deactivate catalysts during processing. These test methods provide a means of quantitatively determining the concentrations of vanadium, nickel, iron, and sodium. Thus, these test methods can be used to aid in determining the quality and value of the crude oil and residual oil.
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1.1 These test methods cover the determination of nickel, vanadium, iron, and sodium in crude oils and residual fuels by flame atomic absorption spectrometry (AAS). Two different test methods are presented.  
1.2 Procedure A, Sections 8–14—Flame AAS is used to analyze a sample that is decomposed with acid for the determination of total Ni, V, and Fe.  
1.3 Procedure B, Sections 15–20—Flame AAS is used to analyze a sample diluted with an organic solvent for the determination of Ni, V, and Na. This test method uses oil-soluble metals for calibration to determine dissolved metals and does not purport to quantitatively determine nor detect insoluble particulates. Hence, this test method may underestimate the metal content, especially sodium, present as inorganic sodium salts.  
1.4 The concentration ranges covered by these test methods are determined by the sensitivity of the instruments, the amount of sample taken for analysis, and the dilution volume. A specific statement is given in Note 1.  
1.5 For each element, each test method has its own unique precision. The user can select the appropriate test method based on the precision required for the specific analysis.  
1.6 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard, unless specifically stated. Other units that appear in this standard are included for information purposes only or because they are in embedded pictures that cannot be edited.  
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. Specific warning statements are given in 8.1, 9.2, 9.5, 11.2, 11.4, and 16.1.  
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1.1 This test method covers the determination of light hydrocarbons and cut point intervals by gas chromatography in live crude oils and condensates with VPCR4 (see Note 1) up to 500 kPa at 37.8 °C.
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1.3 This test method may be used for the determination of cut point carbon fraction intervals (see 3.2.1) of live crude oils and condensates from initial boiling point (IBP) to 391 °C (nC24). The nC24 plus fraction is reported.  
1.4 Dead oils or condensates sampled in accordance with 12.1 may also be analyzed.  
1.5 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.  
1.5.1 Exception—Where there is no direct SI equivalent such as tubing size.  
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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SCOPE
1.1 This test method covers and is used to evaluate the tendency of inhibited mineral oil based steam turbine lubricants and mineral oil based anti-wear hydraulic oils to corrode copper catalyst metal and to form sludge during oxidation in the presence of oxygen, water, and copper and iron metals at an elevated temperature. The test method is also used for testing circulating oils having a specific gravity less than that of water and containing rust and oxidation inhibitors.  
Note 1: During round robin testing copper and iron in the oil, water and sludge phases were measured. However, the values for the total iron were found to be so low (that is, below 0.8 mg), that statistical analysis was inappropriate. The results of the cooperative test program are available (see Section 16).  
1.2 This test method is a modification of Test Method D943 where the oxidation stability of the same kinds of oils is determined by following the acid number of oil. The number of test hours required for the oil to reach an acid number of 2.0 mg KOH/g is the oxidation lifetime.  
1.3 Procedure A of this test method requires the determination and report of the weight of the sludge and the total amount of copper in the oil, water, and sludge phases. Procedure B requires the sludge determination only. The acid number determination is optional for both procedures.  
1.4 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.  
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. For specific warning statements, see Section 7 and X1.1.5.  
1.7 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 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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