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ASTM D1018-11(2016)

(Test Method)

Standard Test Method for Hydrogen In Petroleum Fractions (Withdrawn 2021)

Standard Test Method for Hydrogen In Petroleum Fractions (Withdrawn 2021)

SIGNIFICANCE AND USE
4.1 Knowledge of the hydrogen content of petroleum products, particularly fuels, can be helpful in assessing performance characteristics.  
4.2 This test method is suitable for most laboratory applications requiring the determination of hydrogen in liquid petroleum lubricants and products.
SCOPE
1.1 This test method covers the determination of hydrogen in petroleum fractions that can be burned completely without smoking in a wick lamp.  
1.2 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.  
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.
WITHDRAWN RATIONALE
This test method covered the determination of hydrogen in petroleum fractions that can be burned completely without smoking in a wick lamp.
Formerly under the jurisdiction of Committee D02 on Petroleum Products, Liquid Fuels, and Lubricants, this test method was withdrawn in November 2021. This standard is being withdrawn without replacement. Test Method D1018 was originally developed in 1949 when there were few approaches for the determination of hydrogen in petroleum products. Since that time, instrumental methods have been developed for the determination of hydrogen in petroleum products, for example, Test Methods D3701, D4808, and D5291. It is the judgement of the D02.03 officers that this method is no longer needed and could not be revised to comply with the negative voter’s request without a new interlaboratory study, which would be difficult to get the required participation.

General Information

Status
Withdrawn
Publication Date
31-Mar-2016
Withdrawal Date
11-Nov-2021
ICS
75.040 - Crude petroleum
Technical Committee
D02 - Petroleum Products, Liquid Fuels, and Lubricants
Drafting Committee
D02.03 - Elemental Analysis
Current Stage
Ref Project

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ASTM D1018-11(2016) - Standard Test Method for Hydrogen In Petroleum Fractions (Withdrawn 2021)ASTM D1018-11(2016) - Standard Test Method for Hydrogen In Petroleum Fractions (Withdrawn 2021)
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ASTM D1018-11(2016) - Standard Test Method for Hydrogen In Petroleum Fractions (Withdrawn 2021)
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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: D1018 − 11 (Reapproved 2016)
Standard Test Method for
1
Hydrogen In Petroleum Fractions
This standard is issued under the fixed designation D1018; 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.
This standard has been approved for use by agencies of the U.S. Department of Defense.
1. Scope 4. Significance and Use
4.1 Knowledge of the hydrogen content of petroleum
1.1 This test method covers the determination of hydrogen
products, particularly fuels, can be helpful in assessing perfor-
in petroleum fractions that can be burned completely without
mance characteristics.
smoking in a wick lamp.
4.2 This test method is suitable for most laboratory appli-
1.2 The values stated in SI units are to be regarded as
cations requiring the determination of hydrogen in liquid
standard. No other units of measurement are included in this
petroleum lubricants and products.
standard.
1.3 This standard does not purport to address all of the 5. Apparatus
safety concerns, if any, associated with its use. It is the
5.1 Lamp—A lamp (see Note 1) consisting of a 25 mL
responsibility of the user of this standard to establish appro-
Erlenmeyer flask, a burner, and a burner cap conforming to the
priate safety and health practices and determine the applica-
dimensions shown in Fig. 1. The burner consists of two
bility of regulatory limitations prior to use.
concentric glass tubes, the external one having an arm,
provided with standard-taper glass joints for connection with
2. Referenced Documents
the flask, chimney, and burner cap. The burner has a small
2 opening near its base to allow equalization of the pressure
2.1 ASTM Standards:
between the chimney and flask.
D1266 Test Method for Sulfur in Petroleum Products (Lamp
Method) NOTE 1—The lamp and burner are constructed in accordance with
Appendix A3 of Test Method D1266.
D4057 Practice for Manual Sampling of Petroleum and
Petroleum Products 5.2 Chimney—A chimney (see Note 2) conforming to the
D4177 Practice for Automatic Sampling of Petroleum and dimensions shown in Fig. 1.
Petroleum Products
NOTE 2—The chimney is constructed in accordance withAppendixA3
D6299 Practice for Applying Statistical Quality Assurance
of Test Method D1266, except that the delivery tube is cut off and a short
and Control Charting Techniques to Evaluate Analytical
length of glass tubing is sealed on at right angles to the chimney. The
secondary air inlet is not used and is sealed off.
Measurement System Performance
5.3 Absorbers—Two absorption bulbs (see Note 3) suitable
3. Summary of Test Method for collecting and weighing the water formed during combus-
tion of the sample. The bulbs shall be filled in the following
3.1 The test specimen is burned from a cotton wick in an
manner: a 1 cm to 2 cm layer of glass wool, a 5 cm layer of
atmosphere of purified air. The water formed is collected from
6 meshto10 meshcpanhydrouscalciumchloride,a1 cmlayer
the combustion gases by a desiccant and weighed.
of glass wool, a 2 cm layer of phosphorus pentoxide, and glass
wool to the top of the absorbers. One filling is sufficient for
approximately 10 g of water.
1
This test method is under the jurisdiction of ASTM Committee D02 on
NOTE 3—Turner-type absorption bulbs are satisfactory for this test
Petroleum Products, Liquid Fuels, and Lubricants and is the direct responsibility of
method.
Subcommittee D02.03 on Elemental Analysis.
Current edition approved April 1, 2016. Published May 2016. Originally
5.4 Cotton Wicking—Clean, unused, uniform, two-strand
approved in 1949. Last previous edition approved in 2011 as D1018 – 11. DOI:
twisted cotton wicking of good quality, weighing 0.5 g⁄m to
10.1520/D1018-11R16.
2
For referenced ASTM standards, visit the ASTM website, www.astm.org, or 0.6 g⁄m per strand.
contact ASTM Customer Service at service@astm.org. For Annual Book of ASTM
5.5 Air Purifying System—The compressed air (Warning—
Standards volume information, refer to the standard’s Document Summary page on
the ASTM website. Compressed gas under higher pressure) for the combustion
Copyright ©ASTM International, 100 Barr Harbor Drive, PO Box C700, West Conshohocken, PA19428-2959. United States
1

---------------------- Page: 1 ----------------------
D1018 − 11 (2016)
6. Reagents and Materials
6.1 Purity of Reagents—Reagent grade chemicals shall be
used in all tests. Unless otherwise indicated, it is intended that
all reagents conform to the specifications of the Committee on
Analytical Reagents of the American Chemical Society where
4
such specifications are available. Other grades may be used,
provided it is first
...

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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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1.1 This test method covers procedures for quantifying the intrinsic stability of the asphaltenes in an oil by automatic instruments using optical detection.  
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SIGNIFICANCE AND USE
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SIGNIFICANCE AND USE
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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1.3 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.  
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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.
Note 1: As described in Test Method D6377.  
1.2 Methane (C1) to hexane (nC6) and benzene are speciated and quantitated. Samples containing mass fractions of up to 0.5 % methane, 2.0 % ethane, 10 % propane, or 15 % isobutane may be analyzed. A mass fraction with a lower limit of 0.001 % exists for these compounds.  
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5.1 A knowledge of the water content of crude oil is important in the refining, purchase, sale, or transfer of crude oils.  
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).
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1.1 This test method covers the determination of water in crude oil by distillation.  
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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).  
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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.  
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1.4.1 Exception—The values given in parentheses are for information only.  
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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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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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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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