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ASTM D4006-11

(Test Method)

Standard Test Method for Water in Crude Oil by Distillation

Standard Test Method for Water in Crude Oil by Distillation

SIGNIFICANCE AND USE
A knowledge of the water content of crude oil is important in the refining, purchase, sale, or transfer of crude oils.
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 covers the determination of water in crude oil by distillation.
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. For specific warning statements, see 6.1 and A1.1.

General Information

Status
Historical
Publication Date
31-May-2011
ICS
75.040 - Crude petroleum
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

Relations

Replaces
ASTM D4006-07 - Standard Test Method for Water in Crude Oil by Distillation
Effective Date
01-Jun-2011
Replaced By
ASTM D4006-11(2012) - Standard Test Method for Water in Crude Oil by Distillation
Effective Date
01-Nov-2012
Referred By
ASTM D4174-23 - Standard Practice for Cleaning, Flushing, and Purification of Petroleum Fluid Hydraulic Systems
Effective Date
01-Jun-2011
Referred By
ASTM D6470-99(2020) - Standard Test Method for Salt in Crude Oils (Potentiometric Method)
Effective Date
01-Jun-2011
Referred By
ASTM D7059-21 - Standard Test Method for Determination of Methanol in Crude Oils by Multidimensional Gas Chromatography
Effective Date
01-Jun-2011
Referred By
ASTM G205-16 - Standard Guide for Determining Emulsion Properties, Wetting Behavior, and Corrosion-Inhibitory Properties of Crude Oils
Effective Date
01-Jun-2011
Referred By
ASTM D2892-20 - Standard Test Method for Distillation of Crude Petroleum (15-Theoretical Plate Column)
Effective Date
01-Jun-2011

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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: D4006 − 11
Manualof Petroleum Measurement Standards (MPMS), Chapter 10.2
Designation: IP 358/97
Standard Test Method for
1
Water in Crude Oil by Distillation
This standard is issued under the fixed designation D4006; 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.
This standard has been approved for use by agencies of the Department of Defense.
1. Scope* Petroleum Products (API MPMS Chapter 8.1)
D4177Practice for Automatic Sampling of Petroleum and
1.1 This test method covers the determination of water in
Petroleum Products (API MPMS Chapter 8.2)
crude oil by distillation.
D4928Test Method forWater in Crude Oils by Coulometric
1.2 The values stated in SI units are to be regarded as
Karl Fischer Titration (API MPMS Chapter 10.9)
standard. No other units of measurement are included in this
E123SpecificationforApparatusforDeterminationofWater
standard.
by Distillation
1.3 This standard does not purport to address all of the 2.2 API Standards:
safety concerns, if any, associated with its use. It is the
MPMS Chapter 8.1Manual Sampling of Petroleum and
responsibility of the user of this standard to establish appro- Petroleum Products (ASTM Practice D4057)
priate safety and health practices and determine the applica-
MPMS Chapter 8.2Automatic Sampling of Petroleum and
bility of regulatory limitations prior to use. For specific Petroleum Products (ASTM Practice D4177)
warning statements, see 6.1 and A1.1.
MPMS Chapter 10.1Test Method for Sediment in Crude
Oils and Fuel Oils by the Extraction Method (ASTMTest
2. Referenced Documents
Method D473)
2
MPMS Chapter 10.4Determination of Water and/or Sedi-
2.1 ASTM Standards:
ment in Crude Oil by the Centrifuge Method (Field
D95Test Method for Water in Petroleum Products and
Procedure)
BituminousMaterialsbyDistillation(API MPMSChapter
MPMS Chapter 10.5Test Method for Water in Petroleum
10.5)
Products and Bituminous Materials by Distillation
D473TestMethodforSedimentinCrudeOilsandFuelOils
(ASTM Test Method D95)
by the Extraction Method (API MPMS Chapter 10.1)
MPMSChapter10.6TestMethodforWaterandSedimentin
D665Test Method for Rust-Preventing Characteristics of
Fuel Oils by the Centrifuge Method (Laboratory Proce-
Inhibited Mineral Oil in the Presence of Water
dure) (ASTM Test Method D1796)
D1796Test Method for Water and Sediment in Fuel Oils by
MPMSChapter10.9TestMethodforWaterinCrudeOilsby
the Centrifuge Method (Laboratory Procedure) (API
Coulometric Karl Fischer Titration (ASTM Test Method
MPMS Chapter 10.6)
D4928)
D4057Practice for Manual Sampling of Petroleum and
3. Summary of Test Method
1 3.1 The sample is heated under reflux conditions with a
This test method is under the jurisdiction of ASTM Committee D02 on
Petroleum Products and Lubricants and theAPI Committee on Petroleum Measure- waterimmisciblesolventwhichco-distillswiththewaterinthe
ment and is the direct responsibility of Subcommittee D02.02 /COMQ on Hydro-
sample. Condensed solvent and water are continuously sepa-
carbon Measurement for Custody Transfer (Joint ASTM-API).
ratedinatrap—thewatersettlesinthegraduatedsectionofthe
This test method was issued as a joint ASTM-API-IP standard in 1981.
trap, and the solvent returns to the distillation flask.
Current edition approved June 1, 2011. Published August 2011. Originally
approved in 1981. Last previous edition approved in 2007 as D4006–07. DOI:
4. Significance and Use
10.1520/D4006-11.
2
For referenced ASTM standards, visit the ASTM website, www.astm.org, or
4.1 A knowledge of the water content of crude oil is
contact ASTM Customer Service at service@astm.org. For Annual Book of ASTM
important in the refining, purchase, sale, or transfer of crude
Standards volume information, refer to the standard’s Document Summary page on
the ASTM website. oils.
*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 ----------------------
D4006 − 11
5.1.3 The apparatus used in this test will be accepted when
satisfactory results are obtained by the calibration technique
described in Section 8.
6. Solvent
6.1 Xylene—reagent grade (Warning—Extremely flam-
mable.Vapor harmful. See AnnexA1.)Asolvent blank will be
established by placing 400 mL of solvent in the distillation
apparatus and testing as outlined in Section 9. The blank will
be determined to the nearest 0.025 mLand used to correct the
volume of water in the trap as in Section 10.
6.2 Thexyleneusedinthisprocedureisgenerallyamixture
of ortho, meta,
...

This document is not anASTM standard and is intended only to provide the user of anASTM 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:D4006–07 Designation:D4006–11
Designation: Manual of Petroleum Measurement Standards (MPMS), Chapter 10.2
Designation: IP 358/97
Standard Test Method for
1
Water in Crude Oil by Distillation
This standard is issued under the fixed designation D4006; 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.
This standard has been approved for use by agencies of the Department of Defense.
1. Scope*
1.1 This test method covers the determination of water in crude oil by distillation.
1.2
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. For specific warning statements, see 6.1 and A1.1.
2. Referenced Documents
2
2.1 ASTM Standards:
D95 Test Method for Water in Petroleum Products and Bituminous Materials by Distillation D96Test Methods for Water and
Sediment in Crude Oil by
CentrifugeMethod(FieldPro-
cedure) (API MPMS Chapter
10.4)
D473 Test Method for Sediment in Crude Oils and Fuel Oils by the Extraction Method
D665 Test Method for Rust-Preventing Characteristics of Inhibited Mineral Oil in the Presence of Water
D1796 Test Method for Water and Sediment in Fuel Oils by the Centrifuge Method (Laboratory Procedure)
D4057 Practice for Manual Sampling of Petroleum and Petroleum Products (API MPMS Chapter 8.2)
D4177 Practice for Automatic Sampling of Petroleum and Petroleum Products
D4928 Test Method for Water in Crude Oils by Coulometric Karl Fischer Titration
E123 Specification for Apparatus for Determination of Water by Distillation
2.2 API Standards:
MPMS Chapter 8.1 Manual Sampling of Petroleum and Petroleum Products (ASTM Practice D4057(API MPMS Chapter 8.1))
)
MPMS Chapter 8.2 Automatic Sampling of Petroleum and Petroleum Products (ASTM Practice D4177)
MPMS Chapter 10.1 Test Method for Sediment in Crude Oils and Fuel Oils by the Extraction Method (ASTM Test Method
D473)
MPMSChapter10.4 DeterminationofWaterand/orSedimentinCrudeOilbytheCentrifugeMethod(FieldProcedure)(ASTM
Test Method D96)
1
This test method is under the jurisdiction ofASTM Committee D02 on Petroleum Products and Lubricants and theAPI Committee on Petroleum Measurement, and is
the direct responsibility of Subcommittee D02.02.10 on Sediment and Water (API MPMS Chapter 10.0).
This test method was issued as a joint ASTM-API-IP standard in 1981.
Current edition approvedAug.June 1, 2007.2011. Published September 2007.August 2011. Originally approved in 1981. Last previous edition approved in 20052007 as
D4006–81(2005).D4006–07. DOI: 10.1520/D4006-07.10.1520/D4006-11.
2
ForreferencedASTMstandards,visittheASTMwebsite,www.astm.org,orcontactASTMCustomerServiceatservice@astm.org.For Annual Book of ASTM Standards
volume information, refer to the standard’s Document Summary page on the ASTM website.
*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 ----------------------
D4006–11
MPMS Chapter 10.5 Test Method for Water in Petroleum Products and Bituminous Materials by Distillation (ASTM Test
Method D95)
MPMS Chapter 10.6 Test Method for Water and Sediment in Fuel Oils by the Centrifuge Method (Laboratory Procedure)
(ASTM Test Method D1796)
MPMS Chapter 10.9 Test Method for Water in Crude Oils by Coulometric Karl Fischer Titration (ASTM Test Method D4928)
3. Summary of Test Method
3.1 Thesampleisheatedunderrefluxconditionswithawaterimmisciblesolventwhichco-distillswiththewaterinthesample.
Condensed solvent and water are continuously separated in a trap—the water settles in the graduated section of the trap, and the
solvent returns to the distillation flask.
4. Significance and Use
4.1 A knowledge of the water content of crude oil is important in the refining, purchase, sale, or transfer of crude oils.
4.2 Thistestmethodmaynotbesuitableforcrudeoilsthatcontainalcoholsthataresolubleinwater.Incaseswheretheimpact
ontheresultsmaybesignificant,theuserisadvisedtoconsid
...

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ASTM D2892-23(Test Method)
Standard Test Method for Distillation of Crude Petroleum (15-Theoretical Plate Column)

SIGNIFICANCE AND USE
5.1 This test method is one of a number of tests conducted on a crude oil to determine its value. It provides an estimate of the yields of fractions of various boiling ranges and is therefore valuable in technical discussions of a commercial nature.  
5.2 This test method corresponds to the standard laboratory distillation efficiency referred to as 15/5. The fractions produced can be analyzed as produced or combined to produce samples for analytical studies, engineering, and product quality evaluations. The preparation and evaluation of such blends is not part of this test method.  
5.3 This test method can be used as an analytical tool for examination of other petroleum mixtures with the exception of LPG, very light naphthas, and mixtures with initial boiling points above 400 °C.
SCOPE
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).  
1.3 This test method can also be applied to any petroleum mixture except liquefied petroleum gases, very light naphthas, and fractions having initial boiling points above 400 °C.  
1.4 This test method contains the following annexes and appendixes:  
1.4.1 Annex A1—Test Method for the Determination of the Efficiency of a Distillation Column,  
1.4.2 Annex A2—Test Method for the Determination of the Dynamic Holdup of a Distillation Column,  
1.4.3 Annex A3—Test Method for the Determination of the Heat Loss in a Distillation Column (Static Conditions),  
1.4.4 Annex A4—Test Method for the Verification of Temperature Sensor Location,  
1.4.5 Annex A5—Test Method for Determination of the Temperature Response Time,  
1.4.6 Annex A6—Practice for the Calibration of Sensors,  
1.4.7 Annex A7—Test Method for the Verification of Reflux Dividing Valves,  
1.4.8 Annex A8—Practice for Conversion of Observed Vapor Temperature to Atmospheric Equivalent Temperature (AET),  
1.4.9 Appendix X1—Test Method for Dehydration of a Sample of Wet Crude Oil, and  
1.4.10 Appendix X2—Practice for Performance Check.  
1.5 The values stated in SI units are to be regarded as standard. The values given in parentheses after SI units are provided for information only and are not considered standard.  
1.6 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.  
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ASTM D8252-23(Test Method)
Standard Test Method for Vanadium and Nickel in Crude and Residual Oil by X-ray Spectrometry

SIGNIFICANCE AND USE
5.1 This test method provides a rapid and precise elemental measurement with simple sample preparation. Typical analysis times are approximately 4 min to 5 min per sample with a preparation time of approximately 1 min to 3 min per sample.  
5.2 The quality of crude oil is related to the amount of sulfur present. Knowledge of the vanadium and nickel concentration is necessary for processing purposes as well as contractual agreements.  
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1.1 This test method covers the quantitative determination of total vanadium and nickel in crude and residual oil in the concentration ranges shown in Table 1 using X-ray fluorescence (XRF) spectrometry.  
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1.3 This test method is limited to the use of X-ray fluorescence (XRF) spectrometers employing an X-ray tube for excitation in conjunction with wavelength dispersive detection system or energy dispersive high resolution semiconductor detector with the ability to separate signals of adjacent and near-adjacent elements.  
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Standard Guide for Sediment and Water Determination in Crude Oil

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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 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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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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SCOPE
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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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Standard Test Methods for Determination of Nickel, Vanadium, Iron, and Sodium in Crude Oils and Residual Fuels by Flame Atomic Absorption Spectrometry

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.
SCOPE
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.  
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 D8003-22(Test Method)
Standard Test Method for Determination of Light Hydrocarbons and Cut Point Intervals in Live Crude Oils and Condensates by Gas Chromatography

SIGNIFICANCE AND USE
5.1 This test method determines methane (nC1) to hexane (nC6), cut point carbon fraction intervals to nC24 and recovery (nC24+) of live crude oils and condensates without depressurizing, thereby avoiding the loss of highly volatile components and maintaining sample integrity. This test method provides a highly resolved light end profile which can aid in determining and improving appropriate safety measures and product custody transport procedures. Decisions in regards to marketing, scheduling, and processing of crude oils may rely on light end compositional results.  
5.2 Equation of state calculations can be applied to variables provided by this method to allow for additional sample characterization.
SCOPE
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.  
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.  
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 D4310-22a(Test Method)
Standard Test Method for Determination of Sludging and Corrosion Tendencies of Inhibited Mineral Oils

SIGNIFICANCE AND USE
5.1 Insoluble material may form in oils that are subjected to oxidizing conditions.  
5.2 Significant formation of oil insolubles or metal corrosion products, or both, during this test may indicate that the oil will form insolubles or corrode metals, or both, during field service. However, no correlation with field service has been established.
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 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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