75.040 (Crude petroleum) 标准查询与下载

ASTM D4929-15 测定原油中有机氯化物含量的标准试验方法

4.1 Usually organic chlorides do not occur naturally in crude oil. When present, they result from contamination in some manner, such as disposal of waste solvent or as use for dewaxing a pipeline or other equipment. 4.1.1 While an uncontaminated crude oil will contain zero ppm of organic chloride, a very small amount is capable of being handled in a refinery. 4.1.2 A rule of thumb used by refiners is <1 ppm organic chlorides in the whole crude, and 5 ppm in the light naphtha, when the naphtha fraction is 20 % of the original sample. 4.1.2.1 For refiners to ensure < 1 ppm organic chloride in the crude oil, the amount measured in the naphtha fraction must be < 1/f (where f is the naphtha fraction calculated with Eq 3). 4.1.3 Any organic halide present in the crude oil almost always distills into the naphtha fraction. Some varieties can break down during fractionation but most survive this process and are destroyed during further refining usually during hydro-treating (desulfurization of the naphtha). 4.2 Sometimes other halides have been used for dewaxing crude oil; in such cases, any organic halides will cause the same problems as the organic chlorides. 4.3 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. 1.1 These test methods cover the determination of organic chloride (above 1 μg/g organically-bound chlorine) in crude oils, using either distillation and sodium biphenyl reduction or distillation and microcoulometry. 1.2 These test methods 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 5 regarding potential interferences. 1.3 Test Method 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 Test Method B covers the determination of organic chloride in the washed naphtha fraction of crude oil by oxidative combustion followed by microcoulometric titration. 1.5 The values stated in......

Standard Test Methods for Determination of Organic Chloride Content in Crude Oil

ASTM D7829-13 测定原油中沉积和水的标准指南

3.1 Theoretically, all of the sediment and water determination methods are valid for crude oils containing from 0 to 1008201;% by volume sediment and water; the range of application is specified within the scope of each method. The round robins for all methods were conducted on relatively dry oil. All precision and bias statements included in the methods are based upon the round robin data. Analysis becomes more challenging with crude oils containing higher water contents due to the difficulty in obtaining a representative sample, and maintaining the sample quality until analysis begins. 3.2 Currently, Karl Fischer is generally used for dry crude oils containing less than 58201;% water. Distillation is most commonly used for dry and wet crude oils and where separate sediment analysis is available or in situations where the sediment result is not significant. The laboratory centrifuge methods allow for determination of total sediment and water in a single analysis. The field centrifuge method is used when access to controlled laboratory conditions are not available. 3.3 In the event of a dispute with regard to sediment and water content, contracting parties may refer to the technical specifications table to determine the most appropriate referee method based upon knowledge of and experience with the crude oil or product stream. 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. 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.

Standard Guide for Sediment and Water Determination in Crude Oil

ASTM D7900-13e1 使用气相色谱法测定稳定原油中轻烃的标准试验方法

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

Standard Test Method for Determination of Light Hydrocarbons in Stabilized Crude Oils by Gas Chromatography

ASTM D7900-13 采用气相色谱法测定稳定原油中轻质烃的标准试验方法

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

Standard Test Method for Determination of Light Hydrocarbons in Stabilized Crude Oils by Gas Chromatography

ASTM D3230-13 原油中含盐量的标准试验方法(电测法)

5.1 This test method is used to determine the approximate chloride content of crude oils, a knowledge of which is important in deciding whether or not the crude oil needs desalting. The efficiency of the process desalter can also be evaluated. 5.2 Excessive chloride left in the crude oil frequently results in higher corrosion rates in refining units and also has detrimental effects on catalysts used in these units. 5.3 This test method provides a rapid and convenient means of determining the approximate content of chlorides in crude oil and is useful to crude oil processors. 1.1 This test method covers the determination of the approximate chloride (salts) concentration in crude oil. The range of concentration covered is 0 to 500 mg/kg or 0 to 150 lb/10008201;bbl as chloride concentration/volume of crude oil. 1.2 This test method measures conductivity in the crude oil due to the presence of common chlorides, such as sodium, calcium, and magnesium. Other conductive materials may also be present in the crude oil. 1.3 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard. 1.3.1 Exception—Acceptable concentration units are g/m3 or PTB (lb/1000 bbl). 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 and health practices and determine the applicability of regulatory limitations prior to use. For specific warning statements, see 7.3, 7.4, and 7.11.

Standard Test Method for Salts in Crude Oil (Electrometric Method)

ASTM D2892-13 原油蒸馏标准试验方法(15块理论塔板蒸馏柱)

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. 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 ......

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

ASTM D5002-13 采用数字密度分析仪的原油密度和相对密度的标准试验方法

5.1 Density is a fundamental physical property that can 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, can require measurements of the water and sediment contents obtained on similar specimens of the crude oil parcel. 1.1 This test method covers the determination of the density or relative density of crude oils that can be handled in a normal fashion as liquids at test temperatures between 15 and 35°C. 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 round robin testing using crude oils in the 0.75 to 0.95 g/mL range. Lighter crude oil can require special handling to prevent vapor losses. Heavier crudes can require measurements at higher temperatures to eliminate air bubbles in the sample. 1.3 The values stated in SI units are to be regarded as standard. No 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 and health practices and determine the applicability of regulatory limitations prior to use. Specific warning statements are given in 7.4, 7.5, and 7.6.

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

ASTM D4928-12 利用电量计卡耳费歇尔滴定法对原油中水的标准试验方法

5.1 The accurate analysis of a crude oil sample to determine the water content is important in the refining, purchase, sale, or transfer of crude oils. 1.1 This test method covers the determination of water in the range from 0.02 to 5.00 mass or volume % in crude oils. Mercaptan (RSH) and sulfide (S− or H2S) as sulfur are known to interfere with this test method, but at levels of less than 5008201;μg/g [ppm(m)], the interference from these compounds is insignificant (see Section 6). 1.2 This test method can be used to determine water in the 0.005 to 0.02 mass % range, but the effects of the mercaptan and sulfide interference at these levels has not been determined. For the range 0.005 to 0.02 mass %, there is no precision or bias statement. 1.3 This test method is intended for use with standard commercially available coulometric Karl Fischer reagent. 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 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 Section 8.

Standard Test Method for Water in Crude Oils by Coulometric Karl Fischer Titration

ASTM D7157-12 测定含沥青烯残余物, 重油和原油内在稳定性的标准试验方法 (正庚烷相分离, 光学检测)

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. 5.2 This test method can be used by petroleum refiners to control and optimize the refinery processes and by blenders and marketers to assess the intrinsic stability of blended asphaltene-containing heavy fuel oils. 1.1 This test method covers a procedure for quantifying the intrinsic stability of the asphaltenes in an oil by an automatic instrument using an optical device. 1.2 This test method is applicable to residual products from thermal and hydrocracking processes, to products typical of Specifications D396 Grades No. 5L, 5H, and 6, and D2880 Grades No. 3-GT and 4-GT, and to crude oils, providing these products contain 0.5 mass% or greater concentration of asphaltenes (see Test Method D6560). 1.3 This test method quantifies asphaltene stability in terms of state of peptization of the asphaltenes (S-value), intrinsic stability of the oily medium (So) and the solvency requirements of the peptized asphaltenes (Sa). 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 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

Standard Test Method for Determination of Intrinsic Stability of Asphaltene-Containing Residues, Heavy Fuel Oils, and Crude Oils (n-Heptane Phase Separation; Optical Detection)

ASTM D2892-11a 原油蒸馏标准试验方法(15-理论板蒸馏柱)

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. 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. 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. 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 18212;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 A18212;Test Method for the Determination of the Efficiency of a Distillation Column, 1.4.2 Annex A28212;Test Method for the Determination of the Dynamic Holdup of a Distillation Column, 1.4.3 Annex A38212;Test Method for the Determination of the Heat Loss in a Distillation Column (Static Conditions), 1.4.4 Annex A48212;Test Method for the Verification of Temperature Sensor Location, 1.4.5 Annex A58212;Test Method for Determination of the Temperature Response Time, 1.4.6 Annex A68212;Practice for the Calibration of Sensors, 1.4.7 Annex A78212;Test Method for the Verification of Reflux Dividing Valves, 1.4.8 Annex A88212;Practice for Conversion of Observed Vapor Temperature to Atmospheric Equivalent Temperature (AET), 1.4.9 Appendix X18212;Test Method for Dehydration of a Sample of Wet Crude Oil, and 1.4.10 Appendix X28212;Practice for Performance Check. 1.5 The values stated in SI units are to be regarded as the standard. The values given in parentheses......

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

ASTM D2892-11 原油蒸馏用标准试验方法(15 - 理论塔板蒸馏塔)

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. 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. 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. 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 18212;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 A18212;Test Method for the Determination of the Efficiency of a Distillation Column, 1.4.2 Annex A28212;Test Method for the Determination of the Dynamic Holdup of a Distillation Column, 1.4.3 Annex A38212;Test Method for the Determination of the Heat Loss in a Distillation Column (Static Conditions), 1.4.4 Annex A48212;Test Method for the Verification of Temperature Sensor Location, 1.4.5 Annex A58212;Test Method for Determination of the Temperature Response Time, 1.4.6 Annex A68212;Practice for the Calibration of Sensors, 1.4.7 Annex A78212;Test Method for the Verification of Reflux Dividing Valves, 1.4.8 Annex A88212;Practice for Conversion of Observed Vapor Temperature to Atmospheric Equivalent Temperature (AET), 1.4.9 Appendix X18212;Test Method for Dehydration of a Sample of Wet Crude Oil, and 1.4.10 Appendix X28212;Practice for Performance Check. 1.5 The values stated in SI units are to be regarded as the standard. The values gi......

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

ASTM D4007-11 离心法测定原油中水和沉积物的标准试验方法

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 nbsp;nbsp;nbsp;and handling. 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).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 18212;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. 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 and health practices and determine the applicability of regulatory limitations prior to use. Specific warning statements appear in 6.1, 8.3, and A1.5.4.

Standard Test Method for Water and Sediment in Crude Oil by the Centrifuge Method (Laboratory Procedure)

ASTM D4006-11(2012) 蒸馏法测定原油中水的标准试验方法

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.

Standard Test Method for Water in Crude Oil by Distillation

ASTM D4007-11e1 离心法测定原油中水和沉积物的标准试验方法

4.1 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. 4.2 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). 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. 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 and health practices and determine the applicability of regulatory limitations prior to use. Specific warning statements appear in 6.1, 8.3, and A1.5.4.

Standard Test Method for Water and Sediment in Crude Oil by the Centrifuge Method (Laboratory Procedure)

ASTM D1018-11 石油馏分中氢含量的标准试验方法

Knowledge of the hydrogen content of petroleum products, particularly fuels, can be helpful in assessing performance characteristics. This test method is suitable for most laboratory applications requiring the determination of hydrogen in liquid petroleum lubricants and products.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.

Standard Test Method for Hydrogen In Petroleum Fractions

ASTM D7691-11e1 用电感耦合等离子体原子发射光谱法 (ICP-AES) 对原油进行多元素分析的标准试验方法

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. 5.2 The value of crude oil can be determined, in part, by the concentrations of nickel, vanadium, and iron. 5.3 Inductively coupled plasma-atomic emission spectrometry (ICP-AES) is a widely used technique in the oil industry. Its advantages over traditional atomic absorption spectrometry (AAS) include greater sensitivity, freedom from molecular interferences, wide dynamic range, and multi-element capability. See Practice D7260. 1.1 This test method covers the determination of several elements (including iron, nickel, sulfur, and vanadium) occurring in crude oils. 1.2 For analysis of any element using wavelengths below 190 nm, a vacuum or inert gas optical path is required. 1.3 Analysis for elements such as arsenic, selenium, or sulfur in whole crude oil may be difficult by this test method due to the presence of their volatile compounds of these elements in crude oil; but this test method should work for resid samples. 1.4 Because of the particulates present in crude oil samples, if they do not dissolve in the organic solvents used or if they do not get aspirated in the nebulizer, low elemental values may result, particularly for iron and sodium. This can also occur if the elements are associated with water which can drop out of the solution when diluted with solvent. 1.4.1 An alternative in such cases is using Test Method D5708, Procedure B, which involves wet decomposition of the oil sample and measurement by ICP-AES for nickel, vanadium, and iron, or Test Method D5863, Procedure A, which also uses wet acid decomposition and determines vanadium, nickel, iron, and sodium using atomic absorption spectrometry. 1.4.2 From ASTM Interlaboratory Crosscheck Programs (ILCP) on crude oils data available so far, it is not clear that organic solvent dilution techniques would necessarily give lower results than those obtained using acid decomposition techniques. 1.4.3 It is also possible that, part......

Standard Test Method for Multielement Analysis of Crude Oils Using Inductively Coupled Plasma Atomic Emission Spectrometry 40;ICP-AES41;

ASTM D5853-11 原油倾点的标准试验方法

The pour point of a crude oil is an index of the lowest temperature of handleability for certain applications. This is the only pour point method specifically designed for crude oils. The maximum and minimum pour point temperatures provide a temperature window where a crude oil, depending on its thermal history, might appear in the liquid as well as the solid state. The test method can be used to supplement other measurements of cold flow behavior. It is especially useful for the screening of the effect of wax interaction modifiers on the flow behavior of crude oils.1.1 This test method covers two procedures for the determination of the pour point temperatures of crude oils down to −36°C. Procedure A provides a measure of the maximum (upper) pour point temperature and is described in 9.1. Procedure B provides a measure of the minimum (lower) pour point temperature and is described in 9.2. 1.2 The use of this test method is limited to use for crude oils. Pour point temperatures of other petroleum products can be determined by Test Method D97. 1.3 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard. 1.4 WARNINGMercury has been designated by many regulatory agencies as a hazardous material that can cause central nervous system, kidney and liver damage. Mercury, or its vapor, may be hazardous to health and corrosive to materials. Caution should be taken when handling mercury and mercury containing products. See the applicable product Material Safety Data Sheet (MSDS) for details and EPA’s websitehttp://www.epa.gov/mercury/faq.htmfor additional information. Users should be aware that selling mercury and/or mercury containing products into your state or country may be prohibited by law. 1.5 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 hazard statements, see Section 7.

Standard Test Method for Pour Point of Crude Oils

ASTM D4928-11 用电量计卡耳费歇尔滴定法对原油中水的标准试验方法

A knowledge of the water content of crude oil is important in the refining, purchase, sale, or transfer of crude oils.1.1 This test method covers the determination of water in the range from 0.02 to 5 mass or volume % in crude oils. Mercaptan (RSH) and sulfide (S− or H2S) as sulfur are known to interfere with this test method, but at levels of less than 500 μg/g (ppm), the interference from these compounds is insignificant (see Section 5). 1.2 This test method can be used to determine water in the 0.005 to 0.02 mass % range, but the effects of the mercaptan and sulfide interference at these levels has not been determined. 1.3 This test method is intended for use with standard commercially available coulometric Karl Fischer reagent. 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 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 hazard statements, see Section 7.

Standard Test Method for Water in Crude Oils by Coulometric Karl Fischer Titration

ASTM D4006-11(2012)e1 蒸馏法测定原油中水的标准试验方法

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 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). 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.

Standard Test Method for Water in Crude Oil by Distillation

ASTM D7622-10(2015) 使用燃烧和直接冷蒸气原子吸收法测定原油中总汞的标准测试方法与塞曼背景校正

5.1 The emission of mercury during crude oil refining is an environmental concern. The emission of mercury may also contaminate refined products and form amalgams with metals, such as aluminum. 5.2 When representative test portions are analyzed according to this procedure, the total mercury is representative of concentrations in the sample. 1.1 This test method covers the procedure to determine the total mercury content in a sample of crude oil. This test method can be used for total mercury determination in natural and processed liquid and oil products (gasoline, naphtha, etc.). 1.2 This test method may be applied to samples containing between 5.08201;ng/mL to 3508201;ng/mL of mercury. The results may be converted to mass basis. 1.3 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard. 1.4 WARNING—Mercury has been designated by many regulatory agencies as a hazardous material that can cause central nervous system, kidney and liver damage. Mercury, or its vapor, may be hazardous to health and corrosive to materials. Caution should be taken when handling mercury and mercury containing products. See the applicable product Material Safety Data Sheet (MSDS) for details and EPA’s website—http://www.epa.gov/mercury/faq.htm—for additional information. Users should be aware that selling mercury and/or mercury containing products into your state or country may be prohibited by law. 1.5 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.

Standard Test Method for Total Mercury in Crude Oil Using Combustion and Direct Cold Vapor Atomic Absorption Method with Zeeman Background Correction