5.1 The bromine number is useful as a measure of aliphatic unsaturation in petroleum samples. When used in conjunction with the calculation procedure described in Annex A2, it can be used to estimate the percentage of olefins in petroleum distillates boiling up to approximately 315 °C (600 °F).5.2 The bromine number of commercial aliphatic monoolefins provides supporting evidence of their purity and identity.1.1 This test method3 covers the determination of the bromine number of the following materials:1.1.1 Petroleum distillates that are substantially free of material lighter than isobutane and that have 90 % distillation points (by Test Method D86) under 327 °C (626 °F). This test method is generally applicable to gasoline (including leaded, unleaded, and oxygenated fuels), kerosine, and distillates in the gas oil range that fall in the following limits:90 % Distillation Point, °C (°F) Bromine Number, max3Under 205 (400) 175205 to 327 (400 to 626)  101.1.2 Commercial olefins that are essentially mixtures of aliphatic mono-olefins and that fall within the range of 95 to 165 bromine number (see Note 1). This test method has been found suitable for such materials as commercial propylene trimer and tetramer, butene dimer, and mixed nonenes, octenes, and heptenes. This test method is not satisfactory for normal alpha-olefins.NOTE 1: These limits are imposed since the precision of this test method has been determined only up to or within the range of these bromine numbers.1.2 The magnitude of the bromine number is an indication of the quantity of bromine-reactive constituents, not an identification of constituents; therefore, its application as a measure of olefinic unsaturation should not be undertaken without the study given in Annex A1.1.3 For petroleum hydrocarbon mixtures of bromine number less than 1.0, a more precise measure for bromine-reactive constituents can be obtained by using Test Method D2710. If the bromine number is less than 0.5, then Test Method D2710 or the comparable bromine index methods for industrial aromatic hydrocarbons, Test Methods D1492 or D5776 must be used in accordance with their respective scopes. The practice of using a factor of 1000 to convert bromine number to bromine index is not applicable for these lower values of bromine number.1.4 The values stated in SI units are to be regarded as the standard.1.4.1 Exception—The values given in parentheses are for information only.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, health, and environmental practices and determine the applicability of regulatory limitations prior to use. For specific warning statements, see Sections 7, 8, and 9.1.6 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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5.1 The pour point of a petroleum product is an index of the lowest temperature of its utility for certain applications. Flow characteristics, like pour point, can be critical for the correct operation of lubricating oil systems, fuel systems, and pipeline operations.5.2 Petroleum blending operations require precise measurement of the pour point.5.3 In most cases, this test method does not require the use of mechanical refrigeration apparatus (see 7.1).5.4 This test method yields a pour point in a format similar to Test Method D97/IP 15 when the 3 °C interval results are reported.NOTE 2: Since some users may wish to report their results in a format similar to Test Method D97 (in 3 °C intervals) the precisions were derived from the temperatures rounded to the 3° intervals. For statements on bias relative to Test Method D97, see 13.3.5.5 Test results from this test method can be determined at either 1 °C or 3 °C intervals.5.6 This test method has better repeatability and reproducibility relative to Test Method D97/IP 15 as measured in the 1992 and 1998 interlaboratory test programs.41.1 This test method covers the determination of pour point of petroleum products by an automatic instrument that applies a controlled burst of nitrogen gas onto the specimen surface while the specimen is being cooled and detects movement of the surface of the test specimen with an optical device.1.2 This test method is designed to cover the range of temperatures from −57 °C to +51 °C. However, the range of temperatures included in the 1992 interlaboratory test program only covered the temperature range from  −39 °C to +6 °C and the range of temperatures included in the 1998 interlaboratory test program was from −51 °C to −11 °C. (see 13.4).1.3 Test results from this test method can be determined at 1 °C or 3 °C testing intervals.1.4 This test method is not intended for use with crude oils.NOTE 1: The applicability of this test method or residual fuel samples has not been verified. For further information on applicability, refer to 13.4.1.5 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.6 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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4.1 The purpose of this code is to simplify the reporting of solid particle counts and water droplet concentrations present in petroleum products when measured by imaging instruments. Industry is accustomed to using a three number code to report contamination levels and so this reporting method for imaging instruments is presented to organize results in a similar format.4.2 Particle count results as described by this classification are reported per the preferred number ranges in Table 1. Preferred numbers were originally developed by Charles Renard and codified in ISO 3. This format is the preferred reporting format since ISO 4406 has no ability to report water.4.3 Imaging instruments are capable of identifying insoluble water droplets separate from solids, and therefore a suffix code is added after the three (or four) solid particle codes to report water content in parts per million (ppm (v)). To report water content, detected droplets will be converted to ppm (v). The distribution of water droplet size may be reported if it is useful, but it is not required.1.1 This classification identifies a concise code which can be used by imaging instruments for reporting of solid particles and insoluble water content in hydrocarbon-based petroleum products. The coding system includes the reporting of water content and particle counts in the ≥1 µm range.NOTE 1: Calibration is not in accordance with ISO 11171. Comparability to ISO 4406 and its requirements is not inferred.1.2 It is valid for imaging instruments measuring particle size by projected equivalent particle diameter (see 3.1.1), and which are calibrated and verified using particle size and count standards traceable to NIST.21.3 Due to the variation of method and instrument types and resolutions, the reporting of results will include the ASTM standard used to conduct the analysis.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.1.6 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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5.1 This test method is used for the determination of the distillation characteristics of petroleum products, biodiesel, and fractions that may decompose if distilled at atmospheric pressure. This boiling range, obtained at conditions designed to obtain approximately one theoretical plate fractionation, can be used in engineering calculations to design distillation equipment, to prepare appropriate blends for industrial purposes, to determine compliance with regulatory rules, to determine the suitability of the product as feed to a refining process, or for a host of other purposes.5.2 The boiling range is directly related to viscosity, vapor pressure, heating value, average molecular weight, and many other chemical, physical, and mechanical properties. Any of these properties can be the determining factor in the suitability of the product in its intended application.5.3 Petroleum product specifications often include distillation limits based on data by this test method.5.4 Many engineering design correlations have been developed on data by this test method. These correlative methods are used extensively in current engineering practice.1.1 This test method covers the determination, at reduced pressures, of the range of boiling points for petroleum products and biodiesel that can be partially or completely vaporized at a maximum liquid temperature of 400 °C. Both a manual method and an automatic method are specified.1.2 In cases of dispute, the referee test method is the manual test method at a mutually agreed upon pressure.1.3 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.1.4 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use. For specific warning statements, see 6.1.4, 6.1.8.1, 10.11, and A3.2.1.1.5 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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5.1 The pour point of a petroleum product is an index of the lowest temperature of its utility for certain applications. Flow characteristics, like pour point, can be critical for the correct operation of lubricating oil systems, fuel systems, and pipeline operations.5.2 Petroleum blending operations require precise measurement of the pour point.5.3 This test method can determine the pour point of the test specimen with a resolution of 1.0 °C.5.4 Test results from this test method can be determined at either 1 °C or 3 °C intervals.5.5 This test method yields a pour point in a format similar to Test Method D97/IP15 when the 3 °C interval results are reported.NOTE 3: Since some users may wish to report their results in a format similar to Test Method D97 (in 3 °C intervals) the precisions were derived for the temperatures rounded to the 3 °C intervals. For statements on bias relative to Test Method D97, see 13.3.5.6 This test method has better repeatability and reproducibility relative to Test Method D97/IP15 as measured in the 1998 interlaboratory test program. (See Section 13.)1.1 This test method covers the determination of pour point of petroleum products by an automatic instrument that tilts the test jar during cooling and detects movement of the surface of the test specimen with an optical device.1.2 This test method is designed to cover the range of temperatures from −66 °C to +51 °C; however, the range of temperatures included in the 1992 interlaboratory test program only covered the temperature range from −39 °C to +6 °C, and the range of temperatures included in the 1998 interlaboratory test program was −51 °C to −11 °C. (See Section 13.)1.3 Test results from this test method can be determined at 1 °C or 3 °C intervals.1.4 This test method is not intended for use with crude oils.NOTE 1: The applicability of this test method on residual fuel samples has not been verified. For further information on applicability, refer to 13.4.1.5 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.6 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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4.1 Samples of petroleum and petroleum products are obtained for many reasons, including the determination of chemical and physical properties. These properties may be used for: calculating standard volumes; establishing product value; and often safety and regulatory reporting.4.2 There are inherent limitations when performing any type of sampling, any one of which may affect the representative nature of the sample. As examples, a spot sample provides a sample from only one particular point in the tank, vessel compartment, or pipeline. In the case of running or all-level samples, the sample only represents the column of material from which it was taken.4.3 Based on the product, and testing to be performed, this practice provides guidance on sampling equipment, container preparation, and manual sampling procedures for petroleum and petroleum products of a liquid, semi-liquid, or solid state, from the storage tanks, flowlines, pipelines, marine vessels, process vessels, drums, cans, tubes, bags, kettles, and open discharge streams into the primary sample container.1.1 This practice covers procedures and equipment for manually obtaining samples of liquid petroleum and petroleum products, crude oils, and intermediate products from the sample point into the primary container are described. Procedures are also included for the sampling of free water and other heavy components associated with petroleum and petroleum products.1.2 This practice also addresses the sampling of semi-liquid or solid-state petroleum products. For the sampling of green petroleum coke, see Practice D8145. For the sampling of calcined petroleum coke, see Practice D6970.1.3 This practice provides additional specific information about sample container selection, preparation, and sample handling.1.4 This practice does not cover sampling of electrical insulating oils and hydraulic fluids. If sampling is for the precise determination of volatility, use Practice D5842 (API MPMS Chapter 8.4) in conjunction with this practice. For sample mixing and handling, refer to Practice D5854 (API MPMS Chapter 8.3).1.5 The procedures described in this practice may also be applicable in sampling most non-corrosive liquid industrial chemicals provided that all safety precautions specific to these chemicals are followed. Also, refer to Practice E300. The procedures described in this practice are also applicable to sampling liquefied petroleum gases and chemicals. Also refer to Practices D1265 and D3700. The procedure for sampling bituminous materials is described in Practice D140. Practice D4306 provides guidance on sample containers and preparation for sampling aviation fuel.1.6 Units—The values stated in SI units are to be regarded as the standard. USC units are reflected in parentheses.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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5.1 The boiling range distribution of light and medium petroleum distillate fractions provides an insight into the composition of feed stocks and products related to petroleum refining processes. This gas chromatographic determination of boiling range can be used to replace conventional distillation methods for control of refining operations. This test method can be used for product specification testing with the mutual agreement of interested parties.5.2 This test method extends the scope of Test Method D2887 (538 °C) boiling range determination by gas chromatography to include sulfur boiling range distribution in the petroleum distillate fractions. Knowledge of the amount of sulfur and its distribution in hydrocarbons is economically important in determining product value and in determining how best to process or refine intermediate products. Sulfur compounds are known to affect numerous properties of petroleum and petrochemical products. The corrosion of metals and poisoning of catalysts is of particular concern. In addition, the content of sulfur in various refined products may be subject to governmental regulations. Test Methods, such as, D2622, D3120, D5504 and D5623, are available to determine total sulfur content or content of individual sulfur compounds in petroleum and petroleum products. Test Methods, such as, D86, D1160, D2887, D3710, and D2892, are also available to determine the hydrocarbon boiling ranges of such samples. The gas chromatographic determination of the sulfur boiling range assists in process development, in treatment and control of refining operations and is useful for assessing product quality. This determination produces detailed information about the sulfur distribution in a sample that cannot be obtained by either total sulfur analysis or analysis of sulfur in discreet distillation cuts.5.2.1 The hydrocarbon boiling range distributions obtained by Test Method D2887 are theoretically equivalent to those obtained by true boiling point (TBP) distillation (see Test Method D2892). They are not equivalent to results from low efficiency distillation such as those obtained with Test Method D86 or D1160.1.1 This test method covers the determination of the boiling range distribution of petroleum products. The test method is applicable to petroleum products and fractions having a final boiling point of 538 °C (1000 °F) or lower at atmospheric pressure as measured by this test method. This test method is limited to samples having a boiling range greater than 55 °C (100 °F), and having a vapor pressure sufficiently low to permit sampling at ambient temperature.1.1.1 The applicable sulfur concentration range will vary to some extent depending on the boiling point distribution of the sample and the instrumentation used; however, in most cases, the test method is applicable to samples containing levels of sulfur above 10 mg/kg.1.2 This test method requires the use of both FID and SCD for detection. The hydrocarbon simulated distillation data obtained from the FID signal should be performed according to Test Method D2887 Procedure B.1.3 The test method is not applicable for analysis of petroleum distillates containing low molecular weight components (for example, naphthas, reformates, gasolines, crude oils). Materials containing heterogeneous components (for example, alcohols, ethers, acids, or esters) or residue are not to be analyzed by this test method. See Test Methods D3710, D7096, D5307, D7169, or D7500.1.4 This test method does not purport to identify all sulfur species in a sample. The detector response to sulfur is equimolar for all sulfur compounds within the scope (1.1) of this test method. Thus, unidentified sulfur compounds are determined with equal precision to that of identified substances. Total sulfur content is determined from the total area of the sulfur detector.1.4.1 This test method uses the principles of simulated distillation methodology.1.5 The values stated in SI units are to be regarded as standard. The values given in parentheses are for information only.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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5.1 This test method is useful for characterization and rapid quantification of PAH mixtures including petroleum oils, fuels, creosotes, and industrial organic mixtures, either waterborne or obtained from tanks.5.2 The unknown PAH mixture is first characterized by its fluorescence emission and synchronous scanning spectra. Then a suitable site-specific calibration standard with similar spectral characteristics is selected as described in Annex A1. This calibration standard may also be well-characterized by other independent methods such as gas chromatography (GC), GC-mass spectrometry (GC-MS), or high performance liquid chromatography (HPLC). Some suggested independent analytical methods are included in References (1-7)4 and Test Method D4657. Other analytical methods can be substituted by an experienced analyst depending on the intended data quality objectives. Peak maxima intensities of appropriate fluorescence emission spectra are then used to set up suitable calibration curves as a function of concentration. Further discussion of fluorescence techniques as applied to the characterization and quantification of PAHs and petroleum oils can be found in References (8-18).5.3 For the purpose of the present test method polynuclear aromatic hydrocarbons are defined to include substituted polycyclic aromatic hydrocarbons with functional groups such as carboxyl acid, hydroxy, carbonyl and amino groups, and heterocycles giving similar fluorescence responses to PAHs of similar molecular weight ranges. If PAHs in the more classic definition, that is, unsubstituted PAHs, are desired, chemical reactions, extractions, or chromatographic procedures may be required to eliminate these other components. Fortunately, for the most commonly expected PAH mixtures, such substituted PAHs and heterocycles are not major components of the mixtures and do not cause serious errors.1.1 This test method covers a means for quantifying or characterizing total polycyclic aromatic hydrocarbons (PAHs) by fluorescence spectroscopy (Fl) for waterborne samples. The characterization step is for the purpose of finding an appropriate calibration standard with similar emission and synchronous fluorescence spectra.1.2 This test method is applicable to PAHs resulting from petroleum oils, fuel oils, creosotes, or industrial organic mixtures. Samples can be weathered or unweathered, but either the same material or appropriately characterized site-specific PAH or petroleum oil calibration standards with similar fluorescence spectra should be chosen. The degree of spectral similarity needed will depend on the desired level of quantification and on the required data quality objectives.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 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.1.5 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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4.1 Accurate elemental analysis of petroleum products and lubricants is necessary for the determination of chemical properties, which are used to establish compliance with commercial and regulatory specifications.4.2 Inductively coupled plasma-atomic emission spectrometry is one of the more widely used analytical techniques in the oil industry for multi-element analysis as evident from at least twelve standard test methods (for example, Test Methods C1111, D1976, D4951, D5184, D5185, D5600, D5708, D6130, D6349, D6357, D7040, D7111, D7303, and D7691) published for the analysis of fossil fuels and related materials. These have been briefly summarized by Nadkarni (1).54.2.1 Determination of mercury and trace metals in crude oils using atomic spectroscopic methods is discussed in Guide D8056.4.3 The advantages of using an ICP-AES analysis include high sensitivity for many elements of interest in the oil industry, relative freedom from interferences, linear calibration over a wide dynamic concentration range, single or multi-element capability, and ability to calibrate the instrument based on elemental standards irrespective of their elemental chemical forms, within limits described below such as solubility and volatility assuming direct liquid aspiration. Thus, the technique has become a method of choice in most of the oil industry laboratories for metal analyses of petroleum products and lubricants.4.4 In addition to the ICP-AES standards listed in 2.2, a new ICP-MS standard, Test Method D8110, has been issued for analysis of distillate products for multi-element determination of Al, Ca, Cu, Fe, Pb, Mg, and K.1.1 This practice covers information on the calibration and operational guidance for the multi-element measurements using inductively coupled plasma-atomic emission spectrometry (ICP-AES).1.2 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.1.3 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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4.1 This test method may be used to measure the level of chlorine-containing compounds in petroleum products. This knowledge can be used to predict performance or handling characteristics of the product in question.4.2 This test method can also serve as a qualitative tool for the presence or non-detection of chlorine in petroleum products. In light of the efforts in the industry to prepare chlorine free products, this test method would provide information regarding the chlorine levels, if any, in such products.1.1 This test method covers the determination of chlorine in lubricating oils and greases, including new and used lubricating oils and greases containing additives, and in additive concentrates. Its range of applicability is 0.1 m% to 50 m% chlorine. The procedure assumes that compounds containing halogens other than chlorine will not be present.1.2 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.2.1 The preferred units are mass percent.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. Attention is called to specific warning statements incorporated in the test method.

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5.1 Methanol and ethanol are generated by the degradation of cellulosic materials used in the solid insulation systems of electrical equipment. More particularly, methanol comes from the depolymerization of cellulosic materials.3, 4, 5, 65.2 Methanol and ethanol, which are soluble in an insulating liquid to an appreciable degree, will proportionally migrate to that liquid after being produced from the cellulose.5.3 High concentrations or unusual increases in the concentrations of methanol or ethanol, or both, in an insulating liquid may indicate cellulose degradation from aging or incipient fault conditions. Testing for these alcohols may be used to complement dissolved gas-in-oil analysis and furanic compounds as performed in accordance with Test Methods D3612 and D5837 respectively.1.1 This test method describes the determination of by-products of cellulosic materials degradation found in electrical insulation systems that are immersed in insulating liquid. Such materials include paper, pressboard, wood and cotton materials. This test method allows the analysis of methanol and ethanol from the sample matrix by headspace GC-MS or GC-FID.1.2 This test method has been used to test for methanol and ethanol in mineral insulating liquids and less flammable electrical insulating liquids of mineral origin as defined in D3487 and D5222 respectively. Currently, this method is not a practical application for ester liquids.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 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.1.5 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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