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ASTM D2892-01

(Test Method)

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

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

SCOPE
1.1 This test method covers the procedure for the distillation of stabilized crude petroleum 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.
1.2 This test method details procedures for the production of a liquified 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 liquified petroleum gases, very light naphthas, and fractions having initial boiling points above 400°C.
1.4 This test method contains the following Annexes:
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 are provided 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 and health practices and determine the applicability of regulatory limitations prior to use. For specific precautionary notes, see Section 10.

General Information

Status
Historical
Publication Date
09-Dec-2001
ICS
75.040 - Crude petroleum
Technical Committee
D02 - Petroleum Products, Liquid Fuels, and Lubricants
Drafting Committee
D02.08 - Volatility
Current Stage
Ref Project

Relations

Replaces
ASTM D2892-99a - Standard Test Method for Distillation of Crude Petroleum (15-Theoretical Plate Column)
Effective Date
10-Dec-2001
Replaced By
ASTM D2892-03 - Standard Test Method for Distillation of Crude Petroleum (15-Theoretical Plate Column)
Effective Date
10-Jun-2003
Referred By
ASTM D6378-22 - Standard Test Method for Determination of Vapor Pressure (VP<inf>X</inf>) of Petroleum Products, Hydrocarbons, and Hydrocarbon-Oxygenate Mixtures (Triple Expansion Method)
Effective Date
10-Dec-2001
Referred By
ASTM D6897-16 - Standard Test Method for Vapor Pressure of Liquefied Petroleum Gases (LPG) (Expansion Method)
Effective Date
10-Dec-2001
Referred By
ASTM D5188-16 - Standard Test Method for Vapor-Liquid Ratio Temperature Determination of Fuels (Evacuated Chamber and Piston Based Method)
Effective Date
10-Dec-2001
Referred By
ASTM D1655-23 - Standard Specification for Aviation Turbine Fuels
Effective Date
10-Dec-2001
Referred By
ASTM D5236-18a - Standard Test Method for Distillation of Heavy Hydrocarbon Mixtures (Vacuum Potstill Method)
Effective Date
10-Dec-2001
Referred By
ASTM D7213-15(2019) - Standard Test Method for Boiling Range Distribution of Petroleum Distillates in the Boiling Range from 100&#x2009;&#xb0;C to 615&#x2009;&#xb0;C by Gas Chromatography
Effective Date
10-Dec-2001
Referred By
ASTM D7798-20 - Standard Test Method for Boiling Range Distribution of Petroleum Distillates with Final Boiling Points up to 538&#x2009;&#xb0;C by Ultra Fast Gas Chromatography (UF GC)
Effective Date
10-Dec-2001
Referred By
ASTM D2887-22e1 - Standard Test Method for Boiling Range Distribution of Petroleum Fractions by Gas Chromatography
Effective Date
10-Dec-2001
Referred By
ASTM D6352-19e1 - Standard Test Method for Boiling Range Distribution of Petroleum Distillates in Boiling Range from 174&#x2009;&#xb0;C to 700&#x2009;&#xb0;C by Gas Chromatography
Effective Date
10-Dec-2001
Referred By
ASTM D5399-09(2023) - Standard Test Method for Boiling Point Distribution of Hydrocarbon Solvents by Gas Chromatography
Effective Date
10-Dec-2001
Referred By
ASTM D7169-23 - Standard Test Method for Boiling Point Distribution of Samples with Residues Such as Crude Oils and Atmospheric and Vacuum Residues by High Temperature Gas Chromatography
Effective Date
10-Dec-2001
Referred By
ASTM D5191-22 - Standard Test Method for Vapor Pressure of Petroleum Products and Liquid Fuels (Mini Method)
Effective Date
10-Dec-2001
Referred By
ASTM D7398-21 - Standard Test Method for Boiling Range Distribution of Fatty Acid Methyl Esters (FAME) in the Boiling Range from 100 °C to 615 °C by Gas Chromatography
Effective Date
10-Dec-2001

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ASTM D2892-01 - Standard Test Method for Distillation of Crude Petroleum (15-Theoretical Plate Column)
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Standards Content (Sample)

NOTICE: This standard has either been superceded and replaced by a new version or discontinued.
Contact ASTM International (www.astm.org) for the latest information.
An American National Standard
Designation: D 2892 – 01
Standard Test Method for
Distillation of Crude Petroleum (15-Theoretical Plate
1
Column)
This standard is issued under the fixed designation D 2892; the number immediately following the designation indicates the year of
original adoption or, in the case of revision, the year of last revision. A number in parentheses indicates the year of last reapproval. A
superscript epsilon (e) indicates an editorial change since the last revision or reapproval.
1. Scope 1.4.8 Annex A8—Practice for Conversion of Observed
Vapor Temperature to Atmospheric Equivalent Temperature
1.1 This test method covers the procedure for the distillation
2
(AET),
of stabilized crude petroleum to a final cut temperature of
1.4.9 Appendix X1—Test Method for Dehydration of a
400°C Atmospheric Equivalent Temperature (AET). This test
Sample of Wet Crude Oil, and
method employs a fractionating column having an efficiency of
1.4.10 Appendix X2—Practice for Performance Check.
14 to 18 theoretical plates operated at a reflux ratio of 5:1.
1.5 The values stated in SI units are to be regarded as
Performance criteria for the necessary equipment is specified.
standard. The values given in parentheses are provided for
Some typical examples of acceptable apparatus are presented
information only.
in schematic form. This test method offers a compromise
1.6 This standard does not purport to address all of the
between efficiency and time in order to facilitate the compari-
safety concerns, if any, associated with its use. It is the
son of distillation data between laboratories.
responsibility of the user of this standard to establish appro-
1.2 This test method details procedures for the production of
priate safety and health practices and determine the applica-
a liquified gas, distillate fractions, and residuum of standard-
bility of regulatory limitations prior to use. For specific
ized quality on which analytical data can be obtained, and the
precautionary notes, see Section 10.
determination of yields of the above fractions by both mass and
volume. From the preceding information, a graph of tempera-
2. Referenced Documents
ture versus mass % distilled can be produced. This distillation
2.1 ASTM Standards:
curve corresponds to a laboratory technique, which is defined
D 941 Test Method for Density and Relative Density (Spe-
at 15/5 (15 theoretical plate column, 5:1 reflux ratio) or TBP
cific Gravity) of Liquids by Lipkin Bicapillary Pycnom-
(true boiling point).
3
eter
1.3 This test method can also be applied to any petroleum
D 1217 Test Method for Density and Relative Density
mixture except liquified petroleum gases, very light naphthas,
4
(Specific Gravity) of Liquids by Bingham Pycnometer
and fractions having initial boiling points above 400°C.
D 1298 Test Method for Density, Relative Density (Specific
1.4 This test method contains the following Annexes:
Gravity), or API Gravity of Crude Petroleum and Liquid
1.4.1 Annex A1—Test Method for the Determination of the
4
Petroleum Products by Hydrometer Method
Efficiency of a Distillation Column,
D 2427 Test Method for Determination of C through C
2 5
1.4.2 Annex A2—Test Method for the Determination of the
4
Hydrocarbons in Gasolines by Gas Chromatography
Dynamic Holdup of a Distillation Column,
D 2887 Test Method for Boiling Range Distribution of
1.4.3 Annex A3—Test Method for the Determination of the
5
Petroleum Fractions by Gas Chromatography
Heat Loss in a Distillation Column (Static Conditions),
D 3710 Test Method for Boiling Range Distributions of
1.4.4 Annex A4—Test Method for the Verification of Tem-
5
Gasoline and Gasoline Fractions by Gas Chromatography
perature Sensor Location,
5
D 4006 Test Method for Water in Crude Oil by Distillation
1.4.5 Annex A5—Test Method for Determination of the
D 4052 Test Method for Density and Relative Density of
Temperature Response Time,
5
Liquids by Digital Density Meter
1.4.6 Annex A6—Practice for the Calibration of Sensors,
D 4057 Practice for Manual Sampling of Petroleum and
1.4.7 Annex A7—Test Method for the Verification of Reflux
5
Petroleum Products
Dividing Valves,
D 4177 Practice for Automatic Sampling of Petroleum and
5
Petroleum Products
1
This test method is under the jurisdiction of ASTM Committee D02 on
Petroleum Products and Lubricants and is the direct responsibility of Subcommittee
D02.08 on Volatility.
3
Current edition approved Dec. 10, 2001. Published April 2002. Originally Discontinued; see 1993 Annual Book of ASTM Standards, Vol 05.01.
4
published as D 2892 – 70 T. Last previous edition D 2892 – 99a. Annual Book of ASTM Standards, Vol 05.01.
2 5
Defined as having a Reid vapor pressure less than 82.7 kPa (12 psi). Annual Book of ASTM Standards, Vol 05.02.
Copyright © ASTM International, 100 Barr Harbor Drive, PO Box C700, West Conshohocken,
...

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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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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.  
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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 D4929-22(Test Method)
Standard Test Method for Determination of Organic Chloride Content in Crude Oil

SIGNIFICANCE AND USE
5.1 Organic chlorides do not occur naturally in crude oil. When present, they result from contamination in some manner, such as disposal of chlorinated solvent used in many dewaxing pipeline or other equipment operations.  
5.1.1 Uncontaminated crude oil will contain no detectable organic chloride, and most refineries can handle very small amounts without deleterious effects.
5.1.1.1 Most trade contracts specify that no organic chloride is present in the crude oil.  
5.1.2 Several pipelines have set specification limits at  
5.1.2.1 To ensure Eq 3).  
5.1.3 Organic chloride present in the crude oil (for example, methylene chloride, perchloroethylene, etc.) is usually distilled into the naphtha fraction. Some compounds break down during fractionation and produce hydrochloric acid, which has a corrosive effect. Some compounds survive fractionation and are destroyed during hydro-treating (desulfurization of the naphtha).  
5.2 Other halides can also be used for dewaxing crude oil; in such cases, any organic halides will have similar impact on the refining operations as the organic chlorides.  
5.3 Organic chloride species are potentially damaging to refinery processes. Hydrochloric acid can be produced in hydrotreating or reforming reactors and the acid accumulates in condensing regions of the refinery. Unexpected concentrations of organic chlorides cannot be effectively neutralized and damage can result. Organic chlorides are not known to be naturally present in crude oils and usually result from cleaning operations at producing sites, pipelines, or tanks. It is important for the oil industry to have common methods available for the determination of organic chlorides in crude oil, particularly when transfer of custody is involved.
SCOPE
1.1 The procedures in this test method cover the determination of organic chloride (above 1 μg/g organically-bound chlorine) in crude oils, using either distillation and sodium biphenyl reduction, distillation and microcoulometry, or distillation and X-ray fluorescence (XRF) spectrometry.  
1.2 The procedures in this test method involve the distillation of crude oil test specimens to obtain a naphtha fraction prior to chloride determination. The chloride content of the naphtha fraction of the whole crude oil can thereby be obtained. See Section 6 regarding potential interferences.  
1.3 Procedure A covers the determination of organic chloride in the washed naphtha fraction of crude oil by sodium biphenyl reduction followed by potentiometric titration.  
1.4 Procedure B covers the determination of organic chloride in the washed naphtha fraction of crude oil by oxidative combustion followed by microcoulometric titration.  
1.5 Procedure C covers the determination of organic chloride in the washed naphtha fraction of crude oil by X-ray fluorescence spectrometry.  
1.6 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.  
1.6.1 The preferred concentration units are micrograms of chloride per gram of sample, though milligrams of chloride per kilogram of sample is commonly used for Procedure C.  
1.7 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.  
1.8 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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