ASTM D4177 Automatic Sampling of Petroleum and Petroleum Products
ASTM D4177 Standard Practice for Automatic Sampling of Petroleum and Petroleum Products
1. Scope
1.1 This practice covers information for the design, installation, testing, and operation of automated equipment for the extraction of representative samples of petroleum and petroleum products from a flowing stream and storing them in a sample receiver. If sampling is for the precise determination of volatility, use Practice D5842 in conjunction with this practice. For sample mixing, refer to Practice D5854. Petroleum products covered in this practice are considered to be a single phase and exhibit Newtonian characteristics at the point of sampling.
1.2 Applicable Fluids - This practice is applicable to petroleum and petroleum products with vapor pressures at sampling and storage temperatures less than or equal to 101 kPa (14.7 psi). Refer to D5842 when sampling for Reid vapor pressure (RVP) determination.
1.3 Non-applicable Fluids - Petroleum products whose vapor pressure at sampling and sample storage conditions are above 101 kPa (14.7 psi) and liquified gases (that is, LNG, LPG etc.) are not covered by this practice.
1.3.1 While the procedures covered by this practice will produce a representative sample of the flowing liquid into the sample receiver, specialized sample handling may be necessary to maintain sample integrity of more volatile materials at high temperatures or extended residence time in the receiver. Such handling requirements are not within the scope of this practice. Procedures for sampling these fluids are described in Practice D1265, Test Method D1145, and GPA 2166.
1.4 Annex A2 contains theoretical calculations for selecting the sampler location. Annex A3 lists acceptance methodologies for sampling systems and components. Annex A4 gives performance criteria for permanent installations, while Annex A5 has the criteria for portable sampling units. Appendix X1 is a design data sheet for automatic sampling systems; Appendix X2 compares the percent sediment and water to unloading time period.
1.5 The values stated in SI units are to be regarded as the standard. The values given in parentheses are for information only.
2. Referenced Documents
2.1 ASTM Standards:
D923 Practice for Sampling Electrical Insulating Liquids
D1145 Test Method for Sampling Natural Gas
D1265 Practice for Sampling Liquified Petroleum (LP) Gases - Manual Method
D4057 Practice for Manual Sampling of Petroleum and Petroleum Products
D4928 Test Method for Water in Crude Oils by Coulometric Karl Fischer Titration
D5842 Practice for Sampling and Handling of Fuels for Volatility Measurements
D5854 Practice for Mixing and Handling of Liquid Samples of Petroleum and Petroleum Products
2.2 API Standards:
API Manual of Petroleum Measurement Standards, Chapter 3
API Manual of Petroleum Measurement Standards, Chapter 4
API Manual of Petroleum Measurement Standards, Chapter 5
API Manual of Petroleum Measurement Standards, Chapter 6
API Manual of Petroleum Measurement Standards, Chapter 10
2.3 Gas Processors Association Standard:
GPA 2166 Obtaining Natural Gas Samples for Analysis by Gas Chromatography
2.4 Institute of Petroleum Standard:
IP Petroleum Measurement Manual, Part IV, Sampling Section 2, Guide to Automatic Sampling of Liquids from Pipelines, Appendix B, 34th Ed
2.5 Government Standard:
CFR 29, Section 11910.1000
3. Terminology
3.1 Definitions of Terms Specific to This Standard:
3.1.1 automatic sampler, n - a device used to extract a representative sample from the liquid flowing in a pipe.
3.1.2 Discussion - The automatic sampler usually consists of a probe, a sample extractor, an associated controller, a flow measuring device, and a sample receiver.
3.1.3 automatic sampling system, n - a system consisting of stream conditioning, an automatic sampler, and sample mixing and handling.
3.1.4 dissolved water, n - water in solution in petroleum and petroleum products.
3.1.5 emulsion, n - a water in oil mixture, which does not readily separate.
3.1.6 entrained water, n - water suspended in the oil.
3.1.6.1 Discussion - Entrained water includes emulsions but does not include dissolved water.
3.1.7 flow proportional sample, n - flow taken such that the rate is proportional throughout the sampling period to the flow rate of liquid in the pipe.
3.1.8 free water, n - water that exists as a separate phase.
3.1.9 grab, n - the volume of sample extracted from a pipeline by a single actuation of the sample extractor.
3.1.10 homogeneous, adj - when liquid composition is the same at all points in the container, tank, or pipeline cross section.
3.1.11 isokinetic sampling, n - sampling in such a manner that the linear velocity through the opening of the sample probe is equal to the linear velocity in the pipeline at the sampling location and is in the same direction as the bulk of the liquid approaching the sampling probe.
3.1.12 Newtonian fluid, n - a liquid whose viscosity is unaffected by the order of magnitude or agitation to which it may be subjected as long as the temperature is constant.
3.1.13 power mixer, n - a device which uses an external source of power to achieve stream conditioning.
3.1.14 primary sample receiver/container, n - a vessel into which all samples are initially collected.
3.1.15 probe, n - the portion of the automatic sampler that extends into the pipe and directs a portion of the fluid to the sample extractor.
3.1.16 profile testing, n - a procedure for simultaneously sampling at several points across the diameter of a pipe to identify the extent of stratification.
3.1.17 representative sample, n - a portion extracted from a total volume that contains the constituents in the same proportions as are present in the total volume.
3.1.18 sample, n - a portion extracted from a total volume that may or may not contain the constituents in the same proportions as are present in that total volume.
3.1.19 sample controller, n - a device which governs the operation of the sample extractor.
3.1.20 sample extractor, n - a device which removes a sample (grab) from a pipeline, sample loop, or tank.
3.1.21 sample handling and mixing, n - the conditioning, transferring and transporting of a sample.
3.1.22 sample loop (fast loop or slip stream), n - a low volume bypass diverted from the main pipeline.
3.1.23 sampling, n - all the steps required to obtain a sample that is representative of the contents of any pipe, tank, or other vessel and to place that sample into a container from which a representative test specimen can be taken for analysis.
3.1.24 sampling system proving, n - a procedure used to validate an automatic sampling system.
3.1.25 sediment and water (S&W), n - material which co-exists with, but is foreign to, a petroleum liquid.
3.1.25.1 Discussion - S&W may include dissolved water, free water and sediment, and emulsified and entrained water and sediment.
3.1.26 static mixer, n - a device which utilizes the kinetic energy of the flowing fluid to achieve stream conditioning.
3.1.27 stream condition, n - the distribution and dispersion of the pipeline contents, upstream of the sampling location.
3.1.28 stream conditioning, n - the mixing of a flowing stream so that a representative sample can be extracted.
3.1.29 time proportional sample, n - a sample composed of equal volume grabs taken from a pipeline at uniform time intervals during the entire transfer.
3.1.30 worst case conditions, n - the operating conditions for the sampler that represent the most uneven and unstable concentration profile at the sampling location.
