API-8-1-2002

Designation: D4057-XX

Work Item Number: WK34193 Date: 8/31/12

1

This document is not an API/ ASTM standard; it is under consideration within an API/ ASTM technical committee but has not received all approvals required to become an API/ASTM standard. You agree not to reproduce or circulate or quote, in whole or in part, this document outside of API/ASTM Committee/Society activities, or submit it to any other organization or standards bodies (whether national, international, or other) except with the approval of the Chairman of the Committee having jurisdiction and the written authorization of the President of the Society. If you do not agree with these conditions please immediately destroy all copies of the document. Copyright ASTM International, 100 Barr Harbor Drive, West Conshohocken, PA 19428. Copyright API, Washington D.C. All Rights Reserved.

1 Ballot Rationale 2 3

This document is now being balloted concurrently to ASTM D02.02 and D02 after the most recent D02.02 4 4 ballot comments were incorporated into the document. The existing version describes the various 5 sampling methods and apparatus, primarily for crude oils and semi-solids and solids. This version will 6 discuss manual sampling equipment and processes, along with the sampling procedures and sample 7 handling, and will provide more guidance for sampling refined products renewable fuel products. It is the 8 responsibility of the sub-committees for test methods to provide more specific information about sample 9 container selection, preparation, sample handling, mixing and sample size requirements. 10

11

API MPMS Chapter 8.1 12 Standard Practice for 13 Manual Sampling of Petroleum and Petroleum Products1 14 This standard is issued under the fixed designation D4057-XX; the number immediately following the 15 designation indicates the year of original adoption or, in the case of revision, the year of last revision. A 16 number in parentheses indicates the year of last reapproval. A superscript epsilon () indicates an editorial 17 change since the last revision or reapproval. 18

CONTENTS 19

0. Introduction 20

1. Scope 21

2. Referenced Documents 22

2.1 ASTM Standards 23

2.2 API Manual of Petroleum Measurement Standards 24

2.3 GPA Standards 25

2.4 Other Publications 26

3. Terminology 27

4. Significance and Use 28

5. Health and Safety Precautions 29

1 This practice is under the jurisdiction of ASTM Committee D02 on Petroleum Products and Lubricants and is the direct responsibility of Subcommittee D02.02 on Hydrocarbon Measurement for Custody Transfer (Joint ASTM-API).

D4057-XX

2 This document is not an API/ ASTM standard; it is under consideration within an API/ ASTM technical committee but has not received all approvals required to become an API/ASTM standard. You agree not to reproduce or circulate or quote, in whole or in part, this document outside of API/ASTM Committee/Society activities, or submit it to any other organization or standards bodies (whether national, international, or other) except with the approval of the Chairman of the Committee having jurisdiction and the written authorization of the President of the Society. If you do not agree with these conditions please immediately destroy all copies of the document. Copyright ASTM International, 100 Barr Harbor Drive, West Conshohocken, PA 19428. Copyright API, Washington D.C. All Rights Reserved.

5.1 General 30

5.2 Sample Handling 31

5.3 Sample Point Safety 32

5.4 Static Electricity Hazards 33

5.5 Pipeline/Line Sampling 34

5.6 General Health Hazards and Precautions 35

6. Apparatus 36

6.1 General Sample Container Design Considerations 37

6.2 Glass Bottles 38

6.3 Cans 39

6.4 Plastic Bottles 40

6.5 Container Closures 41

6.6 Container Cleanliness 42

6.7 Container Compatibility for Sample Mixing 43

6.8 Low Pressure Variable Volume Containers 44

6.9 High Pressure Spot Sampling Systems and Cylinders 45

7. Sampling Devices/Equipment and Accessories 46

7.1 Introduction 47

7.2 Cage Sampler 48

7.3 Weighted Bottle 49

7.4 Weighted Beaker 50

Current edition approved XXX. XX, XXXX. Published XXX XXXX. DOI: 10.1520/XXXXX-XX.

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7.5 Bottom Water and Remaining On-Board/On-Board Quantity (ROB/OBQ) 51

Sampler/Scraper 52

7.6 Tank Tap Sampling 53

7.7 Pipeline Manual Tap Sample Probe 54

7.8 Zone Sampler (Core Sampler) 55

7.9 Dead Bottom Sampler 56

7.10 Tube SamplerDrum or Barrel 57

7.11 Dipper/Ladle Sampler 58

7.12 Auger Sampler 59

7.13 Pail and Scoop Sampler 60

7.14 Accessory Equipment 61

8. Manual Sampling Concepts and Objective 62

8.1 Objective of Manual Sampling 63

8.2 Training 64

8.3 Physical and Chemical Property Tests 65

9. Sampling Requirements, Considerations and Procedures 66

9.1 General 67

9.2 Sampling Requirements and Considerations 68

9.3 Sampling Methods and Procedures 69

10. Special Instructions for Specific Products 70

10.1 Crude Oil 71

10.2 Refined Products 72

11. Keywords 73

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BIBLIOGRAPHY 74

TABLES 75

TABLE 1 Commonly Used Manual Sampling Devices for Liquid Products 76

TABLE 2 Typical Sampling Procedures and Applicability 77

TABLE 3 Recommended Weighted Sampling Bottle or Beaker Openings 78

TABLE 4 Spot Sample Minimum Requirements 79

TABLE 5 Tap Sampling Requirements 80

TABLE 6 Sampling from Horizontal Cylindrical Tanks 81

TABLE 7 Minimum Number of Packages to be Selected for Sampling 82

TABLE 8 Size of Grease Samples 83

FIGURES 84

1 Illustration of Common Spot Sample Positions 85

2 Typical Sample Carrier 86

3 Amber and Clear Boston Round Bottles 87

4 Cage Samplers 88

5 Weighted Bottle 89

6 Weighted Beakers 90

7 Example of a Bottom Water and ROB/OBQ Sampler/Scraper 91

8 Tank Sample Taps 92

9 Probe Designs 93

10 Example of Core/Interface SamplersThief 94

11 Example of Core/Zone Samplers 95

12 Example of Dead Bottom Samplers 96

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13 Tube Sampler 97

14 Auger Sampler 98

15 Example of Nozzle Extender 99

16a Example of a Fixed Volume Sample Cylinder with an Outage Tube 100

16b Example of a Fixed Volume Sample Cylinder and Transfer Line 101

17a Example of a Single-Piston Variable Volume Sample Cylinder 102

17b Example of a Single-Piston Variable Volume Sample Cylinder 103

17c Example of a Single-Piston Variable Volume Sample Cylinder 104

18 Example of a Double-Piston Variable Volume Sample Cylinder 105

19 Example of a Typical High-Pressure Sampling System 106

20 Example of Probe in a High-Pressure Sampling System Pipeline 107

21 Slotted Standpipe 108

22 Examples of Sample Labels/Tags 109

23 Location of Sampling Points at Different Levels for Rail Cars 110

24 Location of Sampling Points from Exposed Surface for Rail Cars 111

25 Examples of Typical Vapor Control Valves 112

26 Examples of a Small Volume (5 cm) and a Large Volume PSU (10 cm) 113

27 Examples of Closed/Restricted Sampling Equipment 114

28 Example of a Lock Valve and Closed System Sampler 115

29 Example of a Closed System Restricted Flow Sampler 116

APPENDIX 117

APPENDIX A CRUDE OIL SAMPLE HANDLING - TEST MATRIX 118

119

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120

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INTRODUCTION 121

The previous version of the manual sampling practice described the various sampling 122

methods and apparatus, with much focus on crude oils and semi-solids and solids. Also, previous 123

versions did not significantly address closed or restricted sampling, which continue to become 124

more prevalent. 125

This version will provide guidance on manual sampling terminology, concepts, equipment, 126

containers, procedure, and will provide some specific guidance related to particular products and 127

tests. The type and size of the sample obtained, and the handling method, will depend on the 128

purpose for which it was taken. The test method should be referenced for any specific sampling 129

and handling requirements up to the point of testing. It remains the responsibility of the 130

subcommittee for the relevant test method to provide guidance, or warnings, regarding sample 131

container selection; preparation; cleanliness; heat, pressure, or light; sample size requirements 132

for testing and retention; and any other special handling requirements necessary to ensure a 133

representative sample is tested. 134

In addition to the individual test method, for guidance on container, size, mixing and special 135

handling, further guidance may be provided in Practice D5854/API MPMS 8.3, Practice 136

D5842/API MPMS 8.4, and Practice D4306. While this practice will provide some general 137

guidance regarding sample chain of custody, Guide D4840 should also be consulted. 138

This document has been developed jointly between the American Petroleum Institute (API) 139

and ASTM International. 140

1. Scope 141

1.1 In this practice, procedures and equipment for manually obtaining samples of liquid 142

petroleum and petroleum products, crude oils, and intermediate products from the sample 143

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point into the primary container are described. Procedures are also included for the sampling 144

of free water and other heavy components associated with petroleum and petroleum products. 145

1.2 This practice also addresses the sampling of semi-liquid or solid-state petroleum 146

products. 147

1.3 This practice provides additional specific information about sample container 148

selection, preparation, and sample handling. 149

1.4 This practice does not cover sampling of electrical insulating oils and hydraulic fluids. 150

If sampling is for the precise determination of volatility, use Practice D5842/API MPMS 8.4 151

in conjunction with this practice. For sample mixing and handling, refer to Practice 152

D5854/API MPMS 8.3. 153

1.5 The procedures described in this practice may also be applicable in sampling most 154

non-corrosive liquid industrial chemicals provided that all safety precautions specific to these 155

chemicals are followed. Also, refer to Practice E300. The procedures described in this practice 156

are also applicable to sampling liquefied petroleum gases and chemicals. Also refer to 157

Practices D1265 and D3700. The procedure for sampling bituminous materials is described in 158

Practice D140. Practice D4306 provides guidance on sample containers and preparation for 159

sampling aviation fuel. 160

1.6 UnitsThe values stated in SI units are to be regarded as the standard. USC units are 161

reflected in parenthesis. 162

1.7 This standard does not purport to address all of the safety concerns, if any, associated 163

with its use. It is the responsibility of the user of this standard to establish appropriate safety 164

and health practices and determine the applicability of regulatory limitations prior to use. 165

2. Referenced Documents 166

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2.1 ASTM Standards2 167

D86 Standard Test Method for Distillation of Petroleum Products at Atmospheric Pressure 168

D97 Standard Test Method for Pour Point of Petroleum Products 169

D140 Practice for Sampling Bituminous Materials 170

D217 Test Methods for Cone Penetration of Lubricating Grease 171

D244 Test Methods and Practices for Emulsified Asphalts 172

D268 Standard Guide for Sampling and Testing Volatile Solvents and Chemical 173

Intermediates for Use in Paint and Related Coatings and Material 174

D287 Standard Test Method for API Gravity of Crude Petroleum and Petroleum Products 175

(Hydrometer Method) 176

D323 Standard Test Method for Vapor Pressure of Petroleum Products (Reid Method) 177

D346 Practice for Collection and Preparation of Coke Samples for Laboratory Analysis 178

D445 Standard Test Method for Kinematic Viscosity of Transparent and Opaque Liquids 179

(and Calculation of Dynamic Viscosity) 180

D473 Standard Test Method for Sediment in Crude Oils and Fuel Oils by the Extraction 181

Method 182

D664 Standard Test Method for Acid Number of Petroleum Products by Potentiometric 183

Titration 184

D977 Specification for Emulsified Asphalt 185

D1265 Practice for Sampling Liquefied Petroleum (LP) Gases, Manual Method 186

2 For referenced ASTM standards, visit the ASTM website, www.astm.org, or contact ASTM Customer Service at [email protected]. For Annual Book of ASTM Standards volume information, refer to the standards Document Summary page on the ASTM website.

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D1298 Standard Test Method for Density, Relative Density (Specific Gravity), or API 187

Gravity of Crude Petroleum and Liquid Petroleum Products by Hydrometer Method 188

D1856 Test Method for Recovery of Asphalt from Solution by Abson Method 189

D2172 Test Methods for Quantitative Extraction of Bitumen from Bituminous Paving 190

Mixtures 191

D2622 Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-192

ray Fluorescence Spectrometry 193

D3230 Standard Test Method for Salts in Crude Oil (Electrometric Method) 194

D3700 Practice for Obtaining LPG Samples Using a Floating Piston Cylinder 195

D4006 Standard Test Method for Water in Crude Oil by Distillation 196

D4007 Standard Test Method for Water and Sediment in Crude Oil by the Centrifuge 197

Method (Laboratory Procedure) 198

D4177 Practice for Automatic Sampling of Petroleum and Petroleum Products 199

D4294 Standard Test Method for Sulfur in Petroleum and Petroleum Products by Energy 200

Dispersive X-ray Fluorescence Spectrometry 201

D4306 Practice for Aviation Fuel Sample Containers for Tests Affected by Trace 202

Contamination 203

D4377 Standard Test Method for Water in Crude Oils by Potentiometric Karl Fischer 204

Titration 205

D4530 Standard Test Method for Determination of Carbon Residue (Micro Method) 206

D4629 Standard Test Method for Trace Nitrogen in Liquid Petroleum Hydrocarbons by 207

Syringe/Inlet Oxidative Combustion and Chemiluminescence Detection 208

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D4807 Standard Test Method for Sediment in Crude Oil by Membrane Filtration 209

D4840 Guide for Sample Chain-of-Custody Procedures 210

D4928 Standard Test Method for Water in Crude Oils by Coulometric Karl Fischer Titration 211

D4929 Standard Test Methods for Determination of Organic Chloride Content in Crude Oil 212

D5002 Standard Test Method for Density and Relative Density of Crude Oils by Digital 213

Density Analyzer 214

D5191 Standard Test Method for Vapor Pressure of Petroleum Products (Mini Method) 215

D5762 Standard Test Method for Nitrogen in Petroleum and Petroleum Products by Boat-216

Inlet Chemiluminescence 217

D5842 Practice for Sampling and Handling of Fuels for Volatility Measurement 218

D5853 Standard Test Method for Pour Point of Crude Oils 219

D5854 Practice for Mixing and Handling of Liquid Samples of Petroleum and Petroleum 220

Products 221

D5863 Standard Test Methods for Determination of Nickel, Vanadium, Iron, and Sodium in 222

Crude Oils and Residual Fuels by Flame Atomic Absorption Spectrometry 223

D6299 Practice for Applying Statistical Quality Assurance and Control Charting Techniques 224

to Evaluate Analytical Measurement System Performance 225

D6377 Standard Test Method for Determination of Vapor Pressure of Crude Oil: VPCRx 226

(Expansion Method) 227

D6470 Standard Test Method for Salt in Crude Oils (Potentiometric Method) 228

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D6560 Standard Test Method for Determination of Asphaltenes (Heptane Insolubles) in 229

Crude Petroleum and Petroleum Products 230

D6822 Standard Test Method for Density, Relative Density, and API Gravity of Crude 231

Petroleum and Liquid Petroleum Products by Thermohydrometer Method 232

D6849 Practice for Storage and Use of Liquefied Petroleum Gases (LPG) in Sample 233

Cylinders for LPG Test Methods 234

D7169 Standard Test Method for Boiling Point Distribution of Samples with Residues Such 235

as Crude Oils and Atmospheric and Vacuum Residues by High Temperature Gas 236

Chromatography 237

E300 Practice for Sampling Industrial Chemicals 238

E882 Guide for Accountability and Quality Control in the Chemical Analysis Laboratory 239

2.2 API Manual of Petroleum Measurement Standards3 240

Chapter 8.2 Practice for Automatic Sampling of Petroleum and Petroleum Products 241

Chapter 8.3 Practice for Mixing and Handling of Liquid Samples of Petroleum and 242

Petroleum Products 243

Chapter 8.4 Practice for Manual Sampling and Handling of Fuels for Volatility Measurement 244

Chapter 9.1 Standard Test Method for Density, Relative Density (Specific Gravity), or API 245

Gravity of Crude Petroleum and Liquid Petroleum 246

Chapter 9.2 Standard Test Method for Density or Relative Density of Light Hydrocarbons by 247

Pressure Hydrometer 248

3 Available from the American Petroleum Institute, 1220 L St., NW, Washington, DC 20005-4070.

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Chapter 9.3 Standard Test Method for Density, Relative Density, and API Gravity of Crude 249

Petroleum and Liquid Petroleum Products by Thermohydrometer Method 250

Chapter 10.1 Standard Test Method for Sediment in Crude Oils and Fuel Oils by the 251

Extraction Method 252

Chapter 10.2 Standard Test Method for Water in Crude Oil by Distillation 253

Chapter 10.3 Standard Test Method for Water and Sediment in Crude Oil by the Centrifuge 254

Method (Laboratory Procedure) 255

Chapter 10.4 Determination of Water and/or Sediment in Crude Oil by the Centrifuge 256

Method (Field Procedure) 257

Chapter 10.7 Standard Test Method for Water in Crude Oils by Potentiometric Karl Fischer 258

Titration 259

Chapter 10.8 Standard Test Method for Sediment in Crude Oil by Membrane Filtration 260

Chapter 10.9 Standard Test Method for Water in Crude Oils by Coulometric Karl Fischer 261

Titration 262

Chapter 17.10.2 Measurement of Refrigerated and/or Pressurized Cargoes of Board Marine 263

Gas Carriers Part 2 Liquid Petroleum and Chemical Gases 264

Chapter 18.1 Measurement Procedures for Crude Oil Gathered From Small Tanks by Truck 265

Recommended Practice 2003 Protection Against Ignitions Arising Out of Static, Lightning, 266

and Stray Currents 267

2.3 GPA Standards 268

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S 2174 Obtaining Liquid Hydrocarbon Samples for Analysis by Gas Chromatograph4 269

2.4 Other Publications 270

UOP163 Hydrogen Sulfide and Mercaptan Sulfur in Liquid Hydrocarbons by Potentiometric 271

Titration 272

International Safety Guide for Oil Tankers and Terminals (ISGOTT), Safety of Life at Sea 273

(SOLAS) 274

Oil Companies International Marine Forum (OCIMF) 275

3. Terminology 276

3.1 Definitions: 277

3.1.1 assay, nthe procedure to determine the presence, absence, or quantity of one or more 278

components. 279

3.1.2 automatic sampler, na device used to extract a representative sample from the liquid 280

flowing in a pipe. 281

3.1.3 bubble point, nwhen the pressure is lowered on a liquid held at a constant 282

temperature, the pressure at which the first bubble of vapor forms is the bubble point. Bubble 283

point pressures are higher at high temperatures. 284

3.1.5 density, nfor a quantity of a homogeneous substance, the ratio of its mass to its 285

volume. The density varies as the temperature changes and is, therefore, generally expressed as 286

the mass per unit of volume at a specified temperature. 287

3.1.6 dissolved water, nwater in solution in petroleum and petroleum products. 288

4 Available from the Gas Processors Association, 6526 E. 60th St., Tulsa, OK 74145.

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3.1.7 emulsion, na petroleum and petroleum products / water mixture that does not readily 289

separate. 290

3.1.8 entrained water, nwater suspended in the petroleum and petroleum products. 291

Entrained water includes emulsions but does not include dissolved water. 292

3.1.9 free water, nwater that exists as a separate phase. 293

3.1.10 flash point, nin petroleum products, the lowest temperature corrected to a 294

barometric pressure of 101.3 kPa (760-mm Hg), at which application of an ignition source causes 295

the vapors of a specimen of the sample to ignite under specified conditions of test. 296

3.1.11 floating piston cylinder, na high pressure sample container, with a free floating 297

internal piston that effectively divides the container into two separate compartments. 298

3.1.12 high pressure sample cylinder, na receptacle used for storage and transportation of a 299

sample obtained at pressures above atmospheric pressure. 300

3.1.13 inert gas, na gas that does not react with its surroundings. 301

3.1.14 inerting, va procedure used to reduce the oxygen content of a vessels cargo spaces 302

by introducing an inert gas such as nitrogen or carbon dioxide or a mixture of gases such as 303

processed flue gas. 304

3.1.15 intermediate sample container, na container into which all or part of the sample 305

from a primary container (receiver) is transferred for transport, storage, or ease of handling. 306

3.1.16 LPG (Liquefied Petroleum Gas), na gas that is predominantly butane and propane 307

separated from natural gasoline or natural gas and sold in liquid form as fuel-commonly known 308

as bottled gas, tank gas, or LP-gas. 309

3.1.17 maximum fill density (reduced fill density), nthe volume of a container occupied by 310

the sample, usually expressed as a percentage of the total capacity. Transportation legislation 311

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such as U.S. CFR 49, Canadian Transportation of Dangerous Goods Regulations, and IATA 312

regulations limit the percent fill of containers used for shipping LPG and may quote this 313

requirement as a reduced fill density or maximum fill density (normally 80 % maximum liquid 314

fill at 15C). Lower percent fill (lower fill density) may be required if sampling at lower 315

temperatures. 316

3.1.18 on-board quantity (OBQ), nthe material present in a vessels cargo tanks, void 317

spaces, and pipelines before the vessel is loaded. On-board quantity may include any 318

combination of water, oil, slops, oil residue, oil/water emulsion, and sediment. 319

3.1.19 outage tube (internal), na cut to length tube placed inside of the sample cylinder 320

used as a way to remove excess sample from the cylinder via manual evacuation after the sample 321

cylinder assembly is removed from the sample point. Refer to Figures 16a and 16b. 322

3.1.20 portable manual sampling unit, PSU, nan intrinsically safe device used in 323

conjunction with a vapor control valve to obtain required cargo samples under closed or 324

restricted system conditions. Refer to figures 26 and 27. 325

3.1.21 primary sample container, na container in which a sample is initially collected. 326

3.1.21.1 DiscussionExamples of primary sample containers include glass and plastic 327

bottles, cans, core-type thief, and fixed and portable sample containers (receivers). 328

3.1.22 remaining on board, ROB, nthe material remaining in a vessels cargo tanks, void 329

spaces, and pipelines after the cargo is discharged. Remaining on board quantity may include any 330

combination of water, oil, slops, oil residue, oil/water emulsions, and sediment. 331

3.1.23 sample, na portion extracted from a total volume that may or may not contain the 332

constituents in the same proportions that are present in that total volume. 333

3.1.24 sample types 334

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3.1.24.1 all-levels sample, na sample obtained by lowering the closed sampling device to 335

the bottom of the outlet suction level, but always above free water, then opening the sampler and 336

raising it at a uniform rate such that it is between 70 and 85 % full when withdrawn from the 337

product. Alternately, all levels samples may be taken with samplers designed for filling as they 338

pass downward through the product. 339

3.1.24.1a Discussion: If required by the test method, the sampler may be greater than 85% 340

full when withdrawn but in no case shall it be completely full. In these cases, take special 341

handling precautions to consider the hazards associated with product thermal expansion. 342

3.1.24.2 boring sample, na sample of the material contained in a barrel, case, bag, or cake 343

that is obtained from the chips created by boring holes into the material with a ship auger. 344

3.1.24.3 bottom sample, na spot sample collected from the material at the bottom of the 345

tank, container, or line at its lowest point. In practice, the term bottom sample has a variety of 346

meanings. As a result, it is recommended that the exact sampling location (for example 15 cm 347

from the bottom) should be specified when using this term. See Figure 1. 348

3.1.24.4 bottom water sample, na spot sample of free water taken from beneath the 349

petroleum contained in a ship or barge compartment or a storage tank. 350

3.1.24.5 clearance sample, na spot sample taken with the inlet opening of the sampling 351

device 10 cm (some regulatory agencies require 15 cm) below the bottom of the tank outlet. This 352

term is normally associated with small (159-m3 (1000 barrels) or less) tanks, commonly referred 353

to as lease tanks. 354

3.1.24.6 composite sample, na sample prepared by combining a number of samples and 355

treated as a single sample. Also refer to tank composite sample, volumetric composite 356

sample, deck composite sample, and multiple tank composite sample definitions. 357

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3.1.24.7 core sample, na sample of a uniform cross-sectional area taken at a given height 358

in a tank. 359

3.1.24.8 dead bottom sample, na sample obtained from the lowest accessible point in a 360

tank. This is typically directly from the floor (or datum plate) of the shore tank or the bottom of 361

the vessel compartment. 362

3.1.24.9 deck composite sample, na sample typically made by compositing a portion of 363

each sample obtained from all vessel compartments containing a particular product grade. 364

3.1.24.10 dipper sample, na sample obtained by placing a dipper or other collecting vessel 365

in the path of a free-flowing stream to collect a definite volume from the full cross section of the 366

stream at regular time intervals for a constant time rate of flow or at time intervals varied in 367

proportion to the flow rate. 368

3.1.24.11 drain sample, na sample obtained from the water draw-off valve on a storage 369

tank vessel or container. Occasionally, a drain sample may be the same as a bottom sample (for 370

example, in the case of a tank car). 371

3.1.24.12 floating roof sample, na spot sample taken just below the surface to determine 372

the density (API gravity) of the liquid on which the roof is floating. 373

3.1.24.13 grab sample, n(a) Solid- a sample obtained by collecting equal quantities from 374

parts or packages of a shipment of loose solids so that the sample is representative of the entire 375

shipment. (b) Liquid- a sample collected at a specific location in a tank or from a flowing stream 376

in a pipe at a specific time. 377

3.1.24.14 grease sample, nobtained by scooping or dipping a quantity of soft or semi-liquid 378

material contained from a package in a representative manner. 379

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3.1.24.15 loading zone sample, na sample taken from a tank prior to commencement of a 380

transfer, intended to represent only the product expected to be transferred. 381

3.1.24.16 lower sample, na spot sample of liquid from the middle of the lower one third of 382

the tank's content (a distance of five sixths of the depth liquid below the liquid's surface) see 383

Figure 1. 384

3.1.24.17 middle sample, na spot sample taken from the middle of a tank's contents (a 385

distance of one half of the depth of liquid below the liquid's surface. see Figure 1. 386

3.1.24.18 multiple tank composite sample, na mixture of individual samples or composites 387

of samples that have been obtained from several tanks or ship/barge compartments containing 388

the same grade of material. The mixture is blended typically in proportion to the volume of 389

material contained in the respective tanks or compartments. 390

3.1.24.19 representative sample, na portion extracted from the total volume that contains 391

the constituents in the same proportions that are present in that total volume. 392

3.1.24.20 running sample, na sample obtained by lowering an open sampling device to the 393

bottom of the outlet suction level, but always above free water, and returning it to the top of the 394

product at a uniform rate such that the sampling device is between 70 and 85 % full when 395

withdrawn from the product. 396

3.1.24.20a Discussion: If required by the test method, the sampler may be greater than 85% 397

full when withdrawn but in no case shall it be completely full. In these cases, take special 398

handling precautions to consider the hazards associated with product thermal expansion. 399

3.1.24.21 spot sample, na sample taken at a specific location in a tank or from a flowing 400

stream in a pipe at a specific time. 401

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3.1.24.22 suction sample (outlet), na spot sample taken at the lowest level from which 402

product is expected to be pumped from the tank; see Figure 1. 403

3.1.24.23 sump sample, nspot sample taken from within the tank or vessel compartment 404

sump; see Figure 1. 405

3.1.24.24 surface (skim) sample, na spot sample skimmed from the surface of a liquid in a 406

tank; see Figure 1. 407

3.1.24.25 tank composite sample, na blend created from a single tank, as an example 408

combining the upper, middle, and lower samples. For a tank of uniform cross section, such as an 409

upright cylindrical tank, the blend consists of equal parts of the three samples. A combination of 410

other samples may also be used, such as running, all-levels or additional spot samples. For a 411

horizontal cylindrical tank, the blend consists of samples in the proportions shown in Table 5. 412

3.1.24.26 tap sample, na spot sample taken from a sample tap on the side of a tank. It may 413

also be referred to as a tank-side sample. 414

3.1.24.27 test specimen, na representative sub-sample taken from the primary or 415

intermediate sample container for analysis. 416

3.1.24.28 top sample, na spot sample obtained 15 cm (6 inches) below the top surface of 417

the liquid; see Figure 1. 418

3.1.24.29 tube or thief sample, na sample obtained with a sampling tube or special thief, 419

either as a core sample or spot sample, from a specific point in the tank or container. 420

3.1.24.30 upper sample, na spot sample taken from the middle of the upper one third of the 421

tank's contents (a distance of one sixth of the liquid depth below the liquid's surface); see 422

Figure 1. 423

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3.1.24.31 volumetric composite sample, na sample consisting of measured proportional 424

parts from each zone if it is for a single tank. If the volumetric composite is for multiple tanks, or 425

vessel compartments, it consists of measured proportional parts from each tank or compartment 426

sampled. 427

3.1.24.32 zone sample, na sample taken as that part of the liquid column that is trapped 428

within the whole height of a sampling device when it is sealed at a single spot location within a 429

tank after having been fully flushed as it was lowered to that position. 430

3.1.25 sampling, vall the steps required to obtain a sample that is representative of the 431

contents of any pipe, tank, or other vessel and to place that sample in a container from which a 432

representative test specimen can be taken for analysis. 433

3.1.26 slip tube, na graduated hollow rod fitted into a gas-tight housing, the lower end of 434

which is open to the cargos contents and the upper end is fitted with a valve. 435

3.1.27 standpipes, nthe vertical sections of pipe or tubing used for gauging extending from 436

the gauging platform to near the bottom of tanks that are equipped with external or internal 437

floating roofs. Standpipes may also be found on marine vessels. Standpipes are also known as 438

stilling wells or gauge wells. Standpipes without slots do not allow the free flow of product 439

through the standpipe, and are known as solid or unslotted standpipes. 440

3.1.28 ullage (outage), nthe volume of available space in a container unoccupied by 441

contents. 442

3.1.29 vapor control valve, VCV, na valve fitted on a standpipe, expansion trunk, or the 443

deck that permits use of the portable hand-held gauging/sampling instruments while restricting 444

the release of vapors into the atmosphere. 445

3.1.30 vapor pressure RVP, TVP, n 446

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3.1.30.1 Reid vapor pressure, RVP, nthe vapor pressure of a liquid at 37.8C, 311K. 447

3.1.30.2 true vapor pressure, TVP, nthe pressure at which the fluid is in equilibrium 448

between its liquid and gas state. 449

4. Significance and Use 450

4.1 Samples of petroleum and petroleum products are obtained for many reasons, including 451

the determination of chemical and physical properties. These properties may be used for: 452

calculating standard volumes; establishing product value; and often safety and regulatory 453

reporting. 454

4.2 There are inherent limitations when performing any type of sampling, any one of which 455

may affect the representative nature of the sample. As examples, a spot sample provides a 456

sample from only one particular point in the tank, vessel compartment, or pipeline. In the case of 457

running or all-level samples, the sample only represents the column of material from which it 458

was taken. 459

4.3 Based on the product, and testing to be performed, this practice provides guidance on 460

sampling equipment, container preparation, and manual sampling procedures for petroleum and 461

petroleum products of a liquid, semi-liquid, or solid state, from the storage tanks, flowlines, 462

pipelines, marine vessels, process vessels, drums, cans, tubes, bags, kettles, and open discharge 463

streams into the primary sample container. 464

5. Health and Safety Precautions 465

5.1 GeneralThis practice does not purport to cover all safety and health aspects associated 466

with sampling. Personnel involved with sampling of petroleum and petroleum-related products 467

should be familiar with their physical and chemical characteristics, including: potential for fire, 468

explosion, and reactivity; toxicity and health hazards; and appropriate emergency procedures. 469

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Additionally personnel should comply with individual company safe operating practices and 470

local, state, and national regulations, including the use of personal protective equipment (PPE). 471

Upon completion of any sampling activity, ensure the sample point is left in a safe, secure, and 472

clean condition with the handling of any waste in accordance with local requirements. All marine 473

vessel sampling should be performed in the presence of a designated vessel representative. 474

5.2 Sample HandlingFor safety and protection of the integrity of the samples, sample 475

carriers are suggested in most instances. Refer to Figure 2. Because of potential liquid thermal 476

expansion, sample containers that are completely, or nearly full, are not to be transported or 477

stored, unless special precautionary measures are taken. A safe fill of between 70 and 85 % is 478

recommended. Refer to Maximum Fill Density and section 9.3.14 for safe fill of Pressurized 479

Cylinders. Take care to avoid heating samples in containers with gas-tight caps, lids, and 480

stoppers. Handle any sample containing hazardous materials or the residue of hazardous 481

materials offered for shipment/transportation by air, public roadway, rail, or water in such a 482

manner as to ensure compliance with requirements such as training, documentation, labeling, 483

container, packaging, communications, and so forth, set forth in applicable regulations, such as 484

those issued by the International Air Transport Association (IATA) and the U.S. Department of 485

Transportation (DOT). 486

5.3 Sample Point Safety 487

5.3.1 Provide sample points that enable samples to be taken in a safe manner, considering 488

ventilation during sampling, clear access/egress, and lighting. Any potential hazards associated 489

with sampling, or located near the sample point, should be clearly marked. It is recommended 490

that a pressure gauge, a method of closed loop flushing and safe drainage, be provided at pipeline 491

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sample points. Sample points and related equipment should be maintained and inspected 492

regularly. 493

5.3.2 Floating-roof tanks should be sampled from the top platform, thereby avoiding descent 494

onto the floating roof. Descending onto a floating roof is normally considered entering a 495

designated confined space, requiring all facility and regulatory requirements to be strictly 496

followed, including obtaining a confined space permit, and rescue provisions arranged. Toxic 497

and flammable vapors may accumulate on the roof. 498

5.4 Static Electricity Hazards 499

5.4.1 A number of fires and explosions have occurred as a result of hydrocarbon vapors 500

being ignited by static electricity. If electrical charges are not earthed or grounded, they are 501

unable to dissipate and become static. This static electric charge can accumulate and freely 502

migrate to a single point on the sample container by a difference in electrical potential, then jump 503

off as a high-energy spark discharge to a nearby less charged surface, often hot and prolonged 504

enough to ignite nearby hydrocarbon vapors above the lower explosive limit (LEL). This 505

potential shall be managed by safely dissipating static charges, and through proper grounding, 506

when sampling flammable products. 507

5.4.2 Footwear or clothing, capable of causing sparks, should not to be worn during sampling 508

activities in which flammable vapors are likely to be present. Sampling should not be carried out 509

during periods of atmospheric electric disturbance or hail storms. To ground any static charge on 510

their person, the individual performing the sampling should touch part of the tank structure at 511

least 1 m (3 feet) from the sample point immediately before sampling. 512

5.4.3 Precautions are to be observed before sampling to reduce the likelihood of a static 513

charge being present. During tank filling or mixing operations, and for 30 min after the 514

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completion, sampling equipment shall not be introduced into, or remain in, the tank. With full 515

observance of applicable regulatory requirements, and only under very specific and documented 516

conditions, some exceptions to the 30-min relaxation period may apply. Some tanks and vessel 517

compartments have inert gas blankets in the vapor space above the liquid. Unless the 518

effectiveness of the inert blanket can be verified, all static charge precautions and 519

recommendations should be observed. 520

5.4.4 Exercise caution when using equipment made of aluminum, magnesium, or titanium, 521

which may generate incendiary sparks when struck against rusted steel. Some countries restrict 522

the use of sampling equipment made from such materials or from alloys containing more than 523

15 % (m/m) in total of these metals or 6 % (m/m) of magnesium. 524

5.5 Pipeline/Line SamplingWhen sampling a flowing pipeline, maintain electrical 525

continuity between the pipeline and the sample container via the connecting pipework. Do not 526

use plastic containers since they are non-conductive and will not dissipate static electricity. Use a 527

static grounding clamp or other arrangement that ensures adequate electrical continuity is 528

maintained if sampling with a metal container. An effective ground should be verified. 529

NOTE 1: The API safety publication Protection Against Ignitions Arising Out of Static, 530

Lightning, and Stray Currents states that electrical resistances of higher than 10 in metal 531

circuits are indicative of a break in the continuity of the circuit, resulting in the undesirable 532

accumulation of static electricity.5 533

5.6 General Health Hazards and Precautions 534

5 Protection Against Ignitions Arising Out of Static, Lightning, and Stray Currents, Edition 7, American Petroleum Institute, Washington, DC, 2008.

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5.6.1 Petroleum vapor dilutes oxygen in the air and may also be toxic. Hydrogen sulfide 535

vapors are particularly hazardous. Harmful vapors or oxygen deficiency cannot always be 536

detected by smell, visual inspection, or judgment. The use of oxygen and toxic gas monitors, 537

PPE, and emergency rescue precautions should be considered for all sampling operations. Self-538

contained breathing apparatus (SCBA) may be necessary. Personnel should position themselves 539

upwind of the sample point to minimize exposure to any harmful vapor which may be released. 540

5.6.2 This discussion on safety and health is not exhaustive. The appropriate Material Safety 541

Data Sheet (MSDS), API, or ASTM International publication should be consulted, together with 542

applicable regulatory requirements, and the International Safety Guide for Oil Tankers and 543

Terminals (ISGOTT),6 Safety of Life at Sea (SOLAS),7 and Oil Companies International Marine 544

Forum (OCIMF), while always observing company and local health and safety requirements. 545

6. Apparatus 546

6.1 General Sample Container Design Considerations 547

6.1.1 Sample containers come in a variety of shapes, sizes, and materials. Select the proper 548

container based on the product to be sampled to ensure that there will be no interaction between 549

the product sampled and the container that would affect the integrity of either. The following are 550

general design considerations for sample containers: 551

No internal pockets or dead spots; 552

Internal surfaces designed to minimize corrosion, encrustation, and water/sediment 553

clingage; 554

6International Safety Guide for Oil Tankers and Terminals (ISGOTT), Hyperion Books, 2006. 7 International Convention for the Safety of Life at Sea (SOLAS), International Maritime Organization, London, UK, 1974.

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An inspection cover/closure of sufficient size to facilitate filling, inspection, and 555

cleaning; 556

Designed to allow the preparation, and transfer to the analytical apparatus, of a 557

homogeneous mixture of the sample while minimizing the loss of any constituents 558

that affect the representativeness of the sample and the accuracy of the analytical 559

tests. 560

6.1.2 Additional considerations in the selection of sample containers are the type of mixing 561

required before transferring from the primary container, and the analysis to be performed. To 562

facilitate the discussion on proper handling and mixing of samples, sample containers are 563

referred to as either primary or intermediate containers. Regardless of the type of sample 564

container used, the sample container should be large enough to contain the required sample 565

volume and sufficient ullage space for thermal expansion and mixing of the sample. 566

6.1.3 While this practice is meant to provide some guidance related to particular products and 567

tests, it remains the responsibility of the subcommittee for the relevant test method to provide 568

specific guidance regarding sample container selection, preparation, cleanliness, and sample size 569

requirements for testing and retention. Also refer to Practice D5854/API MPMS 8.3, Practice 570

D5842/API MPMS 8.4, and Practice D4306. 571

6.2 Glass Bottles (See Figure 3)Glass containers are suitable for many sample test and 572

storage requirements. Clear glass bottles can be easily examined visually for cleanliness, and 573

allow for visual inspection of the sample for haze (cloudiness), discoloration, free water, and 574

solid impurities. The brown glass bottle affords some protection to the samples when light may 575

affect the test results. Refer to Practice D5854/API MPMS 8.3. 576

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6.3 CansWhen using cans, any seams shall have been soldered on the exterior surfaces 577

with a flux of rosin in a suitable solvent. Such a flux is easily removed with gasoline, whereas 578

many others are very difficult to remove. Cans made of stainless steel with welded seams, and 579

aluminum bottles, are suitable for many sampling operations, but cleanliness is still required. 580

Minute traces of flux may contaminate the sample so that results obtained on tests such as 581

dielectric strength, oxidation resistance, and sludge formation may be erroneous. For aviation 582

fuel sampling, refer to Practice D4306. 583

6.4 Plastic BottlesIn general, plastic bottles made of suitable material may be used for the 584

handling and storage of diesel oil, fuel oil, and lubricating oil. Bottles of this type should not be 585

used for gasoline, aviation jet fuel, kerosene, crude oil, white spirit, medicinal white oil, or other 586

petroleum products unless testing indicates there is no problem with solubility, contamination, or 587

loss of light components. In no circumstances shall nonlinear (conventional) polyethylene 588

containers be used to store samples of liquid hydrocarbons. This is to avoid sample 589

contamination or sample bottle failure. Used engine oil samples that may have been subjected to 590

fuel dilution should not be stored in plastic containers. Plastic bottles do have an advantage in 591

that they will not shatter like glass or corrode like metal containers. 592

6.5 Container Closures 593

6.5.1 Screw caps made of a material that will not deteriorate or contaminate the sample are to 594

be used for glass bottles. Screw caps should provide a vapor-tight seal. Use care when using cork 595

stoppers. Situations in which corks should not be used include: liquids in which loss of light ends 596

may affect any test results; and liquids that are hygroscopic or have a low-water content 597

specification. Rubber stoppers are not to be used. 598

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6.5.2 Cans and plastic bottles should be closed with screw caps made of the same material as 599

the container. Protect can screw caps with a disk faced with a material that will not deteriorate or 600

contaminate the sample when used to store or transport samples. Consideration of closure type is 601

important for samples in which vapor loss will affect the test results. Screw caps of a quality that 602

provide a vapor-tight closure should be used for plastic bottles and cans. Use screw caps for 603

containers used to take samples that will be tested for density or API gravity. 604

6.6 Container CleanlinessSample containers shall be clean and free from all substances 605

that might contaminate the product being sampled (such as water, dirt, lint, washing compounds, 606

naphtha and other solvents, soldering fluxes, acids, rust, and oil). Reusable containers shall be 607

cleaned by a method that has been determined as acceptable for the intended use, for example by 608

rinsing with a suitable solvent. Dry the container, for example either by passing a current of 609

clean warm air through the container or placing it in a hot, dust-free cabinet at 40C or higher. 610

When dry, stopper or cap the container. Normally, it is not necessary to wash new containers. 611

6.7 Container Compatibility for Sample MixingThe sample container should be compatible 612

with the mixing system for remixing samples to ensure that a homogenous sample is transferred 613

to an intermediate container or the analytical apparatus. This is particularly critical with crude 614

oil, some black products, and condensates for sediment and water (S&W) analysis. Cylindrical 615

containers are generally better suited for samples that are to be tested for S&W. Refer to Practice 616

D5854/API MPMS 8.3 for sample mixing and handling requirements. 617

6.8 Low Pressure Variable Volume ContainersLow pressure variable volume sample 618

container designs include collapsible plastics containers, bladders, and vessels fitted with a 619

flexible internal diaphragm. Before use, variable volume sample containers are normally 620

collapsed, evacuated or reduced to the nominal zero volume. The sample container size is 621

D4057-XX


dependent on the quantity required for analysis (and/or retention). Prior to use, it may be 622

appropriate to rinse the sample containers with the product being sampled, in order to avoid 623

contamination from previous sample residue and/or solvents used to clean the low pressure 624

variable volume containers. The sample should be transported to the laboratory in the container 625

in which it was originally obtained (the primary sample container). Plastics containers are not 626

recommended for long-term sample storage, unless it has been demonstrated that the plastic is 627

suitable (i.e. compatible with the sample) so that the integrity of the sample is not compromised. 628

WARNING: The use of containers made of non-linear polyethylene may lead to sample 629

contamination and/or sample container failure. 630

6.9 High Pressure Spot Sampling Systems and Cylinders 631

6.9.1 Sample System Components-All equipment, such as transfer lines, valves and pressure 632

gages, associated with sampling shall be corrosion resistant and designed consistent with the 633

maximum anticipated pressure. Experience has shown that the transfer lines should have a 634

minimum internal diameter of 3 mm (18 in.) nominal and be as short as practical to minimize 635

line blockage or sample vaporization, or both. The use of filters, dryers, needle valves and 636

related equipment are not recommended, unless provisions are made to prevent excessive flow 637

restriction and pressure drop. It is recommended to use a T junction with a purge valve at the 638

sample connection point to allow purging of the dead volume at the sampler connection. Flexible 639

hose or tubing with adequate pressure rating may be used. 640

6.9.2 Sample Cylinders-Sample cylinders are used for the collection of light liquid 641

hydrocarbons and gas samples and subsequent transportation and storage. Typical light liquid 642

hydrocarbon sample containers are fixed volume sample cylinders or floating-piston variable 643

volume sample cylinders. Refer to Practice D6849. 644

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6.9.2.1 Fixed Volume Sample Cylinder-Fixed volume sample cylinders are also known as 645

single cavity sample cylinders or spun cylinders. Refer to Figures 16a and 16b. 646

6.9.2.1.1 Valves-Fixed volume sample cylinders are typically available with either one or two 647

valves serving as cylinder inlet and outlet valves. Recommend using two-valve fixed volume 648

sample cylinders due to their ease of cleaning and purging prior to sampling. For repeated use, it 649

is recommended that one-valve fixed volume sample cylinders be used for only one product, due 650

to difficulty in cleaning. 651

6.9.2.1.2 Internal Outage (Ullage) Tubes- Recommend fixed volume sample cylinders be 652

equipped with an internal outage (ullage) tube, designed to provide a vapor space of typically 653

20% of the cylinder capacity, allowing for liquid thermal expansion. The end of the cylinder 654

fitted with the outage (ullage) tube shall be clearly marked. If the cylinder does not have an 655

internal outage (ullage) tube, use alternative purging and venting procedures to obtain a 656

minimum 20 % ullage in the cylinder. An internal outage tube within a fixed volume sample 657

cylinder may also be known as an ullage tube or dip tube. Typical sample cylinders are shown in 658

Figures 16a and 16b. 659

6.9.2.2 Sample Cylinder Usage Considerations-The type of sample cylinder used and its 660

materials of construction as well as hoses and fittings can affect the validity of the sample, as 661

well as the accuracy of the analysis. 662

6.9.2.2.1 When the observed vapor pressure of the liquid being sampled is close to the line 663

pressure, the reduction in sample pressure associated with the creation of the ullage space may 664

result in phase separation that can make subsequent representative sub-sampling difficult. In 665

these circumstances, a floating-piston variable volume cylinder should be used to ensure that the 666

sample is maintained at sufficient pressure to prevent phase separation. 667

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6.9.2.2.2 Where small concentrations of contaminants must be quantified or where 668

concentrations of volatile compounds other than the predominant component must be quantified, 669

a floating-piston variable volume cylinder is recommended. NOTE 2: Practice D3700 describes 670

a recommended practice for obtaining a representative sample of a light hydrocarbon fluid and 671

the subsequent preparation of that sample for laboratory analysis when dissolved gases are 672

present. Use of Practice D1265, using a fixed volume cylinder, will result in a small but 673

predictable low bias for dissolved gases due to the liquid venting procedure to establish the 20 % 674

minimum ullage. 675

6.9.2.3 Sample Cylinder Construction-Sample cylinder construction is primarily dependent 676

on the pressure and temperature of the product to be sampled, and the pressure vessel approval 677

and certification requirements in the jurisdictions in which it is to be used and transported. All 678

sample cylinder material, and equipment used for obtaining the sample, shall meet appropriate 679

standards for construction, cleanliness and suitability for use, including product compatibility. 680

Use corrosion resistant metal sample cylinders certified by the authority having jurisdiction for 681

pressure vessels with adequate pressure rating for the product being sampled. Common materials 682

used are non-magnetic 300-series stainless steel, Monel, Viton elastomeric components, and 683

possibly other materials. The size of the cylinder depends upon the amount of sample required to 684

perform the anticipated laboratory tests, and retain. Blanking cover caps may be provided to seal 685

the valve connection points of high pressure sample cylinders prior to their transportation 686

between the sampling location and the laboratory. 687

6.9.2.4 Floating Piston Sample Cylinders-A floating piston sample cylinder, also known as 688

pressure-balanced piston cylinders, or constant pressure cylinders, can be used to sample pure 689

D4057-XX


and multi-component liquids and when properly operated, maintains the sample as a single-phase 690

liquid. This device uses one, or two pistons, inside of the sample cylinder to maintain separation 691

between the liquid sampled and the backpressure inert gas. The inert gas is vented slowly to 692

allow the sample to enter the cylinder while maintaining a constant pressure on the sample. 693

Floating piston sample cylinders are typically constructed from a honed metal tube equipped 694

with end caps, valves, piston, a relief device to protect against over-pressure, and a method of 695

displaying the piston position. See Figures 17a, 17b and 17c. 696

6.9.2.4.1 Refrigerated Products-The floating piston sample cylinder shall be safely cooled to 697

the temperature of the product being sampled when sampling refrigerated liquids that are near or 698

below atmospheric pressure. Low cargo temperature (more than approximately 15C below 699

ambient) and low cargo pressure (near atmospheric pressure) may affect the ability of the user to 700

successfully capture a representative liquid sample using a floating-piston variable volume 701

cylinder if additional care is not taken; and the use of a vacuum pump may be required. Refer to 702

Practice D3700 and GPA 2174. 703

6.9.2.4.2 Piston Position Indicator-The floating piston cylinder shall be equipped with a 704

piston position indicator such as a magnetic follower, piston rod, or equivalent that is used to 705

indicate the sample volume to comply with the maximum percent fill (maximum fill density) 706

allowed for storage and transportation. Do not use floating piston cylinders that are not equipped 707

with a piston position indicator without a procedure to allow the operator to verify fill density 708

immediately after sampling prior to transport. Consult the authority having jurisdiction for 709

acceptable procedures. See Figures 17a and 17b. 710

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6.9.2.4.3 Lubricants-Lubricants used to lubricate or seal the floating piston, O ring seals, and 711

other components shall be inert to the product being sampled. 712

6.9.2.5 Cylinder Coatings-Some cylinders may be internally coated or lined to reduce the 713

chances of bare metal surfaces reacting with trace reactive components, potentially altering the 714

quality and integrity of the sample. For example, H2S can be absorbed into the structure of 316 715

stainless steel, so that testing for H2S may require the cylinder to be coated. Protective internal 716

coatings or surface treatments are acceptable for floating piston sample cylinders provided that 717

they do not adversely affect the free movement of the piston, or effectiveness of the seals. 718

6.9.2.6 Cylinder Pressure Relief-Fit a ruptured disk or a self-resetting pressure relief valve to 719

the cylinder to prevent overpressure as the result of liquid thermal expansion. It is recommended 720

to use a spring relief valves if self-resetting is required. Typically, the maximum operating 721

system pressure should be limited to 80% of the nominal rating of the rupture disc for static 722

operating pressure and ambient temperature. The relief maximum burst pressure shall not exceed 723

the cylinder test pressure. Refer to applicable regulatory requirements for safe filling limits. 724

6.9.2.6.1 Cylinder Pressure Relief Inspection-The strength of rupture discs can deteriorate with 725

time due to temperature, corrosion, and fatigue. In addition, pulsating pressure, vacuum/pressure 726

cycling, heat, and corrosive fluids and atmospheres can reduce the discs burst pressure. Relief 727

valves and rupture discs should be inspected regularly. Do not alter valves or safety relief 728

devices that are part of a cylinder permit or exemption. NOTE 3: The USA has an exemption 729

system, and Canada has a permitting procedure for non-American Society of Mechanical 730

Engineers (ASME) or Department of Transportation (DOT) cylinders. 731

6.9.2.6.2 Cylinder Pressure Relief Release-The sudden release, typically accompanied by a 732

loud noise and product released at high velocity, might create a hazard. If the sample cylinder 733

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35 This document is not an API/ ASTM standard; it is under consideration within an API/ ASTM technical committee but has not received all approvals required to become an API/ASTM standard. You agree not to reproduce or circulate or quote, in whole or in part, this document outside of API/ASTM Committee/Society activities, or submit it to any other organization or standards bodies (whether national, international, or other) except with the approval of the Chairman of the Committee having jurisdiction and the written authorization of the President of the Society. If you do not agree with these conditions please immediately destroy all copies of the document. Copyri

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