ДСТУ EN ISO 10416:2019 Промисловість нафтова та газова. Промивальні рідини. Лабораторні випробування (EN ISO 10416:2009, IDT; ISO 10416:2008, IDT)

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EN ISO 10416:2009

Petroleum and natural gas industries —
Drilling fluids — Laboratory testing
(ISO 10416:2008)

прийнято як національний стандарт
методом «підтвердження» за позначенням
Відповідає офіційному тексту

ДСТУ EN ISO 10416:2019
(EN ISO 10416:2009, IDT;
ISO 10416:2008, IDT)

Промисловість нафтова та газова.
Промивальні рідини.
Лабораторні випробування

З наданням чинності від 2019–09–01

Contents

Introduction

1 Scope

2 Normative references

3 Terms and definitions

4 Symbols and abbreviations

5 Barite

5.1 Principle

5.2 Reagents and apparatus

5.3 Sampling

5.4 Calculation of moisture content

5.5 Sieve analysis

5.6 Sedimentation analysis

6 Barite performance

6.1 Principle

6.2 Reagents and apparatus

6.3 Base drilling fluid preparation

6.4 Rheology test

6.5 Calculation

7 Abrasiveness of weighting materials

7.1 Principle

7.2 Reagents and apparatus

7.3 Determination of abrasion

8 Mercury in drilling fluid barite

8.1 Principle

8.2 Reagents and apparatus

8.3 Preparation of standards

8.4 Sample digestion

8.5 Check for recovery of Hg during digestion

8.6 Analysis of standards and samples

8.7 Calculation

9 Cadmium and lead in drilling fluid barite

9.1 Principle

9.2 Reagents and apparatus

9.3 Preparation of combined cadmium and lead standards

9.4 Sample digestion

9.5 Analysis of standards and samples

9.6 Calculation

10 Arsenic in drilling fluid barite

10.1 Principle

10.2 Reagents and apparatus

10.3 Preparation of standards

10.4 Sample digestion

10.5 Analysis of standards and samples

10.6 Calculation

11 Bridging materials for regaining circulation

11.1 Principle

11.2 Apparatus

11.3 Preparation of test drilling fluid

11.4 Static slot test

11.5 Dynamic slot test

11.6 Static marble bed test

11.7 Dynamic marble bed test

11.8 Static ball bearings (BB shot) bed test

11.9 Dynamic ball bearings (BB shot) bed test

12 Filtration-control agents

12.1 Principle

12.2 Reagents and apparatus

12.3 General instructions for preparation of base drilling fluids

12.4 Salt-saturated drilling fluid

12.5 High-hardness, salt-saturated drilling fluid

12.6 10 % potassium chloride (KCl) drilling fluid

12.7 Pre-hydrated bentonite slurry

12.8 Modified seawater drilling fluid

12.9 Low-salinity drilling fluid

12.10 Lime-treated drilling fluid

12.11 Low solids, non-dispersed drilling fluid

12.12 Freshwater lignosulfonate drilling fluid

12.13 Initial performance test

12.14 Performance after heat ageing

13 Methylene blue test for drilled solids and commerical bentonite

13.1 Methylene blue capacity of drill solids

13.2 Methylene blue capacity of commercial bentonite

13.3 Solids content

14 Deflocculation test for thinner evaluation

14.1 Principle

14.2 Reagents and apparatus

14.3 Procedure for moisture content

14.4 Calculation of moisture content

14.5 Preparation of drilling fluid base

14.6 Calculation

14.7 Determination of rheological properties

14.8 Calculation of thinner efficiency

15 Testing base oils used in drilling fluids

15.1 General

15.2 Reagents and apparatus

15.3 Density, relative density (specific gravity), or API gravity-hydrometer method (see ISO 3675)

15.4 Density and relative density of liquids using a digital density meter (see ASTM D 4052)

15.5 Kinematic viscosity of transparent and opaque oils — Calibrated capillary tube method (see ISO 3104)

15.6 Distillation (see ISO 3405)

15.7 Aniline point and mixed aniline point (see ISO 2977:1997)

15.8 Pour point (see ISO 3016)

15.9 Flash point by Pensky-Martens closed tester (see ISO 2719)

15.10 Aromatics content (see IP 391 or ASTM D 5186)

16 Potassium ion content — Ion-selective electrode method

16.1 Principle

16.2 Reagents and apparatus

16.3 Preparation of electrodes

16.4 Operational check of electrode system

16.5 Measurements using a meter with direct concentration readout capability

16.6 Measurements with instruments that provide either a digital or an analogue readout in millivolts

17 Calcium ion content — Ion-selective electrode method

17.1 Principle

17.2 Reagents and apparatus

17.3 Preparation of electrodes

17.4 Operational check of electrode system

17.5 Measurements using a meter with direct concentration readout capability

17.6 Measurements with instruments that provide either a digital or an analogue readout in millivolts

18 Sodium ion content — Ion-selective electrode method

18.1 Principle

18.2 Reagents and apparatus

18.3 Preparation and operational check of the electrode system

18.4 Measurements using a meter with a direct concentration-readout capability

18.5 Measurements using a meter with readout in millivolts

19 Density of solids — Stereopycnometer method

19.1 Principle

19.2 Apparatus

19.3 Procedure — Stereopycnometer method

19.4 Calculation — Stereopycnometer method

20 Density of solids — Air comparison pycnometer method

20.1 Principle

20.2 Apparatus

20.3 Procedure — Air comparison pycnometer method

20.4 Calculation — Air comparison pycnometer method

21 Ageing of water-based drilling fluids

21.1 Principle

21.2 Practices common to preparation, handling and testing over all temperature ranges

21.3 Drilling fluid sample preparation and ageing at ambient temperature

21.4 Drilling fluid ageing at moderate temperatures (ambient to 65 °C (150 °F))

21.5 Drilling fluid ageing at substantially elevated temperatures (over 65 °C (150 °F))

21.6 Inertness and chemical compatibility in high-temperature ageing cells

21.7 Obtaining supplies and services for the ageing of drilling fluid samples

22 Ageing of oil-based drilling fluids

22.1 Principle

22.2 Apparatus

22.3 Practices common to preparation, handling and testing over all temperature ranges

22.4 Drilling fluid ageing at ambient temperatures

22.5 Drilling fluid ageing at moderate temperatures (ambient to 65 °C (150 °F))

22.6 Drilling fluid ageing at substantially elevated temperatures (over 65 °C (150 °F))

22.7 Inertness and chemical compatibility in high-temperature ageing cells

22.8 Obtaining supplies and services for the ageing of drilling fluid samples

23 Shale-particle disintegration test by hot rolling

23.1 Principle

23.2 Reagents and apparatus

23.3 Procedure

23.4 Calculation

24 Drilling fluid materials — High-viscosity polyanionic cellulose (PAC-HV) (regular)

24.1 Principle

24.2 Determination of moisture content

24.3 Procedures with test fluid containing PAC-HV

25 Drilling fluid materials — Low-viscosity polyanionic cellulose (PAC-LV)

25.1 Principle

25.2 Determination of moisture content

25.3 Procedures with test fluid containing PAC-LV

26 Preparation and evaluation of invert-emulsion drilling fluids

26.1 Principle

26.2 Reagents and apparatus

26.3 Mixing of the initial drilling fluid

26.4 Testing the properties of the initial drilling fluid

26.5 Preparation of the sample contaminated by seawater

26.6 Preparation of the sample contaminated by base evaluation clay

26.7 Preparation of the sample contaminated by mixed-salt brine

26.8 Procedure for hot-rolling

26.9 Procedure for static ageing

26.10 Procedure for testing after heat ageing

27 High-temperature/high-pressure filtration testing of drilling fluids using the permeability plugging apparatus and cells with set-screw-secured end caps

27.1 Principle

27.2 Safety considerations

27.3 Apparatus — Permeability-plugging apparatus (PPA) with set-screw-secured end caps

27.4 Procedure for high-temperature/high-pressure (HTHP) filtration

27.5 Test conclusion and disassembly

27.6 Data reporting

28 High-temperature/high-pressure filtration testing of drilling fluids using the permeability-plugging apparatus and cells with threaded end caps

28.1 Principle

28.2 Safety considerations

28.3 Apparatus — Permeability-plugging apparatus (PPA) with threaded end caps

28.4 Procedure for high-temperature/high-pressure (HTHP) filtration

28.5 Test conclusion and disassembly

28.6 Data reporting

Bibliography