ISO 10414-2:2002

Petroleum and natural gas industries — Field testing of drilling fluids — Part 2: Oil-based fluids

ISO 10414-2:2002 provides standard procedures for determining the following characteristics of oil-based drilling fluids: drilling fluid density (mud weight); viscosity and gel strength; filtration; oil, water and solids contents; alkalinity, chloride content and calcium content; electrical stability; lime and calcium contents, calcium chloride and sodium chloride contents; low-gravity solids and weighting material contents. Additional test methods are given that may optionally be used for the determination of shear strength, oil and water contents from cuttings, drilling fluid activity, aniline point, cuttings activity, active sulfides. Procedures are also provided that may optionally be used for sampling, inspection and rejection, rig-site sampling, calibration and verification of glassware, thermometers, viscometers, retort kit cups and drilling fluid balances. Examples of calculations are given for lime, salinity and solids content.

Industries du pétrole et du gaz naturel — Essais in situ des fluides de forage — Partie 2: Fluides à base d'huiles

General Information

• Status: Withdrawn
• Publication Date: 24-Jul-2002
• Withdrawal Date: 24-Jul-2002
• ICS: 75.180.10 - Exploratory, drilling and extraction equipment
• Technical Committee: ISO/TC 67/SC 3 - Drilling and completion fluids, well cements and treatment fluids
• Drafting Committee: ISO/TC 67/SC 3/WG 1 - Drilling, completion and workover fluids
• Current Stage: 9599 - Withdrawal of International Standard
• Completion Date: 08-Jun-2011

Relations

• Revised: ISO 10414-2:2011 - Petroleum and natural gas industries — Field testing of drilling fluids — Part 2: Oil-based fluids
• Effective Date: 15-Apr-2008

Standards Content (Sample)

INTERNATIONAL ISO
STANDARD 10414-2
First edition
2002-07-15


Petroleum and natural gas industries —
Field testing of drilling fluids —
Part 2:
Oil-based fluids
Industries du pétrole et du gaz naturel — Essais in situ des fluides de
forage —
Partie 2: Fluides à base d'huiles




Reference number
ISO 10414-2:2002(E)
©
 ISO 2002

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ISO 10414-2:2002(E)
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ISO 10414-2:2002(E)
Contents Page
Foreword.v
Introduction.vi
1 Scope .1
2 Term and definition .2
3 Abbreviated terms .2
4 Determination of drilling fluid density (mud weight) .2
4.1 Principle.2
4.2 Apparatus .2
4.3 Procedure .3
4.4 Calculation .3
5 Alternative method for determination of drilling fluid density.4
5.1 Principle.4
5.2 Apparatus .5
5.3 Procedure .5
5.4 Calculation .5
6 Viscosity and gel strength.6
6.1 Principle.6
6.2 Determination of viscosity using the Marsh funnel .6
6.3 Determination of viscosity and/or gel strength using a direct-indicating viscometer.6
7 Filtration.9
7.1 Principle.9
7.2 High temperature/high pressure test up to 175 °C (350 °F) .9
7.3 High temperature/high pressure test 175 °C (350 °F) up to and including 230 °C (450 °F).11
8 Retort test for oil, water and solids contents .13
8.1 Principle.13
8.2 Apparatus .14
8.3 Procedure .14
8.4 Calculation .15
9 Chemical analysis of oil-based drilling fluids .16
9.1 Principle.16
9.2 Reagents and apparatus.17
9.3 Whole-drilling-fluid alkalinity .17
9.4 Whole-drilling-fluid chloride content.18
9.5 Whole-drilling-fluid calcium content .19
10 Electrical stability test.20
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ISO 10414-2:2002(E)
10.1 Principle.20
10.2 Apparatus .20
10.3 Equipment calibration/performance test.21
10.4 Electrical stability measurements.21
11 Lime, salinity and solids calculations .22
11.1 Principle.22
11.2 Apparatus .22
11.3 Whole-drilling-fluid calculations .23
11.4 Aqueous phase calculations .24
11.5 Solids calculations .27
Annex A (informative) Measurement of shear strength using shearometer tube .32
Annex B (informative) Determination of oil and water content of cuttings.34
Annex C (informative) Determination of aqueous-phase activity of emulsified water using an
electrohygrometer.37
Annex D (informative) Determination of aniline point .41
Annex E (informative) Lime, salinity and solids calculations.44
Annex F (informative) Sampling, inspection and rejection of drilling materials .56
Annex G (informative) Rig-site sampling.58
Annex H (informative) Determination of cutting activity by the Chenevert method .60
Annex I (informative) Chemical analysis of active sulfides by the Garrett gas train method .63
Annex J (informative) Calibration and verification of glassware, thermometers, viscometers, retort kit
cup and drilling fluid balances .67
Bibliography .72


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ISO 10414-2:2002(E)
Foreword
ISO (the International Organization for Standardization) is a worldwide federation of national standards bodies (ISO
member bodies). The work of preparing International Standards is normally carried out through ISO technical
committees. Each member body interested in a subject for which a technical committee has been established has
the right to be represented on that committee. International organizations, governmental and non-governmental, in
liaison with ISO, also take part in the work. ISO collaborates closely with the International Electrotechnical
Commission (IEC) on all matters of electrotechnical standardization.
International Standards are drafted in accordance with the rules given in the ISO/IEC Directives, Part 3.
The main task of technical committees is to prepare International Standards. Draft International Standards adopted
by the technical committees are circulated to the member bodies for voting. Publication as an International
Standard requires approval by at least 75 % of the member bodies casting a vote.
Attention is drawn to the possibility that some of the elements of this part of ISO 10414 may be the subject of
patent rights. ISO shall not be held responsible for identifying any or all such patent rights.
ISO 10414-2 was prepared by Technical Committee ISO/TC 67, Materials, equipment and offshore structures for
petroleum and natural gas industries, Subcommittee SC 3, Drilling and completion fluids and well cements.
ISO 10414 consists of the following parts, under the general title Petroleum and natural gas industries — Field
testing of drilling fluids:
 Part 1: Water-based fluids
 Part 2: Oil-based fluids.
Annexes A to J of this part of ISO 10414 are for information only.
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ISO 10414-2:2002(E)
Introduction
This part of ISO 10414 is based on API RP 13B-2, third edition, February 1998.
As with any laboratory procedure requiring the use of potentially hazardous chemicals, the user is expected to have
received proper knowledge and training in the use and disposal of these chemicals. The user is responsible for
compliance with all applicable local, regional, and national requirements for worker and local health, safety and
environmental liability.
In this part of ISO 10414, where practical, US customary units are included in brackets for information.
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INTERNATIONAL STANDARD ISO 10414-2:2002(E)

Petroleum and natural gas industries — Field testing of drilling
fluids —
Part 2:
Oil-based fluids
1 Scope
This part of ISO 10414 provides standard procedures for determining the following characteristics of oil-based
drilling fluids:
a) drilling fluid density (mud weight);
b) viscosity and gel strength;
c) filtration;
d) oil, water and solids contents;
e) alkalinity, chloride content and calcium content;
f) electrical stability;
g) lime and calcium contents, calcium chloride and sodium chloride contents;
h) low-gravity solids and weighting material contents.
Annexes A, B, C, D, H and I provide additional test methods that may optionally be used for the determination of
i) shear strength,
j) oil and water contents from cuttings,
k) drilling fluid activity,
l) aniline point,
m) cuttings activity,
n) active sulfides.
Annexes F, G and J provide procedures that may optionally be used for
o) sampling, inspection and rejection,
p) rig-site sampling,
q) calibration and verification of glassware, thermometers, viscometers, retort kit cups and drilling fluid balances.
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ISO 10414-2:2002(E)
Annex E provides examples of calculations for
r) lime, salinity and solids content.
2 Term and definition
For the purposes of this part of ISO 10414, the following term and definition applies:
2.1
ACS reagent grade
grade of chemical meeting the purity standards specified by the American Chemical Society (ACS)
3 Abbreviated terms
ACS American Chemical Society
CAS Chemical Abstracts Service
EDTA ethylenediaminetetraacetic acid
ES electrical stability
HT/HP high temperature, high pressure
OCMA Oilfield Chemical Manufacturer’s Association
PNP propylene glycol normal-propyl ether
PTFE polytetrafluoroethylene
TC to contain
TD to deliver
USC United States Customary (units)
4 Determination of drilling fluid density (mud weight)
4.1 Principle
A procedure is given for determining the mass of a given volume of liquid (= density). The density of drilling fluid is
expressed as grams per cubic centimetre, or kilograms per cubic metre.
4.2 Apparatus
3 3
4.2.1 Any density-measuring instrument having an accuracy of ± 0,01 g/cm or 10 kg/m .
The mud balance is the instrument generally used for drilling fluid density determinations. The mud balance is
designed such that the drilling fluid holding cup, at one end of the beam, is balanced by a fixed counterweight at
the other end, with a sliding-weight rider free to move along a graduated scale. A level-bubble is mounted on the
beam to allow for accurate balancing. Attachments for extending the range of the balance may be used when
necessary.
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ISO 10414-2:2002(E)
3
The instrument should be calibrated frequently with fresh water. Fresh water should give a reading of 1,00 g/cm or
3
1 000 kg/m at 21 °C (70 °F). If it does not, adjust the balancing screw or the amount of lead shot in the well at the
end of the graduated arm as required.
4.2.2 Thermometer, with a range of 0 °C to 105 °C (32 °F to 220 °F).
4.3 Procedure
4.3.1 The instrument base should be set on a flat, level surface.
4.3.2 Measure the temperature of the drilling fluid and record.
4.3.3 Fill the clean, dry cup with drilling fluid to be tested; put the cap on the filled drilling-fluid holding cup and
rotate the cap until it is firmly seated. Ensure that some of the drilling fluid is expelled through the hole in the cap, in
order to free any trapped air or gas.
4.3.4 Holding the cap firmly on the drilling-fluid holding cup (with cap hole covered), wash or wipe the outside of
the cup clean and dry.
4.3.5 Place the beam on the base support and balance it by moving the rider along the graduated scale. Balance
is achieved when the bubble is under the centreline.
4.3.6 Read the drilling fluid density at the edge of the rider toward the drilling-fluid cup. Make appropriate
corrections when a range extender is used.
4.4 Calculation
3 3
4.4.1 Report the drilling fluid density, ρ , to the nearest 0,01 g/cm or 10 kg/m .
s
4.4.2 To convert the reading to other units, use the following:
3
ρ=×1 000 g/cm (1)
s
3
ρ =×16 lb/ft (2)
s
ρ=×119,8 lb/US gal (3)
s
where ρ is the density, expressed in kilograms per cubic metre.
s
3
∇ρ = 9,81 × g/cm (4)
s
∇ρ = 0,0226 × psi/1 000 ft (5)
s
where ∇ρ is the drilling fluid density gradient, expressed in kilopascals per metre.
s
A list of density conversions from SI to USC units is given in Table 1.
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ISO 10414-2:2002(E)
Table 1 — Density conversions between SI and USC units
Grams per Kilograms Pounds Pounds per
cubic per cubic per US cubic foot
a
centimetre metre gallon
3 3 3
(lb/US gal)
g/cm kg/m (lb/ft )
0,70 700 5,8 43,6
0,80 800 6,7 49,8
0,90 900 7,5 56,1
b
1,00 1 000 62,3
8,345
1,10 1 100 9,2 68,5
1,20 1 200 10,0 74,8
1,30 1 300 10,9 81,0
1,40 1 400 11,7 87,2
1,50 1 500 12,5 93,5
1,60 1 600 13,4 99,7
1,70 1 700 14,2 105,9
1,80 1 800 15,0 112,1
1,90 1 900 15,9 118,4
2,00 2 000 16,7 124,6
2,10 2 100 17,5 130,8
2,20 2 200 18,4 137,1
2,30 2 300 19,2 143,3
2,40 2 400 20,0 149,5
2,50 2 500 20,9 155,8
2,60 2 600 21,7 162,0
2,70 2 700 22,5 168,2
2,80 2 800 23,4 174,4
2,90 2 900 24,2 180,7
a
Same value as relative density.
b
Accurate conversion factor.

5 Alternative method for determination of drilling fluid density
5.1 Principle
The pressurized mud balance provides a more accurate method for determining the density of a drilling fluid
containing entrained air or gas than does the conventional mud balance. The pressurized mud balance is similar in
operation to the conventional mud balance, the difference being that the slurry sample is placed in a fixed-volume
sample cup under pressure.
The purpose of placing the sample under pressure is to minimize the effect of entrained air or gas upon slurry
density measurements. By pressurizing the sample cup, any entrained air or gas is decreased to a negligible
volume, thus providing a slurry density measurement more closely in agreement with that obtained under downhole
conditions.
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ISO 10414-2:2002(E)
5.2 Apparatus
3 3
5.2.1 Any density-measuring instrument having an accuracy of ± 0,01 g/cm or 10 kg/m .
The pressurized mud balance is the instrument generally used for density determinations of pressurized drilling
fluids. The pressurized mud balance is designed such that the drilling-fluid holding cup and screw-on lid, at one end
of the beam, is balanced by a fixed counterweight at the other end, with a sliding-weight rider free to move along a
graduated scale. A level-bubble is mounted on the beam to allow for accurate balancing.
3 3
Calibrate the instrument frequently with fresh water. Fresh water should give a reading of 1,0 g/cm or 1 000 kg/m
at 21 °C (69,8 °F). If it does not, adjust the balancing screw or the amount of lead shot in the well at the end of the
graduated arm as required.
5.2.2 Thermometer, with a range of 0 °C to 105 °C (32 °F to 220 °F).
5.3 Procedure
5.3.1 Measure the temperature of the drilling fluid and record.
5.3.2 Fill the sample cup to a level slightly (approximately 6 mm) below the upper edge of the cup.
5.3.3 Place the lid on the cup with the attached check-valve in the down (open) position. Push the lid downward
into the mouth of the cup until surface contact is made between the outer skirt of the lid and the upper edge of the
cup. Any excess slurry will be expelled through the check-valve. When the lid has been placed on the cup, pull the
check-valve up into the closed position, rinse off the cup and threads with water, and screw the threaded cap on
the cup.
5.3.4 The pressurizing plunger is similar in operation to a syringe. Fill the plunger by submersing its end in the
slurry with the piston rod completely inside. Then draw the piston rod upward, thereby filling the cylinder with slurry.
This volume should be expelled with the plunger action and refilled with fresh slurry sample to ensure that this
plunger volume is not diluted with liquid remaining from the last clean-up of the plunger mechanism.
5.3.5 Push the nose of the plunger onto the mating O-ring surface of the cap valve. Pressurize the sample cup
by maintaining a downward force on the cylinder housing in order to hold the check-valve down (open) and at the
same time to force the piston rod inside. A force of approximately 225 N (50 lbf) or greater should be maintained on
the piston rod.
5.3.6 The check-valve in the lid is pressure-actuated; when the inside of the cup is pressurized, the check-valve
is pushed upward into the closed position. To close the valve gradually ease up on the cylinder housing while
maintaining pressure on the piston rod. When the check-valve closes, release pressure on the piston rod before
disconnecting the plunger.
5.3.7 The pressurized slurry sample is now ready for weighing. Rinse the exterior of the cup and wipe dry. Place
instrument on the knife edge. Move the sliding weight right or left until the beam is balanced. The beam is balanced
when the attached bubble is centred between the two black marks. Read the density from one of the four calibrated
scales on the arrow side of the sliding weight. The density can be read directly in units of grams per cubic
centimetre, pounds per gallon, and pounds per cubic foot, or as a drilling fluid gradient in pounds per square inch
per 1 000 feet.
5.3.8 To release the pressure inside the cup, reconnect the empty plunger assembly and push downward on the
cylinder housing.
5.3.9 Clean the cup and rinse thoroughly with base oil.
5.4 Calculation
3 3
Report the drilling fluid density to the nearest 0,01 g/cm or 10 kg/m .
For conversions, use the formulas given in 4.4.2.
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ISO 10414-2:2002(E)
6 Viscosity and gel strength
6.1 Principle
Viscosity and gel strength are measurements that relate to the flow properties (rheology) of drilling fluids. The
following instruments are used to measure viscosity and/or gel strength of drilling fluids:
a) Marsh funnel — a simple device for indicating viscosity on a routine basis;
b) direct-indicating viscometer — a mechanical device for measurement of viscosity at varying shear rates.
NOTE Information on the rheology of drilling fluids can be found in API RP 13D.
6.2 Determination of viscosity using the Marsh funnel
6.2.1 Apparatus
6.2.1.1 Marsh funnel, calibrated to deliver 946 ml (1 quart) of fresh water at a temperature of (21 ± 3) °C
[(70 ± 5) °F] in (26 ± 0,5) s, with a graduated cup as a receiver.
The Marsh funnel shall have the following characteristics:
a) funnel cone, length 305 mm (12,0 in), diameter 152 mm (6,0 in) and a capacity to bottom of screen of
1 500 ml (1,6 quarts);
b) orifice, length 50,8 mm (2,0 in) and inside diameter 4,7 mm (0,185 in);
c) screen, with 1,6 mm (0,063 in) openings (12 mesh); fixed at 19,0 mm (0,748 in) below top of funnel.
6.2.1.2 Graduated cup, with capacity at least 946 ml (1 quart).
6.2.1.3 Stopwatch.
6.2.1.4 Thermometer, with a range of 0 °C to 105 °C (32 °F to 220 °F).
6.2.2 Procedure
6.2.2.1 Cover the funnel orifice with a finger and pour freshly sampled drilling fluid through the screen into the
clean, upright funnel. Fill until fluid reaches the bottom of the screen.
6.2.2.2 Remove finger and start the stopwatch. Measure the time for drilling fluid to fill to the 946 ml (1 quart)
mark of the cup.
6.2.2.3 Measure the temperature of the fluid, in degrees Celsius (degrees Fahrenheit).
6.2.2.4 Report the time (6.2.2.2), to the nearest second, with the volume, as the Marsh funnel viscosity. Report
the temperature (6.2.2.3) of the fluid to the nearest degree Celsius (degree Fahrenheit).
6.3 Determination of viscosity and/or gel strength using a direct-indicating viscometer
6.3.1 Apparatus
6.3.1.1 Direct-indicating viscometer, powered by an electric motor or a hand crank.
Drilling fluid is placed in the annular space between two concentric cylinders. The outer cylinder or rotor sleeve is
driven at a constant rotational velocity. The rotation of the rotor sleeve in the fluid produces a torque on the inner
cylinder or bob. A torsion spring restrains the movement of the bob, and a dial attached to the bob indicates
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ISO 10414-2:2002(E)
displacement of the bob. Instrument constants should be adjusted so that plastic viscosity and yield point are
obtained by using readings from rotor sleeve speeds of 300 r/min and 600 r/min.
The components shall meet the following specifications.
a) Rotor sleeve
Inside diameter 36,83 mm (1,450 in)
Total length: 87,0 mm (3,425 in)
Scribed line: 58,4 mm (2,30 in) above the bottom of sleeve, with two rows of 3,18 mm (0,125 in)
holes spaced 120° (2,09 rad) apart, around rotor sleeve just below scribed line.
b) Bob, closed, with flat base and tapered top
Diameter: 34,49 mm (1,358 in)
Cylinder length: 38,0 mm (1,496 in)
c) Torsion spring constant:
386 dyne-cm/degree deflection
d) Rotor sleeve speeds
High speed: 600 r/min
Low speed: 300 r/min
NOTE Other rotor speeds are available in viscometers from various manufacturers.
6.3.1.2 Stopwatch.
6.3.1.3 Thermostatically controlled viscometer cup.
6.3.1.4 Thermometer, with a range of 0 °C to 105 °C (32 °F to 220 °F).
6.3.2 Procedure
6.3.2.1 Place a sample of the drilling fluid in a thermostatically controlled viscometer cup. Leave enough empty
volume (approximately 100 ml) in the cup for displacement of fluid due to the viscometer bob and sleeve. Immerse
the rotor sleeve exactly to the scribed line. Measurements in the field should be made with minimum delay from the
time of drilling fluid sampling. Testing should be carried out at either (50 ± 1) °C [(120 ± 2) °F] or
(65 ± 1) °C [(150 ± 2) °F]. The place of sampling should be stated on the report.
The maximum recommended operating temperature is 90 °C (200 °F). If fluids have to be tested above this
temperature, either a solid metal bob, or a hollow metal bob with a completely dry interior should be used.
WARNING — Liquid trapped inside a hollow bob may vaporize when immersed in high-temperature fluid
and cause the bob to explode.
6.3.2.2 Heat (or cool) the sample to the selected temperature. Use intermittent or constant shear at 600 r/min
to stir the sample while heating (or cooling) to obtain a uniform sample temperature. After the cup temperature
reaches the selected temperature, immerse the thermometer into the sample and continue stirring until the sample
reaches the selected temperature. Record the temperature of the sample.
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ISO 10414-2:2002(E)
6.3.2.3 With the sleeve rotating at 600 r/min, wait for the viscometer dial reading to reach a steady value (the
time required is dependent on the drilling fluid characteristics). Record the dial reading R in pascals for
600
600 r/min.
6.3.2.4 Reduce the rotor speed to 300 r/min and wait for the dial reading to reach steady value. Record the
dial reading R in pascals for 300 r/min.
300
6.3.2.5 Stir the drilling fluid sample for 10 s at 600 r/min.
6.3.2.6 Allow drilling fluid sample to stand undisturbed for 10 s. Slowly and steadily turn the hand-wheel in the
appropriate direction to produce a positive dial reading. Record the maximum reading as the initial gel strength. For
instruments having a 3 r/min speed, the maximum reading attained after starting rotation at 3 r/min is the initial gel
strength. Record the initial gel strength (10-second gel) in pascals (pounds per 100 square feet).
2
NOTE To convert the dial reading to pounds per 100 square feet: 1 Pa = 0,48 lb/100 ft .
6.3.2.7 Restir the drilling fluid sample at 600 r/min for 10 s and then allow the drilling fluid to stand undisturbed
for 10 min. Repeat the measu
...