ISO 16110-2:2010

INTERNATIONAL ISO
STANDARD 16110-2
First edition
2010-02-15
Hydrogen generators using fuel
processing technologies —
Part 2:
Test methods for performance
Générateurs d'hydrogène faisant appel aux technologies du traitement
du carburant —
Partie 2: Méthodes d'essai de rendement

Reference number
©
ISO 2010
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©  ISO 2010
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ii © ISO 2010 – All rights reserved

Contents Page
Foreword .iv
Introduction.v
1 Scope.1
2 Normative references.1
3 Terms, definitions and symbols .2
3.1 Terms and definitions .2
3.2 Symbols.3
4 Test conditions .3
4.1 Test boundary.3
5 Measurement technique .5
5.1 General .5
5.2 Operational parameters .5
5.3 Environmental aspects .6
5.4 Ambient conditions .8
6 Test plan.8
6.1 General .8
6.2 Test operating modes .8
6.3 Measurement, test frequency and duration.10
6.4 Uncertainty analysis.11
7 Test procedure.11
7.1 Safe operation of the hydrogen generator and test equipment .11
7.2 Execution of the test plan.11
8 Calculations .12
8.1 Electrical power input .12
8.2 Calculation of flow rates.13
8.3 Calculation of fuel, steam and hydrogen energy .15
8.4 Calculation of efficiency .20
9 Test reports.21
9.1 General .21
9.2 Summary report.21
9.3 Detailed report .22
9.4 Full report.22
Annex A (normative) Symbols and abbreviated terms .23
Annex B (informative) Guidance for uncertainty analysis.26
Annex C (normative) Calculation of fuel heating value .29
Annex D (informative) Definition of hydrogen generator efficiency.33
Annex E (informative) Reference gas .35
Bibliography.38

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 2.
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 document may be the subject of patent
rights. ISO shall not be held responsible for identifying any or all such patent rights.
ISO 16110-2 was prepared by Technical Committee ISO/TC 197, Hydrogen technologies.
ISO 16110 consists of the following parts, under the general title Hydrogen generators using fuel processing
technologies:
⎯ Part 1: Safety
⎯ Part 2: Test methods for performance

iv © ISO 2010 – All rights reserved

Introduction
This part of ISO 16110 describes how to measure and document the performance of stationary hydrogen
generators for residential, commercial and industrial applications.
The following hydrogen generation types have been considered:
⎯ hydrogen generators using fuel processing technologies.

INTERNATIONAL STANDARD ISO 16110-2:2010(E)

Hydrogen generators using fuel processing technologies —
Part 2:
Test methods for performance
1 Scope
This part of ISO 16110 provides test procedures for determining the performance of packaged, self-contained
or factory matched hydrogen generation systems with a capacity less than 400 m /h at 0 °C and 101,325 kPa,
herein referred to as hydrogen generators, that convert a fuel to a hydrogen-rich stream of composition and
conditions suitable for the type of device using the hydrogen (e.g. a fuel cell power system, or a hydrogen
compression, storage and delivery system).
2 Normative references
The following referenced documents are indispensable for the application of this document. For dated
references, only the edition cited applies. For undated references, the latest edition of the referenced
document (including any amendments) applies.
ISO 3744, Acoustics — Determination of sound power levels of noise sources using sound pressure —
Engineering method in an essentially free field over a reflecting plane
ISO 4677 (all parts), Atmospheres for conditioning and testing — Determination of relative humidity
ISO 5167 (all parts), Measurement of fluid flow by means of pressure differential devices inserted in circular
cross-section conduits running full
ISO 6060, Water quality — Determination of the chemical oxygen demand
ISO 6326 (all parts), Natural gas — Determination of sulfur compounds
ISO 6974 (all parts), Natural gas — Determination of composition with defined uncertainty by gas
chromatography
ISO 6975, Natural gas — Extended analysis — Gas-chromatographic method
ISO 7934, Stationary source emissions — Determination of the mass concentration of sulfur dioxide —
Hydrogen peroxide/barium perchlorate/Thorin method
ISO 9096, Stationary source emissions — Manual determination of mass concentration of particulate matter
ISO 10101 (all parts), Natural gas — Determination of water by the Karl Fischer method
ISO 10523, Water quality — Determination of pH
ISO 10707, Water quality — Evaluation in an aqueous medium of the “ultimate” aerobic biodegradability of
organic compounds — Method by analysis of biochemical oxygen demand (closed bottle test)
ISO 11042 (all parts), Gas turbines — Exhaust gas emission
ISO 11541, Natural gas — Determination of water content at high pressure
ISO 11564, Stationary source emissions — Determination of the mass concentration of nitrogen oxides —
Naphthylethylenediamine photometric method
ISO 14687-1, Hydrogen fuel — Product specification — Part 1: All applications except proton exchange
membrane (PEM) fuel cell for road vehicles
ISO 14687-2, Hydrogen fuel — Product specification — Part 2: Proton exchange membrane (PEM) fuel cell
applications for road vehicles
ISO 16622, Meteorology — Sonic anemometers/thermometers — Acceptance test methods for mean wind
measurements
IEC 61010-1, Safety requirements for electrical equipment for measurement, control, and laboratory use —
Part 1: General requirements
IEC 61672-1, Electroacoustics — Sound level meters — Part 1: Specifications
3 Terms, definitions and symbols
3.1 Terms and definitions
For the purposes of this document, the following terms and definitions apply.
3.1.1
audible noise level
sound pressure level produced by the hydrogen generator measured at a specified distance
NOTE Audible noise level is expressed as decibels (dBA) and measured as described in this part of ISO 16110.
3.1.2
background noise level
sound pressure level of ambient noise at the measurement point
3.1.3
cold state
condition of a hydrogen generator at ambient temperature with no substantial fuel or power input
3.1.4
discharge water
water that is released by the hydrogen generator
NOTE Discharge water does not constitute part of a thermal recovery system. It is comprised of the water treatment
waste and the process condensate shown in Figure 1.
3.1.5
hydrogen generator
system that converts a fuel to a hydrogen-rich stream
NOTE The hydrogen generator is composed of all or some of the following subsystems: a fuel processing system, a
fluid management system, a thermal management system, and other subsystems as described in more detail in
ISO 16110-1.
3.1.6
interface point
measurement point of a hydrogen generator at which material and/or energy either enters or leaves
2 © ISO 2010 – All rights reserved

3.1.7
return gas
tail gas
unused reformed hydrogen-rich gas, which returns to the hydrogen generator and is used as a fuel
NOTE Return gas generally includes hydrogen, carbon dioxide, water vapour and slipped hydrocarbon.
3.1.8
standby state
state in which the hydrogen generator is at operating temperature and is in an operational mode from which it
can be promptly switched to an operational mode with net hydrogen output
See Figure 2, item 2.
3.1.9
start-up time
time from cold start to supply of hydrogen gas at the rated hydrogen pressure
See Figure 2, item 1-3.
3.1.10
waste heat
thermal energy released and not recovered
3.2 Symbols
The symbols and their meanings are described in Annex A.
4 Test conditions/Test boundary
Hydrogen generators may have different subsystems depending on types of primary conversion processes
and applications, and they have different streams of material and energy in and out of them. However, a
common system diagram and boundary has been defined for evaluation of the hydrogen generator (see
Figure 1).
The following conditions shall be considered in order to determine the test boundary of the hydrogen
generator:
⎯ All energy recovery systems shall be included within the system boundary.
⎯ Calculation of the heating value of the input fuel (such as natural gas, propane gas, etc.) shall be based
on the conditions of the input fuel at the boundary of the hydrogen generator.
⎯ Calculation of the heating value of the output hydrogen containing gas stream shall be based on the
conditions of the gas stream at the boundary of the hydrogen generator.
⎯ Mechanical systems required for hydrogen generator operation (i.e. ventilation or micro-turbines,
expanders or compressors) shall be included inside the test boundary. The direct measurement of these
mechanical systems inside the test boundary is not required; however, their effects shall be included in
the hydrogen generator operation. If mechanical (shaft) power and energy cross the test boundary,
additional measurements and calculations may be necessary.
NOTE This part of ISO 16110 does not take into account mechanical (shaft) power or mechanical energy inputs or
outputs.
1 system boundary of the hydrogen generator including subsystems and the interface is defined as a conceptual
or functional one
2 inputs 3 outputs
2.1 steam (if imported) 3.1 water treatment waste
2.2 water 3.2 exhaust gas
2.3 treatment chemicals 3.3 process vents
2.4 air/oxidant 3.4 recovered heat
2.5 fuel 3.5 process condensate
2.6 purge gas 3.6 solid waste
2.7 cooling fluid 3.7 hydrogen
2.8 instrument gas 3.8 cooling fluid
2.9 electrical power input 3.9 ventilation exhaust
2.10 atmospheric air 3.10 noise
3.11 waste heat
4 subsystems (the configurations depend on the kind of fuel, type of fuel cell or system)
4.1 water treatment and steam generation
4.2 air/oxidant processing system
4.3 feedstock compression and processing
4.4 fuel processing system
4.5 hydrogen purification (optional)
4.6 hydrogen metering and analysis
4.7 process utilities (cooling fluid, purge gas, instrument gas, electrical, etc.)
4.8 ventilation system
：The interface points in the boundary to be measured for calculation data.
NOTE The fuel input can also consist of return gas.
Figure 1 — Typical hydrogen generator diagram
4 © ISO 2010 – All rights reserved

5 Measurement technique
5.1 General
The types of measuring instruments and measurement methods shall conform to the relevant International
Standards and shall be selected to meet the measurement uncertainty targets in line with the uncertainty
analysis of 6.4. If necessary, external equipment with required specification shall be added.
5.2 Operational parameters
5.2.1 Electrical power input
The electrical power input to the hydrogen generator, the voltage, the current and the power factor shall be
determined and measured in accordance with IEC 61010-1.
5.2.2 Input and output fluid characteristics
5.2.2.1 General
The composition, the heating value (only for fuels), the temperature, the pressure and the flow rate of the input
and output fluids shall be determined as per 5.2.2.2 to 5.2.2.6.
If there is fluctuation greater than ± 2 % in any measured value, the amplitude and the frequency of the
fluctuation shall be measured and reported as part of the test results.
5.2.2.2 Composition of fluids
The composition of each input and output fluid shall be measured. The measurement technique shall be
appropriate to the chemical composition of the fluid in question. If the fluid is not critical to operability or utility
consumption, direct measurement of the fluid composition shall not be required for conformance with this part
of ISO 16110.
If the only chemical oxidant employed is atmospheric air, only the moisture content shall be measured. The
moisture content value may be calculated from other direct measurements (e.g. wet bulb and dry bulb
temperatures) and reported as relative humidity.
The composition of natural gas shall be measured in accordance with methods detailed in ISO 6974 and
ISO 6975.
The sulfur compounds (including odorant) of natural gas shall be measured according to methods detailed in
ISO 6326.
The water vapour content of natural gas shall be measured according to methods detailed in ISO 10101 and
ISO 11541.
The hydrogen composition shall be determined using the test methods specified in ISO 14687-1 or
ISO 14687-2, as applicable.
The composition of other fluids shall be measured in accordance with the standard(s) appropriate to the fluids.
5.2.2.3 Heating value
The heating value of the input and output fluids shall only be measured for combustible fluids. The heating
value shall be determined through either calorimetric methods, or via calculation based on the fluid
composition as specified in Clause 8. The accuracy and detection limits of the composition measurement
technique shall be determined, and its effect on the uncertainty analysis of 6.4 shall be explicitly considered.
Pre-analysed bottled fuel gas may be substituted for gas sampling, provided that the uncertainty of the
analysed gas is consistent with the uncertainty required by the uncertainty analysis of 6.4.
In principle, the lower heating value (LHV) shall be used for all the calculations defined in this part of
ISO 16110. Should the higher heating value (HHV) be applied instead of LHV, the abbreviation “HHV” shall be
added to all the results that derive from the use of the HHV, such as the heating value of gaseous fuel
calculated as per Equation (15), the energy of gaseous fuel calculated as per Equation (16), the input energy
of gaseous fuel calculated as per Equation (15) and the efficiency calculated as per Annex D.
EXAMPLE If the value of efficiency is based on the HHV, it should be expressed as follows:
η = XX% (HHV)
h
NOTE In case of LHV, it is not necessary to add the abbreviation “LHV”.
5.2.2.4 Temperature
The temperature of each fluid shall be measured at the boundary of the hydrogen generator.
5.2.2.5 Pressure
The static pressure of each fluid shall be measured at the boundary of the hydrogen generator.
The height above grade shall be measured and recorded for input and output liquids.
The potential effects of condensable fractions shall be considered in the uncertainty analysis of 6.4 and in the
location of the pressure measurement means.
If the discharge of a particular fluid is to the atmosphere, its pressure need not be measured.
5.2.2.6 Flow rate
The flow rate of each fluid shall be measured at the boundary of the hydrogen generator.
Flow rates may be determined by means of a volumetric meter, mass flow meter or turbine type flow meter. If
such a method is not practicable, flow measurement by nozzles, orifices or venturi meters should be used and
they shall be applied in accordance with ISO 5167.
If a particular fluid is not chemically modified in the hydrogen generator, such as cooling fluid, instrument air or
purge gas, only the input or output flow rate shall be measured.
The effects of the flow measurement on the operability of the hydrogen generator shall be considered.
5.2.3 Solid output characteristics
Any solid outputs from the hydrogen generator, which is generated on a continuous basis, and which have to
be removed or disposed of continuously or in a repetitive batch operation, shall be characterized. The
following properties shall be measured:
a) composition;
b) mass generation rate;
c) frequency of removal, if a batch operation is necessary.
5.3 Environmental aspects
5.3.1 Particulate emission
Particulate emission in the exhaust gases shall be measured in accordance with ISO 9096.
6 © ISO 2010 – All rights reserved

5.3.2 SOx and NOx emission
5.3.2.1 SOx emission
SOx emission in the exhaust gases shall be measured in accordance with ISO 7934. Other methods suitable
for the service may be used providing they are consistent with the uncertainty analysis of 6.4.
5.3.2.2 NOx emission
NOx emission in the exhaust gases shall be measured in accordance with ISO 11564. Other methods suitable
for the service may be used providing they are consistent with the uncertainty analysis of 6.4.
5.3.3 CO and CO emission
CO emission in the exhaust gases shall be measured in accordance with ISO 11042-1 and ISO 11042-2.
CO may be calculated based on carbon content of the fuel.
CO emission in the exhaust gases shall be measured in accordance with ISO 11042-1 and ISO 11042-2.
5.3.4 Total hydrocarbon emission
Total hydrocarbon emission in the exhaust gases shall be measured in accordance with ISO 11042-1 and
ISO 11042-2.
5.3.5 Discharge water quality measurement
5.3.5.1 General
Quality measurements for water discharged from a hydrogen generator shall include the determination of:
a) volume of discharge water;
b) temperature of discharge water;
c) pH;
d) chemical oxygen demand (COD) or, if necessary, biochemical oxygen demand (BOD).
5.3.5.2 pH
The pH shall be measured in accordance with ISO 10523.
5.3.5.3 Chemical oxygen demand (COD)
The COD shall be measured in accordance with ISO 6060.
5.3.5.4 Biochemical oxygen demand (BOD)
When applicable, the BOD shall be measured in accordance with ISO 10707.
5.3.6 Audible noise level
The audible noise level produced by the hydrogen generator shall be measured using a sound level meter that
complies with IEC 61672-1. The test shall be conducted in accordance with ISO 3744 and shall record the
following parameters:
a) measuring surface (at distance from the body of hydrogen generator);
b) number of measuring points;
c) the background noise level, which shall be measured with the hydrogen generator in the cold state.
5.4 Ambient conditions
Ambient humidity, wind, pressure and temperature shall be measured.
Ambient humidity measurement shall be performed as per ISO 4677-1 and ISO 4677-2.
Ambient wind measurement shall be performed as per ISO 16622.
6 Test plan
6.1 General
A detailed test plan shall be prepared taking into consideration the following:
a) the test operating modes specified in 6.2;
b) the measurements, the test frequency and duration specified in 6.3;
c) the uncertainty analysis of 6.4.
6.2 Test operating modes
The hydrogen generator shall be tested in the operation modes listed below and shown in Figure 2:
a) start-up from cold state to the minimum hydrogen rated output;
b) steady-state operation at the minimum hydrogen rated output;
c) ramp-up from minimum hydrogen rated output to maximum hydrogen rated output;
d) steady-state operation at the maximum hydrogen rated output;
e) ramp-down from maximum hydrogen rated output to minimum hydrogen rated output;
f) shutdown to cold state;
g) standby state.
NOTE The hydrogen generator operating modes listed above do not prevent documentation of additional process
states in accordance with the methods of this part of ISO 16110, nor do they prevent inclusion of additional test data in the
data reports defined in this part of ISO 16110.
8 © ISO 2010 – All rights reserved

Key
X time
Y utility inputs
Z hydrogen product
Operating states
1 cold state
2 standby state (optional)
3 operational state (hydrogen product available)
4 maximum hydrogen rated output
Transitional states
1-3 cold state to operational state
2-3 standby state to operational state
3-4 ramp-up from minimum hydrogen rated output to maximum hydrogen rated output
4-3 ramp-down from maximum hydrogen rated output to minimum hydrogen rated output
Figure 2 — Hydrogen generator operating modes
For steady-state operational testing, the criteria in Table 1 shall be used to define the permissible deviations
allowed during testing for each parameter. For all transient testing, the parameters not directly affected by the
transient test shall be in accordance with Table 1.

Table 1 — Maximum permissible variations in test operating conditions
during a steady-state period
Average variation rate
Parameter
per hour
Power input, kW ± 2 %
Barometric pressure at site, kPa
± 0,5 %
Heating value, kJ/mol ± 2 %
Gaseous fuel pressure as delivered to system, kPa ± 1 %
Gaseous output hydrogen pressure, kPa ± 1 %
Fuel input and hydrogen output flow, m /s
± 2 %
During transients measured during ramp-up and ramp-down, impurity levels in the hydrogen product shall be
within the manufacturer's specifications.
6.3 Measurement, test frequency and duration
Measurements shall be taken during each phase of the test operating sequence as shown in Table 2.
NOTE For hydrogen generators not equipped with one or more of the operating modes, no measurements are
required and no results need to be included in the test report. If relevant, other steady-state outputs between minimum and
maximum hydrogen rated output may be selected.
Table 2 — Test item and system status
Steady-state conditions Ramp-up
and ramp-
Start-up
Maximum Minimum
down
Item Test Standby and
hydrogen hydrogen
shutdown
rated rated
output output
Operational aspects
1 Electrical power input as per 5.2.1 × × × ×
2 Input fluid characteristics as per 5.2.2 × × × × ×
3 Output fluid characteristics as per 5.2.2 × × × × ×
4 Solid output characteristics as per 5.2.3 × × × ×
Environmental aspects
1 Particulate emissions as per 5.3.1 × × ×
2 SOx and NOx emissions as per 5.3.2 × × ×
3 CO and CO emissions as per 5.3.3 × × ×
4 Total hydrocarbon emissions as per 5.3.4 × × ×
5 Discharge water quality as per 5.3.5 × × ×
6 Audible noise level as per 5.3.6 × × × × ×
The duration and frequency of measurements shall be determined according to the type of hydrogen
generator tested. A sufficient number of measurements and number of measurement sets shall be established
based on requirements for measured value fluctuations, stability of average values, and the uncertainty
analysis of 6.4. The required frequency of measurement shall be chosen based on the expected duration of
10 © ISO 2010 – All rights reserved

the transient measurements required under this part of ISO 16110. The test results shall be analysed to
determine the absolute and relative uncertainty.
If discrete measurement is used, the interval between measurements shall not be less than 10 minutes. The
frequency of discrete measurements, if employed, shall be expressly considered in the uncertainty analysis of
6.4.
For continuous monitoring of the readings, at least one hour of steady-state operation shall be required.
NOTE In computing results of tests, the determination can be made with averaged values of observations made
during a single test.
6.4 Uncertainty analysis
6.4.1 General
An uncertainty analysis shall be performed on all tests. The test results shall be analysed to determine the
absolute and relative uncertainty.
NOTE Guidance on how to carry out an uncertainty analysis is provided in Annex B.
6.4.2 Uncertainty of test instruments
The uncertainty of the measurements to be taken shall be established based on the instrument calibration
documents prior to initiating the testing process. The uncertainty shall be expressed as a +/− value expressed
in the units of the variable. For measured values requiring multiple inputs, such as flow rate, care shall be
taken to account for the total uncertainty for all instruments.
7 Test procedure
7.1 Safe operation of the hydrogen generator and test equipment
The hydrogen generator shall be operated in accordance with the manufacturer's written operating
instructions at all times during the execution of the test plan.
NOTE All hazards associated with each gas and testing equipment need to be taken into consideration. Guidance
can be found in the manufacturer-related safety information located in the respective manufacturer instruction manuals
and the Material Safety Data Sheets (MSDS) for gases and solids associated with the system.
7.2 Execution of the test plan
7.2.1 Operational data
The test plan specified in Clause 6 shall be executed as planned.
At a minimum, the following operational data shall be included in the overall summary of the testing process:
a) start-up time;
b) minimum operational hydrogen rated output, including the following data:
1) capacity,
2) hydrogen pressure and temperature fluctuations and frequency,
3) hydrogen flow fluctuations and frequency,
4) hydrogen purity variations and frequency (if above purity specifications);
c) ramp-up rate from minimum to maximum hydrogen rated output, including the following data:
1) capacity,
2) hydrogen flow fluctuations and frequency,
3) hydrogen pressure and temperature fluctuations and frequency,
4) hydrogen purity variations and frequency (if above purity specifications);
d) maximum hydrogen rated output, including the following data:
1) capacity,
2) hydrogen pressure and temperature fluctuations and frequency,
3) hydrogen flow fluctuations and frequency,
4) hydrogen purity variations and frequency (if above purity specifications);
e) ramp-down rate from maximum to minimum hydrogen rated output, including the following data:
1) capacity,
2) hydrogen flow fluctuations and frequency,
3) hydrogen pressure and temperature fluctuations and frequency,
4) hydrogen purity variations and frequency (if above purity specifications);
f) shut-down time.
7.2.2 Data acquisition plan
The data acquisition system (i.e. duration and frequency of readings) shall be taken into account in the
uncertainty (see B.2) and the data recording equipment that is suitable for the required frequency of readings
and reading speed shall be prepared in advance of the tests.
8 Calculations
8.1 Electrical power input
When the voltage, current, and power factor of electrical power input are measured, electrical power input
(P ) shall be calculated as follows:
in
a) three phase system
PV=×3 ×I×λ (1)
in in in in
where
P is the electrical power input (W);
in
V is the voltage of electrical power input (line to line) (V);
in
I is the current of electrical power input (A);
in
λ is the power factor of electrical power input.
in
12 © ISO 2010 – All rights reserved

b) single phase system
PV=×I×λ (2)
in in in in
where
P is the electrical power input (W);
in
V is the voltage of electrical power input (line to neutral) (V);
in
I is the current of electrical power input (A);
in
λ is the power factor of electrical power input.
in
c) direct current
PV=×I (3)
in in in
where
P is the electrical power input (W);
in
V is the voltage of electrical power input (V);
in
I is the current of electrical power input (A).
in
8.2 Calculation of flow rates
Fuel, return gas, steam input rates and hydrogen output flow rate shall be calculated by means of the
following equations.
8.2.1 Gaseous fuel
q = q × ρ (4)
mf vf0 f0
where
q is the mass flow rate of gaseous fuel (kg/s);
mf
q is the volumetric flow rate of gaseous fuel at reference conditions calculated as per Equation (5)
vf0
(m /s);
ρ is the density of gaseous fuel at reference conditions (kg/m );
f0
qq=×(/tt)×(p/p ) (5)
vf0 vf 0 f f 0
where
q is the volumetric flow rate of the fuel at temperature t and pressure p (m /s);
vf f f
t is the reference temperature (288,15 K);
t is the temperature of gaseous fuel at test conditions (K);
f
p is the pressure of gaseous fuel at test conditions (kPa);
f
p is the reference pressure (101,325 kPa).
8.2.2 Liquid fuel
q = q × ρ (6)
ml vl0 l0
where
q is the mass flow rate of liquid fuel (kg/s);
ml
q is the volumetric flow rate of liquid fuel at reference conditions (m /s);
vl0
ρ is the density of liquid fuel at reference conditions (kg/m ).
8.2.3 Return gas
q = q × ρ (7)
mrh vrh0 h0
where
q is the mass flow rate of hydrogen in return gas (kg/s);
mrh
q is the volumetric flow rate of hydrogen in return gas at reference conditions, calculated as per
vrh0
Equation (8) (m /s);
ρ is the density of hydrogen at reference conditions (kg/m ).
h0
q = q × x (8)
vrh0 vr0 rh
where
q is the volumetric flow rate of return gas at reference conditions (m /s) calculated as per
vr0
Equation (9);
x is the molar ratio of hydrogen in return gas.
rh
qq=×t//t×pp (9)
()( )
vr0 vr 0 r r 0
where
q is the volumetric flow rate of return gas at temperature t and pressure p (m /s);
vr r r
t is the reference temperature (288,15 K);
t is the temperature of return gas at test conditions (K);
r
p is the pressure of return gas at test conditions (kPa);
r
p is the reference pressure (101,325 kPa).
8.2.4 Steam input
q = q × ρ (10)
ms vs0 s0
where
q is the mass flow rate of steam (kg/s);
ms
q is the volumetric flow rate of steam at reference conditions calculated as per Equation (11) (m /s);
vs0
ρ is the density of steam at reference conditions (kg/m ).
s0
14 © ISO 2010 – All rights reserved

qq=×t//t ×pp (11)
()( )
vs0 vs 0 s s 0
where
q is the volumetric flow rate of steam at temperature t and pressure p (m /s);
vs s s
t is the reference temperature (288,15 K);
t is the temperature of steam at test conditions (K);
s
p is the pressure of steam at test conditions (kPa);
s
p is the reference pressure (101,325 kPa).
8.2.5 Gaseous hydrogen output
q = q × ρ (12)
mh vh0 h0
where
q is the mass flow rate of the hydrogen in hydrogen-rich gas (kg/s);
mh
q is the volumetric flow rate of hydrogen in hydrogen-rich gas at reference conditions calculated as
vh0
per Equation (13) (m /s);
ρ is the density of the hydrogen at reference conditions (kg/m ).
h0
q = q × x (13)
vh0 vhr0 h
where
q is the volumetric flow rate of hydrogen-rich gas at reference conditions calculated as per
vhr0
Equation (14) (m /s);
x is the molar ratio of hydrogen in hydrogen-rich gas.
h
qq=×t//t×pp (14)
()( )
vhr0 vhr 0 h h 0
where
q is the volumetric flow rate of hydrogen-rich gas at temperature t and pressure p (m /s);
vhr h h
t is the reference temperature (288,15 K);
t is the temperature of hydrogen-rich gas at test conditions (K);
h
p is the pressure of hydrogen-rich gas at test conditions (kPa);
h
p is the reference pressure (101,325 kPa).
8.3 Calculation of fuel, steam and hydrogen energy
8.3.1 General
Input and output energies shall be calculated by means of the following equations.
In the equations below, the heating value determined through calorimetric methods (see 5.2.2.3) may be used
instead of that calculated based on the fluid composition.
8.3.2 Input energy of gaseous fuel
The input energy of gaseous fuel per unit of time (Q ) shall be calculated from the following equation:
inf
fv
i nf vf0
QM =×E q (15)
()
o
where
Q is the input energy of gaseous fuel per unit of time (kJ/s);
inf
E is the energy of gaseous fuel calculated as per Equation (16) (kJ/mol);
fv
−2 3
M is the reference molar volume of ideal gas (2,3645x10 m /mol) at the reference temperature,
o
t = 288,15 K;
q is the volumetric flow rate of gaseous fuel at reference conditions calculated as per Equation (5)
vf0
(m /s).
The energy of gaseous fuel per unit of volume (E ) at a temperature t and a pressure p of a mixture of known
fv f f
composition shall be calculated from the following equation:
E = Q + h − h + E (16)
fv f0 f f0 pf
where
Q is the heating value of gaseous fuel at reference conditions calculated as per Equation (17) (kJ/mol);
f0
h is the specific enthalpy of gaseous fuel at temperature t calculated as per Equation (18) (kJ/mol);
f f
h is the specific enthalpy of gaseous fuel at the reference temperature t (kJ/mol);
f0 0
E is the pressure energy of gaseous fuel calculated as per Equation (20) (kJ/mol).
pf
The heating value of gaseous fuel (Q ) at reference conditions shall be calculated from the following equation:
f0
N
Qx= Q (17)
f0 ∑jjf0
j=1
where
Q is the heating value of gaseous fuel component j at reference conditions (kJ/mol);
f0j
x is the molar ratio of gaseous fuel component j.
j
NOTE Numerical values of Q are given in Table C.1.
f0j
The specific enthalpy of gaseous fuel at temperature t (h ) shall be calculated from the following equation:
f f
N
hx= h (18)
ffjj
∑
j=1
where
x is the molar ratio of gaseous fuel component j;
j
h is the specific enthalpy of gaseous fuel component j at temperature t calculated as per Equation (19)
fj f
(kJ/mol).
16 © ISO 2010 – All rights reserved

The specific enthalpy of gaseous fuel component j at temperature t (h ) shall be calculated as follows:
f fj
⎡⎤
⎛⎞⎛ ⎞
Bt××C t
frjjf f
−3
⎢⎥
⎜⎟⎜ ⎟
hA=×t+ + ×10 (19)
()
ffjjf
⎢⎥⎜⎟2 000⎜ ⎟
31× 0
⎝⎠⎝ ⎠
⎣⎦
where
A , B and C are the constants of gaseous fuel component j and given in Worksheet 1 of Annex C;
fj fj fj
t is the temperature of gaseous fuel at test conditions (K).
f
The specific enthalpy of gaseous fuel at the reference temperature t (h ) shall be calculated from
0 f0
Equation (18), except that the temperature shall be changed to the reference temperature t .
The pressure energy of gaseous fuel (E ) shall be calculated from the following equation:
pf
E =×Rt ×In (p /p ) 20
pf 0 f 0
where
−3
R is the universal gas constant (8,314 x 10 kJ/mol K);
t is the reference temperature (288,15 K);
p is the pressure of gaseous fuel at test conditions (kPa);
f
p is the reference pressure (101,325 kPa).
8.3.3 Input energy of liquid fuel
The input energy of liquid fuel per unit of time (Q ) shall be calculated from the following equation:
inl
Q = E × q (21)
inl lv vl0
where
Q is the input energy of liquid fuel per unit of time (kJ/s);
inl
E is the energy of liquid fuel per unit of volume at a temperature t calculated as per Equation (22)
lv l
(kJ/m );
q is the volumetric flow rate of liquid fuel at reference conditions (m /s).
vl0
The energy of liquid fuel per unit of volume at a temperature t (E ) shall be calculated from the following
l lv
equation:
E = ρ × Q (22)
lv l ll
where
ρ is the density of liquid fuel at temperature t (kg/m );
l l
Q is the measured heating value of liquid fuel at temperature t (kJ/kg).
ll l
8.3.4 Input energy of hydrogen in return gas
The input energy of hydrogen in return gas per unit of time Q (kJ/s) shall be calculated from the following
ret
equation:
QE=×/M q (23)
()
ret rv o vr0
where
Q is the input energy of hydrogen in return gas per unit of time (kJ/s);
ret
E is the energy of hydrogen in return gas calculated as per Equation (24) (kJ/mol);
rv
−2 3
M is the reference molar volume of ideal gas (2,3645x10 m /mol) at the reference temperature,
o
t = 288,15 K;
q is the volumetric flow rate of return gas at reference conditions calculated as per Equation (9) (m /s).
vr0
The energy of hydrogen in return gas per unit of volume at a temperature t and a pressure p (E ) of a
r r rv
mixture of known composition shall be calculated from the following equation:
rv rh h0 r 0 pr
E=+ xQ h−h+E (24)
()
where
x is the molar ratio of hydrogen in return gas;
rh
Q is the heating value of hydrogen at reference conditions (kJ/mol);
h0
h is the specific enthalpy of hydrogen at temperature t calculated as per Equation (25) (kJ/mol);
r r
h is the specific enthalpy of hydrogen at the reference temperature t (kJ/mol);
0 0
E is the pressure energy of hydrogen in return gas calculated as per Equation (26) (kJ/mol).
pr
NOTE Numerical values of Q are given in Table C.1.
h0
The specific enthalpy of hydrogen at temperature t (h ) shall be calculated from the following equation:
r r
⎡⎤
⎛⎞⎛ ⎞
Bt××C t
hr hr −3
⎢⎥
hA=×t+⎜⎟ +⎜⎟ ×10 (25)
()
rhr
⎜⎟⎜ ⎟
2 000
⎢⎥31× 0
⎝⎠⎝ ⎠
⎣⎦
where
A , B and C are the constants given in Worksheet 1 of Annex C;
h h h
t is the temperature of return gas at test conditions (K).
r
The specific enthalpy of hydrogen at reference temperature t (h ) shall be calculated from Equation (25),
0 0
except that the temperature shall be changed to the reference temperature
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