mfm meter principles
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4.1.2 Vx Meter
This meter is manufactured by Framo of Norway. The Vx meter was developed in
conjunction with Schlumberger who now act as its agents and are starting to use it for
routine well testing operations.
4.1.2.1 Principle of Operation
The meter consists of a blind flange which makes the fluids take a sharp 90 degree turn
upwards into the measurement section. The effect of this is to mix the fluids into a fairly
homogeneous mixture but full homogeneity is not a requirement for the meter.
The fluids then pass through a venturi which is used to measure the mass flow rate of the
fluids. Coincident with this venturi is a nuclear densitometer which measures the density
of the fluids with 2 separate gamma ray frequencies.
Each wavelength has a different rate of absorption which is dependent on both the
density and a quantity known as the “mass attenuation coefficient” (MAC) of each fluid.
It this that is exploited to measure not only the density, but also the mixture proportions
of the fluids.
Physically it is known that.
N = No e -ρµl
(1)
where
N = the gamma ray count rate at the detector
No = the gamma ray count rate at the detector when the pipe is full of vacuum (or air)
ρ = density of the fluid in the pipe
µ = MAC of the fluid in the pipe
l = the length of fluid penetrated (in effect the radius of the venturi throat)
both the density of the fluid in the pipe and the MAC are the length averaged values of
the individual oil, water and gas values. So the equation above can be expressed.
N = No e –(ρoµ
o lo + ρw
µw lw
+ ρg
µg lg )
(2)
Where the subscripts o, w, and g symbolise oil, water, gas.
and
l = length fraction of the specific phase in the radius of the venturi.
Many of the parameters in this equation are known, to wit :
N is measured during metering No is measured during calibration and form then on calculated to allow for source decay
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ρ’s are known from PVT experiments
µ’s are measured during calibration, for each hydrocarbon / water system.
Thus the only unknowns are the length fractions of each component. Of course to solve
for each one requires 3 equations, these are readily supplied since there are two equation
similar to eqn 2 (one for each gamma frequency) and the third simply states that
lo + lw + lg = 1 (3)
With the venturi measuring the mass flow rate and the average density being measured
by the nuclear densitometer, the total volume of fluid passing through the meter is known
and thus the volume of each phase can then be calculated.
No claims are made by the manufacturers that the meter can calculate the densities of the
individual components, high accuracy PVT is required and needs to be updated and
checked on a regular basis. In addition, the MACs of the various components need to be
measured by filling the venturi with 100% of each of the phases in turn and measuring
the count rate. Using eqn (1) allows the MAC to be calculated. When using this meter as
an infield test device this process needs to be repeated periodically to ensure accuracy is
maintained.
In the case were water salinity is changing on a regular basis this could be awkward, but
it would be possible to adjust the input density of the water by measuring the salinity of
the water with a handheld refractometer (it takes seconds) and looking up the density in a
set of tables. MACs can be calculated theoretically if the composition is known, so using
a variety of mixtures of injection and formation water a look-up table could be
established to allow input of the MAC of any given salinity also.
One of the advantages of this meter over other MPFMs discussed in this document is that
all the measurements are taken at the same point in the pipe because the nuclear
densitometer is located directly across the venturi. This ensures that the data used to solve
for the flow rate is all referenced to the same section of fluid and prevents problems that
might otherwise arise from slugs of liquid and gas being measured at the same time.
4.1.2.2 Accuracy
The Vx meter accuracy depends the GVF of the fluid stream and is quoted as follows.
The larger of 300 bbls / day and 2.5% of reading (GVF 0 – 98%) for liquidsand
The larger of 1% of reading and 3400 acf/d (GVF 0 – 30%)
the larger of 3% of reading and 10,200 acf/d (GVF 30 – 60%)
the larger of 10% of reading and 34,000 acf/d (GVF 60 – 90%)
the larger of 15% of reading and 50,000 acf/d (GVF 90 – 95%)
the larger of 20% of reading and 68,000 acf/d (GVF 95 – 98%)
for gas.
3% absolute (GVF 0 – 70%)
4% absolute (GVF 70 – 80%)
5% absolute (GVF 80 – 90%)8% absolute (GVF 90 – 95%)
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for water cut
These values are quoted with a 90% confidence level (2_and_a_bit sigma) and indicate
that the meter works best in the top half of its working range and at high pressures where
GVFs are lower.
The values quoted suffer from the same issue as the AGAR unit, in that (for oil) the 300
bbls / day fixed error is only small for rates above 12,000 bbl / day. Below this, the
percentage error increases steadily until at 3000 bbl / day the allowable error is 10%
which is on the edge of acceptability for allocation purposes.
It will be impossible to operate these at high pressures since they are forced to be
downstream of the choke. It is expected that they will operate at around 800 – 1200 psi
resulting in GVF values of between 30-60% for EKT and EMN TAGI formation fluids,
between 60 and 90% for EMK and EME TAGI formation fluids and in excess of 90% for
the gas condensates produced from the RKF and Strunian sands (see section 5 below).
This will result in gas rates being measured with an accuracy of around 3% for the lowGOR oil and 10% for the high GOR oils. This is considered barely satisfactory for wells
producing mostly oil.
In the case of gas condensates where gas rate accuracy (primary produced phase) will be
only +/- 15 – 20% these meters cannot be considered acceptable. Oil wells in which gas
breakthrough has occurred or gas lift is in place will have a similar problems with gas
rate measurements and GOR calculations will be excessively in error.
The turn down ratio of this meter is claimed to be 50:1 on a mass flow rate basis. It is
possible to replace the venturi in any given meter in about half a day including the
necessary calibration steps, but this is likely to be too long to be done on a routine basis.
Another option of having two meters (one for low rates, one for higher rates) at each
metering station that needs it is feasible but would involve double cost, as well as pipe
and valve requirement to allow switching between meters.
Finally it has recently become possible to equip the Vx with a wide range dP cell for the
Venturi meter. This allows a smaller meter to be used to measure higher rate with a larger
turn down ratio.
4.1.2.4 Likely Future Developments
Schlumberger have spent many millions on the development of this meter over the past
few years. It is now being sold by them with the intention that it should become their
primary well testing tool over the next few years.
Schlumberger are a large company with a large research and development budget and
regularly contribute to the literature on multi-phase metering.
Discussions with Schlumberger reveal commitment to developing and improving the
meter in the next few years to allow gas rate measurements at high GVFs to be improved
significantly. Although it cannot currently (April 04) be used to meter lean condensates,
there is an intention to release a wet gas version of the meter which will use identicalhardware but a new version of the software. Accuracy specifications of this device are
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not yet available but the new software is intended to be used for GVFs in excess of 98%.
Switching the function of a unit from one version to the other will require only reloading
of the software.
This wet gas function of the meter will not resolve the gas rate metering problems in the
90 – 98% range but it is likely that in the next few years, new software will improve thesituation.
4.1.3 Roxar
This meter is manufactured by Roxar of Norway who is better known for their ultrasonic
meters often used on flare lines and their water cut meters. Roxar have in the past had a
reputation for excessive cost due to the use of very expensive dual microwave technology
for measuring the velocity of the fluid stream. Recently this has been replaced with
capacitive sensors which are cheaper, to perform the same task.
4.1.3.1 Principle of Operation
The meter consists of a blind flange which makes the fluids take a sharp 90 degree turn
upwards into the vertical measurement section. The effect of this is to mix the fluids into
a fairly homogeneous mixture but full homogeneity is not a requirement for the meter.
The rest of the meter consists of
A gamma densitometer to measure the density of the fluids. This works similarly to the
Vx meter densitometer, except it has only one gamma frequency and gives no
information about the composition of the mixture.
A dual capacitance sensor to measure relative permittivity of the fluid mixture. This,
combined with the densitometer data, allows an estimation of the oil water and gas cuts,
in oil continuous flow. The readings from the two capacitance meters are also cross
correlated to allow the velocity of flow to be determined.
An inductance sensor to measure the capacitance of the fluid mixture. This combined
with the densitometer data allows an estimation of the oil water and gas cut, in water continuous flow.
Finally there is a venturi meter to measure the mass flow of fluid. This provides a
measure of redundancy to the cross correlation based measurement of fluid velocity.
However, use of this measurement alone does not take into account the slippage between
oil and gas in the meter. To allow for this, input from the cross correlation meter is used.
The cross correlation works by a statistical examination of the response from two pairs
of electrodes set some distance apart. The flow in the pipe contains a mixture of large
and small bubbles of gas dependant on the flow regime. The small bubbles are subject to
very little slip and thus travel at essentially the same speed as the surrounding liquid phase. The large bubbles have significant slip and thus travel faster. By comparing the
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two signals from different points in the pipe the speed of liquid and gas can be estimated.
These velocities are used in a modification of the standard Venturi equations to increase
the accuracy of the venturi calculations. Given the average density of the mixture, the
flow rates can then be determined.
At very high GVFs the cross correlation process sometimes breaks down due to annular flow conditions which give a capacitance signal which is too smooth to correlate. In
these conditions the Venturi meter provides the mass flow rate without the benefit of slip
adjustments. Company literature does not mention that this tends to degrade the
accuracy, but presumably it does.
No attempt is made to estimate the densities of oil water and gas, the meter requires
accurate inputs of;
Oil density Oil permittivity
Water density Water conductivity
Gas density
It also requires inputs describing how the oil water and gas density change with
temperature and pressure. This is provided by reliance on Calsep’s PVT simulator
package “PVTsim”.
The meter has a turndown ratio of about 10:1 in mass flow rate terms. This is
controlled by the venturi whose response is proportional to the square of the mass
flow rate. The turn down ratio can be extended by use of a two venturis in the same
meter, with different diameters, or by use of dual dP sensors with different ranges of
operation.
4.1.3.2 Accuracy.
The accuracy of the meter is quoted as in Table 2 below
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Table 2: Roxar Meter Accuracy Specification.
GVF Range Uncertainties
Gas Liquid WLR
0 - WTr
% rel % rel % abs %
0 – 30 8(1) 2 1.530 – 90 3 2
90 – 96 6 5 3
96 – 99 7 4
99 - 100 - -
Where:
GVF = Gas Volume Fraction
WLR = Water in Liquid Ratio
WTr = Transition point oil/water continuous liquid phase
rel % = Relative uncertainties in gas and liquid flow rates(2)
abs % = Absolute uncertainty for Water to Liquid Ratio (WLR) (2)
• For WLR > WTr WLR is 1.5 x listed value
• Uncertainties are given for pressure > 10 barG
• (1)For GVF > 5%
Repeatability: ¼ of measurement uncertainty
Uncertainties: Based on 90% confidence interval
Note that the error is quoted for liquid rate not oil rate. When the error of the liquidrate is combined with WLR error then the oil rate error can be significant when the
water cut is above about 70%.
It is difficult to directly compare the accuracy figures quoted for different MPFMs
since they are all quoted in a different way, but some attempt is made to do this in
Figures 2 and 3 in comparison with both AGAR and the Vx meter. It is noticeable that
the liquid error at higher than 99% GVF is not specified. Roxar also have a wet gas
meter intended to be used at GVFs greater than 95%. This works on a different
physical principle but details have not been forthcoming from Roxar.
As for all MPFMs, these uncertainties assume perfect fluid property values enteredinto the software. Extra errors are induced by errors in the data. Roxar are unique in
providing estimates of the extra errors induced by faulty input data. These are shown
in table 3 below.
Table 3: Roxar Meter Sensitivity to Input Data.
Quantity Change
% rel
Liq. Rate
% rel
WLR
% abs
Gas rate.
% rel
Note
Oil density: +1 % +0.9 % -0.2 % -0.2 % 1
Gas density: +10 % +1.1 % -0.3 % -0.3 % 1
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Water density: +1 % +0.3 % -0.1 % -0.1 % 1
Oil permitt. + 5 % -0.3 % +1.3 % +0.1 % 1
Water conduct + 1 % -0.02 % + 0.9 % - 0.0 % 2
Notes: 1: Given at 80% GVF, 20 % WLR
2: Given at 80% GVF, 80 % WLR
Some of these parameters are more prone to error than others, to wit
Meter condition oil density is very difficult to calculate to better than +/- 3%
A gas density of +/- 5% should be achievable
Water density in Groupement Berkine circumstances could vary by as much as 10%
although it’s very easy to measure the salinity and thus work out a density and
conductivity.
Oil permittivity is known to a high degree of accuracy. 5% is easily achievable.
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