Device to determine water content in gas well production

FIELD: oil and gas industry, particularly survey of boreholes or wells.

SUBSTANCE: device has working chamber, pressure and temperature control means, impulse tube to which differential pressure transducer is connected. Impulse tube is filled with reference fluid and connected to above working chamber in points spaced apart in vertical direction along working chamber. Upper part of working chamber is connected to access hole of wellhead. Lower end thereof is communicated with atmosphere.

EFFECT: increased efficiency and accuracy of water content determination.

2 dwg

 

The invention relates to gas industry and can be used to determine the amount of water in the droplet phase, contained in the product gas wells to determine the extent of irrigation, quality assessment conducted water shutoff works.

A device for gas-condensate well testing, including sequentially connected separation units, gas flow meter, a device for measuring pressures and temperatures /Pat. 2081311 RF, MPK6E 21 In 47/00, epubl/.

Barriers to achieving the desired technical result known method and device, the following: the release of gas into the atmosphere, tens and hundreds of thousands of cubic meters per study, the complexity of the research related to the need for structural changes in estuarine binding wells (to connect separators), limited research during the time period of positive ambient temperatures.

The task, which is aimed by the invention is the development of operational and environmental method and device that would determine the presence of water in the production of gas wells directly at the wellhead.

When carrying out the invention the problem is solved at the expense of achievement-the first result, which is to improve the accuracy of determination of moisture, and reducing logistics costs.

This technical result on the device object, is achieved in that the device for determining the moisture content of the product gas wells equipped with wellhead piping, having the technological hole containing working chamber, means for controlling the pressure and temperature feature is that the device is equipped with a differential pressure transducer and the pulse tube, which is filled with a reference liquid and connected to a given working chamber at points spaced vertically of the working chamber, a differential pressure sensor connected to the pulse tube, and the said working chamber in the upper part of the pipe connected to the specified technological hole, and at the bottom - with the atmosphere.

It is stated that the working chamber, the pulse tube allows you to determine the moisture content of the product gas wells directly at the wellhead hydrostatic method with an accuracy that allows you to capture the presence in the product gas wells of water in the droplet phase, without changing the existing wellhead piping with minimal cost and low emission of investigational products in the atmosphere.

Determination of moisture products is gas wells directly at the wellhead is based on measuring the absolute density hydrostatic (differential method). It is known that the production of a gas well is a gas-liquid mixture consisting of several gas fractions of water vapor, the solid phase and the liquid droplet (droplet phase). At existing production wells the rate of gas movement from the bottom to the mouth and further chosen such that it provides the removal of the drip component. It is known that at these speeds the droplet sizes are ≤20-50 microns /Zarnitsky GA Theoretical basis of energy use of natural gas pressure. - M.: Nedra, 1968/. At these sizes and pressures in the well and the reservoir (20-160 ATM) it can be assumed that the production well is drip-gas suspension and the distribution of pressure in it is subject to the laws of hydrostatics, i.e. if we take two points of selection pressures, spaced vertically to a height h, then

P2-P1mix·g·h,

then,

Measuring simultaneously with the pressure difference ΔP is the absolute pressure (P), temperature (T) and knowing field data on the composition of the produced dry gas can be calculated to obtain a value for the density of dry gas ρdryat this pressure and temperature. Knowing ρdryand ρmixyou can determine the relative humidity of the gas /carpenters V.M., Podreshetnikov VA, Radk the HIV CENTURIES, Of goshawks LN. Control of the composition and quality of natural gas. - M.: Nedra, 1983/.

It is quite clear that to obtain good results only when the mass percentage of the liquid droplet, exceeding the accuracy class of the used sensors pressure difference. The main advantage of the hydrostatic method is its integral nature, volume.

The invention is illustrated by drawings, where figure 1 presents a diagram of the device for determining the moisture content, figure 2 - scheme of measuring the density of the investigated products.

A device for determining the moisture content of the product gas wells contains the working chamber 1, is a hollow steel vertical cylinder with a length of at least 1.5 m pipes (sewers) of the inlet 2 and outlet 3, representing an insulated tube of a high pressure disperser 4, designed to create a homogeneous fine-dispersed gas-liquid mixture in the working chamber 1, the valve needle device type, regulating the intensity and pressure of the flow in the working chamber 1, the tube 6, for example, pulsed or measuring filled with the reference fluid and connected with the working chamber 1 at points spaced vertically of the working chamber 1. The pulse tube 6 passes the pressure difference in Verkhneye the lower parts of the working chamber 1 differential pressure sensor (DD) 7. The device is also equipped with control means (e.g., sensors) absolute pressure 8 and temperature 9. The sensors are processed in the processing unit 10 and are recorded by the computer 11. As a working environment used, the air supplied from the compressor. As the differential pressure sensor 7 is applied Metran - 22-DD-EXT with working range from 0 to 1600 PA and accuracy class of 0.15% /Metran - 22. The pressure sensor. Manual SPHRE/

As a means of temperature control 9 used a resistance thermometer.

As a means of controlling the absolute pressure of 8 applied, for example, Metran-22-NR.

The performance of sensors (transducers) explosion-proof. As the reference fluid used brake fluid "Dew". Brake fluid Dew-drenched in the pulse tube 6. The density of brake fluid "Dew" at a temperature of 20°With equal 1068 kg/m3. Operating temperature from - 50°to +50°C.

The principle DD 7 family Metran based on the use of piezoresistive effect in heteroepitaxial the silicon film grown on the surface of the monocrystalline plates of synthetic sapphire. When the strain sensitive single-crystal element under the influence of the input ismertetojegyei (for example, pressure or pressure difference) changes the electrical resistance of silicon piezoresistive bridge circuit on the surface of the sensing element. Electronic device DD converts the change of the electric resistance in standard analog DC signal and/or digital signal. In memory of sensory block stored in a digital format the results of preliminary measurements of the output signals of the sensor over the entire operating range of pressures and temperatures. These data are used by the microprocessor to calculate the coefficients of the correction of the output signal when the work DD. The digital signal of the touch unit together with correction factors to the input e of the Converter, a microprocessor which adjusts the signal on temperature and linearizes it. The output of the electronic unit adjusted output signal is converted from digital format to standard output. The sensors of the family "Metran" comply with GOST R 51333.0 and GOST R 51330.10 and entered into the State register of measuring instruments (No. 22235-01).

Determination of moisture content of the product gas wells as follows.

Investigated production of gas from gas wells (flow) line is drawn through the technological hole in the mouth banner operational hectares of the new wells, for example, designed for fastening wellhead pressure gauge. Well at the moment the measurement is valid and continues to provide products without changing the mode. After opening the valve of the wellhead pressure gauge coming through the inlet pipe 2 of the investigational product gas wells, representing the gas-liquid mixture through the disperser 4 is fed into an upper working chamber 1, through which creates a pressure difference in the upper and lower portions of the working chamber 1. The pressure difference across the membrane sensor (built into the pulse tube 6) is passed a reference fluid that fills the pulse tube 6, and then is fixed by the differential pressure sensor 7 (sensor Metran). The absolute density of the gas-liquid mixture and temperature, depending on temperature and pressure conditions, are recorded by means of the control 8 and 9. Proven gas-liquid mixture is vented to the atmosphere through the shut-off and control device 12 in the lower portion of the working chamber 1.

One of the main characteristics of gas-liquid and gas density is determined for homogeneous media the ratio of the mass to its volume. It depends on the gas composition, pressure, temperature and the availability of liquid and solid fractions. In practice, gas production, mainly used density g is for under normal conditions, it is given to working conditions.

The density of methane ρm≈0.7 kg/m3under normal operating conditions. If you take the base dimensions h-1.5 m, then the difference in the readings DD will be

ΔP1m·g·h=0,7 kg/m3·9.8 m/c2·1,5 m ≈10,3 PA

This is under normal conditions, i.e. at 1 ATM. If we take gas at a pressure of 160 atmospheres, in rough approximation

ΔP160≈160·ΔP1=160·10,3 PA=1640 PA

ρm≈0.7 kg/m3·160=112 kg/m3

From this it follows that the required sensor with measurement range of the differential pressure from 0 to 1600 PA at working pressure of 160 atmospheres. These requirements correspond, high-sensitivity, high-precision Metran 22-DD (Metran-DD, Metran-100-DD, model 3051, 3051S Fisher-Rosemount), preserving its characteristics at high operating pressures and temperatures.

The transfer of pressure from the sampling points of pressure to the sensor by using the reference fluid. It is obvious that when using as a working or reference liquid, such as water with a density of 1000 kg/m3there is a pressure difference ΔPFL=PFL·g·h≈1000·9.8·1.5=14700 PA, which will cause distortion of the differential pressure sensor with a measuring range of 1600 PA. Use the opportunity to offset the I of the measuring range selected Metran 22-DD. In our case, for example, move the measuring range DD at 13100 PA, then in the absence of gas in the pipe (figure 2) indications DD will be 14700-13100=1600 PA. When the gas in the pipe from 1 ATM up to 160 ATM readings of the differential pressure sensor will be reduced from 1600 PA to 10 PA. Since generally considered correct measurement from 10% to 100% scale, it corresponds to measurements from 160 PA to 1600 PA. The range of measured densities of approximately 5 kg/m3up to 100 kg/m3.

Consider the measurement process to evaluate the density and composition of the produced gas directly from the well.

From figure 2 readings DD 7 (PCR) can be represented as

where RFLFL·g·h - pressure column h of the reference fluid in the pulse tube 6;

Pto- compensation, the offset range for DD;

PISMISM·g·h - pressure column of the investigational product by the height h.

Then RCRFL·g·h-RtoISM·g·h;

ρISM·g·h=ρFL·g·h-(Rto+PCR);

The direct use of formula (4) to determine the density of the product gas wells involves the presence of known values ρFLand Rto. Dimension ρFLhigh on the accuracy demands of the hydrometer and considering temperature dependency, to specify exactly which Rtoyou want the pressure sensor. So use more simple way. There are two measurements. Then have

Subtracting the first equation from the second, have

Testimony PPR1and RAC2removed from DD 7 in two dimensions, g, and h are known, ρdim1unknown.

Therefore, the first measurement at a known density value, or approximately known. At the first measurement in the working chamber 1 as the working medium is air, the density of which can be accurately calculated, knowing the temperature and pressure using the following formula

ρdim1dstandards d·P1·Tstandards/Pstandards·T1·K1

Our ranges of measurements of the compressibility factor K1

Then (5) can be written

At the second measurement in the working chamber 6 is investigational products gas wells under conditions of P2and T2then according to the formula (7) will be calculated density of the investigated products. The first part of the formula represents the air density in real conditions, i.e. the measurement conditions (pressure and temperature) of the ambient air, and probably it will be close to the density of air at normal conditions, ie=1.205 kg/m3(note: since RAC2<PPR1then the second part of the formula will be the first).

Now, if you consider the moisture content of the investigated products (gas-liquid mixture), located in the working chamber 6, then in all probability it can be assumed that the measured density of the gas mixture (together with water vapor, drip fluid and other) will be different in a big way on the density of dry gas, calculated for the same conditions, i.e. for R2T2according to (6) and (7)

where K2=1-1,57·P2/(T2-198).

Knowing the density of the dry gas ρdryand the density of the gas mixture ρmixdetermine the relative humidity by the formula (2).

Measurement with the use of the invention were carried out on three gas wells, quantitative differences relative humidity products.

Assuming a decisive influence on the determination of density by the formula (5) provide evidence of differential pressure sensor PPR1and RAC2(error ρISM, g, and h consider a minor), the relative error of the indirect measurement of density priblizitelen which will be evaluated by the following formula:

where δ - relative measurement error;

d(RCR) is the absolute error of measurement of density;

Δ - the accuracy class of the differential pressure sensor,% D is the scale used ranges, PA;

ρ is the density of the mixture in the working conditions, kg/m3;

g - free fall acceleration, m/s2;

h - distance between sampling points of pressure, m

If h=1 m, Δ=0.1%, D=1000 PA, g=9.81 m/c2and density when the pressure in the gas line 40 ATM to about 30 kg /m3the value of the relative error of measurement of density is of the order of 0.5%. When converted in units of the density of the mixture under normal conditions this would amount to about 3.5 g/m3.

Thus, using the hydrostatic method of measuring the density of the product gas wells on the basis of domestic sensors "Metran-DD" (accuracy class 0,15) allows you to record the measurement of the density of the gas-liquid mixture with a relative error no more than 1.0%. Accordingly, when the known density of the dry gas may receive operational conclusions about the moisture content of the product gas wells, if it exceeds 1.0% by weight, which corresponds to 5-6 g/ m3. This measurement accuracy allows you to record the presence of product gas wells of water in the droplet phase at a qualitative level.

the Invention provides for the determination of the density of the product gas wells (gas or gas-liquid mixture) in the working conditions for a short time and allows you to work continuously, in operational mode, and the known normal density of the produced gas to give prompt conclusion about the water production well above 1.0% by mass.

A device for determining the moisture content of the product gas wells equipped with wellhead piping, having the technological hole containing working chamber, means for controlling the pressure and temperature, characterized in that the device is equipped with a differential pressure transducer and the pulse tube, which is filled with a reference liquid and connected to a given working chamber at points spaced vertically of the working chamber, a differential pressure sensor connected to the pulse tube, and the said working chamber in the upper part of the pipe connected to the specified technological hole, and in the lower part of the atmosphere.



 

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