CN201196079Y - Condensation gas flux measuring system - Google Patents
Condensation gas flux measuring system Download PDFInfo
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- CN201196079Y CN201196079Y CNU200820108142XU CN200820108142U CN201196079Y CN 201196079 Y CN201196079 Y CN 201196079Y CN U200820108142X U CNU200820108142X U CN U200820108142XU CN 200820108142 U CN200820108142 U CN 200820108142U CN 201196079 Y CN201196079 Y CN 201196079Y
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Abstract
The utility model relates to a condensate gas flow measuring system, comprising a condensate gas exploited well and a gas collecting pipeline provided with an emergency shutdown valve, a heating furnace, a throttle valve, a three-phase non-separation flow meter, a metering separator, an oil flow meter, a gas flow meter and a water flow meter, wherein the three-phase non-separation flow meter comprises a main pipe, a venturi devic for measuring fluid flow in the main pipe, an electrical conductivity measurement sensor provided in the main pipe for calculating the gas phase score ratio of small bubbles, oil phase score ratio, gas phase score ratio and fluid phase score ratio, gas flow speed and fluid flow speed, a capacitor measurement sensor provided in the main pipe for calculating gas phase score ratio of large and small bubbles, oil phase score ratio, gas phase score ratio, fluid phase score ratio, gas flow speed and fluid flow speed, and a gamma density meter provided in the main pipe for calculating fluid density. The condensate gas flow measuring system can accurately measure the water content of condensate oil of a high pressure condensate gas well and realize gas well online detection, thus is practical.
Description
Technical field
The utility model relates to a kind of condensed gas flow quantity measuring systems of field of petroleum exploitation, particularly relates to oil-gas-water three phase flow quantity measuring system in a kind of condensate gas.
Background technology
At present, in the development process of high pressure gas condensate field, the problem that always exists the water content in the condensate accurately to measure.The condensate gas central treating station adopts the mode of gas-liquid separator, flow meter and analytical test to carry out oil-gas-water metering usually.Big (the 2000m of Tarim Basin high pressure condensate gas well gas-oil ratio
3More than/the t), big (the nearly 0.4t/m of profit density contrast
3) etc. characteristics, existing technological process is difficult to get representational profit aggregate sample, can not grasp individual well moisture content and variation tendency, can't correctly carry out oil reservoir development dynamic analysis and development plan and adjust in good time, have a strong impact on the in time supporting of effect of reservoir development and oil gas treatment system.Simultaneously, because measurement of water-content coefficient is inaccurate, can't effectively take anticorrosive measure.
This shows that above-mentioned existing condensed gas flow quantity measuring systems obviously still has inconvenience and defective, and demands urgently further being improved in structure and use.The design people is based on being engaged in this type of product design manufacturing abundant for many years practical experience and professional knowledge, actively studied innovation, in the hope of founding a kind of condensed gas flow quantity measuring systems of new structure, can improve general existing condensed gas flow quantity measuring systems, make it have more practicality.
The utility model content
Main purpose of the present utility model is, overcome the defective that existing condensed gas flow quantity measuring systems exists, and provide a kind of new condensed gas flow quantity measuring systems, technical problem to be solved is to make it can accurately measure high pressure condensate gas well condensate water content, realize oil gas well on-line monitoring, thereby be suitable for practicality more, and have the value on the industry.
The purpose of this utility model and solve its technical problem and realize by the following technical solutions.According to a kind of condensed gas flow quantity measuring systems that the utility model proposes, be used to measure the flow of individual well oil gas water, it comprises: the condensate gas recovery well; Gas gathering line is used to carry the oil gas aqueous mixtures of condensate gas recovery well extraction, is provided with successively on this gas gathering line: emergency shutdown valve is arranged on condensate gas recovery well well head; Heating furnace is used to heat the material of condensate gas recovery well output; Choke valve is arranged at after the heating furnace; Three-phase does not separate flow meter, is used for real time measure oil gas water instantaneous delivery; Metering separator is connected in above-mentioned three-phase and does not separate flow meter, is used for oil gas water three phase is separated; And oil flowmeter, gas flowmeter and water ga(u)ge be connected to described metering separator, is used for the flow that separates back oil, G﹠W is measured separately.
The purpose of this utility model and solve its technical problem and also can be applied to the following technical measures to achieve further.
Aforesaid condensed gas flow quantity measuring systems, wherein said three-phase does not separate flow meter and comprises: trunk line; Venturi is arranged on the trunk line, is used to measure the flow of trunk line inner fluid; Conductivity measurement sensors is arranged in the trunk line, is used to calculate gas phase fraction, each phase phase fraction of oil gas water, gas and the flow rate of liquid of minute bubbles; Capacitance measuring sensor is arranged in the trunk line, is used to calculate gas phase fraction, each phase phase fraction of oil gas water, gas and the flow rate of liquid of large and small bubble; And the gamma densometer, be arranged in the trunk line, be used for the density of Fluid Computation.
Aforesaid condensed gas flow quantity measuring systems, wherein said conductivity measurement sensors comprise and setting gradually along the mixture flow direction: emission electrode, the backup electrode group that is made of two small electrodes, the working electrode group and the exploring electrode that are made of two small electrodes.
Aforesaid condensed gas flow quantity measuring systems, the spacing of two small electrodes of wherein said working electrode group is 65mm; The spacing of two small electrodes of described backup electrode group is 65mm.
Aforesaid condensed gas flow quantity measuring systems, wherein said capacitance measuring sensor comprise and setting gradually along the mixture flow direction: first electrode, first small electrode, excitation variable winding, second small electrode and second largest electrode; Wherein, first electrode and second largest electrode constitute the large electrode group, and first small electrode and second small electrode constitute the 3rd small electrode group.
Aforesaid condensed gas flow quantity measuring systems, the spacing of two large electrodes of wherein said large electrode group is 165mm, two small electrode spacings of described the 3rd small electrode group are 65mm, and the 3rd small electrode group is arranged between two large electrodes of this large electrode group.
Aforesaid condensed gas flow quantity measuring systems, wherein said gamma densometer is made of emitter and receiving system two parts; This emitter is made of radioactive source, plumbous box, mechanical shutter and corrosion resistant plate; This receiving system is made of receiving crystal, photomultiplier and electronics amplifier unit.
Aforesaid condensed gas flow quantity measuring systems, wherein said receiving crystal are that sodium iodide adds thallium.
By technique scheme, the utility model condensed gas flow quantity measuring systems has following advantage at least:
The condensed gas flow quantity measuring systems that the utility model proposes, can online in real time measure oil gas aquatic products amount, can accurately measure individual well moisture content and variation tendency, help monitoring the oil gas well condition of production, for the diagnosis of ill production status provides accurate data information, avoid the generation of abnormal conditions such as water breakthrough, has channeling and serious obstruction, meet the become more meticulous requirement of operation of oil field.
This condensed gas flow quantity measuring systems is a Chinese onshore oil gas field successful Application three-phase flow meter metering first individual well oil gas aquatic products amount, has widened approach for the onshore oil gas field especially one-well metering of high pressure gas condensate field, has indicated the developing direction of one-well metering.
Condensed gas flow quantity measuring systems of the present utility model, owing to also have the oil gas water gaging equipment of three phase separation, thus can verify mutually the survey data of not separating flow meter, thus the accuracy of assurance survey data.
In sum, the condensed gas flow quantity measuring systems of the utility model special construction, it has above-mentioned many advantages and practical value, and in like product, do not see have similar structure design to publish or use and really genus innovation, no matter it structurally or bigger improvement all arranged on the function, have large improvement technically, and produced handy and practical effect, and more existing condensed gas flow quantity measuring systems has the multinomial effect of enhancement, thereby be suitable for practicality more, and have the extensive value of industry, really be a novelty, progressive, practical new design.
Above-mentioned explanation only is the general introduction of technical solutions of the utility model, for can clearer understanding technological means of the present utility model, and can be implemented according to the content of manual, below with preferred embodiment of the present utility model and conjunction with figs. describe in detail as after.
Description of drawings
Fig. 1 is the schematic flow sheet of condensed gas flow quantity measuring systems embodiment of the present utility model.
Fig. 2 is the structural representation that three-phase does not separate flow meter.
Fig. 3 is the structural representation of described capacitance measuring sensor.
Fig. 4 is the structural representation of conductivity measurement sensors.
Fig. 5 is the composition structural representation of on-the-spot secondary meter.
The specific embodiment
For further setting forth the utility model is to reach technological means and the effect that predetermined utility model purpose is taked, below in conjunction with accompanying drawing and preferred embodiment, to according to its specific embodiment of condensed gas flow quantity measuring systems, structure, feature and the effect thereof that the utility model proposes, describe in detail as after.
Seeing also shown in Figure 1ly, is the schematic flow sheet of condensed gas flow quantity measuring systems embodiment of the present utility model.This condensed gas flow quantity measuring systems is used to measure the flow of individual well oil gas water, and it comprises: condensate gas recovery well 10 (be prior art, repeat no more); Gas gathering line 20 is used to carry the oil gas aqueous mixtures of condensate gas recovery well extraction, is provided with successively on this gas gathering line 20: emergency shutdown valve SDV1801 is arranged on condensate gas recovery well well head; Heating furnace 300 is used to heat the material of condensate gas recovery well output; Choke valve 400 is arranged at after the heating furnace; Three-phase does not separate flow meter 100, is used for real time measure oil gas water instantaneous delivery; Metering separator 200 is connected in above-mentioned three-phase and does not separate flow meter, is used for oil gas water three phase is separated; And oil flowmeter FT2202, gas flowmeter FT2201 and water ga(u)ge FT2203 be connected to described metering separator, is used for the flow that separates back oil, G﹠W is measured separately.Described three-phase does not separate the gas gathering line after the choke valve 400 of being connected in of flow meter 100, is used for measuring in real time the flow of mixture of oil, water and gas Oil, Water, Gas.
To 16MPa, temperature drops to 27 ℃ to the well head oil gas aqueous mixtures of condensed gas flow quantity measuring systems of the present utility model (P=24MPa, T=35 ℃) through the oil nozzle throttling, and temperature and pressure show on the spot.Well head gas gathering line 20 is provided with high newspaper of pressure and the low newspaper of pressure, if well head pressure is unusual, touches height and reports pressure switch, treating stations Central Control Room sound and light alarm; Continue to be increased to the setting pressure of well head emergency shutdown valve SDV1801 as pressure, then this emergency shutdown valve automatically shuts down.Oil gas aqueous mixtures in the gas gathering line is warming up to 65 ℃ through well head heating furnace 300, choke valve 400 once more throttling to 7.5MPa, temperature drops to 24 ℃, choke valve 400 front and back pipeline temperature and pressure show on the spot, the temperature and pressure signal passes through well head RTU (remote terminal control system, not shown in the figures) teletransmission to the treating stations Central Control Room.The gas gathering line mixture is delivered to three-phase and does not separate flow meter after throttling.
Seeing also shown in Figure 2ly, is the structural representation that three-phase does not separate flow meter.This three-phase does not separate flow meter 100 and comprises: the trunk line 110 that fuel feeding gas-vapor mix material flow is moving, and be arranged on gamma density meter 120, capacitance measuring sensor 130, conductivity measurement sensors 140 and Venturi 150 on the trunk line 110.The principle that this three-phase does not separate the measurement mixture of oil, water and gas of flow meter is that individual well comes the oil gas aqueous mixtures to be assumed to be four phase fluids, i.e. oil, water, discrete gas and free gas.Air pocket flow velocity identical with gas flow rate (air pocket is discrete gas), minute bubbles flow velocity identical with flow rate of liquid (minute bubbles are free gas), it is identical with aqueous phase flow rate vertically to measure the interior oil phase flow velocity of pipeline section.
If: Q: volume flow dose rate, A: volume phase fraction, v: flow velocity
Q＝A×V (1)
The volume phase fraction equals the product of phase fraction and measuring tube cross-sectional area, because the measuring tube cross-sectional area is known, the calculating of each phase flow rate rate of oil gas water can be exchanged into phase fraction and each calculating of flow velocity mutually.
Described gamma densometer 120 is used for the Fluid Computation hybrid density, it is made of emitter and receiving system two parts, emitter mainly is made of parts such as radioactive source, plumbous box, mechanical shutter and corrosion resistant plates, and receiving system mainly contains receiving crystal (sodium iodide adds thallium), photomultiplier and electronics amplifier unit and constitutes.The gamma-rays bump receiving crystal that radioactive source produces, can produce 1 electronics after each gamma-rays particle hits, electronics obtains energy through the high voltage electric field of photomultiplier, accelerated motion, finally caught by the electronics amplifier unit, and with the electron amount of electric impulse signal by receiving under the counter records.During operate as normal, gamma-rays enters in the pipeline by shutter, owing to have fluid to flow in the pipeline, oil gas water can the absorption portion gamma-rays, but the degree that absorbs has nothing in common with each other, and receiving system can be measured and receive gamma-ray quantity in the unit interval this moment.Utilize empirical formula, calculate the hybrid density of fluid.
Seeing also shown in Figure 3ly, is the structural representation of described capacitance measuring sensor 130.This capacitance measuring sensor 130 is used to measure gas phase fraction, each phase phase fraction of oil gas water, gas and the flow rate of liquid of the large and small bubble that hangs down aqueous fluid.This capacitance measuring sensor 130 comprises and setting gradually along the mixture flow direction: first electrode, first small electrode, excitation variable winding 131, second small electrode and second largest electrode; Wherein, first electrode and second largest electrode formation large electrode group 132, the first small electrodes and second small electrode constitute the 3rd small electrode group 133.The spacing of two large electrodes of this large electrode group 132 is 165mm, two small electrode spacings of described the 3rd small electrode group 133 are 65mm, and the 3rd small electrode group 133 is arranged between two large electrodes of this large electrode group, and excitation variable winding 131 is between first small electrode and second small electrode.These excitation variable winding 131 excitation voltage signals, signal is successively by the 3rd small electrode group 133 and large electrode group 132, the signal of telecommunication that the 3rd small electrode group 133 record minute bubbles cause, the signal of telecommunication that large electrode group 132 record air pockets cause, voltage signal be measured and record in addition during through each electrode.According to the functional relation of voltage and dielectric constant, can draw out the time dependent curve of dielectric constant, this curve of integration can be calculated the average phase fraction of size bubble preset time.
Calculate each phase phase fraction of oil gas water
Capacitivity equation: ε
Mixture=f (α ε
Gas, β ε
Water, γ ε
Oil) (2-1)
Density equation: ρ
Mixture=f (α ρ
Gas, β ρ
Water, γ ρ
Oil) (3)
Normalizing equation: alpha+beta+γ=1 (4)
In the formula:
ε
Mixture: mixture capacitivity (can calculate) by magnitude of voltage
ε
Gas: gas phase capacitivity (known)
ε
Water: water capacitivity (known)
ε
Oil: oil phase capacitivity (known)
ρ
Mixture: mixture density (gamma densimeter measurement value can be calculated)
ρ
Gas: density of gas phase (known)
ρ
Water: water density (known)
ρ
Oil: oil phase density (known)
α: gas phase phase fraction (the unknown)
β: water phase fraction (the unknown)
γ: oil phase phase fraction (the unknown)
Three unknown numbers of three equations, simultaneous solution can obtain gas phase phase fraction, water phase fraction and oil phase phase fraction.
Calculate gas and flow rate of liquid
Exciting electrode 131 excitation voltage signals are the minute bubbles flow velocity by the small electrode record and through the flow velocity that computing cross-correlation is tried to achieve, because the minute bubbles flow velocity is identical with liquid phase flow rate, and V
Liquid=d1/T (d1 is two distances between the small electrode, and T is that bubble is flowing to the used time of second small electrode from first small electrode); Be the air pocket flow velocity by the large electrode record and through the flow velocity that computing cross-correlation is tried to achieve, because the air pocket flow velocity is identical with the gas phase flow velocity, V
Gas=d2/T (d2 is two distances between the large electrode, and T flow to the used time of second largest electrode for this bubble from first electrode).
Seeing also shown in Figure 4ly, is that this conductivity measurement sensors 140 of structural representation of conductivity measurement sensors is arranged in the trunk line 110, is used to calculate gas phase fraction, each phase phase fraction of oil gas water, gas and the flow rate of liquid of minute bubbles.This conductivity measurement sensors 140 comprises and setting gradually along the mixture flow direction: emission electrode 141, the backup electrode group 142 that is made of two small electrodes, the working electrode group 143 and the exploring electrode 144 that are made of two small electrodes.The spacing of two small electrodes of described working electrode group 143 is 65mm; The spacing of two small electrodes of described backup electrode group 142 is 65mm.Emission electrode 141 emission voltage signals, signal moves from bottom to up with fluid, passes through backup electrode group 142, working electrode group 143 and exploring electrode 144 successively.Measured and the record in addition of voltage signal during through two electrode groups.According to the functional relation of voltage and dielectric constant, can draw out the time dependent curve of dielectric constant, this curve of integration can be calculated the average phase fraction of minute bubbles preset time.
Calculate each phase phase fraction of oil gas water
Electrical conductivity equation: σ
Mixture=f (α σ
Gas, β σ
Water, γ σ
Oil) (2-2)
Density equation: ρ
Mixture=f (α ρ
Gas, β ρ
Water, γ ρ
Oil) (3)
Normalizing equation: alpha+beta+γ=1 (4)
In the formula:
σ
Mixture: conductivity of mixture (can calculate) by magnitude of voltage
σ
Gas: gas phase electrical conductivity (known)
σ
Water: water electrical conductivity (known)
σ
Oil: oil phase electrical conductivity (known)
ρ
Mixture: mixture density (gamma densimeter measurement value can be calculated)
ρ
Gas: density of gas phase (known)
ρ
Water: water density (known)
ρ
Oil: oil phase density (known)
α: gas phase phase fraction (the unknown)
β: water phase fraction (the unknown)
γ: oil phase phase fraction (the unknown)
Three unknown numbers of three equations, simultaneous solution can obtain gas phase phase fraction, water phase fraction and oil phase phase fraction.
Calculate gas and flow rate of liquid
Emission electrode emission voltage signal, the measured and record in addition of voltage signal during through small electrode.After a period of time, two time dependent curves of some voltages of each self-forming of small electrode of working electrode group are done computing cross-correlation to these curves, if when drawing maximum, what can think that two small electrodes measure is same fluid.This time corresponding T of maximum occurs and think that promptly same logistics moves to the back required time of one electrode from last electrode, at this moment V
Gas(V
Liquid)=d/T=0.065/T.(d is the distance between the small electrode, known d=0.065m).
The conversion of capacitance measuring sensor and conductance measurement sensor
Conductivity measurement sensors has an exploring electrode, the signal of telecommunication that the continual measurement of this electrode receives, and it is converted into electrical conductivity, (electrical conductivity of vacant duct is 1 when electrical conductivity reaches 30 left and right sides, oil-overflow pipeline electrical conductivity is 2～2.3, and water-filled pipeline electrical conductivity is saturation value 〉=35), (moisture is 65%～75%), capacitance measuring sensor quits work, and conductivity measurement sensors is started working.
Described Venturi 150 is used to measure liquid phase flow rate.This Venturi becomes the fluid pressure difference of certain relation to measure fluid flow by measuring with flow, utilizes the pressure that produces before and after the fluid throttling to change and measures.
In the formula:
M: liquid quality flow
E: penalty coefficient
C: discharge coefficient (c=f (Re
D, β)
Re
D: the Reynolds coefficient
β: Venturi tube trunnion internal diameter/Venturi tube internal diameter
γ: level pressure thermal capacitance/constant volume thermal capacitance
ε: sampling factor (ε=f (dP/P, beta, gamma)
ρ: fluid density
A: Wen's trunnion passes through area
DP: fluid is by differential pressure before and after the Venturi tube
When capacitance measuring sensor or conductivity measurement sensors cross-correlation calculation flow velocity, when the cross-correlation success rate is on the low side (being that the cross-correlation calculation success rate is lower than minimum permissible value), the liquid phase flow rate that the venturi of winning the confidence calculates.
The three-phase that oil gas water gaging of the present utility model is does not separate flow meter 100 and also comprises on-the-spot secondary meter 160, see also shown in Figure 5ly, on-the-spot secondary meter 160 mainly is made up of flow computer 161, power module 162, safety barrier 163, densometer interface card 164 and wiring terminal 165 etc.Described flow computer 161 is made up of communication module and computing module.The signal that communication module collects capacitance sensor and conductivity sensor, and the data importing flow computer of densometer interface card output, with result of calculation (oil gas water flow, temperature, pressure and differential pressure) with the data wire teletransmission to Industrial Personal Computer (IPC).Computing module is responsible for calculating oil gas water instantaneous delivery.The 24V direct current that described power module is responsible for inserting distributes, and is transmitter (pressure transmitter, differential pressure transmitter and temperature transmitter), capacitance sensor, conductivity sensor, gamma densometer and flow computer power supply.Described safety barrier is the associate device of inbeing safe explosion prevention instrument and meter, does not under normal circumstances influence the function of measuring system.It is arranged on a side of harbor, and when the intrinsic safe explosion-proof system broke down, the energy (electric energy) that can will scurry into the hazardous area was limited in the safety value, thereby guarantees produced on-site safety.Described densometer interface card is collected the signal that the gamma densometer is gathered, and draws the instantaneous hybrid density of fluid by computing, with result of calculation input flow rate computer.The data remote of flow computer output is to the Central Control Room Industrial Personal Computer (IPC), and Industrial Personal Computer (IPC) is used the flow software for display after receiving data, realizes functions such as the instantaneous demonstration of oil gas water flow, oil well measurement and meter calibration.
See also shown in Figure 1ly, after three-phase does not separate flow meter 100, be connected in metering separator 200 by pipeline.This metering separator comprises with tank body, thereby be provided with baffle plate 212 and baffle plate 223 in the inside of tank body tank interior is divided into three chambeies: profit hybrid chamber 210, oil pocket 220 and water cavity 230.The principle that these metering separator 200 application of weight are separated is opened oil and gas and water.Mixture of oil, water and gas enters eliminator after the gas-liquid Gravity Separation, and gas phase is discharged by gaseous phase outlet, and at gaseous phase outlet gas flowmeter FT2201 is installed after corrugated sheet and mist eliminator remove liquid.Liquid phase water-oil separating under action of gravity, oil spill flow to into oil pocket 220, and water enters water cavity 230 by water communicating pipe 240.Be provided with the oil phase outlet in oil pocket 220 bottoms, and in this outlet, be provided with oil flowmeter FT2202, be used to measure the flow of oil.Be provided with the water outlet in the bottom of water cavity, and in this outlet, be provided with water ga(u)ge FT2203, be used to measure the flow of water.
Profit hybrid chamber and water cavity are communicated with, and according to U type law of connected vessels, design formulas is as follows:
ρ
0h
0＝ρ
0h
1+ρ
1(h
2-h
1)
Wherein: ρ
0: sewage density h
0: water cavity water layer height
ρ
1: oil density
h
1: profit hybrid chamber water layer height
h
2-h
1: profit hybrid chamber oil reservoir height
Suppose h
2-h
1=0, because h
2=1.5m ρ
0=1120kg/m
3ρ
1=720kg/m
3Solving equation 1 can get h
0=1.5m
h
2-h
1=0, all water in the profit hybrid chamber promptly, the height of water cavity water layer liquid level is 1.5m.But the highest operation liquid level of water is 1.22m, less than 1.5m.Therefore, during the eliminator normal running, the oil reservoir liquid level of profit hybrid chamber can not be 0, and promptly the water in the profit hybrid chamber can not overflow to oil pocket.
The water cavity height of baffle plate is 1.8m, and the highest operation liquid level of oil pocket is 1.02m.Therefore, during the eliminator normal running, the water cavity baffle plate that can not overflow of the oil in the oil pocket enters water cavity.
Water cavity
ρ
0h
0＝ρ
0h
1+ρ
1(h
2-h
1)
Suppose h
1=0, because h
2=1.5m ρ
0=1120kg/m
3ρ
1=720kg/m
3Solving equation 1 can get h
0=0.965m
h
1=0, promptly all oil in the profit hybrid chamber, the height of water cavity water layer liquid level should be 0.965m.Because water minimum operation liquid level is 0.98m, greater than 0.965m.Therefore, during the eliminator normal running, the water layer liquid level of profit hybrid chamber can not be 0, and promptly the oil in the profit hybrid chamber can not flow to water cavity from water communicating pipe.
The water cavity height of baffle plate is 1.8m, and the highest operation liquid level of water cavity is 1.22m.Therefore, during the eliminator normal running, the water cavity baffle plate that can not overflow of the water in the water cavity enters oil pocket.
The technology contents that the application does not describe in detail all can find corresponding scheme in the prior art, so do not repeat them here.
The above, it only is preferred embodiment of the present utility model, be not that the utility model is done any pro forma restriction, though the utility model discloses as above with preferred embodiment, yet be not in order to limit the utility model, any those skilled in the art, in not breaking away from the technical solutions of the utility model scope, when the technology contents that can utilize above-mentioned announcement is made a little change or is modified to the equivalent embodiment of equivalent variations, in every case be the content that does not break away from technical solutions of the utility model, according to technical spirit of the present utility model to any simple modification that above embodiment did, equivalent variations and modification all still belong in the scope of technical solutions of the utility model.
Claims (8)
1. condensed gas flow quantity measuring systems is used to measure the flow of individual well oil gas water, it is characterized in that it comprises:
The condensate gas recovery well;
Gas gathering line is used to carry the oil gas aqueous mixtures of condensate gas recovery well extraction, is provided with successively on this gas gathering line:
Emergency shutdown valve is arranged on condensate gas recovery well well head;
Heating furnace is used to heat the material of condensate gas recovery well output;
Choke valve is arranged at after the heating furnace;
Three-phase does not separate flow meter, is used for real time measure oil gas water instantaneous delivery;
Metering separator is connected in above-mentioned three-phase and does not separate flow meter, is used for oil gas water three phase is separated; And
Oil flowmeter, gas flowmeter and water ga(u)ge are connected to described metering separator, are used for the flow that separates back oil, G﹠W is measured separately.
2. condensed gas flow quantity measuring systems according to claim 1 is characterized in that wherein said three-phase does not separate flow meter and comprises:
Trunk line is used to carry measured oil gas aqueous mixtures;
Venturi is arranged on the trunk line, is used to measure the flow of trunk line inner fluid;
Conductivity measurement sensors is arranged in the trunk line, is used to calculate gas phase fraction, each phase phase fraction of oil gas water, gas and the flow rate of liquid of minute bubbles;
Capacitance measuring sensor is arranged in the trunk line, is used to calculate gas phase fraction, each phase phase fraction of oil gas water, gas and the flow rate of liquid of large and small bubble; And
The gamma densometer is arranged in the trunk line, is used for the density of Fluid Computation.
3. condensed gas flow quantity measuring systems according to claim 2 is characterized in that wherein said conductivity measurement sensors comprises to set gradually along the mixture flow direction: emission electrode, the backup electrode group that is made of two small electrodes, the working electrode group and the exploring electrode that are made of two small electrodes.
4. condensed gas flow quantity measuring systems according to claim 3, the spacing that it is characterized in that two small electrodes of wherein said working electrode group is 65mm; The spacing of two small electrodes of described backup electrode group is 65mm.
5. condensed gas flow quantity measuring systems according to claim 2 is characterized in that wherein said capacitance measuring sensor comprises to set gradually along the mixture flow direction: first electrode, first small electrode, excitation variable winding, second small electrode and second largest electrode; Wherein, first electrode and second largest electrode constitute the large electrode group, and first small electrode and second small electrode constitute the 3rd small electrode group.
6. condensed gas flow quantity measuring systems according to claim 5, the spacing that it is characterized in that two large electrodes of wherein said large electrode group is 165mm, two small electrode spacings of described the 3rd small electrode group are 65mm, and the 3rd small electrode group is arranged between two large electrodes of this large electrode group.
7. condensed gas flow quantity measuring systems according to claim 2 is characterized in that wherein said gamma densometer is made of emitter and receiving system two parts; This emitter is made of radioactive source, plumbous box, mechanical shutter and corrosion resistant plate; This receiving system is made of receiving crystal, photomultiplier and electronics amplifier unit.
8. condensed gas flow quantity measuring systems according to claim 7 is characterized in that wherein said receiving crystal is that sodium iodide adds thallium.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CNU200820108142XU CN201196079Y (en) | 2008-05-23 | 2008-05-23 | Condensation gas flux measuring system |
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CNU200820108142XU CN201196079Y (en) | 2008-05-23 | 2008-05-23 | Condensation gas flux measuring system |
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| Publication Number | Publication Date |
|---|---|
| CN201196079Y true CN201196079Y (en) | 2009-02-18 |
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ID=40415715
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|---|---|---|---|
| CNU200820108142XU Expired - Fee Related CN201196079Y (en) | 2008-05-23 | 2008-05-23 | Condensation gas flux measuring system |
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Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101338664B (en) * | 2008-05-23 | 2013-05-15 | 安东石油技术（集团）有限公司 | Condensed gas flow quantity measuring systems |
| TWI495852B (en) * | 2014-08-13 | 2015-08-11 | Finetek Co Ltd | Electromagnetic Flowmeter with Voltage-Amplitude Conductivity-Sensing Function |
| CN110005399A (en) * | 2019-04-16 | 2019-07-12 | 重庆科技学院 | A kind of experimental method of the retrograde gas condensate of condensate gas containing excessive water cubing |
-
2008
- 2008-05-23 CN CNU200820108142XU patent/CN201196079Y/en not_active Expired - Fee Related
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101338664B (en) * | 2008-05-23 | 2013-05-15 | 安东石油技术（集团）有限公司 | Condensed gas flow quantity measuring systems |
| TWI495852B (en) * | 2014-08-13 | 2015-08-11 | Finetek Co Ltd | Electromagnetic Flowmeter with Voltage-Amplitude Conductivity-Sensing Function |
| CN110005399A (en) * | 2019-04-16 | 2019-07-12 | 重庆科技学院 | A kind of experimental method of the retrograde gas condensate of condensate gas containing excessive water cubing |
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