CN114427385A - Gas lift oil production gas injection pressure system and method for reducing gas lift oil production gas injection pressure - Google Patents
Gas lift oil production gas injection pressure system and method for reducing gas lift oil production gas injection pressure Download PDFInfo
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- CN114427385A CN114427385A CN202011002247.9A CN202011002247A CN114427385A CN 114427385 A CN114427385 A CN 114427385A CN 202011002247 A CN202011002247 A CN 202011002247A CN 114427385 A CN114427385 A CN 114427385A
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- 238000002347 injection Methods 0.000 title claims abstract description 60
- 239000007924 injection Substances 0.000 title claims abstract description 60
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 48
- 238000000034 method Methods 0.000 title claims abstract description 22
- 239000007789 gas Substances 0.000 claims abstract description 161
- 239000007788 liquid Substances 0.000 claims abstract description 144
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 46
- 239000003345 natural gas Substances 0.000 claims abstract description 23
- 238000011084 recovery Methods 0.000 claims abstract description 12
- 230000001105 regulatory effect Effects 0.000 claims abstract description 5
- 239000003921 oil Substances 0.000 claims description 109
- 239000000203 mixture Substances 0.000 claims description 36
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 28
- 239000012530 fluid Substances 0.000 claims description 24
- 239000003112 inhibitor Substances 0.000 claims description 12
- 229930195733 hydrocarbon Natural products 0.000 claims description 7
- 150000002430 hydrocarbons Chemical class 0.000 claims description 7
- 230000008569 process Effects 0.000 claims description 7
- 238000012937 correction Methods 0.000 claims description 6
- 238000012360 testing method Methods 0.000 claims description 6
- 239000000126 substance Substances 0.000 claims description 5
- 239000010426 asphalt Substances 0.000 claims description 4
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 claims description 4
- 239000010428 baryte Substances 0.000 claims description 4
- 229910052601 baryte Inorganic materials 0.000 claims description 4
- 238000005260 corrosion Methods 0.000 claims description 4
- 230000007797 corrosion Effects 0.000 claims description 4
- 239000010779 crude oil Substances 0.000 claims description 4
- 239000002283 diesel fuel Substances 0.000 claims description 4
- 239000003350 kerosene Substances 0.000 claims description 4
- 230000003068 static effect Effects 0.000 claims description 4
- 208000002430 Multiple chemical sensitivity Diseases 0.000 claims description 3
- 230000001133 acceleration Effects 0.000 claims description 3
- 238000004364 calculation method Methods 0.000 claims description 3
- 230000005484 gravity Effects 0.000 claims description 3
- 239000003595 mist Substances 0.000 claims 2
- 238000010586 diagram Methods 0.000 description 3
- 238000000605 extraction Methods 0.000 description 3
- 230000009467 reduction Effects 0.000 description 2
- 239000000654 additive Substances 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 230000005514 two-phase flow Effects 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/122—Gas lift
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/122—Gas lift
- E21B43/123—Gas lift valves
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Abstract
The embodiment of the invention discloses a gas lift oil production gas injection pressure system and a method for reducing gas lift oil production gas injection pressure. Wherein, gas lift oil recovery gas injection pressure system includes: the device comprises an oil pipe device, a gas-liquid separator, a liquid storage tank, a natural gas compressor, an adjusting valve and a gas-liquid mixer; the outlet of the oil pipe device is communicated with the inlet of the gas-liquid separator, one outlet of the gas-liquid separator is communicated with the inlet of the liquid storage tank, the other outlet of the gas-liquid separator is communicated with the inlet of the natural gas compressor, a regulating valve is arranged on a pipeline communicating the gas-liquid separator with the natural gas compressor, the outlet of the natural gas compressor is communicated with one inlet of the gas-liquid mixer, and the other inlet of the gas-liquid mixer is communicated with the outlet of the liquid storage tank. The purpose of reducing the air injection pressure is achieved and the cost is low.
Description
Technical Field
The invention belongs to the technical field of oil and gas well production, and particularly relates to a gas lift oil production gas injection pressure system and a method for reducing gas lift oil production gas injection pressure.
Background
Methods for removing fluids from a well bore to maintain low bottom hole pressures and to increase or maintain well production include pumping units, electric pumps, screw pumps, gas lifts, and the like. Wherein gas lift oil recovery and gas lift flowing back all adopt the gas injection mode, reduce the density of output fluid, increase the velocity of flow to effectively realize the bottom of a well oil/water and effectively get rid of. To balance the bottom hole pressure, the gas needs to be compressed at the surface and injected at a higher pressure to achieve balance with the bottom hole pressure.
Currently, during gas lift production and gas lift drainage, the following situations generally occur:
1. for a compact oil-gas reservoir or shale oil-gas production initial-stage pressure is high, but the pressure decreasing speed is very fast, a compressor with high pressure grade is needed to be adopted for designing a gas lift process according to the initial production pressure, and the input cost is high. And as the pressure is rapidly reduced, a compressor with high pressure grade is still adopted, so that the energy consumption is high. If a compressor with a low pressure grade is selected in the initial stage, the production when the initial pressure is high is difficult to realize;
2. in the gas lift liquid drainage production process of deep and ultra-deep oil and gas wells, the grade requirement of the compressor is high, and high requirements are provided for production and ground equipment matching.
3. And in the process of doping the thin oil into the thick oil, simultaneously injecting natural gas into the annular space and evaluating the ground gas injection pressure of the thin oil.
Based on the above situation, a higher-grade compressor and ground corollary equipment need to be equipped, which results in high ground equipment investment in the implementation process of the gas lift process. The air pressure of the oil sleeve ring is balanced in the gas lift production process, and how to reduce the sleeve pressure under a certain oil pressure condition, namely the reduction of the gas lift pressure, is favorable for reducing the pressure grade of a ground pipeline network and the pressure grade of a natural gas compressor.
The prior art mainly reduces the starting pressure during gas lift by arranging the gas lift valve on the pipe column and changing the number of the gas lift valve, the number of the gas lift valve in gas lift design and the like, thereby reducing the ground investment. The method can reduce the gas injection pressure to a certain extent but has limited amplitude under the influence of interference between gas lift valves, complexity of a gas lift pipe column and the like.
Disclosure of Invention
In view of this, the embodiment of the present invention provides a gas lift oil recovery gas injection pressure system and a method for reducing gas lift oil recovery gas injection pressure, which at least solve the problems of limited gas injection pressure reduction and high cost in the prior art.
In a first aspect, an embodiment of the present invention provides a gas lift oil production and gas injection pressure system, including:
the device comprises an oil pipe device, a gas-liquid separator, a liquid storage tank, a natural gas compressor, an adjusting valve and a gas-liquid mixer;
the outlet of the oil pipe device is communicated with the inlet of the gas-liquid separator, one outlet of the gas-liquid separator is communicated with the inlet of the liquid storage tank, the other outlet of the gas-liquid separator is communicated with the inlet of the natural gas compressor, a regulating valve is arranged on a pipeline communicating the gas-liquid separator with the natural gas compressor, the outlet of the natural gas compressor is communicated with one inlet of the gas-liquid mixer, and the other inlet of the gas-liquid mixer is communicated with the outlet of the liquid storage tank.
Optionally, the oil pipe device includes:
the oil pipe is arranged in the oil sleeve, and an oil sleeve annulus is formed between the inner wall of the oil sleeve and the outer wall of the oil pipe.
Optionally, a gas-liquid mixture generated by mixing the compressed gas of the natural gas compressor and the liquid in the liquid storage tank through the gas-liquid mixer is injected into the bottom of the well through an oil pipe device, and the gas-liquid mixture is discharged to the ground through the oil pipe device after being mixed with a bottom-hole product.
Optionally, the liquid in the liquid storage tank includes:
wellbore production fluids hydrocarbons, water, and/or oilfield chemical aids; the wellbore produced liquid hydrocarbons include crude oil, kerosene and/or diesel oil; the water comprises mineralized water and/or weighted water added with barite; the oilfield chemical aid comprises a corrosion inhibitor, a wax inhibitor, an asphalt inhibitor and/or a scale remover.
Optionally, the gas-liquid mixture is fully mixed at the wellhead to form a stable fog or annular fog flow structure.
Optionally, the gas-liquid mixture is mixed at the wellhead to form a pressure loss of 0-0.5 MPa.
In a second aspect, an embodiment of the present invention further provides a method for reducing gas injection pressure in gas lift oil production, where the system described in any one of the first aspects is used, and includes:
keeping the liquid level in the oil pipe device balanced, wherein the liquid level balance is in a gas-liquid layered static state;
injecting a gas-liquid mixture mixed at a wellhead into the shaft through an oil pipe device;
continuously injecting the gas-liquid mixture to enable the pure liquid level in the oil pipe device to descend, enabling the pure liquid level in the oil pipe device and the injection section of the gas-liquid mixture to be close to the oil pipe injection position or the gas lift valve position, and enabling the gas lift valve to be arranged in the oil pipe device;
continuously injecting the gas-liquid mixture, so that the gas-liquid mixture in the oil pipe device enters a production channel through a gas lift valve or an injection point arranged on the oil pipe and is mixed with liquid reserved in a shaft or fluid produced from a stratum;
and after the injection pressure is observed to be slightly reduced and the gas production rate of the production channel is obviously increased, high-pressure gas or pure gas phase with reduced liquid content is continuously injected into the shaft through the oil pipe device.
Optionally, the method includes:
the gas lift pressure is reduced in the process of injecting gas-liquid mixture into a well bore through an oil pipe device, wherein the calculation formula of the gas lift pressure is as follows:
pinj＝pwh+ΔpGLV+Δpf+(ρtb-pan)gL，
wherein p iswhIs wellhead oil pressure, Δ pGLVFor pressure loss through the gas lift valve,. DELTA.pfFor friction loss, g is the acceleration of gravity, L is the gas lift valve depth, ρtbIs the average density, p, of the mixed fluid in the production channelanFor the density of the fluid injected into the channel, pinjIs gas lift pressure.
Alternatively to this, the first and second parts may,
ΔpGLV＝P1R
consider the throttle correction factor as:
wherein:
qscis the standard condition volume flow through the nozzle tip; p1The pressure at the front end of the oil nozzle; a. thecIn order for the gas to pass through the effective area of the oil nozzle,
εslipethe correction coefficient for the air-water slippage is obtained,
T1is the temperature before the mouth; z1Is T1And P1A coefficient of variation under conditions; gamma raymIs the gas phase relative density; kappa is the gas adiabatic index; r is the ratio of the rear end pressure to the front end pressure of the oil nozzle; x is the number ofgIs the mass percent of the gas phase, pmDensity of the gas-water mixture; rhom＝ρg(1-ε)+ρwε，ρwIs the density of water; rhogIs the density of the gas; epsilon is the liquid holding rate,
d is the diameter of the gas lift valve hole; q. q.swWater yield during the test gas period; q. q.sgThe gas yield during the test gas period.
Alternatively to this, the first and second parts may,
wherein R isL/GAlpha is a fitting constant for the injection liquid-gas ratio.
The gas lift oil extraction gas injection pressure system of the invention utilizes a gas-liquid two-phase mixed flow mechanism to reduce the gas injection pressure of the gas lift well, thereby reducing the investment cost of a ground pipe network and the grade of a compressor, and achieving the purposes of improving the capability of reducing the gas injection pressure and reducing the cost.
Additional features and advantages of the invention will be set forth in the detailed description which follows.
Drawings
The above and other objects, features and advantages of the present invention will become more apparent by describing in more detail exemplary embodiments thereof with reference to the attached drawings, in which like reference numerals generally represent like parts throughout.
FIG. 1 shows a schematic block diagram of a gas lift oil recovery gas injection pressure system of one embodiment of the present invention;
FIG. 2 is a schematic diagram illustrating a wellhead fluid injection pattern and fluid change characteristics in a wellbore in a method of reducing gas lift production gas injection pressure according to an embodiment of the present invention;
FIG. 3 is a schematic diagram showing the relationship between injection pressure gradient and liquid-to-gas ratio for one embodiment of the present invention;
wherein, 1, oil pipe; 2. an oil jacket annulus; 3. a gas-liquid separator; 4. a liquid storage tank; 5. a natural gas compressor; 6. adjusting the valve; 7. a gas-liquid mixer.
Detailed Description
Preferred embodiments of the present invention will be described in more detail below. While the following describes preferred embodiments of the present invention, it should be understood that the present invention may be embodied in various forms and should not be limited by the embodiments set forth herein.
A gas lift oil recovery gas injection pressure system comprising:
the system comprises an oil pipe device, a gas-liquid separator 3, a liquid storage tank 4, a natural gas compressor 5, an adjusting valve 6 and a gas-liquid mixer 7;
the outlet of the oil pipe device is communicated with the inlet of the gas-liquid separator 3, one outlet of the gas-liquid separator 3 is communicated with the inlet of the liquid storage tank 4, the other outlet of the gas-liquid separator 3 is communicated with the inlet of the natural gas compressor 5, a regulating valve 6 is arranged on a pipeline communicating the gas-liquid separator 3 with the natural gas compressor 5, the outlet of the natural gas compressor 5 is communicated with one inlet of the gas-liquid mixer 7, and the other inlet of the gas-liquid mixer 7 is communicated with the outlet of the liquid storage tank 4.
Optionally, the oil pipe device includes:
the oil pipe 1 is arranged in the oil sleeve, and an oil sleeve annulus 2 is formed between the inner wall of the oil sleeve and the outer wall of the oil pipe 1.
Optionally, a gas-liquid mixture generated by mixing the compressed gas of the natural gas compressor 5 and the liquid in the liquid storage tank 4 through the gas-liquid mixer 7 is injected into the bottom of the well through an oil pipe device, and the gas-liquid mixture is discharged to the ground through the oil pipe device after being mixed with a bottom-hole product.
Optionally, the liquid in the liquid storage tank 4 comprises:
wellbore production fluids hydrocarbons, water, and/or oilfield chemical aids; the wellbore produced liquid hydrocarbons include crude oil, kerosene and/or diesel oil; the water comprises mineralized water and/or weighted water added with barite; the oilfield chemical aid comprises a corrosion inhibitor, a wax inhibitor, an asphalt inhibitor and/or a scale remover.
Optionally, the gas-liquid mixture is fully mixed at the wellhead to form a stable fog or annular fog flow structure.
Optionally, the gas-liquid mixture is mixed at the wellhead to form a pressure loss of 0-0.5 MPa.
The first embodiment is as follows:
as shown in fig. 1, a gas lift oil extraction and gas injection pressure system for reducing gas lift oil extraction and gas injection pressure comprises an oil pipe 1, a sleeve, a gas-liquid separator 3, a liquid storage tank 4, a natural gas compressor 5, a regulating valve 6, a gas-liquid mixer 7 and the like.
The liquid and the compressed gas are mixed by a gas-liquid mixer 7 and then injected into the well bottom from the oil sleeve annulus 2 or the oil pipe 1, and the injected gas-liquid mixture is mixed with the produced product at the well bottom and produced on the ground from the oil pipe 1 or the oil sleeve annulus 2.
Injecting gas-liquid two-phase mixed fluid, and increasing the pressure gradient of the shaft by using two-phase flow, wherein the liquid can be all related fluids such as shaft produced liquid hydrocarbons (crude oil, kerosene and diesel oil), water (mineralized water and weighted water added with barite), various oilfield chemical additives (corrosion inhibitor, wax inhibitor, asphalt inhibitor and scale remover) and the like.
The liquid and the high-pressure gas form a stable gas-liquid mixture through gas-liquid mixed gas, and the stable gas-liquid mixture is conveyed and injected into the oil sleeve annulus 2 or the oil pipe 1 through a pipeline.
The gas-liquid fluid is fully mixed at a wellhead to form a stable fog or annular fog flow structure, and the gas-liquid fluid is mixed at the wellhead to form pressure loss of 0-0.5 MPa.
Example two:
a method of reducing gas lift production gas injection pressure, comprising:
keeping the liquid level in the oil pipe device balanced, wherein the liquid level balance is in a gas-liquid layered static state;
injecting a gas-liquid mixture mixed at a wellhead into the shaft through an oil pipe device;
continuously injecting the gas-liquid mixture to enable the pure liquid level in the oil pipe device to descend, enabling the pure liquid level in the oil pipe device and the injection section of the gas-liquid mixture to be close to the oil pipe injection position or the gas lift valve position, and enabling the gas lift valve to be arranged in the oil pipe device;
continuously injecting the gas-liquid mixture, so that the gas-liquid mixture in the oil pipe device enters a production channel through a gas lift valve or an injection point arranged on the oil pipe and is mixed with liquid reserved in a shaft or fluid produced from a stratum;
and after the injection pressure is observed to be slightly reduced and the gas production rate of the production channel is obviously increased, high-pressure gas or pure gas phase with reduced liquid content is continuously injected into the shaft through the oil pipe device.
As shown in fig. 2, the gas lift process for reducing the gas lift oil production gas injection pressure includes the following five steps:
1. as shown in (1) in fig. 2, the liquid level in the air of the oil pipe and the oil sleeve ring is balanced and is in a gas-liquid layered static state;
2. injecting a gas-liquid two-phase mixture mixed by a wellhead into the shaft from one of the channels as shown in (2) in FIG. 2;
3. continuing to inject as shown in (3) in fig. 2, lowering the pure liquid level in the oil sleeve annulus, approaching the injection position of the tubular column or the position of the gas lift valve with the mixed injection section of the two phases, and observing that the production port continuously produces single-phase or low-gas-content liquid;
4. continuously injecting as shown in (4) in fig. 2, wherein the oil-jacket-ring aerial two-phase mixed fluid enters the production channel through an injection point arranged on a gas lift valve or a pipe column to be mixed with the liquid reserved in the shaft or the stratum produced fluid, so that the substance mixed with the liquid reserved in the shaft or the stratum produced fluid is produced to the ground, the injection pressure is observed to be slightly reduced, and the gas production rate of the production channel is obviously increased;
5. high-pressure gas for reducing the liquid content is continuously injected or pure gas phase is injected as a gas lift energy source to keep normal production as shown in (5) in figure 2.
A brief calculation method for reducing gas lift pressure in a gas lift production process comprises the following steps:
pinj＝pwh+ΔpGLV+Δpf+(ρtb-pan)gL
wherein p iswhIs wellhead oil pressure, Δ pGLVFor pressure loss through the gas lift valve,. DELTA.pfFor frictional losses, g is the acceleration of gravity, L is the gas lift point depth, ρtbIs the average density, p, of the mixed fluid in the production channelanIs the density of the fluid in the injection channel.
Wherein,
ΔpGLV＝P1R
consider the throttle correction factor as:
wherein:
qscfor standard volume flow through the nozzle tip, 104m3/d；
P1The pressure at the front end of the oil nozzle is MPa;
Acis the effective area of gas passing through the nozzle tip, mm2，
εslipeThe correction coefficient for the air-water slippage is obtained,
T1is the temperature before the mouth, K;
Z1the deviation coefficients under the conditions of T1 and P1;
γmis the gas phase relative density;
kappa is the gas adiabatic index;
r is the ratio of the pressure at the rear end of the nozzle tip to the pressure at the front end of the nozzle tip.
xgIs the mass percent of gas phase
ρmIs the density of a gas-water mixture, kg/m3，ρm＝ρg(1-ε)+ρwε；
ρwIs the density of water, kg/m3；
ρgIs the density of the gas, kg/m3；
Epsilon is the liquid holding rate,
d is the diameter of the gas lift valve hole;
qwfor water production during the test period, m3/d；
qgFor testing the period of qiYield, 104m3/d；
Density of fluid in injection channel:
The calculated pressure gradient versus water-to-gas ratio relationship is shown in fig. 3.
Having described embodiments of the present invention, the foregoing description is intended to be exemplary, not exhaustive, and not limited to the embodiments disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the described embodiments.
Claims (10)
1. The utility model provides a gas lift oil recovery gas injection pressure system which characterized in that includes:
the device comprises an oil pipe device, a gas-liquid separator, a liquid storage tank, a natural gas compressor, an adjusting valve and a gas-liquid mixer;
the outlet of the oil pipe device is communicated with the inlet of the gas-liquid separator, one outlet of the gas-liquid separator is communicated with the inlet of the liquid storage tank, the other outlet of the gas-liquid separator is communicated with the inlet of the natural gas compressor, a regulating valve is arranged on a pipeline communicating the gas-liquid separator with the natural gas compressor, the outlet of the natural gas compressor is communicated with one inlet of the gas-liquid mixer, and the other inlet of the gas-liquid mixer is communicated with the outlet of the liquid storage tank.
2. The gas lift oil recovery gas injection pressure system of claim 1, wherein the oil pipe means comprises:
the oil pipe is arranged in the oil sleeve, and an oil sleeve annulus is formed between the inner wall of the oil sleeve and the outer wall of the oil pipe.
3. The gas lift oil recovery and gas injection pressure system according to claim 1 or 2, wherein a gas-liquid mixture generated by mixing the compressed gas of the natural gas compressor and the liquid in the liquid storage tank through the gas-liquid mixer is injected into the bottom of the well through an oil pipe device, and the gas-liquid mixture is discharged to the surface of the ground after being mixed with the bottom-hole output.
4. The gas lift oil recovery gas injection pressure system of claim 3, wherein the liquid in the liquid storage tank comprises:
wellbore production fluids hydrocarbons, water, and/or oilfield chemical aids; the wellbore produced liquid hydrocarbons include crude oil, kerosene and/or diesel oil; the water comprises mineralized water and/or weighted water added with barite; the oilfield chemical aid comprises a corrosion inhibitor, a wax inhibitor, an asphalt inhibitor and/or a scale remover.
5. The gas lift oil recovery gas injection pressure system of claim 3, wherein the gas-liquid mixture is well mixed at the wellhead to form a stable mist or annular mist flow structure.
6. The gas lift oil recovery gas injection pressure system of claim 5, wherein the gas-liquid mixture is mixed at the wellhead with a pressure loss of 0-0.5 MPa.
7. A method of reducing gas lift production gas injection pressure using the system of any one of claims 1-6, comprising:
keeping the liquid level in the oil pipe device balanced, wherein the liquid level balance is in a gas-liquid layered static state;
injecting a gas-liquid mixture mixed at a wellhead into the shaft through an oil pipe device;
continuously injecting the gas-liquid mixture to enable the pure liquid level in the oil pipe device to descend, enabling the pure liquid level in the oil pipe device and the injection section of the gas-liquid mixture to be close to the oil pipe injection position or the gas lift valve position, and enabling the gas lift valve to be arranged in the oil pipe device;
continuously injecting the gas-liquid mixture, so that the gas-liquid mixture in the oil pipe device enters a production channel through a gas lift valve or an injection point arranged on the oil pipe and is mixed with liquid reserved in a shaft or fluid produced from a stratum;
and after the injection pressure is observed to be slightly reduced and the gas production rate of the production channel is obviously increased, high-pressure gas or pure gas phase with reduced liquid content is continuously injected into the shaft through the oil pipe device.
8. The method of reducing gas lift production gas injection pressure of claim 7, comprising:
the gas lift pressure is reduced in the process of injecting gas-liquid mixture into a well bore through an oil pipe device, wherein the calculation formula of the gas lift pressure is as follows:
pinj＝pwh+ΔpGLV+Δpf+(ρtb-pan)gL，
wherein p iswhIs wellhead oil pressure, Δ pGLVFor pressure loss through the gas lift valve,. DELTA.pfFor friction loss, g is the acceleration of gravity, L is the gas lift valve depth, ρtbIs the average density, p, of the mixed fluid in the production channelanFor the density of the fluid injected into the channel, pinjIs gas lift pressure.
9. The method of reducing gas lift production gas injection pressure according to claim 8,
ΔpGLV＝P1R
consider the throttle correction factor as:
wherein:
qscis the standard condition volume flow through the nozzle tip; p1The pressure at the front end of the oil nozzle; a. thecIn order for the gas to pass through the effective area of the oil nozzle,
εslipethe correction coefficient for the air-water slippage is obtained,
T1is the temperature before the mouth; z1Is T1And P1A coefficient of variation under conditions; gamma raymIs the gas phase relative density; kappa is the gas adiabatic index; r is the ratio of the rear end pressure to the front end pressure of the oil nozzle; x is the number ofgIs the mass percent of the gas phase, pmIs the density of the gas-water mixture; rhom＝ρg(1-ε)+ρwε，ρwIs the density of water; rhogIs the density of the gas; epsilon is the liquid holding rate,
d is the diameter of the gas lift valve hole; q. q.swWater yield during the test gas period; q. q.sgThe gas yield during the test gas period.
10. The method of reducing gas lift production gas injection pressure according to claim 8,
wherein R isL/GThe injection liquid-gas ratio is adopted; α is a fitting constant.
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| CN117948103A (en) * | 2024-03-25 | 2024-04-30 | 洛阳宏润塑业有限公司 | Oilfield gas production pressurization system and process thereof |
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| EP2907965A1 (en) * | 2014-02-17 | 2015-08-19 | Nederlandse Organisatie voor toegepast- natuurwetenschappelijk onderzoek TNO | Gas well deliquification |
| CN108386175A (en) * | 2018-03-29 | 2018-08-10 | 中国石油化工股份有限公司 | A kind of super-viscous oil natural gas injection and the compound viscosity reducing process of thin oil |
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| CN117948103A (en) * | 2024-03-25 | 2024-04-30 | 洛阳宏润塑业有限公司 | Oilfield gas production pressurization system and process thereof |
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