CN111472733B - Intelligent intermittent drainage gas production system and control method thereof - Google Patents
Intelligent intermittent drainage gas production system and control method thereof Download PDFInfo
- Publication number
- CN111472733B CN111472733B CN202010496148.4A CN202010496148A CN111472733B CN 111472733 B CN111472733 B CN 111472733B CN 202010496148 A CN202010496148 A CN 202010496148A CN 111472733 B CN111472733 B CN 111472733B
- Authority
- CN
- China
- Prior art keywords
- pressure
- well
- gas
- oil
- opening
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000000034 method Methods 0.000 title claims abstract description 78
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 71
- 239000007788 liquid Substances 0.000 claims abstract description 55
- 238000004364 calculation method Methods 0.000 claims abstract description 10
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 5
- 238000009825 accumulation Methods 0.000 claims abstract description 3
- 238000005259 measurement Methods 0.000 claims description 26
- 239000012528 membrane Substances 0.000 claims description 22
- 230000001105 regulatory effect Effects 0.000 claims description 18
- 239000012530 fluid Substances 0.000 claims description 13
- 238000011084 recovery Methods 0.000 claims description 10
- 238000005457 optimization Methods 0.000 claims description 9
- 238000004891 communication Methods 0.000 claims description 7
- 239000004973 liquid crystal related substance Substances 0.000 claims description 6
- 230000010354 integration Effects 0.000 claims description 5
- 238000000691 measurement method Methods 0.000 claims description 5
- 238000000195 production control method Methods 0.000 claims description 5
- 230000008901 benefit Effects 0.000 abstract description 9
- 238000007710 freezing Methods 0.000 abstract description 8
- 230000008014 freezing Effects 0.000 abstract description 7
- 230000008859 change Effects 0.000 abstract description 6
- 230000000903 blocking effect Effects 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 74
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 6
- 230000008569 process Effects 0.000 description 5
- 230000007547 defect Effects 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 230000005358 geomagnetic field Effects 0.000 description 3
- 239000003345 natural gas Substances 0.000 description 3
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 230000035939 shock Effects 0.000 description 2
- 239000010409 thin film Substances 0.000 description 2
- 238000013459 approach Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000004880 explosion Methods 0.000 description 1
- 230000004927 fusion Effects 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 238000003825 pressing Methods 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 238000005070 sampling Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
Images
Classifications
-
- 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
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/02—Valve arrangements for boreholes or wells in well heads
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/16—Control means therefor being outside the borehole
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
- Y02P90/02—Total factory control, e.g. smart factories, flexible manufacturing systems [FMS] or integrated manufacturing systems [IMS]
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Control Of Non-Electrical Variables (AREA)
Abstract
The invention discloses an intelligent intermittent drainage gas production system and a control method thereof, wherein the height of a liquid column of a gas well, the gas production rate and the liquid production rate in single operation are calculated, and whether the production operation is optimized or not is judged; according to the calculation result, optimizing the result of the shut-in time by adopting a minimum casing pressure method and a pressure speed change method, determining the shut-in time, and operating the new shut-in time; according to the calculation result, optimizing the well opening time result by adopting a casing pressure microliter method and a pressure velocity ratio method, determining the well opening time length, and operating new well opening time; respectively calculating the liquid accumulation amount, the daily gas production and the daily water production of the barrel well by adopting a shaft volume method; according to the result, the opening degree of the valve is respectively judged by adopting a direct method and an indirect method, and the control is completed by accurately measuring the opening degree of the valve. The invention uses the most effective control mode for each gas well, has the advantages of preventing freezing and blocking, improving the production efficiency of each well and generating greater economic benefit.
Description
Technical Field
The invention belongs to the technical field of natural gas exploitation, and particularly relates to an intelligent intermittent drainage gas production system and a control method thereof.
Background
The method is widely applied to natural gas exploitation and is an important process for gas well drainage and gas production. In the middle and later stages of gas well production, due to low bottom pressure and gas production rate and poor liquid carrying capacity of the gas well, accumulated liquid in a shaft is continuously increased to seriously affect the normal production of the gas well, even the phenomenon of accumulated liquid production stop occurs in part of the gas well, and the intermittent drainage gas production system can realize well opening and closing and ensure the normal and efficient production of the gas well.
The intermittent drainage gas production system is a production process used in natural gas exploitation, the existing intermittent drainage gas production system can only be in a simple mode, cannot form efficient control according to the well condition of a real-time gas well, is low in gas production efficiency, and is easy to generate freezing blockage (interception effect) because the opening cannot be accurately measured in the well exploitation process.
Disclosure of Invention
The technical problem to be solved by the invention is to provide an intelligent intermittent drainage gas production system and a control method thereof aiming at the defects in the prior art, wherein the intelligent intermittent drainage gas production system has an intelligent mode, can use the most effective control mode aiming at each gas well, and also has the advantages of freezing blockage prevention, improvement of the production efficiency of each well and greater economic benefit.
The invention adopts the following technical scheme:
an intelligent intermittent drainage gas production control method comprises the following steps:
s1, calculating the height of a liquid column of the gas well, the gas production rate and the liquid production rate in single operation, and judging whether to optimize the production operation;
s2, according to the calculation result of the step S1, optimizing the result of the well closing time by adopting a minimum casing pressure method and a pressure variable rate method, determining the well closing time length, and operating new well closing time;
s3, according to the calculation result of the step S1, optimizing the well opening time result by adopting a casing pressure microliter method and a pressure variable rate method, determining the well opening time length, and operating new well opening time;
s4, respectively calculating the liquid accumulation volume, the daily gas production and the daily water production of the barrel well by adopting a shaft volume method;
and S5, judging the opening degree of the valve by adopting a direct method and an indirect method according to the results of the steps S2, S3 and S4, and finishing control by accurately measuring the opening degree of the valve.
Specifically, in step S1, the production operation is optimized when the current gas production rate or liquid production rate is less than 5% to 10% of the previous gas production rate or liquid production rate.
Specifically, in step S2, by setting a step size for the oil casing pressure data obtained during the well opening period, when the step size is greater than 0, the casing pressure starts to rise, or when the step size infinitely approaches 0, the oil casing pressure returns to the maximum, and the well closing time is determined by using a pressure optimization method; the method comprises the steps of observing oil casing pressure according to a set step length on oil casing pressure data obtained in the well closing period to obtain a back pressure rate, finishing quick pressure recovery when the back pressure rate is smaller than a set value, entering a slow recovery period, opening the well at the moment, and constraining results of a minimum casing pressure method and a pressure optimization method through a pressure-variable-rate method.
Further, the pressure optimization method determines the casing pressure difference P in the well closing timecxSum oil pressure difference PoxThe calculation is as follows:
Pcx＝|Pci+n-Pci|
Pox＝|Poi+n-Poi|
wherein, PciThe ith casing pressure is obtained; pci+nThe number of the sleeve pressure is i + n; n is an integration step length; poiIs the ith oil pressure; poi+nI + n oil pressures.
Specifically, in step S3, when the upper liquid level reaches the wellhead, the wellhead casing pressure corresponding to the upper liquid level is the minimum working casing pressure, and the minimum casing pressure is calculated as follows:
Pcmin＝(Pp+Ptf+Pa+(Plw+Plf)*L)
wherein, PcminIs the minimum casing pressure; ppThe pressure required for lifting; ptfOil pressure of a well head; paIs at atmospheric pressure; plwTo lift by 1m3The pressure required by the liquid column to the wellhead; plfLost pressure due to fluid friction; l is the lift liquid volume.
Specifically, in step S4, the volume of the wellbore fluid column is:
Pcg+ρw*g*hcw＝Ptg+ρw*g*htw
wherein h istwThe height of the oil pipe liquid column at the communication part of the oil sleeve, PcgThe pressure of a gas column at the liquid level of the oil sleeve annulus is defined as rho w, g and hcwIs a height, PtgIs the gas column pressure at the oil pipe liquid level, PgIs well low pressure, P is well head pressure, hw is liquid column height;
the single-run liquid production capacity is as follows:
V＝V1-V2
V1＝htw1*π*Φt 2/4+hcw1*π*(Φc 2-Φt 2)/4
V2＝htw2*π*Φt 2/4+hcw2*π*(Φc 2-Φt 2)/4
wherein V is the single-run liquid production amount; v1Is the well bore fluid column volume before well opening; v2The volume of the wellbore fluid column after closing the well; h istw1The height of the oil pipe gas column before well opening; h iscw1The lower depth of the casing gas column before well opening; h istw2The height of the oil pipe gas column after the well is shut in; h iscw2The lower depth of the casing gas column after closing the well;
the gas yield in single operation is as follows:
Q＝Q1+Q2
Q1＝(Ptmax-Ptmin)*htg*π*Φt 2/4+(Pcmax-Pcmin)*hcg*π*(Φc 2-Φt 2)/4
Q2＝P'*t*htg*π*Φt 2/4+P'*t*hcg*π*(Φc 2-Φt 2)/4
wherein Q is the single-run gas production; q1Producing gas for wellbore pressure drop; q2Supplying gas production to the stratum; ptmaxThe oil pressure is the oil pressure of the well opening, namely the maximum value of the oil pressure; ptminFor shut-in oil pressure, PcmaxAt maximum casing pressure, PcminIs the minimum casing pressure; p' is a stratum replenishment rate during well opening, and the value is equal to the maximum value of the casing pressure recovery rate after well closing; t is the well opening time; h istgIs the height of the oil pipe gas column; h iscgThe lower depth of the sleeve gas column; phitThe inner diameter of the oil pipe; phicIs the inner diameter of the oil pipe.
Specifically, in step S5, the stability of the direct measurement method and the indirect measurement method in the past K cycles is calculated according to the variance characteristics, the variance value of the direct measurement result and the indirect measurement result is obtained and is inverted, the weight and the weight proportion occupied by each of the direct measurement result and the indirect measurement result are obtained, the angle values of the angle values are obtained according to the weight ratio, and finally the angle values are added together to form the final opening value θ.
Further, the final opening value θ is:
wherein U is the sum of the direct-measured inverse variance and the indirect-measured inverse variance, θzFor direct measurement of opening, UzFor direct measurement of the inverse of the variance, UjFor indirect measurement of the inverse of the variance, θjIs an indirect measurement of the opening.
The intelligent intermittent drainage and gas production control method comprises a controller, wherein the controller is respectively connected with a first digital pressure sensor, a second digital pressure sensor and a third digital pressure sensor and is used for acquiring the pressure value of a gas well and the liquid level data of the gas well by connecting a flow sensor; the controller is connected with the liquid crystal module and the keys for operation control, and is connected with the pneumatic membrane regulating valve through the battery valve; the controller is connected with the server through the communication module and used for uploading data in real time and receiving commands issued by the server.
Compared with the prior art, the invention has at least the following beneficial effects:
according to the intelligent intermittent drainage gas production control method, the opening degree is ensured by adopting an opening degree direct method and an opening degree indirect method, the opening degree of the valve is controlled in the well opening process, and meanwhile, the opening degree of the valve is controlled by monitoring gas flow and temperature data, so that freezing blockage is prevented.
Furthermore, an intelligent gas well switching method is adopted, so that the gas well is switched on and off more efficiently, and the gas production rate is improved to the maximum extent.
According to the intelligent intermittent drainage gas production system, an intelligent adjusting mode is added, and the gas well can be controlled to be opened and closed in real time according to well conditions.
In conclusion, each gas well uses the most effective control mode, so that the anti-freezing and anti-blocking device has the advantages of preventing freezing and blocking, improving the production efficiency of each well and generating greater economic benefit.
The technical solution of the present invention is further described in detail by the accompanying drawings and embodiments.
Drawings
FIG. 1 is a schematic diagram of the system connection of the present invention;
FIG. 2 is a flow chart of the intelligent control of the present invention.
Wherein: 1. a controller; 2. pressing a key; 3. a liquid crystal module; 4. a communication module; 5. a server; 6. an electromagnetic valve; 7, a pneumatic membrane regulating valve; 8. a flow sensor; 9. a first digital pressure sensor; 10. a liquid level sensor; 11. a magnetic force sensor; 12. a second digital pressure sensor; 13. a third digital pressure sensor.
Detailed Description
In the description of the present invention, it should be noted that, unless otherwise explicitly specified or limited, the terms "mounted," "connected," and "connected" are to be construed broadly, e.g., as meaning either a fixed connection, a removable connection, or an integral connection; can be mechanically or electrically connected; they may be connected directly or indirectly through intervening media, or they may be interconnected between two elements. The specific meanings of the above terms in the present invention can be understood in specific cases to those skilled in the art.
Referring to fig. 1, the intelligent intermittent drainage gas production system of the present invention includes a controller 1, a key 2, a liquid crystal module 3, a communication module 4, a server 5, an electromagnetic valve 6, a pneumatic membrane regulating valve 7, a flow sensor 8, a first digital pressure sensor 9, a liquid level sensor 10, a magnetic sensor 11, a second digital pressure sensor 12, and a third digital pressure sensor 13.
The first digital pressure sensor 9 is used for measuring oil pressure, the second digital pressure sensor 12 is used for measuring casing pressure, and the third digital pressure sensor 13 is used for measuring pressure behind a valve; the controller 1 respectively collects pressure values of the gas well through the first digital pressure sensor 9, the second digital pressure sensor 12 and the third digital pressure sensor 13, collects liquid level data of the gas well through the flow sensor 8, meanwhile, the controller 1 conducts well opening and closing actions according to modes set by the liquid crystal module 3 and the keys 2, uploads data to the server 5 in real time through the communication module 4, and receives commands sent by the server 5.
The controller 1 fills gas into the pneumatic membrane regulating valve 7 and exhausts the gas through opening and closing the battery valve 6, so that the pneumatic membrane regulating valve is opened and closed, and the process of water drainage and gas production is completed.
Referring to fig. 2, the intelligent intermittent drainage gas recovery control method of the present invention includes the following steps:
s1, calculating the height of a liquid column of the gas well, the gas production rate and the liquid production rate in single operation, and optimizing the well closing time and the well opening time respectively if the production operation needs to be optimized;
s2, optimizing the result of the shut-in time by adopting a minimum casing pressure method and a pressure variable rate method, determining the shut-in time, operating the new shut-in time, and returning to the recalculation if the reasonable shut-in time is not calculated;
determining the well closing time by a pressure optimization method;
by observing the change of the oil casing pressure data obtained during the well opening in a certain step (integral), when the change is larger than 0, the return is considered to be maximized when the casing pressure starts to rise or when the change is infinitely close to 0.
Pcx＝Pci+n-Pci
Pox＝Poi+n-Poi
Wherein, PciThe ith sleeve pressure is adopted; pci+nThe number of the sleeve pressure is i + n; n is an integration step length; poiIs the ith oil pressure; poi+nIs the (i + n) th oil pressure; n is the integration step.
The pressure variable rate method restrains the results of the minimum sleeve pressure method and the pressure optimization method;
and observing the oil casing pressure according to a certain step length (integral) of the oil casing pressure data obtained in the well closing period to obtain the back pressure rate, and when the back pressure rate is smaller than a certain value (0.005MPa), considering that the quick pressure recovery is finished, entering a slow recovery period, and opening the well at the moment.
Pressure difference P of jacketcxSum oil pressure difference PoxThe calculation is as follows:
Pcx＝|Pci+n-Pci|
Pox＝|Poi+n-Poi|
wherein, PciThe ith sleeve pressure is adopted; pci+nThe number of the sleeve pressure is i + n; n is an integration step length; poiIs the ith oil pressure; poi+nIs the (i + n) th oil pressure.
S3, optimizing the result of the well opening time by adopting a casing pressure microliter method and a pressure velocity ratio method, determining the well opening time, operating the new well opening time, and returning to the recalculation if the reasonable well closing time is not calculated;
determining the well opening time by a minimum casing pressure method;
when the upper liquid level reaches the wellhead, the corresponding wellhead casing pressure is the minimum working casing pressure, and the minimum casing pressure is calculated as follows:
Pcmin＝(Pp+Ptf+Pa+(Plw+Plf)*L)
wherein, PcminIs the minimum casing pressure; ppThe pressure required for lifting; ptfOil pressure of a well head; paIs at atmospheric pressure; plwTo lift by 1m3The pressure required by the liquid column to the wellhead; plfIs the loss pressure caused by fluid friction; l is the lift liquid volume.
S4, calculating the liquid volume of the shaft, the daily gas production and the daily water production by using a shaft volume method;
the volume of the shaft liquid column is specifically as follows:
Pcg+ρw*g*hcw＝Ptg+ρw*g*htw
wherein h istwThe height of the oil pipe liquid column at the communicating part of the oil sleeve, PcgThe pressure of an air column at the annular liquid level of the oil sleeve is defined as rho w, g, hcwIs height, PtgIs the gas column pressure at the oil pipe liquid level, PgIs well low pressure, P is well head pressure, hw is liquid column height;
the liquid yield in single operation is as follows:
V＝V1-V2
V1＝htw1*π*Φt 2/4+hcw1*π*(Φc 2-Φt 2)/4
V2＝htw2*π*Φt 2/4+hcw2*π*(Φc 2-Φt 2)/4
wherein V is the single-run liquid production amount; v1Is the well bore fluid column volume before well opening; v2The volume of the wellbore fluid column after closing the well; h istw1The height of the oil pipe gas column before well opening; h iscw1The lower depth of the casing gas column before well opening; h istw2The height of the oil pipe gas column after the well is shut in; h iscw2The lower depth of the casing gas column after closing the well; phitThe inner diameter of the oil pipe; phicIs the inner diameter of the oil pipe.
The gas yield in single operation is as follows:
Q＝Q1+Q2
Q1＝(Ptmax-Ptmin)*htg*π*Φt 2/4+(Pcmax-Pcmin)*hcg*π*(Φc 2-Φt 2)/4
Q2＝P'*t*htg*π*Φt 2/4+P'*t*hcg*π*(Φc 2-Φt 2)/4
wherein Q is the single-run gas production; q1Producing gas for wellbore pressure drop; q2Supplying gas production to the stratum; ptmaxThe oil pressure is the oil pressure of the well opening, namely the maximum value of the oil pressure; ptminFor shut-in oil pressure, PcmaxAt maximum casing pressure, PcminThe minimum casing pressure, namely the minimum oil pressure; p' is a stratum replenishment rate during well opening, and the value is equal to the maximum value of the casing pressure recovery rate after well closing; t is the well opening time; h is a total oftgIs the height of the oil pipe gas column; h iscgThe lower depth of the sleeve gas column; phitThe inner diameter of the oil pipe; phicIs the inner diameter of the oil pipe.
S5, respectively judging the opening degree of the valve through two modes: the direct method and the indirect method complete control by accurately measuring the opening degree of the valve.
The indirect method judges the stroke of the valve rod by measuring the pressure of gas entering the pneumatic membrane valve cavity, and the stroke of the valve rod is converted by measuring the pressure borne by the membrane to determine the opening degree of the valve because the stroke of the valve rod is in direct proportion to the pressure value borne by the membrane in the pneumatic membrane valve cavity. The opening degree of the valve can be measured without directly contacting the valve rod, the reliability, the shock resistance and the explosion-proof performance are more excellent, and the defect that if the valve is frozen and blocked, the pressure of a diaphragm is increased but the valve rod does not act, misjudgment can occur.
The direct method measures the stroke of the valve rod by measuring the change rate of the geomagnetic field, thereby judging the opening degree of the valve. Because the valve rod belongs to the ferrous material, the stroke of the valve rod is judged by measuring the geomagnetic field distribution of the valve rod accessory by utilizing the principle that the movement of the ferrous material can change the geomagnetic field distribution of the accessory. The method can directly judge the stroke of the valve rod, is not influenced by the freezing and blocking condition of the valve, does not directly contact with the valve rod, has excellent reliability, shock resistance and explosion resistance, and has the defect of being influenced by magnetic substances such as magnets and the like changed by accessories.
The invention has advantages and disadvantages of direct method and indirect method, and can avoid interference of external factors and improve accuracy by data fusion of the two methods.
The frequency characteristics of a direct measurement method and a simple measurement method are used, the stability in the past K periods is calculated through variance characteristics, the more stable the signal is, the more credible the measured data is, the smaller the noise interference is, the angle value is taken according to the method according to the weight ratio, and finally the angle value is added together to form the final angle value.
The variance calculation method of the discrete signal (K cycles in the past) is as follows:
wherein S is variance, T is discrete value, M is average value, and K is sampling frequency.
The variance of the direct and indirect measurements over the past K cycles is calculated, i.e.: sz，SjFrom the characteristics of the variance, the smaller the value is, the more stable the value is, the calculated variance value of the direct measurement result and the indirect measurement result is reciprocal to obtain the weight and the weight proportion occupied by each, namely:
U＝Uz+Uj
calculating a final opening value according to the weight proportion occupied by each, namely:
wherein U is the sum of the direct measured inverse of variance and the indirect measured inverse of variance, θzFor direct measurement of opening, UzFor direct measurement of the inverse of the variance, UjFor indirect measurement of the inverse of the variance, θjIs an indirect measurement of the opening.
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are some, but not all, embodiments of the present invention. The components of the embodiments of the present invention generally described and illustrated in the figures herein may be arranged and designed in a wide variety of different configurations. Thus, the following detailed description of the embodiments of the present invention, presented in the figures, is not intended to limit the scope of the invention, as claimed, but is merely representative of selected embodiments of the invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The invention relates to an intelligent intermittent drainage gas production system.A control mode is set on site through a liquid crystal and a key, and the control mode comprises a manual mode, a constant pressure mode, a timing mode, a flow mode, a mixed mode, an opening mode and an intelligent mode. The system will operate according to the set mode.
1) Manual mode
Selecting a 'well opening' button, and opening a well by a pneumatic membrane regulating valve; and selecting a 'well closing' button, and closing the well by a pneumatic membrane regulating valve.
2) Constant pressure mode
When the casing pressure is greater than the set well opening pressure, the pneumatic membrane regulating valve performs well opening; and when the casing pressure is smaller than the set shut-in pressure, the pneumatic membrane regulating valve closes the well.
3) Flow pattern
When the current measured flow is larger than the set well opening flow, the pneumatic membrane regulating valve executes well opening; and waiting until the set parallel time, and then closing the well by the pneumatic membrane regulating valve.
4) Timing mode
When the time is the set well opening time, the pneumatic membrane regulating valve executes well opening; and when the time is the set shut-in time, the pneumatic membrane regulating valve executes shut-in.
5) Mixed mode
When the time is the set well opening time or the casing pressure is greater than the set well opening pressure, the pneumatic membrane regulating valve executes well opening; and when the time is the set shut-in time or the casing pressure is smaller than the set shut-in pressure, the pneumatic membrane regulating valve closes the well.
6) Opening degree pattern
Setting a preset opening degree, and when the actually measured opening degree is larger than the preset opening degree, reducing the opening degree of the pneumatic membrane regulating valve; and when the actual measurement opening degree is smaller than the preset opening degree, the pneumatic membrane regulating valve increases the opening degree.
7) Intelligent mode
Referring to fig. 2, after the start, the height of the wellbore fluid column and the single run gas production rate and fluid production rate are calculated; judging whether the production operation needs to be optimized; then, respectively optimizing the result of the well closing time and the result of the well opening time, determining the well closing time by adopting a minimum casing pressure method and a pressure velocity ratio method aiming at the optimization of the result of the well closing time, operating new well closing time, and recalculating if the reasonable well closing time is not calculated; and aiming at the optimization of the well opening time result, determining the well opening time by adopting a casing pressure microliter method and a pressure velocity ratio method, operating the new well opening time, and recalculating if the reasonable well opening time is not calculated.
In conclusion, the intelligent intermittent drainage gas production system provided by the invention has the advantages that the well opening and closing strategy is adjusted in real time by acquiring the values of oil pressure, casing pressure and pipeline flow in real time and by a minimum casing pressure method, a casing pressure microliter method and a pressure speed ratio method, so that the gas production and liquid production efficiency is improved; obtaining the gas production rate and the liquid production amount of each period by a shaft volume method, thereby judging the operation effect of the system and dislocating the feedback of the adjustment of the well switching strategy; the opening degree of the thin film valve is judged in a direct mode and an indirect mode so as to accurately feed back the opening degree of the thin film valve, accurately control the opening degree of the valve in the well opening process, reduce the throttling effect and avoid the freezing and blocking phenomena.
The above-mentioned contents are only for illustrating the technical idea of the present invention, and the protection scope of the present invention is not limited thereby, and any modification made on the basis of the technical idea of the present invention falls within the protection scope of the claims of the present invention.
Claims (4)
1. An intelligent intermittent drainage gas production control method is characterized by comprising the following steps:
s1, calculating the height of a liquid column of the gas well, the gas production rate and the liquid production rate in single operation, and judging whether to optimize the production operation;
s2, according to the calculation result of the step S1, the result of the shut-in time is optimized by adopting a minimum casing pressure method and a pressure variable rate method, the shut-in time length is determined, and the new shut-in time is operated, which specifically comprises the following steps:
the method comprises the steps that oil casing pressure data obtained in the well opening period are set according to a set step length, when the step length is larger than 0, casing pressure starts to rise, or when the step length is infinitely close to 0, the oil casing pressure is recovered to reach the maximum, and the well closing time is determined by adopting a pressure variable rate method; observing the back pressure rate of the oil casing pressure according to a set step length by using oil casing pressure data obtained during the well closing period, finishing quick pressure recovery when the back pressure rate is smaller than a set value, entering a slow recovery period, opening the well at the moment, constraining results of a minimum casing pressure method and a pressure optimization method by using a pressure rate method, and determining the casing pressure difference P during the well closing time by using the pressure optimization methodcxSum oil pressure difference PoxThe calculation is as follows:
Pcx＝|Pci+n-Pci|
Pox＝|Poi+n-Poi|
wherein, PciThe ith sleeve pressure is adopted; pci+nThe number of the sleeve pressure is i + n; n is an integration step length; poiIs the ith oil pressure; poi+nIs the (i + n) th oil pressure;
s3, according to the calculation result of the step S1, optimizing the well opening time result by adopting a minimum casing pressure method and a pressure variable rate method, determining the well opening time length, operating the new well opening time, and returning to the recalculation if the reasonable well closing time is not calculated; determining the well opening time by a minimum casing pressure method; when the upper liquid level reaches the wellhead, the corresponding wellhead casing pressure is the minimum working casing pressure, and the minimum working casing pressure is calculated as follows:
Pcmin＝(Pp+Ptf+Pa+(Plw+Plf)*L)
wherein, PcminIs the minimum working sleeve pressure; ppThe pressure required for lifting; ptfOil pressure of a well head; paIs at atmospheric pressure; plwTo lift by 1m3The pressure required by the liquid column to the wellhead; plfIs the loss pressure caused by fluid friction; l is the volume of the lifting liquid;
s4, calculating a shaft liquid accumulation amount, daily produced gas and daily produced water respectively by adopting a shaft volume method;
s5, judging the opening of the valve by adopting a direct method and an indirect method respectively according to the results of the steps S2, S3 and S4, and finishing control by accurately measuring the opening of the valve;
calculating the stability of the direct measurement method and the indirect measurement in the past K periods according to the variance characteristics, obtaining the variance value of the direct measurement result and the indirect measurement result, taking the reciprocal of the variance value, obtaining the weight and the weight proportion occupied by the direct measurement result and the indirect measurement result, taking the angle value of the direct measurement result and the indirect measurement result according to the weight ratio, and finally adding the angle value and the angle value together to form a final opening value theta;
namely:
U＝Uz+Uj
calculating a final opening value theta according to the weight proportion occupied by each, namely:
wherein U is the sum of the direct measured inverse of variance and the indirect measured inverse of variance, θzFor direct measurement of opening, UzFor direct measurementInverse of variance, UjFor indirect measurement of the inverse of the variance, θjIs an indirect measurement of the opening.
2. The method of claim 1, wherein in step S1, the production run is optimized when the current gas or liquid production is less than 5% to 10% of the previous gas or liquid production.
3. The method of claim 1, wherein in step S4, the wellbore fluid volume is specifically:
Pcg+ρw*g*hcw＝Ptg+ρw*g*htw
wherein h istwThe height of the oil pipe liquid column at the communication part of the oil sleeve, PcgThe pressure of a gas column at the liquid level of the oil sleeve annulus is defined as rho w, g and hcwIs height, PtgIs the gas column pressure at the oil pipe liquid level, PgIs well low pressure, P is well head pressure, hw is liquid column height;
the single-run liquid production capacity is as follows:
V＝V1-V2
V1＝htw1*π*Φt 2/4+hcw1*π*(Φc 2-Φt 2)/4
V2＝htw2*π*Φt 2/4+hcw2*π*(Φc 2-Φt 2)/4
wherein V is the single-run liquid production amount; v1Is the well bore fluid column volume before well opening; v2The volume of the wellbore fluid column after closing the well; h is a total oftw1The height of the oil pipe gas column before well opening; h iscw1The lower depth of the casing gas column before well opening; h istw2The height of the oil pipe gas column after the well is shut in; h iscw2The lower depth of the casing gas column after closing the well;
the gas yield in single operation is as follows:
Q＝Q1+Q2
Q1＝(Ptmax-Ptmin)*htg*π*Φt 2/4+(Pcmax-Pcmin)*hcg*π*(Φc 2-Φt 2)/4
Q2＝P'*t*htg*π*Φt 2/4+P'*t*hcg*π*(Φc 2-Φt 2)/4
wherein Q is the single-run gas production; q1Producing gas for wellbore pressure drop; q2Supplying gas production to the stratum; p istmaxThe oil pressure is the oil pressure of the opened well, namely the maximum value of the oil pressure; p istminFor shut-in oil pressure, PcmaxAt maximum casing pressure, PcminIs the minimum casing pressure; p' is the stratum supply rate during the well opening period, and the value is equal to the maximum value of the casing pressure recovery rate after the well is closed; t is the well opening time; h istgIs the height of the oil pipe gas column; h iscgThe lower depth of the sleeve gas column; phitIs the inner diameter of the oil pipe; phicIs the outer diameter of the oil pipe.
4. An intelligent intermittent drainage gas production system is characterized in that the intelligent intermittent drainage gas production control method according to claim 1 is adopted, and comprises a controller (1), wherein the controller (1) is respectively connected with a first digital pressure sensor (9), a second digital pressure sensor (12) and a third digital pressure sensor (13) for collecting pressure values of gas wells, and is connected with a flow sensor (8) for collecting liquid level data of the gas wells; the controller (1) is connected with the liquid crystal module (3) and the key (2) for operation control, and the controller (1) is connected with the pneumatic membrane regulating valve (7) through the battery valve (6); the controller (1) is connected with the server (5) through the communication module (4) and is used for uploading data in real time and receiving commands issued by the server (5).
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010496148.4A CN111472733B (en) | 2020-06-03 | 2020-06-03 | Intelligent intermittent drainage gas production system and control method thereof |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010496148.4A CN111472733B (en) | 2020-06-03 | 2020-06-03 | Intelligent intermittent drainage gas production system and control method thereof |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN111472733A CN111472733A (en) | 2020-07-31 |
| CN111472733B true CN111472733B (en) | 2022-07-05 |
Family
ID=71763794
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010496148.4A Active CN111472733B (en) | 2020-06-03 | 2020-06-03 | Intelligent intermittent drainage gas production system and control method thereof |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111472733B (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN113027382B (en) * | 2020-08-18 | 2023-02-10 | 陕西中良智能科技有限公司 | Machine learning device, intermittent gas well switching intelligent control system and control method |
| CN112065360B (en) * | 2020-09-10 | 2023-11-14 | 中国石油天然气股份有限公司 | Intermittent production system optimization method for low-permeability water-producing gas reservoir gas well |
| CN112943179B (en) * | 2021-01-14 | 2023-04-07 | 中国石油天然气股份有限公司 | Plunger gas lift production system optimization control method |
| CN112943170B (en) * | 2021-03-03 | 2022-08-09 | 盘锦华晨石油装备制造有限公司 | Pressurization and yield increase associated circulating gas lift system for low-pressure gas well |
| CN115711109A (en) * | 2022-11-15 | 2023-02-24 | 盘锦华晨石油装备制造有限公司 | Base station type drainage gas production equipment and system |
Family Cites Families (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5634522A (en) * | 1996-05-31 | 1997-06-03 | Hershberger; Michael D. | Liquid level detection for artificial lift system control |
| US7490675B2 (en) * | 2005-07-13 | 2009-02-17 | Weatherford/Lamb, Inc. | Methods and apparatus for optimizing well production |
| CN103670352B (en) * | 2012-09-18 | 2016-06-08 | 中国石油天然气股份有限公司 | Automatic control method for removing accumulated liquid in gas well |
| CN107605464A (en) * | 2017-09-22 | 2018-01-19 | 中国石油集团西部钻探工程有限公司 | Gas well switch board control system and its control method |
| CN108518204B (en) * | 2018-03-20 | 2020-01-21 | 四川理工学院 | Intermittent gas lift liquid drainage gas production control method and system |
| CN110318715B (en) * | 2019-07-03 | 2021-07-13 | 四川轻化工大学 | Plunger-assisted intermittent gas lift liquid drainage and gas production control system and control method |
-
2020
- 2020-06-03 CN CN202010496148.4A patent/CN111472733B/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CN111472733A (en) | 2020-07-31 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN111472733B (en) | Intelligent intermittent drainage gas production system and control method thereof | |
| CN108518204A (en) | A kind of gap gas lift liquid drainage gas production control method and system | |
| CN106285572B (en) | Control device and its control method are taken out between a kind of pumping unit intelligence | |
| CN103823424B (en) | Method for adjusting stroke times of beam pumper in automation oil extraction system | |
| CN108278104A (en) | A kind of low permeability oil field oil well interval pumping method | |
| CN108979602B (en) | Oil extraction machine energy-saving device and oil well working fluid level model estimation method | |
| CN111119864B (en) | Overflow monitoring method and system based on gas invasion pressure characteristics | |
| CN104570991A (en) | Indicator diagram-based pumping unit regulation and control method | |
| CN103412483B (en) | The model-free gradient optimizing control method and analog adopted noted by a kind of offshore platform | |
| RU2002122762A (en) | SYSTEM AND METHOD FOR OPTIMIZING A FLOW OF A FLUID IN A GAS-LIFT OIL WELL | |
| CN115408956A (en) | Method for acquiring periphysical and mechanical parameters of hydrate reservoir drilling well in real time | |
| CN113027387B (en) | Oil well interval pumping control system and method | |
| CN111075399B (en) | Oil and gas well plunger gas lift control method and system | |
| CN111339481A (en) | Well testing analysis method for coal-bed gas well | |
| CN107989599B (en) | Low-power-consumption wireless communication system and method for plunger pressure gauge | |
| CN103835687A (en) | Method and device for controlling SAGD well steam injection flow | |
| CN117684929B (en) | Oil-water well system energy consumption global optimization control method based on inter-well connectivity | |
| CN111878058A (en) | Device and method for simulating gas migration of shaft in well killing process by using pressure recovery method | |
| WO2021173159A1 (en) | Oil and gas well production system and method | |
| US20150159473A1 (en) | Plunger lift systems and methods | |
| CN114991690B (en) | Formation pressure test method and device while drilling | |
| US11649705B2 (en) | Oil and gas well carbon capture system and method | |
| CN115345090A (en) | Calculation method for dynamic propagation of undersaturated coalbed methane reservoir pressure drop funnel | |
| CN109339768A (en) | A kind of micro- overflow monitoring while drilling method of drilling well | |
| CN112344072A (en) | Water-saving control method |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |