CN113847247B - Spray cooling-assisted oilfield associated gas recovery liquid ring compressor system and method - Google Patents
Spray cooling-assisted oilfield associated gas recovery liquid ring compressor system and method Download PDFInfo
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- CN113847247B CN113847247B CN202111181483.6A CN202111181483A CN113847247B CN 113847247 B CN113847247 B CN 113847247B CN 202111181483 A CN202111181483 A CN 202111181483A CN 113847247 B CN113847247 B CN 113847247B
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- 239000007788 liquid Substances 0.000 title claims abstract description 90
- 239000007921 spray Substances 0.000 title claims abstract description 71
- 238000001816 cooling Methods 0.000 title claims abstract description 35
- 238000000034 method Methods 0.000 title claims abstract description 30
- 238000011084 recovery Methods 0.000 title claims abstract description 22
- 239000000498 cooling water Substances 0.000 claims abstract description 88
- 230000001105 regulatory effect Effects 0.000 claims abstract description 61
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 61
- 238000010992 reflux Methods 0.000 claims description 23
- 238000005507 spraying Methods 0.000 claims description 20
- 238000000605 extraction Methods 0.000 claims description 6
- 230000001276 controlling effect Effects 0.000 claims description 4
- 238000004891 communication Methods 0.000 claims description 3
- 238000004519 manufacturing process Methods 0.000 abstract description 4
- 238000012423 maintenance Methods 0.000 abstract description 2
- 239000007789 gas Substances 0.000 description 98
- 239000003921 oil Substances 0.000 description 7
- 238000002474 experimental method Methods 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 230000007547 defect Effects 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 238000004064 recycling Methods 0.000 description 3
- 230000009286 beneficial effect Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 239000010865 sewage Substances 0.000 description 2
- 238000005299 abrasion Methods 0.000 description 1
- 238000004939 coking Methods 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 239000000112 cooling gas Substances 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000000354 decomposition reaction Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000004945 emulsification Methods 0.000 description 1
- 239000010687 lubricating oil Substances 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 239000012224 working solution Substances 0.000 description 1
Classifications
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
- F04C29/00—Component parts, details or accessories of pumps or pumping installations, not provided for in groups F04C18/00 - F04C28/00
- F04C29/04—Heating; Cooling; Heat insulation
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
- F04C19/00—Rotary-piston pumps with fluid ring or the like, specially adapted for elastic fluids
- F04C19/004—Details concerning the operating liquid, e.g. nature, separation, cooling, cleaning, control of the supply
Abstract
The invention provides a spray cooling-assisted oilfield associated gas recovery liquid ring compressor system and a method, wherein the system comprises a spray device, a control module, a condenser, a first pressure transmitter, a return gas automatic regulating valve, a temperature transmitter, a liquid ring compressor, a gas-water separator, a gas return pipeline, an exhaust pipe, a second pressure transmitter, a gas-water separator valve, a water return pipeline, a heat exchanger, a liquid ring compressor discharge pipe, a liquid ring compressor air inlet pipeline, a spray cooling water automatic regulating valve, a cooling water outlet pipe, a cooling water inlet pipe, a condenser inlet pipeline and a liquid level meter; according to the invention, the liquid ring compressor system is used for replacing a screw compressor system in the oilfield associated gas recovery system, and a heat exchange cooling mode of combining conventional cooling of a condenser with auxiliary cooling of spray cooling water is adopted for oilfield associated gas, so that the consumption of cooling water is saved, the maintenance cost of equipment is reduced, and the reliability, safety and adjustability and stability of the equipment in the production process are greatly improved.
Description
Technical Field
The invention belongs to the technical field of oilfield associated gas recovery, and particularly relates to a spray cooling-assisted oilfield associated gas recovery liquid ring compressor system and a method.
Background
In recent years, various technical schemes are developed aiming at recycling of oilfield associated gas, wherein a plurality of technical schemes are disclosed in the form of application patents or published academic papers or are applied to production practice of oilfield. For example, the patent application of the invention with the application number of 201710756645.1 discloses an oilfield associated gas recovery and production sewage treatment device based on a hydrate method, which comprises an oil-gas-water three-phase separator, a gas-liquid-solid three-phase separator, a crude oil storage tank, a settling tank, a condensing tower, a filter, a sewage tank, a gas buffer tank, a screw pump, a slurry pump, a gas-liquid two-phase pump, a compressor, a pressure gauge, a flowmeter, a hydrate generation decomposition unit, a one-way valve, a stop valve, a two-phase separator and a water storage tank. In general, the existing oilfield associated gas recovery technology plays a positive role in protecting the environment and improving the resource utilization rate, however, the existing oilfield associated gas recovery technology also has the following defects:
in the process of treating oilfield associated gas, the prior art mainly conveys and pressurizes the oilfield associated gas through a screw compressor system (subsystem of an oilfield associated gas recovery system), and then realizes recovery and utilization of the oilfield associated gas after other working procedures. On the one hand, since the temperature of the oilfield associated gas is typically up to 140 ℃, and the flow rate varies greatly, the minimum flow value may be zero, and thus it is often necessary to adjust the return of some of the discharged gas to the intake of the screw compressor to stabilize the operating pressure of the apparatus; on the other hand, the process of compressing gas by the screw compressor can also cause larger temperature rise (generally reaching more than 90 ℃), thereby obviously increasing the exhaust temperature rise of the screw compressor, increasing the failure rate of thermal expansion and seizing or oil drop coking and seizing of the screw compressor, and obviously reducing the inlet gas flow of the screw compressor. The inlet gas flow of the screw compressor is obviously reduced, so that the phenomenon that the screw compressor is greatly surging caused by stall of air flow, incapability of rising of exhaust pressure and even gas backflow can be caused, and the screw compressor parts are fallen off or damaged when serious. In addition, the low-pressure natural gas contains more water drops, and condensed water in a condenser in front of the screw compressor is sucked into the screw compressor along with the gas. When the water content of the sucked gas is too high, the problems of blockage of a flow passage, increased abrasion, increased vibration, emulsification of lubricating oil, rusting of parts and the like of the screw compressor can be caused. Therefore, the screw compressor system has more problems in the use process, in order to ensure that the temperature of the screw compressor is not too high in the working process, condenser cooling gas needs to be arranged at the suction inlet and the discharge outlet of the screw compressor in the prior art, and the structural design not only consumes energy, but also can separate out a large amount of liquid in the subsequent cooling process, so that the subsequent process of the oilfield associated gas recovery system is greatly negatively influenced.
Disclosure of Invention
The invention aims to overcome the technical defects of high fault rate, narrow reflux adjusting range and large cooling water loss of a screw compressor system in the existing oilfield associated gas recovery system. The aim is achieved by the following technical scheme:
the utility model provides a spray cooling auxiliary oil field associated gas retrieves liquid ring compressor system, including spray set, control module, the condenser, first pressure transmitter, return gas automatic regulating valve, temperature transmitter, liquid ring compressor, gas-water separator, gas return line, blast pipe, second pressure transmitter, gas-water separator valve, return water pipeline, heat exchanger, liquid ring compressor discharge pipe, liquid ring compressor air inlet line, spray cooling water automatic regulating valve, cooling water outlet pipe, cooling water inlet pipe, condenser inlet pipeline, level gauge;
the condenser inlet pipeline is sequentially communicated with the condenser, the liquid ring compressor air inlet pipeline, the liquid ring compressor discharge pipe and the gas-water separator; the spraying device (1) is communicated with the liquid ring compressor air inlet pipeline (16) through a spraying cooling water pipeline, and a spraying cooling water automatic regulating valve (17) is arranged on the spraying cooling water pipeline;
one side of the gas-water separator is communicated with one end of the exhaust pipe, the other end of the exhaust pipe is provided with an exhaust port, the side surface of the exhaust pipe is provided with an opening communicated with a gas return pipeline, and a return gas automatic regulating valve is arranged on the gas return pipeline; the other side of the gas-water separator is sequentially communicated with a water return pipeline, a heat exchanger and a liquid ring compressor; the second pressure transmitter, the gas-water separator valve and the liquid level meter are respectively communicated with the gas-water separator;
the spray device, the first pressure transmitter, the reflux gas automatic regulating valve, the temperature transmitter, the second pressure transmitter, the gas-water separator valve, the spray cooling water automatic regulating valve and the liquid level meter are in communication connection with the control module.
The basic inventive concept of the technical proposal is that in the oilfield associated gas recovery system, the subsystem of the liquid ring compressor system is used for replacing the screw compressor system, and the technical effect of the oilfield associated gas recovery system is improved as a whole while the inherent technical defect of the screw compressor system, namely the specific technical task of oilfield associated gas recovery, is overcome. In addition, on the heat exchange cooling problem of the oilfield associated gas, the invention adopts a mode of combining the conventional heat exchange cooling of the condenser with the auxiliary heat exchange cooling of the spray cooling water. By auxiliary heat exchange cooling is meant that the oil field associated gas needs to be further heat exchanged cooled using spray cooling water if and only if the temperature of the oil field associated gas is still relatively high after heat exchange cooling by the cooling water in the condenser.
In the above technical scheme, the control module is preferably a single chip microcomputer, an industrial personal computer or a PLC.
In addition, when the technical scheme of the invention is implemented, each pressure transmitter can be replaced by a corresponding pressure sensor, and each temperature transmitter can be replaced by a corresponding temperature sensor.
The invention also provides a control method for spraying cooling water by taking the related device or the component in the technical scheme as a substance technical means, which comprises the following steps:
step 1, presetting a condensed gas temperature value t in a control module 2 0 ；
Step 2, detecting a temperature value t of the oilfield associated gas after heat exchange by a temperature transmitter 2 Feedback to the control module;
step 3, when t 2 >t 0 When the automatic spray cooling water regulating valve is required to be opened for spraying, if the opening of the automatic spray cooling water regulating valve is 100%, the control module is required to send out an alarm to prompt a user to check faults; if the situation is not found, the control module calculates the self-cooling water sprayingAn opening adjustment amount of the dynamic adjustment valve;
the opening adjustment amount of the spray cooling water automatic regulating valve can be calculated by an empirical formula as follows:
Ks＝5.058*S 3 *V 0 *(t 2 -t 0 )/d 2 ；
wherein V is 0 : rated extraction rate of liquid ring compressor, unit: m is m 3 /min；
t 2 : the temperature value of the oilfield associated gas after heat exchange detected by the temperature transmitter, namely the temperature of the oilfield associated gas after heat exchange and cooling by the condenser, is as follows: the temperature is lower than the temperature;
d: the drift diameter of the automatic spray cooling water regulating valve is as follows: mm;
S 3 : opening safety factor, the general value range: 1.1 to 1.2;
and 4, adjusting the opening of the automatic spray cooling water adjusting valve, returning to the step 2 after 1 minute intervals, and continuously adjusting the opening of the automatic spray cooling water adjusting valve by the control module according to the temperature change.
The invention has the main beneficial effects as follows:
(1) The liquid ring compressor is close to isothermal compression when compressing gas, internal parts are not blocked or worn due to temperature rise, the temperature of discharged gas is low, the problem that the subsequent process is influenced due to the fact that the water content of the compressed gas is high is avoided, meanwhile, a condenser at a discharge port (namely, the condenser is not required to be arranged at the discharge port of the liquid ring compressor) can be omitted, the consumption of cooling water is saved, and the maintenance cost of equipment is reduced.
(2) The liquid ring compressor needs water as working fluid, so a large amount of water drops can be sucked, therefore, the problem of low-pressure natural gas water drops can not cause any influence on the liquid ring compressor, but can play a positive role in reducing the supplement amount of the working fluid, effectively avoid the situation that the screw compressor fails due to overlarge water suction amount, and greatly improve the reliability and safety of the production process.
(3) Because the liquid ring compressor compresses gas by the liquid ring formed by working water, the liquid ring is not a rigid part, has larger adjustability, and allows larger deviation for suction pressure values, compared with a system adopting a screw compressor, the adjustable liquid ring compressor has the advantages that the adjustability is much higher, the stability during adjustment is better, and the problems of surging and the like can not occur.
(4) The conventional heat exchange cooling of the condenser and the auxiliary heat exchange cooling of the spray cooling water are combined to perform heat exchange cooling on the oilfield associated gas, so that the consumption of cooling water is saved, the control process is simplified (four temperature transmitters are needed to be used in the technical scheme of performing heat exchange cooling by independently using the condenser, and the control process of heat exchange cooling can be completed), and in addition, after the spray cooling water is sucked into the liquid ring compressor, the spray cooling water can be used as the supplementary working liquid of the liquid ring compressor.
Drawings
Fig. 1 is a schematic diagram of the structure and operation principle of an embodiment of the present invention.
In the figure:
1, a spraying device; 2-a control module;
3-a condenser; 4-a first pressure transmitter;
5-reflux gas automatic regulating valve; 6-a temperature transmitter;
7, a liquid ring compressor; 8-a gas-water separator;
9-a gas return line; 10-exhaust pipe;
11-second pressure transmitter 12-gas-water separator valve;
13—a water return line; 14-a heat exchanger;
15-liquid ring compressor discharge tube; 16-a liquid ring compressor air inlet pipeline;
17-automatic regulating valve for spraying cooling water; 18-cooling water outlet pipe;
19—cooling water inlet pipe; 20-condenser inlet line;
21-level gauge.
Detailed Description
In order to facilitate a better understanding of the technical solution of the present invention by a person skilled in the art, an embodiment of the present invention is described below with reference to the accompanying drawings:
as shown in fig. 1, the spray cooling-assisted oilfield associated gas recycling liquid ring compressor system comprises a spray device 1, a control module 2, a condenser 3, a first pressure transmitter 4, a return gas automatic regulating valve 5, a temperature transmitter 6, a liquid ring compressor 7, a gas-water separator 8, a gas return pipeline 9, an exhaust pipe 10, a second pressure transmitter 11, a gas-water separator valve 12, a return water pipeline 13, a heat exchanger 14, a liquid ring compressor exhaust pipe 15, a liquid ring compressor air inlet pipeline 16, a spray cooling water automatic regulating valve 17, a cooling water outlet pipe 18, a cooling water inlet pipe 19, a condenser inlet pipeline 20 and a liquid level meter 21.
The condenser inlet pipeline 20 is sequentially communicated with the condenser 3, the liquid ring compressor air inlet pipeline 16, the liquid ring compressor 7, the liquid ring compressor discharge pipe 15 and the gas-water separator 8, the spray device 1 is communicated with the liquid ring compressor air inlet pipeline 16 through a spray cooling water pipeline, and the spray cooling water automatic regulating valve 17 is arranged on the spray cooling water pipeline. The condenser inlet line 20, the vent line inside the condenser 3, the liquid ring compressor inlet line 16, the liquid ring compressor 7 and the liquid ring compressor discharge line 15 constitute an air intake system in the present invention. The spray device 1, a spray cooling water pipeline which communicates the spray device 1 with a liquid ring compressor air inlet pipeline 16, a spray cooling water automatic regulating valve 17 arranged on the spray cooling water pipeline, a water pipeline inside the condenser 3, a cooling water inlet pipe 19 and a cooling water outlet pipe 18 which communicate with the condenser 3 jointly form a cooling water system in the invention.
One side of the gas-water separator 8 is communicated with one end of the exhaust pipe 10, the other end of the exhaust pipe 10 is provided with an exhaust port, the side surface of the exhaust pipe 10 is provided with an opening communicated with the gas return pipeline 9, and the return gas automatic regulating valve 5 is arranged on the gas return pipeline 9; the other side of the gas-water separator 8 is sequentially communicated with a water return pipeline 13, a heat exchanger 14 and a liquid ring compressor 7; the second pressure transmitter 11, the gas-water separator valve 12 and the liquid level gauge 21 are respectively communicated with the gas-water separator 8.
The spray device 1, the first pressure transmitter 4, the reflux gas automatic regulating valve 5, the temperature transmitter 6, the second pressure transmitter 11, the gas-water separator valve 12, the spray cooling water automatic regulating valve 17 and the liquid level meter 21 are in communication connection with the control module 2.
It should be noted that, the temperature transmitter in the present embodiment may be replaced by a corresponding temperature sensor, and similarly, each pressure transmitter in the present embodiment may also be replaced by a corresponding pressure sensor, that is, the first pressure sensor and the second pressure sensor replace the first pressure transmitter and the second pressure transmitter in the present embodiment respectively. The first and second means that the positions where the pressure sensor and the pressure transmitter are mounted are different, and the first and second are not limited to the above. In addition, the control module 2 in this embodiment may be a single chip microcomputer, a PLC (programmable logic controller), or an industrial personal computer with a corresponding control function in the prior art.
The foregoing describes structural features of an embodiment of the present invention with reference to the accompanying drawings, and the following further describes the working principle and working procedure thereof:
when the oil field associated gas pumping device works, water is firstly supplied to the gas-water separator 8 to a certain liquid level through the gas-water separator valve 12, working water flows into the liquid ring compressor 7 through the water return pipeline 13 and the heat exchanger 14, and at the moment, the liquid ring compressor 7 can be started to start pumping the oil field associated gas. The sucked oilfield associated gas enters the condenser 3 through the condenser inlet pipeline 20, and the cooling water enters the condenser 3 through the cooling water inlet pipe 19 to exchange heat with the oilfield associated gas for cooling, and is discharged through the cooling water outlet pipe 18. If the temperature of the oilfield associated gas after heat exchange and cooling in the condenser 3 is still higher, the automatic spray cooling water regulating valve 17 is opened, the spray device 1 is started, and the spray cooling water is sprayed into the air inlet pipeline 16 of the liquid ring compressor, so that the oilfield associated gas with higher temperature and the spray cooling water are subjected to further heat exchange and cooling.
The cooled oilfield associated gas (carrying part of water) enters the liquid ring compressor 7 through the liquid ring compressor air inlet pipeline 16, is compressed and is discharged into the gas-water separator 8. The oil field associated gas carrying water is separated in the gas-water separator 8, the separated liquid water is converged into working water, flows into the water return pipeline 13 from the bottom of the gas-water separator 8, is cooled by the heat exchanger 14 and enters the liquid ring compressor 7 for recycling, and the separated gas is discharged out of the gas-water separator 8 through the exhaust pipe 10 and then is led to the next process flow (recycled through a subsequent treatment program or returned to the condenser 3 through the gas return pipeline 9 as the case may be).
This is done under the control of the control module 2, for example, the control module 2 detects the pressure value p of the oilfield associated gas in the liquid ring compressor inlet line 16 based on the first pressure transmitter 4 1 (i.e., the intake pressure value of the liquid ring compressor 7), and P 1 And a preset pressure value P 0 And comparing to confirm whether the automatic reflux gas regulating valve 5 needs to be opened to realize gas reflux.
In general, the control of the spray cooling assisted oilfield associated gas recovery liquid ring compressor system of the present invention is divided into two aspects, namely control of the return gas and control of the spray cooling water, which are two simultaneous, but relatively independent processes. As for the flow rate of the cooling water for heat exchange in the condenser 3, no valve adjustment is required. Specifically, the condenser 3 of the present invention can be selected in terms of the average intake air amount, and does not need to be selected in terms of the maximum capacity, so that the cost of the apparatus is significantly reduced, and the amount of cooling water is kept at an average value. When the temperature of the oilfield associated gas is still higher after the oilfield associated gas is subjected to heat exchange and cooling through the condenser 3 (which is not the case), the temperature transmitter 6 sends information of the higher temperature to the control module 2, the control module 2 sends out a command, the spray cooling water automatic regulating valve 17 is opened, the spray device 1 is started, and the oilfield associated gas is subjected to heat exchange and cooling by using the spray cooling water. The heat exchange cooling mode adopted by the invention is not only beneficial to saving cooling water, but also can be used as a supplementary working solution of the liquid ring compressor after spraying cooling water is sucked into the liquid ring compressor.
Hereinafter, a method of controlling spray cooling water and a method of controlling return gas will be described, respectively.
1. Control method for spraying cooling water
Step 1, presetting a condensed gas temperature value t in a control module 2 0 ；
Step 2, the temperature transmitter 6 detects the temperature value t of the oilfield associated gas after heat exchange 2 Feedback to the control module 2;
step 3, when t 2 >t 0 When the automatic spray cooling water regulating valve 17 is required to be opened for spraying, if the opening of the automatic spray cooling water regulating valve 17 is 100%, the control module 2 is required to send out an alarm to prompt a user to check faults; if the situation is not found, the control module 2 calculates the opening adjustment quantity of the automatic spray cooling water adjusting valve 17;
the opening adjustment amount of the spray cooling water automatic regulating valve 17 can be calculated by an empirical formula as follows:
Ks＝5.058*S 3 *V 0 *(t 2 -t 0 )/d 2 ；
wherein V is 0 : rated extraction rate of liquid ring compressor, unit: m is m 3 /min；
t 2 : the temperature value of the oilfield associated gas after heat exchange detected by the temperature transmitter 6, namely the temperature of the oilfield associated gas after heat exchange and cooling by the condenser 3, is as follows: the temperature is lower than the temperature;
d: the diameter of the spray cooling water automatic regulating valve 17, unit: mm;
S 3 : opening safety factor, the general value range: 1.1 to 1.2;
and 4, adjusting the opening of the automatic spray cooling water adjusting valve 17, returning to the step 2 after 1 minute intervals, and continuously adjusting the opening of the automatic spray cooling water adjusting valve 17 by the control module 2 according to the temperature change.
The following is substituted into specific numerical values in the experiment to further explain the cooling water flow control method:
in this experiment, the rated extraction V of the liquid ring compressor 7 was known 0 ＝12m 3 The valve diameter of the automatic cooling water regulating valve 17 used is d=25 mm, s 3 Take a value of 1.1.
Step 1, presetting a condensed gas temperature value t in a control module 2 0 ＝45℃；
Step 2, the temperature value t detected by the second temperature transmitter 6 2 =50 ℃, fed back to the control module 2;
step 3, at this time t 2 >t 0 The opening degree of the automatic spray cooling water regulating valve 17 is zero, and the control module 2 calculates the opening degree regulating amount of the automatic spray cooling water regulating valve 17:
Ks＝5.058*S 3 *V 0 *(t 2 -t 0 )/d 2 ＝5.058*1.1*12*(50-45)/25 2 ≈53％
the control module 2 adjusts the opening of the automatic spray cooling water adjusting valve 17 according to the values, and returns to the step 2 after 1 minute intervals, and the control module 2 can continuously adjust the opening of the automatic spray cooling water adjusting valve according to the temperature change.
2. Method for controlling return gas
The control method of the reflux gas comprises the following steps:
step 1, presetting a suction pressure value P of oilfield associated gas in a control module 2 0 And a largely adjusted allowable deviation range rate dp;
step 2, the first pressure transmitter 4 detects the inlet pressure value P of the liquid ring compressor 7 1 Second pressure transmitter 11 detects an outlet pressure value P of liquid ring compressor 7 2 Feedback to the control module 2;
step 3-1, when (P 0 -P 1 )/P 0 ︱>At dp, the opening of the automatic return gas regulating valve 5 in the gas return line 9 is greatly adjusted, if at that time P 0 <P 1 And the opening degree of the reflux gas automatic regulating valve 5 is 0, the control module 2 gives an alarm to prompt an operator to check whether the air inlet system has faults or not; if the situation is not found, the control module 2 calculates the opening adjustment quantity of the automatic reflux gas regulating valve 5;
the opening adjustment amount of the return air automatic regulating valve 5 can be calculated by an empirical formula as follows:
Kq 2 ＝V 0 *(P 0 -P 1 )/(S 1 *P 2 *d 2 )；
in the method, in the process of the invention,
P 0 : the control module 2 presets the suction absolute pressure value of the oilfield associated gas in units of: MPa;
P 1 : inlet absolute pressure value detected by the first pressure transmitter 4 in units of: MPa;
P 2 : outlet absolute pressure value detected by second pressure transmitter 11 in units of: MPa;
V 0 : rated extraction rate of liquid ring compressor, unit: m is m 3 /min；
d: valve diameter of the return air automatic regulating valve 5, unit: m;
S 1 : the opening degree of the automatic reflux gas regulating valve 5 calculates an empirical coefficient, and the typical value range is as follows: 1000-3000; (the main effect of this range of values is the speed of response of the adjustment, which is generally averaged when practicing the invention and can be adjusted according to the actual tuning conditions.)
Step 3-2, when (P 0 -P 1 )/P 0 ︱<At dp, the opening of the automatic reflux gas regulating valve 5 is only required to be regulated in a small range, and the regulating quantity can be calculated according to the following empirical formula:
Kq 2 ＝V 0 *(P 0 -P 1 )/(S 2 *p 2 *d 2 )；
s in 2 : the opening degree of the automatic reflux gas regulating valve 5 calculates an empirical coefficient, and the typical value range is as follows: 200-1000; (the main effect of this range of values is the speed of response of the adjustment, which is generally averaged when practicing the invention and can be adjusted according to the actual tuning conditions.)
Step 4, determining the existing opening Kq of the automatic reflux gas regulating valve 5 1 Kq is the opening value before readjusting the opening;
step 5, calculating the opening Kq=Kq of the reflux gas automatic regulating valve 5 to be regulated 1 +Kq 2 Then readjust the reflux gas automaticallyThe opening degree of the valve 5;
and 6, after the opening degree of the reflux gas automatic regulating valve 5 is regulated, returning to the step 2, so that the circulation control of the reflux gas is realized.
The following is a specific numerical value substituted into a certain experiment to further explain the control method of the reflux gas:
in this experiment, the rated extraction V of the liquid ring compressor 7 0 ＝12m 3 Per min, preset suction pressure value P 0 The largely adjusted allowable deviation range rate is set to dp=15%, the valve path of the return gas automatic regulating valve 5 used is d=50mm=0.05m, and the inlet pressure value P detected by the first pressure transmitter 4 is set to d=50mm=0.05m 1 Outlet pressure value P detected by pressure transmitter 11 =0.09 MPa 2 ＝0.6MPa，S 1 A value 1413;
at this time, | (P) 0 -P 1 )/P 0 ︱＝(0.11-0.09)/0.11≈0.18>dp, the opening of the reflux gas automatic regulating valve 5 is required to be greatly adjusted:
Kq 2 ＝V 0 *(P 0 -P 1 )/(1413*p 2 *d 2 )；
＝12*(0.11-0.09)/(1413*0.6*0.05 2 )
≈0.113＝11.3％；
at this time, kq 1 ＝Kq＝0；
Calculating the opening Kq=Kq to be adjusted 1 +Kq 2 After the opening of the return gas automatic regulating valve 5 is readjusted, the process returns to step 2, thereby realizing the circulation control of the return gas.
Claims (5)
1. The utility model provides an oil field associated gas recovery liquid ring compressor system that spray cooling is supplementary which characterized in that: the device comprises a spraying device (1), a control module (2), a condenser (3), a first pressure transmitter (4), a reflux gas automatic regulating valve (5), a temperature transmitter (6), a liquid ring compressor (7), a gas-water separator (8), a gas reflux pipeline (9), an exhaust pipe (10), a second pressure transmitter (11), a gas-water separator valve (12), a reflux pipeline (13), a heat exchanger (14), a liquid ring compressor discharge pipe (15), a liquid ring compressor air inlet pipeline (16), a spraying cooling water automatic regulating valve (17), a cooling water outlet pipe (18), a cooling water inlet pipe (19), a condenser inlet pipeline (20) and a liquid level meter (21);
the condenser inlet pipeline (20) is sequentially communicated with the condenser (3), the liquid ring compressor air inlet pipeline (16), the liquid ring compressor (7), the liquid ring compressor discharge pipe (15) and the gas-water separator (8); the spraying device (1) is communicated with the liquid ring compressor air inlet pipeline (16) through a spraying cooling water pipeline, and a spraying cooling water automatic regulating valve (17) is arranged on the spraying cooling water pipeline;
one side of the gas-water separator (8) is communicated with one end of the exhaust pipe (10), the other end of the exhaust pipe (10) is provided with an exhaust port, the side surface of the exhaust pipe (10) is provided with an opening communicated with the gas return pipeline (9), and the return gas automatic regulating valve (5) is arranged on the gas return pipeline (9); the other side of the gas-water separator (8) is sequentially communicated with a water return pipeline (13), a heat exchanger (14) and a liquid ring compressor (7); the second pressure transmitter (11), the gas-water separator valve (12) and the liquid level meter (21) are respectively communicated with the gas-water separator (8);
the spraying device (1), the first pressure transmitter (4), the reflux gas automatic regulating valve (5), the temperature transmitter (6), the second pressure transmitter (11), the gas-water separator valve (12), the spraying cooling water automatic regulating valve (17) and the liquid level meter (21) are in communication connection with the control module (2);
the condenser (3) is selected according to the average air inflow, and valve adjustment is not needed;
the control module (2) detects a pressure value P1 of oilfield associated gas in the liquid ring compressor air inlet pipeline (16) according to the first pressure transmitter (4), and compares the pressure value P1 with a preset pressure value P0 to confirm whether a return gas automatic regulating valve (5) needs to be opened to realize gas return.
2. The spray cooling assisted oilfield associated gas recovery liquid ring compressor system of claim 1, wherein: the control module (2) is a singlechip, an industrial personal computer or a PLC.
3. The spray cooling assisted oilfield associated gas recovery liquid ring compressor system of claim 1, wherein: the temperature transmitter (6) is replaced by a temperature sensor.
4. The spray cooling assisted oilfield associated gas recovery liquid ring compressor system of claim 1, wherein: the first pressure transmitter (4) and the second pressure transmitter (11) are replaced by a first pressure sensor and a second pressure sensor respectively.
5. A method of controlling spray cooling water based on the spray cooling assisted oilfield associated gas recovery liquid ring compressor system of claim 1, comprising the steps of:
step 1, presetting a condensed gas temperature value t in a control module (2) 0 ；
Step 2, detecting the temperature value t of the oilfield associated gas subjected to heat exchange by a temperature transmitter (6) 2 Feedback to the control module (2);
step 3, when t 2 >t 0 When the automatic spray cooling water regulating valve (17) is required to be opened for spraying, if the opening of the automatic spray cooling water regulating valve (17) is 100% at the moment, the control module (2) is required to send out an alarm to prompt a user to check faults; if the situation is not found, the control module (2) calculates the opening adjustment quantity of the automatic spray cooling water adjusting valve (17); the opening adjustment amount of the spray cooling water automatic regulating valve (17) is calculated as follows by an empirical formula:
Ks=5.058* S 3 * V 0 *( t 2 - t 0 )/d 2 ；
wherein V is 0 : rated extraction rate of liquid ring compressor, unit: m is equal to min;
t 2 : the temperature value of the oilfield associated gas after heat exchange detected by the temperature transmitter (6), namely, the temperature value is condensedThe temperature of the oilfield associated gas after heat exchange and cooling of the device (3) is as follows: the temperature is lower than the temperature;
d: the drift diameter of the spray cooling water automatic regulating valve (17) is as follows: mm;
S 3 : opening safety factor, the general value range: 1.1 to 1.2;
and 4, adjusting the opening of the automatic spray cooling water adjusting valve (17), returning to the step 2 after 1 minute interval, and continuously adjusting the opening of the automatic spray cooling water adjusting valve (17) by the control module (2) according to the temperature change.
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