CN114412427B - Gas lift and production integrated oil gas exploitation system - Google Patents
Gas lift and production integrated oil gas exploitation system Download PDFInfo
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- CN114412427B CN114412427B CN202011083281.3A CN202011083281A CN114412427B CN 114412427 B CN114412427 B CN 114412427B CN 202011083281 A CN202011083281 A CN 202011083281A CN 114412427 B CN114412427 B CN 114412427B
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- 238000004519 manufacturing process Methods 0.000 title claims abstract description 163
- 239000007788 liquid Substances 0.000 claims abstract description 121
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 27
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 27
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 27
- 238000000034 method Methods 0.000 claims description 75
- 238000012544 monitoring process Methods 0.000 claims description 16
- 239000012071 phase Substances 0.000 claims description 16
- 239000007791 liquid phase Substances 0.000 claims description 15
- 238000001514 detection method Methods 0.000 claims description 13
- 238000011084 recovery Methods 0.000 claims description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 6
- 239000007789 gas Substances 0.000 description 183
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 10
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 8
- 229910052757 nitrogen Inorganic materials 0.000 description 5
- 230000008901 benefit Effects 0.000 description 4
- 238000010586 diagram Methods 0.000 description 4
- 239000003345 natural gas Substances 0.000 description 4
- 238000010276 construction Methods 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 230000006870 function Effects 0.000 description 3
- 238000000926 separation method Methods 0.000 description 3
- 238000013459 approach Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 238000010924 continuous production Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 238000009428 plumbing Methods 0.000 description 1
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/34—Arrangements for separating materials produced by the well
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
The invention provides an oil gas exploitation system integrating gas lift and production. The hydrocarbon production system is connected to a production tree of an oil and gas field. The gas production tree comprises: an oil pipe at the inner layer; and a sleeve sleeved outside the oil pipe. The hydrocarbon production system comprises: production lines and gas lift lines. The production pipeline comprises: the input end of the gas-liquid separator is connected to an oil pipe of the gas production tree; a gas phase leg, comprising: the input port of the air pump is connected to the gas phase medium outlet of the gas-liquid separator, and the output port of the air pump is connected to the output trunk line through the gas circuit valve. The rear end of the gas lift pipeline is connected to the output port of the air pump, and the front end of the gas lift pipeline is connected to the sleeve of the gas production tree through the sleeve valve. The invention integrates the gas lift and the production pipeline into the oil gas exploitation system, fully utilizes the existing oil gas production equipment, is flexible and convenient, has simple structure and lower cost, and can effectively control the cost.
Description
Technical Field
The invention relates to the field of oil gas exploitation in the mechanical industry, in particular to an oil gas exploitation system integrating gas lift and production.
Background
In the field of oil and gas development, a water production gas well enters a middle and later production stage, gas production is reduced due to the fact that formation energy is reduced, so that liquid cannot be carried independently, bottom hole effusion is easily caused, flooding is caused, and a drainage and gas production process is required to be implemented at the moment to maintain stable production. The gas lift process is a drainage process in which high-pressure gas is injected from a casing, and bottom hole effusion is discharged from an oil pipe, so that the production of a gas well can be restored.
The implementation form of the gas lift process comprises vehicle-mounted gas lift, interwell gas lift process and the like. The vehicle-mounted gas lift generally adopts a compressor to boost the nitrogen generated by the nitrogen making vehicle and then injects the nitrogen into the sleeve. Interwell gas lift is the direct introduction of natural gas from an adjacent high pressure gas well into the casing.
During the continuous production time, the applicant has found that both gas lift processes have drawbacks as above: (1) the vehicle-mounted gas lift is convenient and flexible, but not timely, special nitrogen making equipment is needed, and the system is complex and has higher cost; (2) the gas lift between wells can only be used in the condition that a plurality of wells are nearby, at least one well is required to have pressure capable of achieving lifting pressure, and the gas lift requirement of a single well or a site with low pressure nearby all wells cannot be met.
Disclosure of Invention
First, the technical problem to be solved
The present invention provides a gas lift and production integrated hydrocarbon recovery system in an effort to at least partially address at least one of the above-identified problems.
(II) technical scheme
In order to achieve the above object, the invention provides an oil and gas exploitation system integrating gas lift and production. The hydrocarbon production system is connected to a production tree of an oil and gas field. The gas production tree comprises: an oil pipe at the inner layer; and a sleeve sleeved outside the oil pipe. The hydrocarbon production system includes: production lines and gas lift lines. The production pipeline comprises: the input end of the gas-liquid separator is connected to an oil pipe of the gas production tree; a gas phase leg, comprising: the input port of the air pump is connected to the gas phase medium outlet of the gas-liquid separator, and the output port of the air pump is connected to the output trunk line through the gas circuit valve. The rear end of the gas lift pipeline is connected to the output port of the air pump, and the front end of the gas lift pipeline is connected to the sleeve of the gas production tree through the sleeve valve.
(III) beneficial effects
According to the technical scheme, the gas lift and production integrated oil and gas exploitation system has at least one of the following beneficial effects:
(1) The gas lift and the production pipeline are integrated in the oil gas exploitation system, the gas required by the gas lift is generated by utilizing the gas-liquid separator of the production pipeline, the existing oil gas production equipment is fully utilized, and the device is flexible and convenient, simple in structure and low in cost.
(2) The system realizes two functions of pressurized production or gas lift, can solve various problems of a wellhead, has small equipment investment and simple management, and can effectively control the cost.
(3) The gas lift process and the production process can be switched in time by utilizing the valve, the condition in the well can be monitored in real time according to the operation parameters of the well head, the gas lift work can be carried out at any time, the gas well is prevented from being flooded thoroughly, and the gas lift and drainage gas production process can be switched in time, so that the operation is more flexible and convenient.
(4) The gas produced on site or the gas in the output trunk line is utilized for gas lift operation, no special nitrogen making equipment or the oil gas pressure of other oil wells is needed, the application scene is wider, and the on-site gas lift requirement of a single well or all adjacent wells with lower pressure is met.
(5) The control method is realized manually, gas lift and production processes can be carried out according to different working conditions and different stages, the economic benefit of the oil and gas field is exerted to the maximum extent, and the production cost is reduced.
(6) The control method is further realized through the control logic of the control system, so that the automatic switching of the production process and the gas lift process can be realized, and the automation degree of production can be greatly improved.
Drawings
FIG. 1 is a schematic diagram of a first embodiment of an integrated gas lift and production hydrocarbon recovery system of the present invention.
FIG. 2 is a flow chart of control logic of the control system of the first embodiment of the hydrocarbon production system of the present invention.
Fig. 2A is a detailed flowchart of the step of "execute drainage flow" in fig. 2.
FIG. 3 is a schematic diagram of a second embodiment of an integrated gas lift and production hydrocarbon recovery system of the present invention.
FIG. 4 is a flow chart of control logic of a control system in a second embodiment of the hydrocarbon production system of the present invention.
[ Main reference numerals in the drawings ]
Production line A1 bypass line A2 gas lift line B
100-gas production tree;
101-an oil pipe; 102-a sleeve;
201-an oil pipe valve; 202-tubing pressure sensor;
203-split-flow tubing; 204-a mains pressure sensor;
205-level sensor;
211-a main through valve; 212-a gas-liquid separator;
213-an air pump; 214-a gas circuit pressure sensor;
215-a liquid pump; 216-a liquid path one-way valve;
217-gas circuit valve; 218-an air path check valve;
221-bypass valve;
301-a sleeve pressure sensor; 302-sleeve valve;
303-a gas lift check valve;
400-a control system;
500-output trunk.
Detailed Description
The invention provides a gas lift and production integrated oil gas exploitation system, which realizes two functions of production or gas lift by controlling the opening and closing of each valve, fully utilizes the existing oil gas production equipment, and has the advantages of flexibility, convenience, wide application range and the like.
The present invention will be further described in detail below with reference to specific embodiments and with reference to the accompanying drawings, in order to make the objects, technical solutions and advantages of the present invention more apparent. It should be understood that these embodiments are provided so that this disclosure will satisfy applicable legal requirements, and that this invention may be embodied in many different forms and should not be construed as limited to the embodiments set forth herein.
1. First embodiment of an oil and gas production System
FIG. 1 is a schematic diagram of a first embodiment of an integrated gas lift and production hydrocarbon recovery system of the present invention. As shown in fig. 1, the oil and gas production system of the present embodiment is connected to a production tree 100 of an oil and gas field.
Wherein, gas production tree 100 includes: an inner layer oil pipe 101; and a sleeve 102 sleeved outside the oil pipe.
The oil and gas exploitation system of the embodiment comprises:
production line A1, comprising:
a gas-liquid separator 212, the input end of which is connected to the oil pipe 101 of the gas production tree;
a gas phase leg, comprising: an air pump 213, the input of which is connected to the gas phase medium outlet of the gas-liquid separator, and the output of which is connected to the output trunk line 500 through an air path valve 217;
the gas lift line B is connected at its rear end to the output of the air pump and at its front end to the casing 102 of the production tree via a casing valve 302.
By the above-described structure of the hydrocarbon production system, the switching of the first production process and the first lift process can be achieved by controlling the gas path valve 217 and the sleeve valve 302.
The production line of the hydrocarbon production system of this embodiment further includes: the liquid phase branch has its input connected to the liquid phase medium outlet of the gas-liquid separator and its output connected to the output trunk 500. The liquid phase branch is used for conveying liquid phase medium separated by the gas-liquid separator, mainly water.
Wherein, the liquid phase branch road includes: the liquid pump 215 has its input connected to the liquid medium outlet of the gas-liquid separator and its output connected to the output rail 500 as well. It should be noted that the liquid pump is not always on, but the liquid pump is turned on for discharging only if the liquid in the gas-liquid separator reaches a certain amount. Specifically, the control system controls the liquid pump to start and stop depending on the acquired gas-liquid separator liquid level information monitored by the liquid level sensor 205 to discharge the liquid in the gas-liquid separator.
It will be clear to those skilled in the art that in general, the medium extracted from the oil and gas well is a miscible medium, and therefore a gas-liquid separator is required to separate the medium, wherein the gas-phase medium is to be mined, the liquid-phase medium is mostly water, and the liquid-phase oil is only a small part and is not the main subject of mining. Therefore, a liquid phase branch is not necessary. In other embodiments of the present invention, there may be no liquid phase branch, and the liquid separated by the gas-liquid separator may be directly discharged without affecting the implementation of the present invention.
Furthermore, although in the present embodiment, both the liquid phase medium and the gas phase medium are transported through the output trunk 500, the purpose thereof is to achieve simplification and optimization of the pipeline, which is not necessary for the implementation of the present invention. In other embodiments of the present invention, the gas phase medium and the liquid phase medium may be transported through different pipelines, respectively, and the present invention may be implemented as well.
In order to avoid backflow of the medium in the pipeline during the operation of starting and stopping the pump, a one-way valve is arranged in each pipeline. Referring to fig. 1, a gas path check valve 218 is provided in the gas path branch, which allows only one-way flow of the gas medium from the gas path valve to the output trunk. A liquid path one-way valve 216 is provided in the liquid phase branch, which allows only one-way flow of liquid medium from the liquid pump output port to the output rail. A gas lift check valve 303 is provided in the gas lift line which allows only one-way flow of medium from the air pump output port to the sleeve valve.
Based on the construction of the oil and gas production system as described above, the process conditions of the oil and gas production system will be described in detail. Namely, through the control of the air path valve 217, the sleeve valve 302, the air pump 213 and the liquid pump 215, the switching between the first production process and the first lift process is realized, which specifically comprises:
1. first production process
The application scene is as follows: the oil and gas well can normally produce oil gas, and the pressure of the oil pipe is smaller than the pressure of an output trunk line.
Component status: the air passage valve 217 is opened, the sleeve valve 302 is closed, and the air pump 213 is opened.
The technical process comprises the following steps: natural gas of an oil and gas well and a miscible medium of a bottom hole effusion enter a gas-liquid separator 212 from an oil pipe 101, the separated gas is pressurized by an air pump 213 and then is conveyed to an output trunk line 500 through an air passage valve 217 and a first one-way valve 218, and oil and gas production is achieved.
2. First gas lift process
The application scene is as follows: the oil and gas well oil pipe effusion, but not serious, the gas production can carry out the circulating liquid discharge production.
Component status: the air passage valve 217 is closed, the sleeve valve 302 is opened, and the air pump 213 is opened.
The technical process comprises the following steps: the gas in the oil pipe and the miscible medium of the bottom hole effusion enter the gas-liquid separator 212 from the oil pipe 101, and the separated liquid is pressurized by the liquid pump 215 and is output by the output trunk line 500; the separated gas is pressurized by the air pump 213 and is delivered to the casing of the production tree by the gas lift line B. The gas in the casing enters the tubing via the bottom hole, along with the bottom hole fluid from the production tubing, and into the gas-liquid separator 212. And the gas lift is realized by circulating and reciprocating in this way.
In order to monitor the operation state of the oil and gas exploitation system, a plurality of groups of sensors are arranged in the embodiment. Referring to fig. 1, the sensor in the present embodiment includes:
1. a tubing pressure sensor 202 having a detection end connected to the tubing for monitoring tubing pressure P 202 Unit MPa;
2. a casing pressure sensor 301, the detection end of which is connected to the casing for monitoring the casing pressure P 301 The unit is MPa;
3. the gas path pressure sensor 214 has a detection end connected to the gas pump outlet side of the gas phase branch for monitoring the gas path pressure P 214 The unit is MPa;
4. a liquid level sensor 205 connected to the gas-liquid separator for monitoring the liquid level L in the gas-liquid separator 205 The unit is m.
Based on the structure of the oil and gas exploitation system, the invention also provides a control method to achieve the purposes of selecting and automatically controlling the first gas lift process and the first production process.
In this embodiment, the control method is performed by the control system 400 to realize automatic control of the system. It will be clear to a person skilled in the art that the control method may also be performed manually.
In this embodiment, the control system 400 is configured to control the valve, the air pump, the liquid pump, etc. according to the following parameters and preset control logic, so as to achieve the purposes of the first lift process, the first production process conversion and automatic control:
1. the preset parameters stored internally include: production critical pressure P s Gas lift end pressure P min Upper limit of liquid level L max And a lower limit of liquid level L min . Wherein the critical pressure P is produced s Gas lift end pressure P min Determined from gas well primary data. Upper limit of liquid level L max And a lower limit of liquid level L min Empirically determined;
2. a monitored parameter obtained from a sensor, comprising: (1) tubing pressure P acquired by tubing pressure sensor 202 202 The method comprises the steps of carrying out a first treatment on the surface of the (2) Casing pressure P acquired by casing pressure sensor 301 301 The method comprises the steps of carrying out a first treatment on the surface of the (3) Gas-liquid separator liquid level L acquired by liquid level sensor 205 205 。
The control system 400 includes a memory and a processor. The memory is pre-stored with instructions and preset parameters: production critical pressure, gas lift end pressure, upper liquid level limit and lower liquid level limit. The processor is electrically coupled to the memory and configured to execute the control logic shown in fig. 2 based on the instructions and preset parameters stored in the memory.
FIG. 2 is a flow chart of control logic of the control system of the first embodiment of the hydrocarbon production system of the present invention. As shown in fig. 2, the control logic includes:
step S21, judging the oil pipe pressure P 202 Whether or not it is greater than the production critical pressure P s If yes, executing step S22, otherwise executing step S23;
step S22, marking the production state, executing the first production process, and executing step S24;
wherein a value of 0 is assigned to X, i.e. indicating that the first production process is being performed.
The first production process is executed, namely, an instruction is sent to each valve, and the following steps are carried out: the air passage valve 217 is opened, the sleeve valve 302 is closed, and the air pump 213 is started.
Step S23, marking the gas lift state, executing a first gas lift process, and executing step S24;
wherein a value of 1 is assigned to X, i.e. indicating that the first lift process is being performed.
Wherein, the first gas lift process is executed, namely, instructions are sent to each valve, and the following steps are carried out: the sleeve valve 302 is opened, the air passage valve 217 is closed, and the air pump 213 is started.
Step S24, executing a drainage flow;
fig. 2A is a detailed flowchart of the step of "execute drainage flow" in fig. 2. As shown in fig. 2A, step S24 further includes:
substep S241, judging the liquid level L in the gas-liquid separator 205 Whether or not it is higher than the upper limit L of the liquid level max If so, sub-step S242 is performed; if not, executing sub-step S243;
in the substep S242, an instruction is sent to the liquid pump, and the instruction: the liquid pump is started, and then step S25 is executed;
substep S243, judging the liquid level L in the gas-liquid separator 205 Whether or not it is below the lower limit L of the liquid level min If so, sub-step S244 is performed; if not, executing step S25;
in the substep S244, an instruction is sent to the liquid pump, and the instruction: the liquid pump is turned off, and then step S25 is executed;
thus, the step S24 is completed.
Step S25, judging the current state, if the current state is the production state (x=0), executing step S21 again after time delay; if the gas lift state (x=1), step S26 is performed;
in this step, the delay time was 5 seconds. In actual operation, the delay time can be set by those skilled in the art as required.
Step S26, judging the casing pressure P 301 With tubing pressure P 202 Whether or not the difference is equal to or less than the gas lift end pressure P min If yes, go to step S21; if not, step S24 is performed.
Furthermore, the control system sets the following protection: when the air path pressure P 214 And after exceeding the upper limit and reaching a certain time, closing the system and giving an alarm.
The control method is realized manually, the gas lift and the production process of the oil-gas field can be carried out according to different working conditions and different stages, the economic benefit of the oil-gas field is exerted to the maximum extent, and the production cost is reduced. The control method is further realized through the control logic of the control system, so that the automatic switching of the first production process and the first gas lift process can be realized, and the automation degree of production can be greatly improved.
2. Second embodiment of the oil and gas production System
FIG. 3 is a schematic diagram of a second embodiment of an integrated gas lift and production hydrocarbon recovery system of the present invention. Compared with fig. 1, the oil and gas exploitation system of the embodiment is added with the following steps: bypass line A2 and corresponding valves and plumbing.
Referring to fig. 3, the gas lift and production integrated hydrocarbon production system of the present embodiment further includes:
a diversion pipe fitting 203, the inflow port of which is connected to the oil pipe 101 of the gas production tree, and the input end of the gas-liquid separator is connected to the first outflow port of the diversion pipe fitting;
bypass line A2, comprising: the bypass valve 221 has its input connected to the second outflow of the diverting fitting and its output connected to the output mains 500.
In addition, the oil and gas exploitation system of the embodiment further comprises: the oil pipe valve 201 is connected between the oil pipe 101 of the gas production tree and the inflow port of the shunt pipe fitting; the main valve 211 is connected between the first outflow port of the split pipe and the input end of the gas-liquid separator.
Through the above structure of the oil gas exploitation system, the first production process, the second production process, the first gas lift process and the second gas lift process are switched through the control of the gas path valve 217, the oil pipe valve 201, the main through valve 211, the bypass valve 221, the sleeve valve 302, the air pump 213 and the liquid pump 215. Specifically:
1. first production process
The application scene is as follows: the oil and gas well can normally produce oil gas, and the pressure of the oil pipe is smaller than the pressure of an output trunk line.
Component status: the sleeve valve 302 is closed, the main through valve 211 is opened, the air passage valve 217 is opened, the bypass valve 221 is closed, the oil pipe valve 201 is opened, and the air pump 213 is opened.
The technical process comprises the following steps: the bottom natural gas and the accumulated liquid are pumped out by the oil pipe 101, enter the gas-liquid separator 212 through the oil pipe valve 201 and the split pipe fitting 203, and are subjected to gas-liquid separation. The separated gas is pressurized by the air pump 213 and then is conveyed to the output trunk 500 through the air passage valve 217 and the air passage check valve 218, so that the oil and gas production is realized. The separated liquid is pressurized by the liquid pump and then delivered to the output rail 500 via the liquid path check valve 216.
2. Second production process
The application scene is as follows: the gas well can normally produce gas, and the pressure of the oil pipe is larger than the pressure of the output trunk line.
Component status: the sleeve valve 302 is closed, the bypass valve 221 is opened, the main through valve 211 is closed, the oil pipe valve 201 is opened, and the air pump 213 is closed.
The technical process comprises the following steps: under self pressure, the bottom hole natural gas is pumped out by the oil pipe and is delivered to the output trunk line 500 through the oil pipe valve 201, the diversion pipe 203 and the bypass valve 221.
3. First gas lift process
The application scene is as follows: the oil pipe of the oil and gas well is accumulated liquid, but not serious, and the gas production can be used for circulating liquid discharge production.
Component status: the sleeve valve 302 is opened, the oil pipe valve 201 is opened, the main through valve 211 is opened, the bypass valve 221 is closed, the air passage valve 217 is closed, and the air pump 213 is opened.
The technical process comprises the following steps: the mixed phase medium of the oil-gas field is pumped out by the oil pipe 101, enters the gas-liquid separation tank 212 through the oil pipe valve 201 and the main through valve 211, and the separated gas is pressurized by the air pump 213 and then is conveyed to the sleeve 102, and the separated liquid is pressurized by the liquid pump 215 and is conveyed to the output trunk 500. The gas in the sleeve 102 enters the oil pipe 101 from the bottom of the well, then enters the gas-liquid separator 212 again through the oil pipe valve 201 and the main through valve 211, and meanwhile, the bottom-hole effusion is carried to the oil pipe 101.
The above process is cycled until the pressures of the casing pressure sensor 301 and the tubing pressure sensor 202 approach a certain value, and after the bottom hole fluid is considered to have been carried over, the first production process or the second production process may be used for production.
4. Second gas lift process
The application scene is as follows: the accumulated liquid in the oil pipe of the oil-gas well can not produce gas or the gas production is very small, and the gas required by gas lift is not enough.
Component status: the oil pipe valve 201 is opened, the bypass valve 221 is opened, the main through valve 211 is opened, the air passage valve 217 is closed, the sleeve valve 302 is opened, and the air pump 213 is opened.
The technical process comprises the following steps: the mixed phase medium of the oil-gas field enters a gas-liquid separation tank 212 from a trunk line 205 through a bypass pipeline A2, a split pipe fitting 203 and a main through valve 211, the separated gas is pressurized by an air pump 213 and then is conveyed to a sleeve 102, and the separated liquid is pressurized by a liquid pump 215 and is conveyed to an output trunk line 500. The gas in the sleeve 102 enters the oil pipe 101 from the bottom of the well, is mixed with the medium from the bypass pipeline A2 at the position of the shunt pipe fitting 203 through the oil pipe valve 201, enters the gas-liquid separator 212 through the main through valve 211, and simultaneously carries the bottom-hole effusion to the oil pipe 101.
The above process is cycled until the pressures of the casing pressure sensor 301 and the tubing pressure sensor 202 approach a certain value, and after the bottom hole fluid is considered to have been carried over, the first production process or the second production process may be used for production.
Also, in order to monitor the operating conditions of the hydrocarbon production system, multiple sets of sensors are provided in this embodiment. Referring to fig. 4, the sensor in the present embodiment includes:
1. the oil pipe pressure sensor 202 is connected with an oil pipe at a detection end and is used for monitoring the oil pipe pressure P202 in MPa;
2. the gas circuit pressure sensor 214, the detection end of which is connected to the outlet side of the gas pump of the gas phase branch circuit, is used for monitoring the gas circuit pressure P214, and the unit is MPa;
3. a trunk line pressure sensor 204, the detection end of which is connected to the output trunk line and is used for monitoring the trunk line pressure P204, wherein the unit is MPa;
4. the casing pressure sensor 301, the detection end of which is connected to the casing and is used for monitoring casing pressure P301, and the unit is MPa;
5. the liquid level sensor 205 is connected to the gas-liquid separator and is used for monitoring the liquid level L205 in the gas-liquid separator, wherein the unit is m.
Based on the structure of the oil and gas exploitation system, the invention also provides a control method to achieve the purposes of selecting and automatically controlling the first gas lift process and the first production process.
In this embodiment, the control method is performed by the control system 400 to realize automatic control of the system. It will be clear to a person skilled in the art that the control method may also be performed manually.
In this embodiment, the control system 400 is configured to control the valve, the air pump, the liquid pump, etc. according to the following parameters and preset control logic, so as to achieve the purposes of the first lift process, the first production process conversion and automatic control:
1. the preset parameters stored internally include: production critical pressure P s Critical pressure Pj of circulating gas lift and end pressure P of gas lift min Upper limit of liquid level L max And a lower limit of liquid level L min . Wherein the critical pressure P is produced s Critical pressure Pj of circulating gas lift and end pressure P of gas lift min Determined from gas well primary data. Upper limit of liquid level L max And a lower limit of liquid level L min Empirically determined;
2. a monitored parameter obtained from a sensor, comprising: (1) tubing pressure P acquired by tubing pressure sensor 202 202 The method comprises the steps of carrying out a first treatment on the surface of the (2) Casing pressure P acquired by casing pressure sensor 301 301 The method comprises the steps of carrying out a first treatment on the surface of the (3) The rail pressure P acquired by the rail pressure sensor 204 204 The method comprises the steps of carrying out a first treatment on the surface of the (4) Gas-liquid separator liquid level L acquired by liquid level sensor 205 205 。
The control system 400 includes a memory and a processor. The memory is pre-stored with instructions and preset parameters: production critical pressure P s Critical pressure Pj of circulating gas lift and end pressure P of gas lift min Upper limit of liquid level L max And a lower limit of liquid level L min . The processor is electrically coupled to the memory and configured to execute the control logic shown in fig. 4 based on the instructions and preset parameters stored in the memory.
FIG. 4 is a flow chart of control logic of a control system in a second embodiment of the hydrocarbon production system of the present invention. As shown in fig. 4, the control logic includes:
step S41, judging the oil pipe pressure P 202 Whether or not it is greater than the production critical pressure P s If yes, executing step S42, otherwise executing step S45;
step S42, judging the oil pipe pressure P 202 Whether or not it is greater than the mains pressure P 204 If yes, go to step S43, otherwise, go to step S44;
step S43, executing a second production process, and then executing step S42;
wherein, the second production process is executed, namely, instructions are sent to each valve, and the following steps are carried out: stopping the air pump 213, opening the bypass valve 221, closing the main through valve 211, and opening the oil pipe valve 201;
step S44, marking the production state and executing the first production process;
wherein a value of 0 is assigned to X, i.e. indicating that the first production process is being performed.
The first production process is executed, namely, an instruction is sent to each valve, and the following steps are carried out: the bypass valve 221 is closed, the air passage valve 217 is opened, the main through valve 211 is opened, the oil pipe valve 201 is opened, the sleeve valve 302 is closed, and the air pump 213 is started.
Step S45, judging the oil pipe pressure P 202 If yes, executing step S46, otherwise, executing step S47;
step S46: executing a first gas lift process, and executing a step S48;
wherein, executing the first lift process, namely sending an instruction to: closing the bypass valve 221, opening the sleeve valve 302, closing the air passage valve 217, opening the main through valve 211, opening the oil pipe valve 201, and starting the air pump 213;
step S47, executing a second gas lift process, and executing step S48;
wherein, executing the second gas lift process, namely sending an instruction to make: opening the sleeve valve 302, closing the air passage valve 217, opening the main through valve 211, opening the oil pipe valve 201, opening the bypass valve 221, starting the air pump 213, and executing step S48;
step S48, marking a gas lift state;
wherein a value of 1 is assigned to X, i.e. indicating that either the first or the second gas lift process is being performed.
It can be seen that the step of marking the status may be performed simultaneously with the gas lift (or production) process, or may be performed before or after the gas lift (or production) process, and the present invention may be implemented.
Step S49, executing a drainage process;
the drainage process is similar to that shown in fig. 2, and will not be further described herein.
Step S410, judging whether X is 0 (judging whether the first production process is currently operated or not), if yes, executing step S41 after delaying for a certain time, otherwise executing step S411;
step S411, judging the casing pressure P 301 With tubing pressure P 202 Whether or not the difference is equal to or less than the gas lift end pressure P min If yes, step S41 is executed, otherwise step S49 is executed.
Furthermore, the control system sets the following protection: when the air path pressure P 214 And after exceeding the upper limit and reaching a certain time, closing the system and giving an alarm.
Through the control logic of the control system, the automatic switching of the first production process and the second production process and the first gas lift process and the second gas lift process can be realized, and the automation degree of production can be greatly improved.
Thus far, two embodiments of the present invention have been described in detail with reference to the accompanying drawings. It should be noted that, in the drawings or the text of the specification, implementations not shown or described are all forms known to those of ordinary skill in the art, and not described in detail. Furthermore, the above definitions of the elements and methods are not limited to the specific structures, shapes or modes mentioned in the embodiments, and may be modified or replaced simply by one skilled in the art, for example:
(1) The valve type can be a gate valve, a ball valve, a stop valve and the like;
(2) The control of the valve can be manual or electric, and an automatic control system is adopted for logic control.
From the foregoing description, it should be apparent to those skilled in the art that the gas lift and production integrated hydrocarbon recovery system of the present invention.
In summary, the invention realizes two functions of pressurized production or gas lift by controlling the opening and closing of each valve, and one set of equipment can solve various problems of a wellhead; meanwhile, the self-pressurization equipment is used for gas lift, so that the gas lift is not influenced by gas source pressure or the number of nearby wells, and the application scene is wider. The characteristics enable the invention to have good application prospect and high practical value in the field of oil and gas exploitation.
It should be noted that, in the embodiments, directional terms, such as "upper", "lower", "front", "rear", "left", "right", etc., refer to the directions of the drawings only, and are not intended to limit the scope of the present invention. Like elements are denoted by like or similar reference numerals throughout the drawings. Conventional structures or constructions will be omitted when they may cause confusion in understanding the present invention.
And the shapes and dimensions of the various elements in the drawings do not reflect actual sizes and proportions, but merely illustrate the contents of embodiments of the present invention. In addition, in the claims, any reference signs placed between parentheses shall not be construed as limiting the claim.
In the description of the present invention, it should be noted that, unless explicitly specified and limited otherwise, the terms "connected," "connected," and "connected" are to be construed broadly, and may be either fixedly connected, detachably connected, or integrally connected, for example; can be mechanically or electrically connected; can be directly connected or indirectly connected through an intermediate medium, and can be communication between two elements. The specific meaning of the term will be understood by those of ordinary skill in the art as the case may be.
Furthermore, the word "comprising" does not exclude the presence of elements or steps not listed in a claim. The word "a" or "an" preceding an element does not exclude the presence of a plurality of such elements.
Ordinal numbers such as "first," "second," "third," "primary," "secondary," and Arabic numerals, letters, etc., used in the specification and the claims are intended to modify a corresponding element (or step) only to distinguish one element (or step) from another element (or step) having the same name, and do not indicate any ordinal number for the element (or step) nor the order of the element (or step) from another element (or step).
Furthermore, unless specifically described or steps must occur in sequence, the order of the above steps is not limited to the list above and may be changed or rearranged according to the desired design. In addition, the above embodiments may be mixed with each other or other embodiments based on design and reliability, i.e. the technical features of the different embodiments may be freely combined to form more embodiments.
The algorithms and displays presented herein are not inherently related to any particular computer, virtual system, or other apparatus. Various general-purpose systems may also be used with the teachings herein. The required structure for a construction of such a system is apparent from the description above. In addition, the present invention is not directed to any particular programming language. It should be appreciated that the present invention can be implemented in a variety of programming languages, and the above description of specific languages is provided for disclosure of preferred embodiments of the invention.
While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
Claims (6)
1. An integrated gas lift and production hydrocarbon recovery system characterized by being connected to a hydrocarbon recovery tree of an oil and gas field;
the gas production tree comprises: an oil pipe at the inner layer; a sleeve sleeved outside the oil pipe;
the hydrocarbon production system includes:
a production line comprising:
the input end of the gas-liquid separator is connected to an oil pipe of the gas production tree;
a gas phase leg, comprising: the air pump is connected with the gas phase medium outlet of the gas-liquid separator at the input port and connected with the output trunk line through the air circuit valve at the output port;
the rear end of the gas lifting pipeline is connected to the output port of the air pump, and the front end of the gas lifting pipeline is connected to the sleeve of the gas production tree through a sleeve valve;
the inflow port of the split pipe fitting is connected to an oil pipe of the gas production tree, and the first outflow port of the split pipe fitting is connected to the input end of the gas-liquid separator;
a bypass line comprising: the input end of the bypass valve is connected to the second outflow port of the shunt pipe fitting, and the output end of the bypass valve is connected to the output trunk line;
the oil pipe valve is connected between the oil pipe of the gas production tree and the inflow port of the split pipe fitting;
the main through valve is connected between the first outflow port of the split pipe fitting and the input end of the gas-liquid separator;
the oil pipe pressure sensor is connected with the oil pipe at the detection end and is used for monitoring the pressure of the oil pipe;
the detection end of the sleeve pressure sensor is connected with the sleeve and is used for monitoring the sleeve pressure;
the main line pressure sensor is connected with the output main line at the detection end and is used for monitoring the main line pressure;
the control system is used for realizing the switching and automatic control of a production process, a second production process, a first gas lift process and a second gas lift process according to preset parameters, the oil pipe pressure, the casing pipe pressure and the trunk line pressure
The oil gas exploitation system is switched among a first production process, a second production process, a first gas lift process and a second gas lift process, wherein:
in the first production process, the sleeve valve is closed, the main through valve is opened, the gas path valve is opened, the bypass valve is closed, the oil pipe valve is opened, and the air pump is opened;
in the second production process, the sleeve valve is closed, the bypass valve is opened, the main through valve is closed, the oil pipe valve is opened, and the air pump is closed;
in the first air lift process, a sleeve valve is opened, an oil pipe valve is opened, a main through valve is opened, a bypass valve is closed, an air passage valve is closed, and an air pump is opened;
in the second gas lift process, an oil pipe valve is opened, a bypass valve is opened, a main through valve is opened, a gas circuit valve is closed, a sleeve valve is opened, and an air pump is opened;
the control system includes a memory and a processor;
the memory is pre-stored with instructions and preset parameters: production critical pressure, cycle gas lift critical pressure, gas lift end pressure;
the processor is electrically coupled to the memory and configured to execute the following control logic based on the instructions and preset parameters stored in the memory:
step S41, judging whether the oil pipe pressure is larger than the production critical pressure, if yes, executing step S42, otherwise, executing step S45;
step S42, judging whether the oil pipe pressure is greater than the main line pressure, if yes, executing step S43, otherwise, executing step S44;
step S43, executing a second production process, and then executing step S42;
step S44, marking the production state and executing the first production process;
step S45, judging whether the oil pipe pressure is greater than the circulating gas lift critical pressure, if yes, executing step S46, otherwise, executing step S47;
step S46: executing a first gas lift process, and executing a step S48;
step S47, executing a second gas lift process, and executing step S48;
step S48, marking a gas lift state;
step S49, executing a drainage process;
step S410, judging the current state, if the current state is the production state, executing step S41 after delaying for a certain time; if the gas lift state is established, step S411 is executed;
step S411, judging whether the difference between the casing pressure and the oil pipe pressure is less than or equal to the gas lift end pressure, if yes, executing step S41, otherwise, executing step S49.
2. The hydrocarbon production system of claim 1, wherein switching between a first production process and a first lift process, wherein:
in the first production process, a gas circuit valve is opened, a sleeve valve is closed, and an air pump is opened;
in the first air lift process, the air passage valve is closed, the sleeve valve is opened, and the air pump is opened.
3. The hydrocarbon production system of claim 2, further comprising:
the oil pipe pressure sensor is connected with the oil pipe at the detection end and is used for monitoring the pressure of the oil pipe;
the detection end of the sleeve pressure sensor is connected with the sleeve and is used for monitoring the sleeve pressure;
and the control system is used for realizing the switching and automatic control of the first production process and the first gas lift process according to preset parameters, the oil pipe pressure and the casing pressure.
4. The hydrocarbon production system of claim 3, wherein the control system comprises a memory and a processor;
the memory is pre-stored with instructions and preset parameters: production critical pressure, gas lift end pressure;
the processor is electrically coupled to the memory and configured to execute the following control logic based on the instructions and preset parameters stored in the memory:
step S21, judging whether the oil pipe pressure is larger than the production critical pressure, if yes, executing step S22, otherwise, executing step S23;
step S22, marking the production state, executing the first production process, and executing step S24;
step S23, marking the gas lift state, executing a first gas lift process, and executing step S24;
step S24, executing a drainage flow;
step S25, judging the current state, if the current state is the production state, executing step S21 again after time delay; if the gas lift state is the gas lift state, executing step S26;
step S26, judging whether the difference between the casing pressure and the oil pipe pressure is smaller than or equal to the gas lift ending pressure, if yes, executing step S21; if not, step S24 is performed.
5. The hydrocarbon production system of claim 1 or 4, wherein:
the hydrocarbon production system further comprises: the detection end of the gas circuit pressure sensor is connected to the outlet side of the gas pump of the gas phase branch circuit and is used for monitoring the gas circuit pressure; in the control system, preset parameters are pre-stored in the memory: an upper limit of the air pump outlet pressure; the control logic further comprises: when the pressure of the air path exceeds the upper limit of the pressure of the outlet of the air pump and reaches a certain time, the system is closed and an alarm is given; and/or
The hydrocarbon production system further comprises: the liquid level sensor is connected with the gas-liquid separator and is used for monitoring the liquid level in the gas-liquid separator; in the control system, preset parameters are pre-stored in the memory: an upper liquid level limit and a lower liquid level limit; the step of the control logic of executing the water draining process comprises the following steps:
sub-step S241, judging whether the liquid level is higher than the upper limit of the liquid level, if so, executing sub-step S242; if not, executing sub-step S243;
in the substep S242, an instruction is sent to the liquid pump, and the instruction: the liquid pump is started, and then the subsequent step of the step of executing the water draining process is executed;
substep S243, determining whether the liquid level in the gas-liquid separator is below the lower liquid level limit, if so, executing substep S244; if not, executing the subsequent step of the step of executing the water draining process;
in the substep S244, an instruction is sent to the liquid pump, and the instruction: the liquid pump is turned off and then the subsequent steps of the "perform drainage process" are performed.
6. An oil and gas production system according to any one of claims 1 to 4 wherein:
the production line further comprises: a liquid phase leg, comprising: a liquid pump, the input port of which is connected to the liquid medium outlet of the gas-liquid separator, and the output port of which is connected to the output trunk line;
in the oil gas exploitation system, a gas path one-way valve is arranged in a gas phase branch and only allows gas phase medium from the gas path valve to an output trunk line to flow unidirectionally; a liquid path one-way valve is arranged in the liquid phase branch and only allows liquid phase medium from the output port of the liquid pump to the output trunk line to flow in one way; a gas lift check valve is provided in the gas lift line that allows only one-way flow of medium from the air pump output port to the sleeve valve.
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