RU2681738C1 - Optimization system of work of oil and gas wells group - Google Patents

Abstract

FIELD: oil and gas industry.SUBSTANCE: invention relates to the oil industry, in particular to the field of control parameters of the well fluid (WF) in the system of optimization of the group of wells by controlling the installations of electric centrifugal pumps (ECPs) on the oil and gas well cluster according to the operating conditions of the well and the parameters of the WF. This system contains a wellhead module (WM) installed on the discharge pipeline of each well, which is made in the form of a pipeline segment with connecting flanges, a device for measuring the component composition of the WF. Output of each WM is connected by a pipeline to the input of a fluid flow switch that connects it either to the input of a group metering unit (GMU) or to an outlet collective pipeline. In this case, the electric motor of each WM is connected to the general control unit of the system, which, in turn, is connected to the switch by control tires. At the same time, the wells are connected to wellhead modules installed on the discharge pipeline of each well with movable nozzles, driven by electric motors and connected to the inlet nozzles of a circular flow switch, the outlet of which is connected to the inlet of the sensor of a flow-through protonic magnetic resonance analyzer (PMRA) with an inductor, a quarter wave line connected to the transmitter and receiver PMRA, the output of which is connected to a control unit connected to voltage and frequency converters (VFC), the outputs of which are connected by power buses to submersible electric motors in installations of centrifugal pumps of oil and gas wells.EFFECT: technical result consists in expanding the functionality of the inventive system.3 cl, 2 dwg

Description

The invention relates to the oil industry, in particular to the field of monitoring parameters of a borehole fluid (SCF) in a system for optimizing the operation of a group of wells by controlling the installation of electric centrifugal pumps (ESP) on a cluster of oil and gas wells according to the operating conditions of the well and parameters of the drilling fluid in accordance with GOST R 8.615-2005 GSI . Measurement of the amount of oil and gas extracted from the bowels (Order of the Ministry of Energy No. 69 dated 03/31/2005).

A known control system of technological modes of a group of oil and gas wells according to patent RU 2168011, class. Е21В 47/10, Е21В 43/34, dated May 27, 2001, comprising a switch for wells, an inlet pipe, a connecting switch to a gravity-type separator for separating gas, and pipelines for discharging gas and liquid from the separator. A Coriolis-type mass flowmeter is installed on the liquid line to measure the flow rate and density of the oil-water emulsion, as well as a device for continuously measuring the water content in the emulsion — a capacitive, microwave, infrared, or radio frequency moisture meter. The known system allows remote monitoring of a group of wells at a lower cost than the previous one, since one metering device is shared between a group of wells.

The main disadvantage of the known system is the inability to function in real time. This is due to the fact that the measurement of the productive parameters of oil and gas wells and the identification of changes in these parameters is carried out sequentially according to a predetermined measurement schedule. This circumstance, together with the absence of any means of automatic regulation of the production system, results in the inability to build a response of productive parameters when varying the parameters of the downhole equipment, and to implement optimization of hydrocarbon recovery from the reservoir. It is impossible to reduce the time intervals between measurements by increasing the switching frequency, since this reduces the reliability of the system and increases the risk of accidents (rupture of the pipeline), and also quickly generates a switch resource, which leads to spurious flows between switch ports and introduces uncontrolled measurement errors.

A device for otmigorization of an oil well with a simultaneous measurement of its flow rate according to patent RU 2318988, class. Е21В 43/00, dated 10.03. 2008, containing a shut-off element installed on the flow oil pipeline, in front of which a wellhead pressure sensor and an annular pressure sensor placed on the annulus of the well are installed, which are connected to a control unit, the output of which is connected to the shut-off actuator. The output of the oil pipeline is connected to the annulus by a gas pipeline equipped with a second locking body with its actuator, the input of which is connected to the control unit. At the same time, each of the locking elements is made in the form of a valve with an adjustable throughput. The known device allows not only to automatically measure well operation modes, but also to change them according to a predetermined algorithm, i.e. solve the simplified task of optimizing the operation of an oil well. The device can allow the well to work for a long time, optimizing its wellhead pressure if changes in water cut and gas factor are insignificant. The system is autonomous, i.e. does not require highly qualified staff.

The main disadvantage of the known system is the lack of measuring tools that allow real-time measurement of the component composition of the well fluid. It is impossible to calculate the flow rate of a group of wells according to once measured (once a month) parameters obtained using a group metering unit (GZU), because in this calculation, the water cut and gas factor of the well or group of wells are assumed to be constant (constant). Without knowledge of the real-time parameters of the well (flow rate, component of oil and gas - oil, water and gas), it is impossible to optimize the composition of the well, and especially the group of wells. Another serious drawback of the known system is that it is applicable for solving one optimization problem - stabilization of wellhead pressure in one well and is poorly suited for optimizing the operation of a group of wells that have a mutual influence on each other. In addition, it does not allow to identify suboptimal production modes or failures in the operation of downhole equipment (unexpected emissions of water, gas, etc.).

The prototype is a system for optimizing the work of a group of oil and gas wells according to patent RU 135354 U1, class. Е21В 43/12, Е21В 47/06 dated 05/13/2013, containing a wellhead module (UM) installed on a discharge oil pipeline of each well with a shut-off element (30) and pressure and temperature differential sensors, while the UM is made in the form of a pipe segment with connecting flanges inside of which there is a device for measuring the component composition of the SKZh and a locking member in the form of an adjustable constrictive device with pressure drop measurement sensors on it, and the output of each PA is connected by a pipeline to the input of the fluid flow switch connecting about it either with the input of a group metering unit (GZU), or with an output collective pipeline, and each PA contains a control interface connected to a ZO and differential pressure and temperature sensors, which is connected to a common control unit of the system with its control and data transfer buses, which, in turn, is connected to the switches by the control bus and to the GZU.

The main disadvantage of the known system is that, as a control action to optimize the operation of the well and group of wells, there is a locking device in the form of a tapering section of the pipe segment, which creates dynamic resistance to the flow of the SCF and affects only the pressure at the wellhead. This leads to increased load on the electric motor of the ESP and additional energy consumption.

Another serious drawback is that a high-frequency impedance meter and a neutron densitometer are used as a device for measuring the component composition of the SCR. The first device with high water cuts of oil works with a high error, because its readings are affected by the phase inversion at 60-70% humidity - the transition from an oil-in-water emulsion to an oil-in-water emulsion. The neutron densitometer contains a radioactive source, which requires continuous protection of equipment, i.e. the constant presence of qualified personnel in the well and field.

Another disadvantage is the low representativeness of the sample, since measures are not provided for its homogenization before measurement and the measurement of the sample is carried out at the same point of the narrowing CM.

Another disadvantage is the lack of a device for measuring flow rate (well flow rate) and gas content of SKZh, which is a requirement of GOST R 8.615-2005 GSI. Measurement of the amount of oil and gas extracted from the bowels (Order of the Ministry of Energy No. 69 dated 03/31/2005). Each component of the SKZh requires a separate device for measurement, which results in a complex measuring complex, which in turn requires the continuous protection of equipment and the constant presence of qualified personnel in the well and field.

The objective of the invention is to develop a system for optimizing the work of a group of oil and gas wells, which eliminated the disadvantages of analogues and prototype.

The technical result consists in expanding the functionality of the claimed system through the use of: a voltage and frequency converter (VLF) for controlling the operation of electric motors of electric centrifugal pump installations (ESP) on a cluster of oil and gas wells; wellhead module in the form of an expanding conical section of pipe; a movable nozzle for sampling from the MIND; rapid flow proton magnetic resonance analyzer (PMRA) as a device for measuring the SCR parameters - the concentration of water, oil and gas, flow rate and density of components.

The technical result is achieved in that a system for optimizing the operation of a group of oil and gas wells, comprising an wellhead module (UM) installed on a flow oil pipeline of each well, which is made in the form of a section of a pipeline with connecting flanges, a device for measuring the composition of the SKZh, the output of each UM is connected by a pipeline to the input a fluid flow switch connecting it either to the input of a group metering unit (GZU), or to an output collective pipeline, while the electric motor of the CM is connected to a common control unit of the system, which, in turn, is connected to the switch by the control buses, according to the present invention, the wells are connected to wellhead modules with movable nozzles, driven by electric motors and connected to the input branch pipes of the circular switch, mounted on the discharge pipeline of each well flows, the outlet pipe of which is connected to the input pipe of the flow-through proton magnetic resonance analyzer (PMRA) sensor with an inductance coil spine, a quarter wave line is connected with the transmitter and receiver PMRA whose output is connected to the control unit connected to a voltage and frequency converter (VFC), the outputs of which are connected with busbars submersible installations of electric motors of pumps in oil and gas wells. In this case, the MIND is made in the form of an expanding conical section of the pipe, and flowing PMRA is used to measure the parameters of the SKZh.

The invention is illustrated in the drawing, where in FIG. 1. presents a diagram (for example, three wells) of the implementation of the inventive system.

Designations in the drawing:

1a-1c — wells;

2a-2c - flow gas pipelines;

3a-3c — wellhead modules;

4 - trunk pipeline;

5a-5c — movable nozzles;

6a-6c — combs;

7a-7c - electric motors;

8a-8c - input branch pipes of the circular switch;

9 - circular switch;

10 - output pipe of a circular switch;

11 - sensor;

12 - flow through PMR express analyzer;

13 - discharge pipe;

14 - inductor;

15 - transmitter;

16 - receiver;

17 - PMR relaxometer;

18 - control unit;

19a-19c - tires;

20a-20v - voltage and frequency converters (VLF);

21a-21v - submersible electric motors;

22a-22v - electric centrifugal pumps.

The system includes wells 1a-1v (there can be much more wells - up to 24 on gas-distributing unit) connected to wellhead modules 3a-3b installed on the flow oil pipeline 2a-2v in each well, outlet pipes connected to main pipeline 4, movable pipes 5a-5b, through the combs 6a-6c driven by electric motors (step or other) 7a-7b and connected to the inlet pipes 8a-8b of the circular flow switch 9, the output pipe 10 of which is connected to the input pipe of the sensor 11 flow through PMR express analysis Ora 12 with a discharge pipe 13 for draining the measured sample into the pipeline 4, inductance 14 of the sensor 11, a quarter wave line connected to the transmitter 15 and receiver 16 of the PMR 17 PMR analyzer 12 connected to the control unit 18, buses 19a-19b connected to voltage and frequency converters (VLF) 20a-20v, the outputs of which are connected to submersible electric motors 21a-21v of electric centrifugal pump installations 22a-22v.

The system implementation scheme works as follows. Downhole fluid from wells 1a-1c through flow pipelines 2a-2v in each of the wells alternately enters the wellhead modules 3a-3b and exits through the outlet pipes into the main pipeline 4. Part of the downhole fluid enters the movable pipes 5a-5b, through combs 6a-6b driven by electric motors 7a-7c and further through the inlet pipes 8a-8c of the circular flow switch 9 through the output pipe 10, in turn, depending on the position of the flow switch 9, enters the sensor 11 of the flowmeter PMR relaxometer 17 express analyzer 12, where measurements of the SKZh parameters are performed and then through the discharge pipe 13 the measured sample is poured into the pipeline 4. In the inductor 14 of the sensor 11, the sample is irradiated with an RF pulse from transmitter 15 of the relaxometer 17, after which a PMR signal is generated in the coil 14, which through a quarter the wave line enters the receiver 16 of the PMR relaxometer 17 of the PMR analyzer 12, connected to the control unit 18, in which a control signal is generated and from which signals are sent via buses 19a-19b the voltage and frequency converters (VFDs) 20a-20v, which change the voltage and frequency of submersible electric motors 21a-21v of electric centrifugal pump installations 22a-22v.

To test the operability of the inventive system, a stand for controlling the movement of the pipe in the wellhead module for sampling gas-liquid mixtures was assembled (Fig. 2).

The performed model experiments showed the suitability of the designed samples for solving the problems of optimizing the well’s operation through the control units and the LPF located at the wellhead by changing the rotation speed u and the moment M of the rotor of the ESP submersible electric motor through the LPF depending on the changing parameters of the flow velocity ν, density ρ, the concentration of water W and gas G.

Claims (3)

1. A system for optimizing the operation of a group of oil and gas wells, comprising an wellhead module (UM) installed on a flow oil pipeline of each well, which is made in the form of a section of a pipeline with connecting flanges, a device for measuring the composition of the wellbore fluid (SKZh), the output of each UM is connected by a pipeline to the input a fluid flow switch connecting it either to the input of a group metering unit (GZU), or to an output collective pipeline, while the electric motor of each PA is connected to general system control unit, which, in turn, is connected to a switch by control buses, characterized in that the wells are connected to wellhead modules installed on the discharge oil pipe of each well with movable nozzles, driven by electric motors and connected to the input branch pipes of the circular flow switch, output the branch pipe of which is connected to the inlet pipe of the flow-through proton magnetic resonance analyzer (PMRA) sensor with an inductance coil, a quarter wave line connected to the PMRA transmitter and receiver, the output of which is connected to a control unit connected to voltage and frequency converters (VFDs), the outputs of which are connected by power buses to submersible electric motors in electric centrifugal pump installations for oil and gas wells. 2. The system according to p. 1, characterized in that the PA is made in the form of an expanding conical pipe section. 3. The system according to claim 1, characterized in that the flowing PMRA is used to measure the parameters of the SKZh.

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