RU2346156C1 - Hydrocarbon material extraction control system - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: invention refers to coal industry, and is meant for controlling hydrocarbon material extraction. System includes several groups of wells each of which consists of well subsystems integrated by means of local information computer network which, by means of a link, is connected to the extraction control device unit through a heterogeneous information network. Each well subsystem consists of a parameter control module which is connected through the first communication link to the ground control unit of process modes, which in its turn is connected to local information computer network. Additionally, in the well subsystem there is the second communication link and information control unit which is connected to parameter control module and through the second communication link - to control unit of process modes, and whereto there connected is electric power supply device. Each well subsystem represents a distributed structure consisting of the first, second and third levels. The first level in bottom-hole zone consists of several downhole surveying devices, each of which includes the first controller, the inputs of which are connected to the first thermodynamic parameter gage unit and to the first actuator unit, and which is connected through the first link unit to the second level of the well subsystem, which is located in the area of lift string shoe. System parameter control module is connected through the first communication link to the process equipment control unit which is included in the third subsystem level and located on the surface.

EFFECT: improving control quality owing to output optimisation and control action realisation based on continuous monitoring of status of productive formation and wells.

2 cl, 4 dwg

Description

The existing hydrocarbon production process (HCS) includes complex technological management objects - productive formations, reservoirs (groups) of production and injection wells, a pipeline system, hydrocarbon and water treatment equipment, and the energy subsystem.

In the control system for hydrocarbon production, the main objects of control are the reservoir and groups of production and injection wells, which are characterized by a multitude of variable values that have significant uncertainty and unsteadiness [Sereda NG, Sakharov VA, Timashev AN Satellite oilman and gasman. Directory. - M .: Nedra, 1986. - 325 p.]. Among the main control actions on productive formations is the regulation of fluid pumping and pumping through production and injection wells, and on wells - control of flow rate, injection and pressure. This process, which is a single complex hydromechanical system, can be optimized based on operational control methods that use a sufficient amount of reliable measurement information and ensure synchronization of the correct actions of elements and factors that can give the greatest efficiency in general [Shakhverdiev A.X., Maximov M. M., Rybitskaya L.P., Zakharov I.V. Creation of an optimal management system for oil field development facilities. // Oil industry, No. 10, 2004, p.40-45].

Known control systems for hydrocarbon production based on periodic downhole measurements by cable and autonomous devices [Osadchiy V.M. State and prospects of geophysical (GIS) and hydrodynamic (GDI) studies of mechanized wells equipped with rod (SHG) and electric centrifugal (ESP) pumps, gas lift in Russia / Karotazhnik, No. 10-11, Tver, 2004 and US 2005/0217350 A1]. The development of control actions in such systems is carried out on the basis of selective discrete measurements, often initiated by repair work at the well, not more often than several times a year. In the course of these measurements, the state of the productive formation (s) and the producing well are evaluated by hydrodynamic and geophysical studies. Based on the results of these studies, the model of the field being developed is corrected, based on which, in turn, the parameters and components of the production process are changed. The disadvantages of this system are low efficiency, lack of opportunities for optimizing control actions due to the discreteness (spatial and temporal) of information feedback and significant delay in the case of using stand-alone devices. In addition, the lack of prerequisites for the use of downhole control tools significantly limits the efficiency of the hydrocarbon production process, especially when developing multi-layer deposits.

Cases of selective application of control systems are also known [Technical solutions that allow oil companies to save time and money. // Oil and gas technology, No. 2, 2002, p.41-43. A.Anderson. Integration Intelligent Well Systems With Other Comletion Techologies // The oil & gas review, 2005] according to Baker Oil Tools systems. These systems use a cable channel and control the flow rate by real-time pressure and temperature measurements using temperatureless adjustable fittings. As water is pumped into the reservoir, the operator monitors in real time the changes in the parameters and the state of each injection zone.

The disadvantages of the system are its high complexity and cost; in addition, in the case of using such a system, there is no consideration of the mutual influence of neighboring producing wells. Therefore, such systems are used for single highly debit wells developing multilayer reservoirs.

Closest to the proposed technical solution is the system [Lepekhin V.I., Vidyakin N.G., Valeev A.S., Cannes A.G. Development and operating experience of a complex of equipment for oil production automation. // Oil industry, No. 5, 2004, p.111-112], which is selected as a prototype. The mentioned system architecture refers to distributed control systems and includes at each well: a telemetry system consisting of a parameter control module that measures the pressure in the well at the reception of the submersible pump, the temperature of the submersible motor and the insulation resistance of electrical circuits, and a communication channel using galvanic circuits supplying current to the electric drive (combined channel); surface control device for technological conditions, located on the surface. The control devices for the technological regimes of each well are connected by a local information and computer network within the same group (cluster) of wells, which, in turn, is connected to the production control device in this field through a heterogeneous information network. At the well level, the system provides pressure stabilization in accordance with the set point, changing the operating mode of the pump equipment drive. The condition of submersible electrical equipment is also monitored. Changing the settings is possible remotely in software-controlled mode. The advantage of the system is simplicity, ease of operation. However, this system is not without drawbacks, namely:

1. The limited practical application associated with the orientation of the system to a specific production method, namely with the help of electric submersible pumps, the use of a combined communication channel of the telemetry system negatively affects the reliability of the information received and the reliability of communication.

2. The significant limitations of the downhole measurement information does not allow correct and efficient change of control actions, and the absence of downhole control means limits their set.

The aim of the invention is to improve the quality of the hydrocarbon production control system by optimizing the production and implementation of control actions based on operational monitoring of the state of the productive formation (s) and wells, expanding functionality due to invariance to the development method used.

The problem is solved by the hydrocarbon production control system at the field, which includes several groups of wells, each of which contains borehole subsystems connected by a local information and computer network, which is connected via a communication block through a heterogeneous information network to a production control device, and each borehole subsystem contains a module control parameters, which through the first communication channel is connected to a ground control device for technological modes, to Thoroe connected to a local area network information. The difference of the proposed system is that the well subsystem additionally contains a second communication channel and an information-regulating device, which is connected to the parameter monitoring module and, through the second communication channel, to the technological mode control device and to which the power supply device is connected. In the proposed system, each borehole subsystem can be implemented in the form of a distributed structure consisting of the first, second and third levels. The first level in the bottom-hole zone includes several downhole probes, each of which contains a first controller, the inputs of which are connected to the first block of sensors of thermodynamic parameters and the first block of actuators and which is connected through the first block to the second level of the borehole subsystem located in the shoe area lifting columns. The second level of the downhole subsystem includes a second controller connected via a second communication unit to the first level of the subsystem, as well as to the second block of thermodynamic parameter sensors, the second block of actuators, the parameter control module and the transceiver, and the parameter control module is connected through the first communication channel with a control device for technological equipment included in the third level of the subsystem located in the ground part, and the transceiver is connected Erez second communication channel to the third communication unit and the third controller are also included in the third level subsystem, wherein the third controller is connected through the interface unit with a local information network.

The invention is illustrated by drawings, where Fig. 1 is a structural diagram of a proposed hydrocarbon production control system (hereinafter referred to as a system), Fig. 2 shows an embodiment of a well subsystem, Fig. 3 shows the location of gas-liquid zones of a field, Fig. 4 shows the scheme of hydrocarbon production from the reservoir in the presence of a gas cap and underlying water.

The system (figure 1) includes a set of software and hardware related to groups (clusters) of wells 1 and 2 and connected to a heterogeneous information network 3, to which a production control device 4 and external objects 5 are also connected. At the level of each group wells, in turn, there is a set of borehole subsystems 6 ... 7, united by a local information-computer network 8, which is connected via a communication unit 9 to a heterogeneous information network 3. In turn, each borehole subsystem has connected to the network 8, the ground control device for technological conditions 10, which is connected by the first communication channel 11 with the parameter monitoring module 12 and the second communication channel 13 with the information regulatory device 14, the operation of which is provided by the power supply device 15.

The system in the steady state performs the following functions:

- monitoring the current state of field development and production;

- analysis of the potential of wells and development facilities;

- collection and storage of geological and field data;

- development of optimal control actions for each system object and their synchronous implementation.

The borehole subsystem contains, in contrast to the prototype, an information-regulating device 14, which contains means for measuring parameters in the well and actuators providing the control process in the borehole zone. The communication channel 13 transmits the measurement information to the surface of the device 10, as well as the commands and settings from block 10 to block 14. The device 15 provides power to the hardware of block 14. Like the prototype, the parameter control module 12 provides, through the communication channel 11, control of the parameters of the units by device 10.

The production control device 4 at a given field, the location of which is regulated only by the reach of a heterogeneous information network 3, thanks to this network, block 9, and a local information computer network 8, can quickly obtain the necessary information from each well and transmit control commands, instructions, settings to each well .

The presence of an additional telemetry channel in the well, firstly, provides universality of application, and secondly, increases the reliability and reliability of the transmission of measurement information and commands.

The need for universality is determined by:

1) The difference used in mining equipment - in addition to electric submersible pumps, sucker rod pumps are used, moreover, there is a fountain method of extraction.

In this case, there are no blocks 11 and 12.

2) Different functions of wells - production or injection (lack of submersible pump).

Subsystem 6 (figure 2) has a distributed three-level structure. Functions and purposes of blocks 11, 12 and 13 - similarly to figure 1. The first level of the subsystem, in the bottomhole zone, includes several downhole probes 16 ... 17. The composition of each downhole probe includes a first block of thermodynamic parameters sensors 18, a first controller 19, a first communication unit 20, a power supply 21, a first block of actuating devices 22. The second level of the downhole subsystem is localized in the area of the shoe of the lifting string and includes a parameter monitoring module 12 , the second controller 23, the second block of sensors of thermodynamic parameters 24, the second block of actuators 25, the transceiver 26, the second communication unit 27 and the power supply 28. The third level of the subsystem, location wife in the ground part, is formed by a third controller 29, a third communication unit 30, a process equipment control device 31, an interface unit 32. The third level of the subsystem is connected, on the one hand, with the second level with the first communication channel 11 and the second communication channel 12, on the other, through block 32 - with a local computer network (LIVS).

Downhole probe 16 operates as follows. The controller 19 implements a predetermined measurement program with the help of sensors 18. The controller 19 performs control actions at this level using actuators 22, and the actuators, in addition to mechanical ones (valves, gate valves), include emission sources of chemicals (scale inhibitors, corrosion and etc.). The main purpose of the communication unit 20 is the exchange of information between downhole probes and the controller of the second level of the downhole subsystem. The power supply 21 provides power to the hardware of the downhole probe and can be autonomous or only a converter of electrical energy (in the case of a wire connection between the downhole probes and the second level of the subsystem).

The main purpose of the second level of the subsystem is to collect and pre-process the measurement information of downhole probes, transmit control commands to them, and also exchange information through block 26 through the communication channel 13 with the third level of the subsystem. At the second level of the borehole subsystem, the task of collecting measurement information and performing control similarly to the first level is also solved, in addition, block 12 provides control of the parameters of the pumping unit and their transmission through the first communication channel 11 combined with current-carrying circuits to the ground part. The presence of communication between blocks 12 and 23 allows you to organize a reservation of information transfer in the event of a failure of channel 11 or 13. Communication channel 13 can be wired, wireless or combined (a combination thereof). In addition, the presence of two independent communication channels provides maximum versatility in the use of equipment (mutual independence). Block 28 provides power to the hardware at this subsystem level. Its implementation is similar to block 21, in addition, it is possible to select a small part of the electric power from the drive of a submersible pump unit.

At the third level of the subsystem through the third controller 29 is the collection, processing and storage of information. Through block 32, data is exchanged with a local information computer network (LIVS). The third communication unit 30 provides a connection through the communication channel 13 of the controller 29 to the downhole part. The technological modes of the equipment as a function of the measurement information and the control program (commands) are controlled by a device 31, which also controls the parameters of the submersible pumping equipment received from unit 12, and sends this data to the third controller 29, which, if these parameters go beyond the permissible limits, regulates or turns off the pump electric drive.

Based on the foregoing, in accordance with the schemes of figure 1 and figure 2:

- ground control device for technological conditions 10 includes blocks 29 ... 32;

- the device information and control 14 consists of downhole probes 16 ... 17, as well as blocks 23 ... 27;

- the power supply device 15 includes a block 28 and blocks 21 from the composition of downhole probes.

Using specific examples, we illustrate the operation of the system. As already mentioned, to increase the efficiency of hydrocarbon production, various impacts on the formation and wells are performed (geological and technical measures - geological and technical measures). The selection of parameters for the geological and technical measures is a stage that has a significant impact on the final result, and should be based on the dynamics of the entire hydrocarbon production process. The dominant effects on the formation are: regulation of the flow of pumping and injection; per well: regulation, first of all, of bottomhole pressure, as well as flow rate of the well, phase transformations of gas-liquid mixtures, the amount of impurities, the shape and speed of advancement of water-gas-oil contacts. Since the real production process is a very complex multi-connected phenomenon, therefore, mathematical models are used that describe various processes with a certain level of adequacy.

A mathematical control model can be represented, for example [Emaletdinov A.K., Baykov I.V. On the problem of designing automated control and modeling of the subsystem for maintaining the reservoir pressure of an automated process control system for oil production // Vestnik OGU, 2004, No. 12, p.160-163.], As:

- вектор состояния объекта (коэффициент обводненности, пластовые давления и потоки);Where

- the state vector of the object (water cut coefficient, reservoir pressure and flows);

- вектор управляющих воздействий (давления и дебиты скважин);

- vector of control actions (pressure and flow rates of wells);

A - matrix of object parameters (hydrodynamic connections of wells).

For the case of process control by pumping - pumping fluid to maintain reservoir pressure, the condition [Emaletdinov AK, Baykov IV. On the problem of designing automated control and modeling of the subsystem for maintaining the reservoir pressure of an automated process control system for oil production // Vestnik OGU, 2004, No. 12, p.160-163.]:

where q _Di , (i = 1 ... k) is the production rate k of the producing wells,

q _Nj , (j = 1 ... m) is the flow rate of m injection wells.

.Moreover, the rate of injection of the displacing fluid should be optimal - q ₀ , and

.

In this case, it is necessary to accurately determine, in real time, the parameters of fluid injection in injection wells and pumping in production wells, taking into account the mutual influence of the entire population of wells.

As can be seen from figure 3, the oil-saturated zone is surrounded by a flooded area. Here are the management objects:

- productive layer;

- group of producing wells (d1 ... d6);

- group of injection wells (n1 ... n6).

Control actions:

- regulation of production from each producing well;

- regulation of injection into each injection well.

In the process of external waterflooding, the current contour of the oil-water contact (WOC) due to the heterogeneous hydraulic conductivity of the reservoir has progressed unevenly with respect to the producing wells. This information was obtained in the on-line mode by measuring the thermodynamic parameters of the first level of the system in the bottom-hole zones of production and injection wells, preliminary processing and transmission of measurement information to the ground part and then through a heterogeneous information network to the production control device.

The production control device analyzes the current position of the oil well and sends commands and settings to the process control devices of each well in accordance with, for example, the task of leveling the oil well, namely:

- well n1 - cessation of injection, well d1 - decrease in production volume;

- well n2 - decrease in injection volume, well d2 - increase in production volume;

- well n3 - stabilization of the injection volume, and well d3 - stabilization of the production volume;

- well n4 - decrease in injection volume, well d4 - increase in production volume;

- well n5 - stabilization of the injection volume, and well d5 - stabilization of the production volume;

- well 6 - decrease in injection volume, well 6 - increase in production.

In the case of the location of the oil reservoir between the gas cap and the aquifer (Fig. 4) during operation, the faces of the production wells occupy different positions relative to the current oil-gas contact and gas-oil contact (GOC). Moreover, in the bottom-hole zone of well d3 there is a water cone. Information about the state of the object is obtained similarly to the above. In this case, the management objects:

- productive layer;

- group of producing wells (d1, d2, d3).

Control actions:

- regulation of production from producing wells;

- selection of geological and technical measures in production wells.

The production control device similarly generates commands and settings in order to:

- increase the production volume at well d1;

- at well 2, to ensure stabilization of production;

- at well D3, reduce production volume with subsequent transfer of the perforation interval up and isolation of the existing perforation interval.

It should be noted that the change in fluid flow occurs in accordance with the previously indicated restrictions by law:

q _i = f [A (t) X (t)]

where q - fluid flow i - wells;

A - matrix of object parameters (hydrodynamic connections of wells);

X (t) is the current state of the object.

It is necessary to dwell separately on the problem of hydrocarbon production from oil wells operating several formations together. As shown in [Belous VB, Mazhar A.A., Gulyaev D.N., Ipatov A.I., Kremenetsky M.I. A new technology for monitoring oil wells operating together in several reservoirs. // Oil industry, 2006, No. 12, pp. 62-67], the possibility of this method can be provided on the basis of a multi-sensor autonomous measuring system installed in the roof of each reservoir. However, the presence of only autonomous meters and the absence of the necessary regulators does not allow us to fully solve the problem of optimizing the production of hydrocarbons from multilayer fields. Therefore, the presence of a distributed measuring borehole subsystem, coupled with actuators, for example, for regulating individual flows of gas-liquid borehole mixtures in the proposed technical solution, ensures the efficient operation of multilayer fields.

Thus, the advantage of the proposed system are.

1. Operational optimization of the development and implementation of control actions based on operational monitoring of the state of the productive formation (s) and wells.

2. The invariance of the system to the used method of field development.

3. Expanding the list of control actions through the use of downhole actuators, which is especially important when developing multi-layer deposits.

Claims (2)

1. A hydrocarbon production control system for a field comprising several groups of wells, each of which contains borehole subsystems connected by a local information computer network, which is connected via a communication block through a heterogeneous information network to a production control device, each borehole subsystem containing a monitoring module parameters, which through the first communication channel is connected to a ground control device for technological modes, which is connected to a local nformatsionno computing network, characterized in that the downhole subsystem further comprises a second communication channel, information and a control device which is connected to the control module and parameters through the second communication channel - to the technological mode control device and that is connected to power supply device. 2. The system according to claim 1, characterized in that each borehole subsystem is a distributed structure consisting of first, second and third levels, and the first level in the bottomhole zone includes several downhole probes, each of which contains a first controller, inputs which is connected to the first block of sensors of thermodynamic parameters and the first block of actuators and which is connected through the first block of communication with the second level of the borehole subsystem located in the area of the shoe columns, which includes a second controller connected through the second communication unit to the first level of the subsystem, as well as to the second block of sensors of thermodynamic parameters, the second block of actuators, the parameter control module and the transceiver, and the parameter control module is connected through the first communication channel with a control device for technological equipment included in the third level of the subsystem located in the ground part, and the transceiver is connected through the second channel to ides with the third communication unit and the third controller are also included in the third level subsystem, wherein the third controller is connected through the interface unit with a local information network.

Images