Patent Application
20100147511
The present application relates in general to well systems and more particularly to injection wells.
It is often desired to inject a fluid into a subterranean geological formation. With reference to hydrocarbon operations it is often desired to dispose of the produced water through reinjection and/or to inject a fluid, typically water, as a method of tertiary hydrocarbon production. Typically, the injection fluid is pumped from the surface of the well, through the well and into the geological formation. For example, reservoir fluid is produced from the well to the surface. The produced fluid is separated into the primarily hydrocarbon fractions, or phases, and a primarily water fraction. It may be necessary to chemically treat the water fraction to make it again compatible with the reservoir formation. The water fraction is then injected into the reservoir formation via the wellbore. To monitor and control the water injection, data such as pressure and flow rate are obtained at the surface (wellhead). This process of injecting is often inefficient and the manner of monitoring the injection of fluids is often inaccurate.
One embodiment of a method includes the steps of operating a pump disposed in a wellbore to inject a fluid into a formation penetrated by the wellbore; obtaining a well parameter in real-time; and outputting a signal in response to a correlation of the well parameter and a preselected threshold parameter.
An embodiment of a method for surveillance of a well includes the steps of providing a pumping system in a wellbore that penetrates a formation; producing a fluid from the formation into the wellbore; injecting a fraction of the fluid from the wellbore into the formation via operation of the pumping system; surveying the pumping system in real-time via a sensor that senses well data; determining in real-time the correlation of a well parameter with a preselected threshold well parameter, wherein the well parameter is related to the sensed well data; and outputting a signal in response to the well parameter exceeding the preselected threshold parameter. The method may further include separating, in the wellbore, the fluid into a primarily oil fraction and a primarily water fraction, wherein the primarily water fraction is the fraction of the fluid injected into the formation by an electric submersible pump system of the pump system. The method may also include the step of producing the primarily oil fraction of the fluid from the wellbore by a second pump of the pump system. In some embodiments, the well parameter may be derived from the sensed well data and the well parameter may be an injectability parameter. The well data may be sensed in the wellbore, proximate to the formation zone in which the fluid is injected.
An embodiment of an injection well surveillance system includes a wellbore penetrating a formation; a fluid separation system disposed in the wellbore, the system separating a primarily oil fraction and a primarily water fraction from a fluid produced from a producing zone of the formation into the wellbore; a pump system disposed in the wellbore, the pump system including an injection pump injecting the primarily water fraction into an injection zone of the formation; a sensor disposed in the wellbore, the sensor sensing well data; and a control center to receive the sensed well data and to output a signal in response to a correlation of a well parameter associated with the sensed well data and a threshold well parameter.
The foregoing has outlined some of the features and technical advantages of the present application in order that the detailed description that follows may be better understood. Additional features and advantages will be described hereinafter which form the subject of the claims.
The foregoing and other features and aspects will be best understood with reference to the following detailed description of a specific embodiment, when read in conjunction with the accompanying drawings, wherein:
Refer now to the drawings wherein depicted elements are not necessarily shown to scale and wherein like or similar elements are designated by the same reference numeral through the several views.
The present application generally relates to a system and method for remote real-time surveillance, control, and optimization of injection well systems. The devices, systems and methods described herein may enable a well operator or well field manager to better manage and optimize operation of one or more pumping systems without physically attending the wellsite. For example, the system and methodology enhances the monitoring, surveillance, diagnostics, and optimization of injection well systems using real-time and on-time data in a cost efficient manner.
Referring generally to
Surveillance and control system 20 further comprises a remote control center 26 where surveillance data is obtained from wellsite 22 and pumping systems 24 on a real-time and on-time basis. Surveillance data may include, without limitation, data related to the well which may include surface and downhole parameters, such as pressure, temperature, fluid density, water cut of fluid, hydrocarbon fraction of fluids, fluid flow rates, pump speeds, pump temperatures, and the like.
Control center 26 may comprise one or more processor-based control systems 28, such as computer-based workstations where wellsite operators or managers can observe data obtained from wellsite 22 and pumping systems 24. This well data can be used for analysis, planning, and decision-making with respect to operation of pumping system 24 and the overall wellsite. Additionally, control systems 28 can be used to provide control instructions to wellsite 22 along with, for example, action updates, data polling, and queries.
Either at remote control center 26 or at another remote location, surveillance and control system 20 can include a data storage system 30 to retain data. Data storage system 30 also can be used to provide user security controls, alarm and alert management, business process management, and other functionality in cooperation with remote control center 26. For example, remote control center 26 and data storage system 30 enable a multidiscipline collaboration and historical interrogation of wellsite data to aid in diagnostic analysis and optimization of pumping system operation.
Control system 28 in cooperation with data storage system 30 also can be used to instigate alarms/alerts when real-time data or data trends indicate changes causing concern with respect to operation of pumping systems 24, e.g. movement of parameter values into a sub-optimal range or beyond a predetermined threshold value. The alerts can be provided at control system 28 and/or at a variety of other monitoring locations. For example, the alerts may be provided to remote handheld devices 32, such as cellular telephones 34 or personal digital assistants 36.
The two-way communication between wellsite 22 and the various remote locations, e.g. remote control center 26, data storage system 30, and remote handheld devices 32, is accomplished over a network 38. Network 38 can be established via a variety of transmission mechanisms, including wired and wireless mechanisms 40. For example, the two-way communication of data between wellsite 22 and the remote locations can be sent at least in part over the Internet. Portions of the network may be hardwired, may comprise satellites 42 for satellite transmission, may comprise cellular or radio towers 44 for wireless transfer, or may comprise a variety of other data transmission technologies for conveying data, including real-time data, between the wellsite 22 and the various remote locations of surveillance and control system 20.
Control system 28 is designed to automate processing of much of the data flow within surveillance and control system 20. In the present example, control system 28 is a computer-based system having a central processing unit (CPU) 46, as illustrated in
As illustrated by the flowchart of
The use of communication tools, such as network 38, control system 28, remote handheld devices 32, data storage systems 30, and other potential devices coupled into network 38, enables a well operator to facilitate surveillance and optimization of well behavior without traveling to the specific wellsite. As illustrated in the flowchart of
Furthermore, the well operator can program control system 28 and CPU 46 to provide alerts/warnings when well-related parameters fall outside a desired range or cross a specific set point, as illustrated by block 68. For example, alerts may be communicated when input performance thresholds or set points, such as injectability parameters of the Hall plot of
One example of a wellsite 22 and wellsite equipment used in the injection and/or production of hydrocarbon-based fluids is illustrated in
In addition to sensor devices 80 and other surveillance equipment, surveillance and control system 20 may comprise a variety of controllable devices 82 which regulate operation of injection well 74 and pumping system 24. Controllable devices 82 can be controlled remotely via control signals sent over network 38 from one or more remote locations, such as remote control center 26. One example of a controllable device 82 is a variable speed drive that can be controlled remotely and in operational connection with an electrical submersible pump 78. Controllable devices 82 may comprise a variety of other controllable devices that may be positioned at the surface and/or in the wellbore. For example, and without limitation, controllable devices may include downhole fluid separators 82a (
In the illustrated embodiment, controllable devices 82 e.g. pump controllers, valves, downhole separator, etc., and sensor devices 80, interface with a site communications box 84 which is used to relay signals between the various wellsite devices and network 38. By way of example, the site communications box 84 may comprise a satellite radio and process-assisted communicator 86 for relaying signals to and from satellite 42. The data from wellsite 22, for example, can be transferred to a remote management system 88 that provides Internet access to the data from a variety of Internet accessible remote locations 90, as illustrated in
As illustrated in
In one embodiment, surveillance and control system 20 comprises a web-based application that allows individuals to monitor and control equipment at one or more wellsites 22 from virtually anywhere in the world. In this embodiment, an operator requires only a web browser and an Internet connection to gain access at a variety of remote locations 90. With the use of, for example, a graphical user interface, the operator can simply click on-screen buttons and select drop-down menus to easily access any monitored and/or control points, as discussed more fully below. Of course, access to the system can be controlled by various security measures, including user profile permissions as set by, for example, a project supervisor.
Refer now to
Wellbore 74 is completed with a downhole separator, generally denoted by the numeral 82a, to promote the separation of fluid phases of wellbore fluid 100. In the illustrated embodiment, downhole separator 82a promotes separation of the wellbore fluid into a primarily oil phase 100a and a primarily water phase 100b. Downhole separator 82a may be provided in various configurations and may include sensors 80 and controllable elements 82, such as valves and the like. Some examples of downhole separator devices and systems are disclosed in U.S. Pat. No. 6,719,048 which is incorporated herein by reference.
In the illustrated embodiment of
An embodiment of a method of surveillance of a wellbore is now described with reference to
In this embodiment, sensor 80b includes a fluid flow rate sensor and a pressure sensor. Surveillance system 20 may accumulate data from sensor 80b. The data obtained at sensors 80b may be analyzed and processed, for example by control system 28, to determine a well parameter such as an injection performance parameter and/or capabilities of well 74. For example, well data sensed at sensor 80b may be utilized to generate and provide well information such as that represented by the Hall Plot illustrated in
Traditionally, injection fluids are pumped from the surface of the well down the wellbore and injected into the formation. Further, the injection pressure is often measured or sensed at the surface of the well. The illustrated embodiments provide pressure and flow rate data proximate to the injection zone 76b and therefore they may be more indicative of the injection capabilities of the formation and performance of the injection operations.
In the illustrated embodiment of
In one embodiment of a method of operation, receipt of well data by sensor 80b may indicate that a selected well parameter of concern is being approached or exceeded. Analysis or processing of well data sensed by sensor 80b may provide a well parameter that is of concern. For example, injection fluid flow rate and/or injection pressure may be sensed by sensor 80b. This well data may be indicative of a well parameter, such as a high injection pressure, that corresponds to a threshold parameter of concern. In some embodiments, the sensed well data, for example, injection pressure, injection flow rate, and elapsed time, may be analyzed and processed to obtain a well parameter indicative of the injectivity or the like of the well or formation. Correlation of this obtained well parameter with a threshold parameter may indicative of an operational concern, such as those illustrated in
In another example, a sensor 80, for example 80b, may sense well data indicating that the wellbore fluid being injected into the formation is primarily hydrocarbon based (fluid 100a) and is therefore not the desired produced water portion that is being injected. System 20 may communicate an alert to the operator that a threshold parameter indicative of the hydrocarbon, or oil, fraction of the injected wellbore fluid has been exceeded. System 20 may further communicate an output signal to controllable devices 82, including pump system 24 and pumps 78, actuating an action to mitigate the injection of the hydrocarbon fluid 100a. The action actuated may include without limitation, shutting down a pump such as pump 78b; changing the speed of one or more of pumps 78 and thus the fluid flow rate; increasing or decreasing the resident time of fluid 100 in downhole separator 82a; and operating one or more valves.
From the foregoing detailed description of specific embodiments of the invention, it should be apparent that systems and methods for monitoring and/or controlling wellbore operations that are novel have been disclosed. Although specific embodiments of the invention have been disclosed herein in some detail, this has been done solely for the purposes of describing various features and aspects of the invention, and is not intended to be limiting with respect to the scope of the invention. It is contemplated that various substitutions, alterations, and/or modifications, including but not limited to those implementation variations which may have been suggested herein, may be made to the disclosed embodiments without departing from the spirit and scope of the invention as defined by the appended claims which follow.
