Patent Application
20050121197
A variety of fluids are contained in formations found within the Earth. Some of these fluids, such as water and oil, are desirable and may be produced to the Earth's surface for numerous uses. Many types of mechanisms are employed to produce the fluids from subterranean formations. For example, wellbores may be drilled into a formation to accommodate the deployment of a downhole completion used to control the upward production of fluid.
When fluid is removed from a formation, an underbalance of pressure, i.e. drawdown, occurs between the region of fluid intake at the completion and the surrounding reservoir or formation. If the pressure underbalance is too great, however, the formation may become mechanically unstable, resulting in sanding, further formation breakdown or formation compaction or subsidence. If, on the other hand, the pressure underbalance is substantially reduced, the production of fluid can be inefficient. Furthermore, the pressure underbalance (drawdown) that is allowed without incurring information failure may change with time as the producing formation is depleted and the in situ effective stresses increase.
In general, the present invention provides a method and system for producing a fluid from a subterranean formation. The method and system enable the production of fluid from the formation while controlling the potential for sanding or other mechanical instability of the formation. Additionally, the fluid production may be optimized for a given formation without exceeding a predetermined envelope that defines the stability of the formation during production relative to the pressure underbalance.
Certain embodiments of the invention will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements, and:
In the following description, numerous details are set forth to provide an understanding of the present invention. However, it will be understood by those of ordinary skill in the art that the present invention may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.
The present invention generally relates to a method and system for controlling the production of fluid from a subterranean formation. The method and system are utilized in optimizing fluid production without creating undue risk of formation mechanical instability that can result in sanding. The devices and methodology of the present invention, however, are not limited to the specific applications that are described herein.
Referring generally to
System 20 comprises a completion 30 deployed at a desired location in wellbore 24 by a deployment system 32. Deployment system 32 extends downwardly in wellbore 24 from a well head 34. Deployment system 32 may comprise a tubing 36, such as production tubing or coil tubing. Tubing 36 defines an internal flow path 38 along which fluids are produced to a desired collection point, e.g. a point at a surface 40 of the Earth. It should also be noted that system 20 can be designed such that flow path 38 is located along the annulus between deployment system 32 and casing 26.
Completion 30 may have a variety of configurations. In one example, completion 30 comprises a flow control mechanism 42 controllable to reduce or increase the flow of fluid along flow path 38. Flow control mechanism 42 may comprise a valve or a choke 43. Flow control mechanism 42 also may comprise an artificial lift mechanism 44 able to pump fluid along flow path 38. Artificial lift mechanism 44 may be used as an alternative or in addition to the choke or valve 43, depending on the specific formation. One example of artificial lift mechanism 44 is an electric submersible pumping system.
Regardless of the specific type of completion 30 used in system 20, fluid moves into completion 30 and is produced along flow path 38. It also should be noted that system 20 may have a variety of configurations that can comprise, for example, a completion within a cased wellbore, an open hole completion in a wellbore without a casing and a variety of other sand control devices. In any of these embodiments, fluid entering completion 30 creates a region of lower pressure 46 relative to the reservoir or formation pressure 48. This region of lower pressure 46 is sometimes referred to as the bottom hole flowing pressure, and the difference between bottom hole flowing pressure 46 and the reservoir pressure 48 can be referred to as a pressure underbalance or drawdown. Increasing the rate of fluid production increases the pressure underbalance, but the creation of an underbalance too great for a given formation 22 can lead to mechanical instability of the formation. Mechanical instability can lead to sanding, compaction and other detrimental results.
Referring again to
System 20 further comprises a reservoir pressure sensing system 54 position to sense reservoir pressure 48. Pressure sensing system 54 also may comprise a variety of sensing techniques, such as the use of real-time pressure sensors or other sensors able to determine reservoir pressure 48. Reservoir pressure sensing system 54 also may transmit data wirelessly or through a control line, such as control line 52. The data from sensing systems 50 and 54 may be transmitted to an interface 56 for comparison. Interface 56 may be positioned locally at the well or at a distant location. System 20 also may comprise an automated control 58 designed to receive the data from sensor systems 50 and 54, compare the data, determine any needed changes in bottom hole flowing pressure, and provide an appropriate control signal to flow control mechanism 42. One example of an automated control 58 is a computerized control utilizing one or more processors that receives the signals from downhole, determines the pressure underbalance, compares the underbalance to a specific stability envelope for the formation 22, and provides appropriate control signals to change the rate of fluid production and thus the bottom hole flowing pressure.
Sensor system 50 and reservoir pressure sensor system 54 both continually monitor bottom hole flowing pressure and reservoir pressure, respectively. The continual monitoring utilizes constant or periodic detection of both bottom hole flowing pressure 46 and reservoir pressure 48 to continually track the pressures and changes in pressures during production of fluid from formation 22. For example, sensor system 50 and reservoir pressure sensor system 54 may operate at a given sampling rate controlled by automated control 58. If the underbalance of pressure 46 relative to pressure 48 becomes too great, valve or choke 43 (or artificial lift mechanism 44) is adjusted to reduce the flow of fluid along flow path 38. The reduction in flow rate effectively increases the bottom hole flowing pressure 46 such that the difference between pressure 46 and reservoir pressure 48 is reduced.
Referring generally to
Stability envelope 60 is illustrated on a graph 61 having a vertical axis 62, representing bottom hole flowing pressure, and a horizontal axis 64, representing reservoir pressure. A line 66 divides the graph into regions of “no flow” 68 and “flow” 70. In other words, line 66 represents an equilibrium of pressure between the bottom hole flowing pressure and the reservoir pressure. When the ratio of bottom hole flowing pressure 46 to reservoir pressure 48 falls below line 66, flow of fluid along flow path 38 can be achieved. However, a formation stability line 72 represents the ratio of bottom hole flowing pressure to reservoir pressure at which the pressure underbalance can lead to mechanical instability of the formation. A safe drawdown region 74 is created between line 66 and stability line 72. If the pressure underbalance remains within safe drawdown region 74, production of wellbore fluid can occur without risking sanding or other detrimental results of mechanical instability of formation 22.
Graph 61 also illustrates a danger zone 76 disposed between stability line 72 and a formation failure line 78. In some formations, there may be a zone of unpredictability, such as danger zone 76, in which the risk of formation failure is increased. Although control schemes or algorithms can be designed that allow the pressure underbalance to enter zone 76, it is often desirable to ensure the pressure underbalance remains within safe drawdown region 74. Also, if the ratio of bottom hole flowing pressure to reservoir pressure falls within zone 76, additional or other preventative and corrective actions can be taken. For example, the controller may be adjusted to increase the sampling rate of the data to improve control over the system 20.
The real-time monitoring of bottom hole flowing pressure 46 and reservoir pressure 48 enables the optimization of fluid production. The pressure underbalance may be continuously controlled to maintain the ratio of bottom hole flowing pressure to reservoir pressure within a specific optimization region 80 of safe drawdown region 74. For example, in
A series of graph points 84, 86, 88, 90, 92 and 94 are illustrated on graph 61 at sequential periods during the production of fluid from reservoir 22. The graph points are illustrative of the comparison of data received from pressure sensing system 50 and reservoir pressure sensing system 54. Based on the sensor data related to graph points 84 and 86, for example, the rate of production is increased via flow control mechanism 42. The increased rate of production will create a lower bottom hole flowing pressure 46, effectively moving graph points 84 and 86 downwardly to optimization region 80. In this example, the continuous monitoring of downhole pressures and the comparison of those pressures with stability envelope 60, enables an increase in production without undue risk of sanding. Graph points 88, 90 and 94 provide an example of when the relative bottom hole flowing pressures and reservoir pressures are at a desired level. However, graph point 92 illustrates the production rate is moving too close to creating mechanical instability within formation 22. Accordingly, flow control mechanism 42 can be adjusted to reduce flow of fluid along flow path 38. The reduction in flow effectively decreases the pressure underbalance and restores operation of system 20 to optimization region 80.
As illustrated in
As production continues and the reservoir is further depleted, the reservoir pressure 48 also decreases. The decreased reservoir pressure typically requires a decrease in pressure underbalance, as represented by the shorter arrow 98 in
In the systems and methodology described above, different types of control regimes may be incorporated into system 20 depending on the environmental parameters and design parameters for a given application. By way of example, controller 58 may comprise a computerized control programmed according to one or more available control algorithms. In one embodiment illustrated in
The specific automatic adjustment to system 20 can vary depending on the position of the ratio within the stability envelope and on system design objectives. For example, control 58 may be designed to provide signals to flow control mechanism 42 to increase the production rate if the ratio falls outside optimization region 80 but within safe drawdown region 74. When the ratio falls outside safe drawdown region 74 and in a region of stability envelope 60 representing a threat to the mechanical stability of formation 22, the production rate may be decreased. However, control system 58 may be programmed to make other system adjustments. In one embodiment, for example, control system 58 is designed to increase the sensor sampling rate when the ratio moves outside or towards the boundary of optimization region 80. It should be noted that the functionality of the control system example illustrated in
Although only a few embodiments of the present invention have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this invention. Accordingly, such modifications are intended to be included within the scope of this invention as defined in the claims.
