Untitled record

A method and device for generating and transmitting a fluid pressure signal deep into a hole

Full description

Background of the invention

The invention generally relates to depth-of-hole devices used to signal the occurrence of an event(s). More specifically, the invention relates to systems of fluid pressure modulation telemetry technology used with such devices for transmitting signals.

Drilling and completion systems known in the art include what are called measurement-while-drilling (MWD) systems. Measurement-while-drilling (MWD) systems include one or more sensors configured in equipment housed in the wellbore, typically during drilling, completion, or processing, that detect a physical parameter related to a condition in the wellbore or to a characteristic of the landforms surrounding the wellbore. Measurement-while-drilling (MWD) systems also include electronic circuits that convert measurements made by one or more sensors into a representative signal and which are applied to some forms of telemetry technology to include fluid pressure. A telemetry technique is used to incorporate the pressure of a flow-altering device to drill or manipulate a fluid through the device in a pre-determined manner to communicate the represented signal to the Earth's surface. The signal is typically captured by one or more sensors positioned at the ground surface in a fluid circulation system. A detection, interpretation and recording system coupled to the pressure sensor decodes the signal represented to extract the measurement made by the one or more sensors. Typical drilling measuring devices are described, for example, in US Patent Nos. 3,958,217, 3,736,556, 4,078,620, and 5,073,877.

A common problem with all telemetry systems for including pressure gauges during prior art drilling is pressure noise in the fluid circulation system. Such noise can be caused by, among other things, two pulsations at the output of the fluid circulation pump and vibrations and shocks caused by the movement of the drilling rig (and thus the equipment itself). Pressure noise can make telemetry detection during drilling difficult, particularly at high data rates. It is common in Measure While Drilling (MWD) telemetry technology to represent the signal value as a binary coded decimal word that includes a number of digital bits related to the measurement range of the specific sensor of the sensors represented in the telemetry technology signal. As known in the art, different embedding techniques are applied to fluid pressure to represent numerical combinations of &one&zero& in telemetry technology. Typical modulation techniques include instantaneous pressure increases (positive remote pulsation measurement technique), instantaneous pressure drops (negative pulsation telemetry technique), and transmitting phase shift signals to a stable interface (mud syrinx).

Detecting the correct string of binary coded information to extract the representative signal can be difficult in noisy conditions, and may require expensive and difficult-to-operate equipment at the ground level. Also, the typical telemetry generator used in Measurement While Drilling (MWD) systems is expensive to manufacture and operate.

Detection of certain types of deep-hole conditions may be represented by simpler telemetry signals than are provided in a typical drilling telemetry system.

One solution to the shortcomings of traditional telemetry technology during drilling is described for use in sending simple indications of hole depth status, for example in US Patent No. 5,626,192 issued by Connell et al. The device described in this patent is a collar sound source locator device housing which is configured to be run at the end of a twisted pipe drilling cable. The housing of a ring detector in the device connects electrical signals to a control device in the device, which, when a ring detection signal arrives, activates a valve consisting of a group of side openings. When opened, the nozzles deliver the fluid flowing through the device to the annular space between the outside of the convoluted tubing and the wellbore wall. While the effectiveness of the device has been demonstrated in Connell et al. Patent 5626192, there are circumstances where diverting fluid flow from inside the tubing/device to the annular space outside of it is not desirable. Such conditions include, but are not limited to, placing a plug or pumping acid or rust-removing chemicals through the convoluted pipes.

And the device.

What is needed is a fluid pressure telemetry system that provides strong, easily detectable signals at the ground surface and maintains fluid flow within the device.

General description of the invention

One of the features of the invention is a system for connecting a device prepared in a well hole. The system includes a selectively operable flow diverter to deliver a fluid flow through a first path along the inside of a housing and a second path along the inside of the housing. The system includes a starter that is operationally coupled to the flow diverter to induce selective operation thereof in response to a first event.

The first event may include any of a number of occurrences, including but not limited to detecting certain components of the depth of a hole, sensing certain conditions of a well hole, sensing the states of a particular series or component, sensing the characteristics of a particular ground formation and the expiration of a period of time, executing a program, or A subprogramme for receiving or transmitting a signal from or to components at the surface or in the wellbore.

Depending on the nature of the first event, the initiator may also include at least one detector, software, analyzer, timer, or sensor (named a few) in order to sense the occurrence of the first event. In one embodiment, the flow diverter is an actuator-actuated piston. One embodiment of the actuator is a ball screw actuated by an electric motor. One embodiment of the initiator is a sensor operationally connected to a sound source direction finder of a casing collar. The first event involves the detection of an envelope collar by a sound source locator device. When a casing collar is detected in the wellbore, the piston is moved from a first position to a second position to divert flow from the first pass to the second pass for a selected amount of time to indicate the casing collar has been detected. A method for connecting from a device configured in a well hole according to another name of the invention includes conducting a fluid flow through a first path having a first flow restriction. The first flow path is located along the inside of the device. When a first event occurs, the fluid flow is diverted along a second path that has a second flow constraint in response to the first event. The second path is located along the inside of the device. Other features and advantages of the invention will be clear from the following explanation and the appended claims.

Brief explanation of the drawings

Figure (1): shows a cut-out view of one embodiment of a device according to the invention.

Figures 2 and 3 show a schematic diagram of the signal generator section in the embodiment of Figure 1, where the signal generator valve is shown in the open and closed positions, respectively.

Figure (4): shows a graph of pressure with respect to time for a remote measurement technique for a signal generated by

The example device in Figure 1 is of a type of telemetry technology that can be generated using the device of the invention.

Figure (5): shows a graph of pressure with respect to time for a remote measurement technique for a signal generated by

The example device in Figure 1 is of another type of telemetry technology that can be generated using the device of the invention.

Figure (6): shows an embodiment of the device connected to the end of a series of twisted pipes and prepared in a hole

Well hole.

Detailed description

One embodiment of a signaling device according to the invention is shown in Figure 1 in a cropped view. The device shown in (10) is generally configured within a fully cylindrical structure adapted to be coupled to the end of a drill pipe, twisted tubing, or the like. In this embodiment, for convenience of assembly and maintenance, the housing may be formed from individual sections (12a) which are coupled together by connectors (12).

In this embodiment, each of the sections (12a) includes therein a special unit forming part of the complete device (10). In one embodiment, one of the units in that embodiment includes a signal amount

(20) and processor/controller (40). The processor/controller (40) can be any type

Known in the art to receive signals from an initiator and operate a telemetry transmitter in a manner corresponding to signals received from the initiator.

A second one of the units can include an electrical power source (60), which in this embodiment includes at least one battery, such as a lithium battery. The actual type of electrical power source used in any particular embodiment of the invention is the subject of the designer's choice and is not intended to limit the invention. As will be readily appreciated by those skilled in the art, however, the use of batteries completely reduces the complexity of the device when compared to the use of turbines or other power sources driven by fluid flow through the device.

A third unit in this embodiment includes an initiator (70). It may be operated by coupling the initiator (70) to a processor/controller (40). It will also be further explained to operate the signal amount (20) in a corresponding manner to the event for selected events. Sections (12a) also specify a fluid channel (16). A fluid channel is adapted to direct the flow of drilling, completion, or processing fluids. Along the inside of the device (10), as will be explained further.

In this embodiment, the signal sum (20) includes a flow transformer (26) that is selectively operable. The flow transducer (26) is hydraulically centered within a portion of the fluid channel (16) which is formed within the signal sum section (12a). In one embodiment, as will be explained in more detail, the flow adapter (26) includes a piston coupled to an actuator (not shown in Figure 1). It will also be explained further,

When the flow diverter piston (6 2) is in the retracted position, fluid entering the upper end (10a) of the device (10) is free to flow along a first flow path (not shown in Figure 1) in the fluid channel (16) to the lower end (10b). ) for device (10). Some of the fluid also flows along the second flow path (not shown in Figure 1) in the fluid channel (16), as will be explained further. When the flow diverter piston (26) is extended by the actuator (not shown in Fig. 1), out through the lower end (10b) of the device (10). In one embodiment, all fluid flow is completely or entirely diverted.

The initiator (70) is configured to sense the occurrence of an event(s). The types of events that may be sensed by the initiator are changed (70). Depending on the type of event, the initiator (70) may include at least one detector, software, analyzer, timer, or sensor (to name a few), which enables the initiator (70) to sense the event. In general, and among others, an event may include the detection of certain downhole components, the sensing of certain wellbore conditions, the sensing of a particular series or individual component conditions, the sensing of certain ground formation characteristics, a period of time, the execution of a program or subprogram, or the reception Or sending a signal to or from components at the surface or in the wellbore.

More specifically, among others, the event may include the detection of casing rings (including a casing ring sound source locator), a well hole temperature sensor or instrument (including a temperature sensor), or a well hole pressure sensor or instrument. (including a pressure sensor) or a well hole orientation sensor or a specific tool (including a guidance sensor) or a specific chemical composition sensor at the bottom of the hole, such as

Broader pH (including a chemical composition sensor such as a pH or capacitance meter), specific flow rate sensing (including a flow rate sensor), ocean NMR sensing in the instrument chain (including a NMR sensor), or gamma-ray backscatter sensing. From the perimeters of the tool string (including a gamma ray detector), sensing a certain distance from a point in the wellbore (including a proximity sensor), sensing the completion of a job by a tool component of a tool (including a job completion sensor), sensing a tool failure, or A tool component (including a failure sensor) or an execution signal for a program or subprogram (including an appropriate tag, for example) or receiving a signal such as data or a command from the surface or from another point in the wellbore (including a boxer receiver) or transmitting a signal Such as data or feed to the surface or to another point in the wellbore (including an appropriate transmitter) or sensing a specific condition in the tool or other tools and components (including an appropriate condition sensor). These types of events (and their respective sensors) are intended only to serve as examples that may be used in embodiments of the invention and are not intended to limit the types of events that may be used with any specific embodiment of the invention. As an example for various types of events, the initiator (70) may be configured to detect the presence of envelope loops, a condition in which the envelope loop locator will include a magnetic flux type. This type of ring positioner is well known in the art and generally includes a permanent magnet (not shown in Fig. 1) to magnetize a solid casing in the wellbore (not shown in Fig. 1) and a finder coil (not shown in Fig. 1) into which voltages are induced Related to changes in the magnetic flux passing through it. The process of determining the position of the ring when it fits into the device will be explained further

(١٠.

The amount of the signal (20) is shown by cutting over the schematic graphs in Figures 2 and 3. Referring first to Figure 2, which shows the previously mentioned piston (26) in the retracted position, a fluid flow, generally shown in (14) enters the signal amount (20) through the inlet tip (22) [which is part of the fluid channel (16). ) in Figure 1] to the previously described first flow path (22a) and a second flow path (24). The second flow path, shown in (24) therein includes a nozzle (30) which has a selected internal diameter and is configured to fit tightly, in this embodiment, to the discharge side (24a) of the second flow path (24). The second flow path (24) and the first flow path (22a) are connected at their branching ends or downstream in the discharge side or downstream (32) of the signal sum (20) [hydraulically coupled to the fluid channel (16) in Figure 1]. As shown in Figure 2 by arrows, when the piston (26) is retracted, some of the fluid flow (14) passes through the first flow path (22a) while other, smaller portions of the fluid flow (4 1) may pass through the second flow path (24 ). The first (22a) and second (24) flow paths are shown in Figure 2, where they are located along the inside of the signal magnitude (20). It should be understood early that the actual direction of fluid flow along either the first (22a) or the second path may be in any direction with respect to the length of the signal sum (20) and the device (10). It is only necessary for the fluid flow to finally enter the device (10) at one end and exit the device (10) at the other end. The first flow paths (22a) and the second (24) may thus take any internal configuration of the device The first flow paths (22a) and the second (24) may thus take any internal configuration of the device (10) through which such a fluid can enter and exit the device (10) during a flow diversion The fluid as described in this patent. Accordingly, the expression ''along the inside'' as used to designate flow paths (22a) and (24) is intended to include within its scope any internal configuration of a fluid flow.

In one embodiment, the second flow path (24) is positioned such that the nozzle (30) is accessible from the discharge side (32) of the signal sum (20). In another embodiment, the second flow path (24) is positioned such that the nozzle (30) is accessible from the inlet side (22) of the signal amplifier (20). The nozzle (30) can be made accessible from either the discharge side (32) or the inlet side (22) for quick and efficient removal of the nozzle (30). For example, if the nozzle (30) is accessible from the inlet side (22), an operator simply needs to disassemble the parts of the device (10) above the signal amount (20) [where the parts are typically few and are simply disassembled to disassemble the nozzle (30). The nozzle (30) may be included in the second flow path (24) in any other manner which makes it possible to decouple the nozzle (30) from the signal sum (20). Therefore, it is not intended that the position of the nozzle (30) and the configuration of the flow paths (22), (22a), (24) and (32) shown in Figures 2 and 3 limit the scope of the invention. A further explanation of the detachable nozzle feature will be provided. The piston (26) is moved as previously described along a corresponding hole (28) by an actuator (34), which may be a linear actuator. The piston (26) will typically be sealed within the bore (28) by a seal as shown in (33) and be able to move axially along the bore (28). The actuator (34) in this embodiment is a ball screw driven by an electric motor. Other devices may include a combination of a solenoid and a high-permeability magnetic piston. The use of an electrically actuated actuator has the advantage of a simple actuator design, avoiding complex and expensive hydraulic systems typically associated with actuators used in prior art measurement-while-drilling (MWD) systems.

The piston (26) is coupled on its back side (the side opposite that exposed to the inlet fluid flow (14)] to a pressure equalization system (36) & the pressure equalization system includes a pressure equalizer (37) in hydraulic connection on one side to the front side (100 ) to the piston (26) and on its other side to a fluid reservoir (38) in hydraulic contact with the back side (rear face) of the piston (26). The reservoir (38) may be filled with hydraulic oil or the like. The compensator (37) in this embodiment is a piston which is free to move along a corresponding bore, but other types of compensator such as a diaphragm, bellows, or the like may be used in other embodiments of a pressure compensation system. The purpose of the pressure compensation system (36) is to provide equal flow fluid pressure, which is fluid flow pressure at the front side (100) of the piston (26), to both the side and front side (100) and back sides of the piston (26).

By equalizing the pressure on both sides [front side (100) and back side] of the piston (26), the actuator (34) needs to provide just enough force to the piston (26) to overcome the seal friction, rather than having to overcome additional interfacial pressure caused by Fluid flow (14) through signal amount (20). This feature reduces the size and power demands of the actuator (34) when compared with unbalanced flow converter systems.

In this embodiment a safety valve (39), which in this embodiment is a ruptureable disc, may be configured in the pressure equalization system (36) in hydraulic communication with the reservoir (38) on one side and with the after side (102) of the piston (26). On his other side. Other embodiments may include a pressure relief valve such as a safety valve (39). The purpose of the safety valve (39) is to provide a mechanism to move the piston (26) hydraulically to its drawn position in the event of pressure exceeding.

Variation via the signal amount (20) pre-selected values. The operation of the safety valve will be explained further

(٣٩).

Referring now to Figure 3, when the piston (26) is moved along the bore (28) by the actuator (34) or extended, the first fluid flow path (22a) is partially or completely closed to the fluid flow (14) thereby diverting some The fluid flows at least into the second flow path (24), which includes the nozzle (30). In one embodiment, all fluid flow is completely or entirely diverted. Because at least some of the fluid flow (14) is diverted through the nozzle (30), which may have an orifice smaller than the inside diameter of the first flow path (22a), the fluid pressure on the inlet side (22) of the device (10) will increase [ Front side (100) of piston (26)]. As previously described, the nozzle (30) may be changed by accessing the discharge side (32) or inlet side (22) of the fluid flow path. The nozzle (30) may be held in place during operation of the device by spirals or any other mechanism adapted to hold the nozzle (30) securely in place during operation of the device, and may also be easily replaceable by the system operator when needed. In this embodiment, the nozzle (30) can be tested to provide a detectably large vibration amplitude or any other selected vibration amplitude, and a pressure increase in the fluid flow when the piston (26) is extended to partially or completely close the first flow path (22a). As will be easily appreciated by those skilled in the art, this special feature of this embodiment of the invention makes it possible for the device (10) to be used with a wide range of expected fluid flow rates in drilling various wells, without having to have the signal amount specifically configured to a specific range of Fluid flow rates. This may obviate the need, as in prior art signaling systems to be

It has many different signal amounts available each adapted to a specific flow rate range to make the device useful over a number of flow rate ranges.

In this embodiment, the front face (26a) of the piston (26) is preferably shaped to efficiently transfer any solid material, which may be in the fluid flow (14). To the special passage open for the piston (26). In this embodiment, the front face (26a) is beveled to direct any solids into the fluid flow (14). An advantage provided by flushing or similarly shaping the front face (26a) is a reduction in the possibility of solids accumulating in the first and second fluid flow paths (22a) and (24) in order to block them. Also facing (26a) are any intentionally introduced solids, such as “process balls”, which are extruded through the convoluted tubes, thus reducing the possibility of any such process balls or other solids being held by gravity or eddy currents in a corner outside the direct path of fluid flow. A safety valve (39), as previously described, is provided to make it possible for the piston (26) to be withdrawn by fluid flow (14) under certain conditions. For example, if the nozzle (30) becomes blocked by crumbs or the like, the increased pressure that will occur along the piston (26) may be excessive and dangerous. When the differential pressure through the safety valve (39) exceeds the selected value, the valve (39) will open, causing the pressure on the after side (102) of the piston (26) to be applied to the back side (rear face) of the piston (26). A higher fluid pressure on the upstream side (100) will force the piston (26) to its retracted position, opening the first flow path (22a). The safety valve (39) also provides the ability to retract the piston (26) in the event that the actuator (34) fails to operate it. In these cases only the system operator will need to

Increase the fluid flow rate until the differential pressure between the pre-side (100) and the after-side (102) exceeds the selected opening pressure of the safety valve (39).

Referring to Figure 6, in operation, the initiator (70) produces a signal in response to the detection of sensing a first event (which can be any number of occurrences, as described previously). In the embodiment including the controller/processor (40), the signal is transmitted to the controller/processor (40 of Fig. 1), where the controller/processor (40 of Fig. 1) then sends an operating signal to the actuator (34 of Fig. 2) . In the embodiment the controller/processor (40) is included, the signal is transmitted to the actuator (34). In response to the signal (in any of the embodiments), the actuator (34) then causes the flow transducer (26 in FIG. 2) to change its position, as previously described. A change in the pressure of the fluid flowing through the convoluted tubes (80) to which the device (10) is connected will be detected by a pressure sensor (84) set up at the ground surface and in pressure contact with the high-pressure side of a fluid circulation system (hence the interior of the convoluted tubes 0 8). The pressure measurements made by the sensor (84) may be coupled to a recording and interpretation system. The pressure measurements made by the sensor (84) may be coupled to a recording and interpretation system (86) of any type known in the art to decode a telemetry technique to include pressure. Although the pressure sensor (84) is shown as being set up at the ground surface, in other applications the pressure sensor may be set up at a selected depth in the wellbore (82).

In an exemplary embodiment, the initiator (70) includes a casing ring positioner which produces a voltage when the positioner is moved following a change in the path of a magnetic flux through a casing, as detected in casing rings (71) in a wellbore (82). Thus, the first event is the discovery of an episode

casing. Each time a casing loop is detected by the initiator (70), the initiator (70) sends a signal to the controller/processor (40) or directly to the actuator (34) depending on the embodiment. Although the device (10) as shown in Figure 6 is transported to the wellbore (82) at the end of the twisted tubing (80), it must be clearly understood that another means of transporting the device to the wellbore may be used by the invention, Such as drill pipe or production pipes. The various types of telemetry signal technology that are possible using the device of the invention are shown in graphical form in Figures 4 and 5. Figure 4 shows a graph of pressure measured by the sensor (84 in Figure 6) with respect to time. In this embodiment, a voltage pulse which is generated by the starter (70) is received by the processor/controller (40) which engages the actuator (4 3) to move the piston to the expansion position at time T1 causing a corresponding pressure increase from P1 to P2 at T1. After a preselected period of time, which in this embodiment is shown as T1 to T2, the processor l operates the control device (40) and the actuator (34) to retract the piston (26), causing a reduction in pressure from P2 to P1. The length of time between the detection of an event which causes the piston to expand and subsequently contract can be programmed into the processor/controller (40) to represent the detection of a different event, or to have some other pre-determined meaning or significance. In one example, the detection of a casing ring may be represented by a shorter duration of a pressure increase from T1 to T1, while the detection of floating equipment may be represented by a longer pressure increase time such as from T3 to T5 as shown in Figure 4. As another example, the detection of different types of triggers by different sensors (not shown in the figures, but examples of those provided earlier in this patent) may cause pressure changes with individually settable residence times. An example of a different type of event could be one of the indicated temperature sensors

Previously in the device, a temperature event such as a temperature change exceeding a pre-determined limit by producing a pressure increase with a corresponding selected residence time will be marked as a "temperature event". Other examples of gamma radiation detection events may include above a threshold level such as would occur when a gamma ray detector is used as the initiator (70) passing near a radioactive marker. Those skilled in the art will appreciate that both the different types of sensors described above in this patent and also other types of sensors may be used to detect a condition which may be characterized by an “event” sign. Each such event detected in the device (10) may cause the transmission of a specific coded pressure signal according to the schematics of the telemetry technique described in this patent. In one embodiment, each encoded pressure signal is a specific event. The actuator (34 of Fig. 2) in this embodiment of the invention (motorized ball screw) may also move the piston (26 of Fig. 2) to positions intermediate to the fully expanded and fully retracted positions. This makes it possible for another type of telemetry technique in which more than one pressure change may influence the fluid flow to detect different types of events. Referring to Figure 5, one such event occurs, shown as an increase in pressure from P3 to P4 at T6. Increasing pressure from to P4 may be accomplished, for example, by moving the piston (26) half the distance from its retracted to its extended position. At T7, pressure is increased from P4 to P5 at T7, by extending the piston (26) remaining from the travel to the fully extended position. As in the previous example of telemetry coordination, the residence time of each pressure change can be programmed to correspond to any selected event detected by the instrument (10). Still also, the pressure change from P5 back to P3 shown at T8 may be generated by a complete retraction of the piston in a single operation. The reverse process, generating a pressure change from P3 to P5 by fully positioning the piston at T9, is demonstrated

Low pressure is indicated by pulling the piston half way from P5 to P4 at T9 and from P4 to P3 at T10. In this embodiment of the invention, the programmer/controller (40 of FIG. 1) may be programmed to operate the actuator (34 of FIG. 2) to move the piston (26 of FIG. 2) an intermediate distance between the fully expanded and fully retracted positions so as to produce an average pressure change similar to that shown In Figure 5 to represent different types of detected events. In addition, the residence time of pressure changes can be chosen to represent different types of detected events. The invention provides a device which can communicate the occurrence of an event by modulating the pressure of a fluid flowing through the device. The device can be used in situations where it is not desirable to selectively divert a fluid inside convoluted tubing, drill pipe or tubing into an annular space outside the tubing in the wellbore. Also, the invention provides in some embodiments a signal sum that is relatively immune to clogging by solid matter in the flowing fluid. Other embodiments of the invention have a tellable nozzle such that the device can be adjusted to operate in a variety of fluid flow rate ranges without having to have signal amounts scaled to correspond to the expected flow rate range. While the invention has been described in relation to a limited number of embodiments, it will be appreciated by those skilled in the art that other embodiments may be derived which are not outside the scope of the invention as disclosed herein. Accordingly, the scope of the invention must be determined only by the attached claims.