BRPI0721726A2 - reamer for use in a descending hole drill string - Google Patents

Abstract

HARNESS FOR USE ON A DOWN-HILL DRILLING COLUMN. A wired reamer for use in a downhole drill string is revealed. In some embodiments, the reamer includes a reamer body comprising a passageway therethrough and drill cable located within the passageway to transmit at least one of the power or communications. In other embodiments, the reamer includes a reamer body comprising a passageway enclosed within the reamer body, drill cable located within the passageway for transmitting at least one of power or communications, a sensor and a processor located within the housing. Reamer. The sensor is connected with the drill cable to transmit data measured by the sensor through the drill cable, and the processor is connected with the drill cable to receive data from the sensor.

Description

"HARNESS FOR USE IN A DOWN-HILL DRILLING COLUMN"

BACKGROUND

When drilling oil and gas wells it is often necessary or desirable to "widen" a wellbore that has been previously created by a drill bit or other cutting tool to widen protruding edges, remove collapsed areas and grooves in the wall. well, rectify the wellbore, stabilize the drill string, and enlarge the wellbore. For these reasons, a reamer may be positioned behind a drill bit, or other cutting frame, in the drill assembly to widen the hole after the drill has formed the well hole. It is sometimes preferred that such an enlargement step be performed when the drill is being withdrawn from the wellbore, this process being referred to as "backfeeding." Also, it is sometimes necessary to extend a reamer in a subsequent pass to rectify or clean the wellbore. In plated drilling applications, the reamer is required to drill the primary bore before placing the plating column.

When drilling oil and gas wells using rotary steerable tools, it is desirable to widen the wellbore as close to the drill as possible to minimize the distance between the drill wellbore and the borehole reamer. Because rotary steerable tools commonly need to communicate with the metering-during-drilling (MWD) system, it is important that all tools located between the rotary steerable tool and the MWD telemetry system enable power transmission and communications through the fermentation system. .

There are three main categories of reamers. Fixed blade reamers, including reamers near the drill, have fixed blades that will not move or expand. A fixed blade reamer cuts a larger hole because it has a larger inside diameter than the pilot drill. The fixed blade reamer can be used to enlarge a wellbore by a relatively small amount. Once the reamer blade is fixed, the well bore opening is on the surface or adjacent to a larger hole section. A fixed blade reamer can be used to widen protruding edges, drill well holes, remove grooves in the well wall, and remove crumbling areas. Roller reamers have roll cutters that are mounted on a main body and can be used to enlarge the hole, widen the protruding edges, rectify well holes, remove well wall grooves and collapsed areas, as well as stabilize a drill string. and reduce the total torque of the drill string. Extendable blade reamers or extendable reamers, including reamers, have arms that can be extended over the surface or downward hole to a predetermined diameter to cut a larger hole. An extendable blade reamer can be used to increase the hole by a substantial amount, widen protruding edges, rectify well holes, and remove grooves in the well wall and collapsed areas.

Conventional subargers are typically used in conjunction with a pilot drill bit that is positioned below or downstream of the subarger. A sub-spreader can be used to drill and expand the wellbore below a section provided with a lining or, as in coated drilling applications, can be used to drill the wellbore from the surface or below a larger lined section. . In casing drilling applications, a drilling set including at least one drill and reamer is used to drill the wellbore below the casing column. The casing column is used as a replacement for the drill pipe, transferring torque fluid downward to the drill set. After the hole is completed, the sub-spreader arms are retracted and the drill set is recovered to the surface.

The sub-spreaders usually have articulated arms with roller cones and PDC cutters attached to them. The arms are actuated by mechanical or hydraulic forces acting on the arms, causing the arms to pivot at an opposite end to the cutting end of the arms and thus extend or retract. These arms can be forced against formation by a piston or drive arm. In conventional operations, the sub-spreader arms are retracted to allow the tool to pass through a smaller hole section or coated hole section. Once the fermentation has passed through the smaller hole section or coated section, the sub-widening arms are extended. The pilot drill drills the wellbore, while at the same time the sub widener widens the wellbore formed by the drill. Typical examples of these types of reamers are found in US Patents 3,224,507, 3,425,500 and 4,055,226.

In coated drilling applications, the sub-reamer opens on the surface with the casing column attached behind the reamer. The casing column is used as a replacement for the conventional drill pipe. The sub-spreader needs to be able to close back to a size that will allow the drill set to be removed from the wellbore. The drilling set may need to be removed if a portion of the set fails or if the wellbore has been completed.

Conventional reamers have several disadvantages. If a reamer cutting frame is worn, the hole geometry may not open to the desired size. Also, the reamer cutting frame may not be selected correctly to properly stabilize a drilling set. In addition, a conventional sub-widener may fail to fully extend or fully retract. A conventional sub-spreader typically has rotary cutter pocket recesses formed in the body to store the retracted arms and roller cone cutters when the tool is in a closed state. Bag recesses tend to fill with debris from the drilling operation, which hinders arm closure. If the arms are not fully closed, the drill string can easily be suspended within the wellbore when an attempt is made to remove the column from the wellbore. In coated drilling applications, if the reamer arms do not close, the reamer may be suspended over the casing column.

The method of activating and deactivating the arms of an understeer can also create operational limitations to drilling. Some underlugs use a sphere to assist in activating and deactivating the reamer arms. Although a ball drop can be used to lock the reamer arm position, the sub-widener cannot be used under tools that do not have a through hole to allow the ball to pass through. In addition, there may be a limitation on cycle numbers that the reamer arms can be activated and deactivated. In addition, some sub-extenders are designed to expand automatically when drilling fluid is pumped through the drill string. Sub-extenders acting in response only to flow are very sensitive to flow. This way these sub-spreaders can open and close each time the pumps are turned on and off. The main operational limitation may be the ability to maintain the full extension of the reamer arms at the required flow rate required for drilling. Many sub-extenders have limited or no indication on the surface that the sub-expander is in the fully extended or retracted position. Thus, in some applications, it may be desirable to control when the sub-expander expands or retracts independently of flow rather than automatically expanding in response to drilling fluid. It may also be desirable to vary the size of the hole being drilled at the bottom, depending on the location of the wellbore.

Another method for widening a wellbore under a pre-lined wellbore section includes the use of a vane reamer behind a conventional drill bit. In such an assembly, a conventional pilot drill is arranged at the lower end of the drill assembly with a fin reamer disposed at some distance behind the drill drill. The fin reamer generally comprises a tubular body with one or more longitudinally extending "fins" or radially outwardly extending blades from the tubular body. Once the fin reamer has passed through any of the coated portions of the wellbore, the pilot drill rotates around the centerline of the drill geometry shaft to drill a lower wellbore in the center at the desired path path. while the finned eccentric reamer follows the pilot drill and engages the formation to enlarge the pilot well hole to the desired diameter.

Still another method for enlarging a wellbore beneath a pre-lined wellbore section includes the use of a two-center drill, or bi-center, which is a one-piece drilling structure which Provides a combination of reamer and pilot drill. The pilot drill is disposed at the lower end of the drill assembly, and the eccentric sub-spreader drill is arranged slightly above the pilot drill. Once the bi-core drill has passed through any coated portions of the wellbore, the pilot drill rotates around the centerline of the drill shaft and drills a pilot wellbore in the center on the desired path path. while the eccentric sub-spreader drill follows the pilot drill and engages the formation to extend the pilot well hole to the desired diameter. The diameter of the pilot drill is made as large as possible for stability while still being able to pass through the coated pit hole. Examples of bi-center drills can be found in US Patent Nos. 6,039,131 and 6,269,893.

As described above, flanged reamers and two-core drills include sub-widener portions that are eccentric. A number of disadvantages are associated with this project. Due to directional bias problems, the eccentric underbreaking portions have difficulty reliably underbreaking the borehole to the desired diameter. Well geometry has a large amount of spiraling, which increases well bore torque and axial friction. With respect to a bi-center drill, the eccentric sub-spreader drill tends to cause the pilot drill to swing undesirably off center, thereby pushing the pilot drill away from the preferred drilling path of the pit path. . A similar problem is experienced with finned reamers, which only widen the wellbore to the desired diameter if the pilot drill remains centered in the wellbore during drilling.

In the oil and gas industry, it is desirable to detect and control the operating forces acting on the tool in order to determine if the tool has been confirmed damaged, to limit the damage the tool may suffer, and / or to ensure that a particular operation is performed. performed correctly. Sensors to detect vibration, axial forces, torsional forces, and bending forces, and to transmit this data in real time to the surface, can be used to identify when a drilling tool is subjected to forces that have exceeded its operating parameters. Drilling operations can then be modified to prevent or limit tool damage and / or to correct an ongoing operation.

In order to optimize the drilling operation and / or drilling well, it is desirable to provide information that refers to the operational parameters of the drill string and the environmental conditions of the surrounding formation being drilled. For example, it is often necessary to frequently adjust the wellbore direction during drilling to either accommodate a planned change in direction, or to compensate for unwanted and unwanted wellbore deflections. In addition, it is desirable that information concerning tool operation, drilling environment, and type or features of the formation be provided to the operator on a real time basis. The ability to obtain real-time data measurements during drilling allows for a relatively more economical and efficient drilling operation. Therefore, it is important that any tool located between the MWD or LWD sensors and the MWD telemetry system enables power transmission and / or communication through the tool.

For real time data during drilling, a collection of drilling tools and measuring devices, commonly known as the descending hole assembly (BHA), is positioned at the descending hole end of the drill string. Typically, the BHA includes the drill bit, any steering or forming assessment tools, deflected drilling mechanisms, mud motors, and heavy collars, which are used in the drilling operation. A Drill Measurement (MWD) or Drill Profiling (LWD) collar is often positioned just above the drill bit to make measurements that refer to the wellbore direction or wellbore formation properties when it is being drilled. perforated. Recorded measurements from MWD and LWD systems can be transmitted to the surface in real time using a variety of methods known to those skilled in the art. Once received, these measurements will allow those on the surface to make decisions regarding the drilling operation. Due to limitations in the transmission of information, it is common for more detailed information or tool reliability information to be stored for unloading when the tool is retrieved on the surface.

Accordingly, various systems have been developed which allow downhole sensors to measure drilling parameters in real time and transmit the resulting information or data to the surface substantially instantaneously with measurements. For example, mud pulse telemetry systems transmit signals from an associated downhole sensor to the surface through the drill mud in the drill string. As another example, integrated telemetry drill pipe, or physical conductor pipe, transmits downhole sensor signals to the surface through drill pipe contained in the drill pipe wall. These telemetry systems and associated sensors can be located at a significant distance from the drill bit. Environmental information measured by the system may not necessarily correlate with current conditions surrounding the drill bit. More accurately, the system is responding to conditions that are substantially spaced from the drill bit. For example, a conventional telemetry system may have a depth delay of up to or greater than 60 feet (18.3 m). As a result of this information delay, it is possible to drill a hydrocarbon production formation prior to detection of the outlet, resulting in the need to drill several feet of wellbore to get back within the zone of interest. In response to this undesirable information delay or depth delay, various sensor systems or packages, close to the drill bit, have been developed which are designed to be placed adjacent to or near the drill bit. However, such sensors near the drill continue to be located at a spaced distance from a drill drill assembly, which will introduce a delay in determining formation changes.

In order to use a near-drill sensor system and allow real-time monitoring and adjustment of drilling parameters, a system or method must be provided for transmitting the measured data or information detected from the downhole sensor either directly to the drill. surface or to another telemetry system for subsequent transmission to the surface. Similarly, a system or method may need to be provided to transmit the required electrical energy to the downhole sensor system from the surface or some other power source. As a result, all of the tools in the directional BHA must have the ability to transfer power and communication through your body, or the tools must be located above the telemetry system. The conventional reamers available today do not have the ability to transmit power and communication through your body, and as a result, the placement of the sub-reamers went a significant distance from the drill. In coated drilling applications, this means that the directional BHA below the coating column is very long and is incidental to operational problems such as debris formation and vibration.

Several systems have been developed for communicating or transmitting information directly to the surface, for example via a power line, wire line or cable to the surface. These physical conductor connectors provide a physical conductor connection from close to the surface drill bit; however, the wire or cable line must be installed on or otherwise fixed or connected to the drill string. This line of wire or cable is subject to wear and tear during use and thus may be incidental to damage or even destruction during normal drilling operations. The drill assembly may not be particularly suitable for accommodating such wire lines, with the result that wire line sensors may not be able to be located in close proximity to the drill bit. Wire lines and wire line connectors by their nature create blockages in the drill pipe, thus excluding some types of ream activation mechanisms.

Systems have also been developed for the transmission of acoustic or seismic signals or waves through the drill string or surrounding the formation. Acoustic or seismic signals are generated by a down-hole acoustic or seismic generator. However, a relatively large amount of power is typically required in the downhole to generate a sufficient signal so that it can be detectable on the surface. A relatively large power source must be provided in the downhole or repeaters used at intervals along the column to amplify the signal it propagates along the drill string.

In addition, systems have been developed which require the transmission of electromagnetic signals through the surrounding formation. Electromagnetic transmission of detected information often involves the use of a torus positioned adjacent the drill bit to generate an electromagnetic wave through formation. As with acoustic and seismic transmission, transmission of electromagnetic signals through formation typically requires a relatively large amount of power, particularly where the electromagnetic signal must be detectable on the surface. Also, the attenuation of electromagnetic signals when they are propagated through formation is increased with increasing distance over which signals must be transmitted.

A physical conductor drill pipe has also been developed which allows significant amounts of data to be transferred from the descending hole to the surface. These systems require the physical conductor to be extended over the length of the drill string and to communicate with the drill BHA. Communications through connections can be problematic, and given the large number of connections in a typical drill string, these systems can be a problem for reliability and maintenance issues.

BRIEF DESCRIPTION OF THE DRAWINGS For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings, in which:

Figure 1 is a representative schematic of a reamer wired with power drill cable and / or communications through the reamer flow bore in accordance with the present invention;

Figure 2 shows the wired reamer of Figure 1 with the power and / or communications cable through the reamer body;

Figure 3 is a representative schematic of an adjustable, wired blade reamer with power drill cable and / or communications through the reamer flow bore in accordance with the present invention;

Fig. 4 shows the wired reamer of Fig. 3, with the power and / or communications cable through the reamer body;

Figure 5 shows the wired reamer of Figure 1 with the power and / or communications drill cable for the reamer flow hole;

Figure 6 shows the wired reamer of Figure 2 with the power and / or communications drill cable for the reamer body; Figure 7 shows the wired reamer of Figure 1 with the power and / or communications drill cable contained in the reamer flow bore;

Figure 8 shows the wired reamer of Figure 2 with the power and / or communications drill cable contained in the reamer body;

Figure 9 shows the wired reamer of Figure 1 with

sensors;

Figure 10 shows the wired reamer of Figure 2 with

sensors;

Figure 11 shows the wired reamer of Figure 3 with

sensors;

Figure 12 shows the wired reamer of Figure 4 with

sensors;

Figure 13 shows the wired reamer of Figure 1 with wireless sensors;

Figure 14 shows the wired reamer of Figure 2 with wireless sensors;

Figure 15 shows the sensor wired reamer of Figure 9 with access to a processor; Figure 16 shows the sensor wired reamer of Figure

with sensors and access to a processor;

Figure 17 shows the wired reamer of Figure 7 with sensors and a processor;

Figure 18 shows the wired reamer of Figure 1 with controllers and actuators;

Figure 19 shows the wired reamer of Figure 2 with controller and actuators;

Figure 20 shows the intelligent reamer of Figure 15 with controllers and actuators; Fig. 21 shows the intelligent reamer of Fig. 16 with controller and actuators;

Figure 22 shows the intelligent reamer of Figure 20 with controllers and actuators; and

Figure 23 shows the smart reamer of Figure 21 with controller and actuators.

DETAILED DESCRIPTION OF THE FORMS OF CONCRETIZATION

Preferred

The following discussion is directed to various embodiments of the invention. While one or more of these embodiments may be preferred, the exposed embodiments should not be construed, or otherwise used, as limiting the scope of exposure, including the claims. In addition, one skilled in the art will understand that the following description is broadly applicable, and the discussion of any embodiment is intended solely to be exemplary of this embodiment, and not intended to suggest that the scope of the exposure, including the claims, is limited to that embodiment.

Certain terms are used throughout the following description and claims to refer to particular features or components. As one skilled in the art will appreciate, different people may refer to the same feature or component by different names. This document is not intended to distinguish between components or characteristics that differ in name but not in function. The figures in the drawings are not necessarily to scale. Certain features and components here may be shown to be exaggerated in scale or in somewhat schematic form, and some details of conventional elements may not be shown for the sake of clarity and conciseness.

In the following discussion and claims, the terms "including" and "comprising" are used in an open manner, and should therefore be construed to mean "including, but not limited to ...". Also, the term "mating" or "mating" is intended to mean either an indirect connection or a direct connection. Thus, if a first device mates with a second device, this connection may be through a direct connection, or through an indirect connection through other devices and connections.

A wired reamer allows power and / or communication through the reamer to other downhole tools, to surface equipment, or to the reamer itself. The ability to pass power and / or communication through the reamer overcomes some limitations regarding where the reamer can be placed in a drilling BHA. In addition, position sensors on the reamer allow data collection relating to tool operation, well bore geometry, drilling environment, and evaluation of surrounding formations being drilled. Data can be transmitted to the surface or to another telemetry tool using tool communication and used to optimize drilling operation, or stored within the tool for later unloading. In addition, data measured by the sensors may be transmitted to a surface-mounted processor, another down-hole tool, or the reamer itself. In such configurations, the reamer is "smart", meaning that the reamer communicates with a processor to decipher data collected by the sensors.

In addition, the positioning of controllers and actuators over the reamer enables reamer control during drilling operations by direct command or feedback from algorithms developed as a function of the data measured by the sensors. Direct commands or feedback can be transmitted using tooled communication to the controllers, directing the controllers to actuate the actuators when necessary to optimize drilling operation. For example, controllers on the reamer may extend or retract the reamer arms, or otherwise reconfigure the reamer to limit forces sustained by the reamer.

Monitoring reamer performance can help determine when the reamer is physically damaged, such as excessive wear of the cutter frame, failing roller bearings, broken reamer arms, or when the reamer arms are not fully extended or retracted. Monitoring the performance of drilling parameters can help determine if the weight on the reamer arms is too high or too low, the vibration of the reamer is in an unacceptable range, or the torque across the reamer arms is in an unacceptable range. .

The wired reamer can be located between a measuring telemetry during drilling (MWD) system and an instrumented, steerable, rotary drill sensor, or drilling during profiling (LWD) sensor. In rotatable, rotatable, drill-down hole assemblies, a wired reamer may allow the reamer to be located near the drill, reducing the created rat hole. In coated drilling applications, a wired reamer may allow for less adherence to the straight or directional BHA.

In some embodiments of a wired reamer, power and / or communication is provided through the reamer hole or the reamer body to the tools located in the descending hole of the reamer or to the reamer itself. The communication passage may be through the reamer hole or embedded in the reamer body. Also, the small vibration and / or communication power pass may be a conductive metal wire, conductive rod, fiber optic line, sonic or acoustic path, vibration path, electromagnetic (EM) signal, or wireless transmission. In the case of a conductor wire or rod, the conductor may be isolated from the reamer housing.

Figure 1 is a schematic of a representative embodiment of a wired reamer allowing power and / or communication to pass through the reamer. Wired reamer 100 comprises a body 105 with a flow bore 110 therethrough and a cutting frame 113 along the outer surface of the body 105. A through feeder assembly 115 extends through the flow bore 110. The feeder assembly The through-pass 115 further comprises a protected passageway 120 surrounding at least a portion of the power and / or communications drill cable 125. The drill cable 125 allows power and / or communication to and / or other tools located at the top of the hole or hole. descending from reamer 100.

In this representative embodiment, the passage 120 for the power and / or communications drill cable 125 extends through the flow bore 110 of the wired reamer 100. In other embodiments, the passage 120 for the drill cable 125 may extending through the reamer body 105 rather than through the flow bore 110. Figure 2 shows the wired reamer 100 shown in Figure 1 with the passage 120 for the power and / or communications drill cable 125 extending Because the passageway 120 is located within the body 105, there is no need for a through feeder assembly to house and protect the drill cable 125 as shown in Figure 1.

In addition, the representative embodiment shown in Figure 1 is a fixed blade reamer. In other embodiments, the reamer 100 may be another type of reamer, including an adjustable blade reamer. Figure 3 is a schematic of a representative embodiment of a wired adjustable blade reamer. Thus, the reamer 100 further comprises arms 130 which can retract and extend. As shown, the arms 130 open from the right, which corresponds to the descending hole end of the reamer 100. Alternatively, the arms 130 may open from the left, or the top end of the reamer hole 100, or if arcing outward from the center of reamer 100. The arms 130 further comprise cutting frames 113. Although shown in Figure 3, when positioned over the arms 130, the cutting frames 113 may alternatively or additionally be positioned over the reamer body 105 at the top of the hole or in the downward hole of the arms 130.

As described above, the passageway 120 for the drill cable 125 may extend through the reamer body 105, rather than through the flow bore 110. Figure 4 shows the reamer 100, shown in Figure 3, with the passageway 120 for power and / or communications drill cable 125 extending through the body 105 of the reamer 100. Because the passageway 120 is located within the body 105, there is no need for a bypass power assembly to house and protect the drill cable. 125, as shown in figure 3.

Power and / or communication need not be contiguous through a reamer, as they are depicted in Figures 1 to 4. Instead, power or communication may be provided through the reamer. Also, power and / or communication need not pass through the reamer, but instead can only be provided to the reamer. Figure 5 shows the wired reamer 100, shown in Figure 1, with the passage 120 for the power and / or communications drill cable 125 extending to, but not through, the flow hole 110 of the reamer 100. Similarly, Figure 6 shows the wired reamer 100, shown in Figure 2, with the passage 120 for the power and / or communications drill cable 125 extending to, but not through, the body 105 of the reamer 100. In addition, power and / or communication need not pass through or to the reamer, but instead may be contained entirely within the reamer. Figure 7 shows the wired reamer 100, shown in figure 1, with the passage 120 for the power and / or communications drill cable 125 contained within the flow hole 110 of the reamer 100. Similarly, Figure 8 shows the wired reamer 100, shown in Figure 2, with the passage 120 for the power and / or communications drill cable 125 contained within the body 105 of the reamer 100.

To optimize a drilling operation and / or formation assessment, it is desirable to be provided with information that relates to the reamer operating parameter as well as formation data of the surrounding formation being drilled. Therefore, in some embodiments, the instrumented wired reamer is equipped with sensors to collect such information. These embodiments may be applicable to all three types of reamers, fixed blade, adjustable, and expandable. Power for sensor operation can be provided by a power source connected to the reamer, such as a downhole power generator or battery pack, or from the surface via wire line or physical wired tubular components. Alternatively, the power source may be located above the wired reamer itself.

Sensors can be positioned inside the reamer as well as on its outer surface, including the arms. For example, some sensors that measure formation data are optimized by wellbore wall contact where, like other sensors, they work best centered on the wellbore. Sensors may be positioned on the outer reamer surface below or above the reamer arms and / or over the reamer arms. Other sensors can be used to monitor drilling or environmental data. For example, to monitor the borehole gauge and potential smoothness, sensors, specifically bore gauges, may be positioned above the arms, within the arms, or below the arms. Bore gauge sensors can be simple mechanical sensors, such as a spring sensor, or more complex acoustic gauges, which rely on pulse-echo, pitch / pickup, or other data acquisition techniques. In gauge measurement, mechanical sensors are best positioned on the arms, while mechanical sensors are best positioned on the reamer body. Sensors can be positioned on the reamer to monitor and report other information, such as positioning, for example, open, closed or partially open, closed situation, and forces acting on the tool such as vibration, weight on the control arms. reamer, reamer arm torque, tool RPM, temperature, pressure and / or tension / effort through the tool.

Certain types of forming evaluation sensors may be better suited for placement over the reamer body versus the reamer arms. For example, certain resistivity sensors are better suited to be placed on the reamer arms versus the reamer body, while other types of resistivity devices work better centered in the borehole and thus over the reamer body. This does not mean, however, that these sensors will work only in these locations. Other formation evaluation sensors that may be positioned on the reamer include nuclear porosity, sonic, magnetic imaging, and formation test sensors.

Information collected by the sensors can be stored on a memory chip located on the reamer. Information can be retrieved using an external port or surface wireless communication when the reamer is removed from the downward hole to the surface. Additionally or alternatively, the collected information may be transmitted using tool communication with another storage device, located on or over another downhole or surface tool. Tool communications are made either electrically via a physical conductor connection or through other communication techniques such as small EM vibration or acoustic transmission. Transmission of information to the surface can be done in real time using various communication techniques such as mud pulse telemetry, acoustic telemetry, electromagnetic induction, fiber optic wire lines, fiber optic components, or conductor-connected piping. physicists.

Figure 9 shows the wired reamer 100 of figure 1 with sensors for data collection. The wired reamer 100 further comprises sensors 140 located along the reamer 100. As shown, the sensors 140 are located on the outer surface of reamer 100, at the top of the cutting frame hole 113, at the descending hole of the cutting frame 113, and on the cutting frame 113. The wired reamer 100 further comprises a junction 145, which allows data collected by the sensors 140 to be communicated to the power and / or communications drill cable 125, which in this embodiment extends through the bypass feed assembly 115 inserted through the reamer flow bore 110.

Similarly, Fig. 10 shows the wired reamer 100 of Fig. 2 with sensors for data collection. In this embodiment, the passage 120 for the power and / or communications drill cable 125 passes through the reamer body 105. Because the drill cable 125 passes through the reamer body 105, rather than the reamer flow hole 110, a junction between sensors 140 and drill cable 125 is not required. Figure 9 and Figure 10 represent fixed blade reamers. As discussed above, the reamer may be another type of reamer, including an adjustable blade reamer. In addition, a wired adjustable blade reamer such as those shown in Figure 3 and Figure 4 can be configured with sensors for data collection. Figure 11 and Figure 12 represent the adjustable-bladed reamer 100 of Figure 3 and Figure 4 respectively with sensors 140 located on the reamer 100 and, in the case of Figure 11, the junction 145 coupled to the sensors 140 and the drill string 125. The embodiments exemplified by Figure 9 and

Figure 11 comprise a wired connection, more specifically the junction 145, between the sensors 140 and the power and / or communications drill cable 125. In other embodiments, this connection may be wireless rather than physical conductors. For example, Figure 13 shows the wired reamer 100 with sensors 140 shown in Figure 9 with a wireless connection 150 instead of junction 145 between sensors 140 and drill cable 125. Wireless connection 150 is still comprises a source 155 and a receiver 160 for respectively transmitting and receiving data collected by sensors 140 from sensors 140 to drill cable 125.

Similarly, the wired connection between the sensor (s) 140 located over the cutting frame 113 and the power and / or communications drill cable 125 extending through the reamer body 105 of the embodiments exemplified by figure 10e and figure 12 may be replaced by a wireless connection. For example, Figure 14 shows the wired reamer 100 with sensors 140, shown in Figure 10, with a wireless connection 150 instead of a wired connection between sensor (s) 140 located over the 113. As previously described, the wireless connection 150 further comprises the source 155 and the receiver 160 for transmitting and receiving, respectively, data collected by the sensors 140 from the sensors 140 to the power cable. drilling 125.

Power and / or communication need not be contiguous through a reamer, as they are depicted in figures 9 to 14. Instead, power or communication may be provided through the reamer. Also, power and / or communication need not pass through the reamer, but instead can only be provided to the reamer as shown in Figure 5 and Figure 6. In addition, power and / or communication need not pass through the reamer. to or from the reamer, but instead may be contained entirely within the reamer as shown in Figure 7 and Figure 8.

A processor can be used to collect, process, analyze and store information measured by downhole sensors. Therefore, in some embodiments, the sensor-wired reamer is provided with access to a processor through its communication through tooling in such embodiments, the reamer is referred to as "smart". The processor may be located on the surface, located over another down hole tool, or on the smart reamer itself.

Data collected by the sensors located on the smart reamer is transmitted to the processor through tool communication. Data collected by sensors located on other down-hole tool tools can also be transmitted to the processor via communication through the reamer tool. Alternatively, information collected from sensors, including those located on the reamer and other downhole tools, can be stored on a memory chip located on the reamer. Information can be retrieved from this memory chip using an external port or endless communication on the surface or when the reamer is removed from the downward hole to the surface. Additionally or alternatively, the collected information may be transmitted using tool communication to another storage device, either located on the surface or over another downward tool hole. Inter-tool communication can be performed either electrically via a physical conductor connection or through other communication techniques such as small EM vibration or acoustic transmission. Transmission of information to the surface can be done in real time using various communication techniques such as mud pulse telemetry, acoustic telemetry, electromagnetic induction, wire line, fiber optic components, or physical wired tubular components. However, the data can be retrieved from the sensors, the data is finally transferred to the processor for processing and analysis.

Fig. 15 shows the sensor wired reamer of Fig. 9 having access to a processor through communication via the reamer tool. As previously described, the wired reamer 100 comprises the flow bore 110 therethrough, the cutting frame 113 along the outer surface of the body 105, and the sensors 140 also located along the reamer 100. The bypass feed assembly 115 extends through the flow bore 110. The bypass feed assembly 115 further comprises the passage 120 surrounding at least a portion of the power and / or communications drill cable 125. The drill cable 125 allows power and / or communication for and / or other tools located at the top of the hole or descending hole of reamer 100, including a processor 165. Processor 165 may be located on the surface or over another descending hole tool. Data collected by the sensors 140 on the reamer 100 and sensors located over the other downhole tool with connectivity to the power and / or communications drill cable 125 of the reamer 100 is transmitted to processor 165 via the power drill cable and / or communications 125.

Figure 16 shows the wired reamer of Figure 7 with sensors and access to a processor through communication through the reamer tool. The only distinction between Figure 15 and Figure 16 refers to the power and / or communications drill cable 125 of the reamer 100. In Figure 15, the drill cable 125 extends through the reamer 100, while in Figure 16, the drill cable 125 extends but not through the reamer 100. In contrast to both figure 15 and figure 16, figure 17 shows the wired reamer of figure 5 with sensors and a processor. The embodiments exemplified in Fig. 17 comprise the power and / or communications drill string 125 contained in the ripper 100 rather than extending through or to the ripper 100. Thus, in the embodiments exemplified in Fig. 17, the processor 165 is necessarily located within reamer 100.

As in the previously described embodiments, power and / or communication need not be contiguous through the smart reamer, as they are depicted in Figure 15. Instead, power or communication may be provided through the smart reamer. Also, power and / or communication need not pass through the smart reamer, but instead can only be provided to the reamer as depicted in figure 16. In addition, power and / or communication need not pass through or to the smart reamer, but instead may be contained entirely in the reamer as shown in figure 17. Also, as with the previously described embodiments, the smart reamer may be a fixed blade reamer as illustrated in the figures 15 through 17, an adjustable blade reamer, or another type of reamer. In embodiments of the smart reamer having communication through or to the reamer, the processor may be located on the surface, over another descending tool hole, or over the reamer itself. In embodiments of the smart reamer having communication contained in the reamer, the processor is necessarily located over the reamer itself.

To optimize drilling and / or well drilling operation, it is desirable to control reamer operation. Therefore, in some embodiments of the wired reamer, the controllers and actuators are located on the reamer. Controllers and actuators may be electrical, hydraulic, mechanical, or other suitable type known in the industry. A signal can be sent to a controller, causing a controller to actuate an actuator, thereby controlling the operation of the reamer. For example, a signal may be sent to a controller causing a controller to actuate an actuator to extend, retract, and / or lock the reamer arms.

In some embodiments, the signal may be a direct command originating from a surface operator. Direct command can be sent to a controller located on the reamer via any number of communication techniques, such as mud pulse, EM, acoustic, or tubular components with physical conductors. Upon receiving direct command, a controller may actuate an actuator, also located on the reamer, causing the actuator to retract in a desired manner, for example to retract the reamer arms.

Various actuator actuating devices include, but are not limited to, electric motors, internally insulated hydraulic actuators, borehole fluid actuated actuators, pressure actuated devices, or drill string actuated devices. For example, the reamer arms may be activated using hydraulic flow or pressure against an internal piston, which in turn drives the reamer arms outward. In addition, a ball drop device can be used to assist with opening, closing or locking the position of the reamer arms. As another example, an electric actuator may be used to limit the movement of the reamer arms and to lock the reamer in an open, closed, or partially open position. The electric actuator can be a solenoid, switch, or circuit. As yet another example, the reamer arms can be actuated using an electric motor. A sensor can be used to determine the position of the reamer arms to confirm proper tool operation. As another alternative, electric valves may be used to alter the reamer piston area, thereby altering the activation flow or pressure required to engage the reamer arms. As yet another alternative, an oscillating plate pump may be used to activate the reamer arms. Electric valves can control pump activation or pressure relief against the reamer arms or a piston connected to the reamer arms. Finally, the reamer arms can be activated by temporarily connecting a motor drive rod to the reamer arms.

Figure 18 shows the wired reamer 100 of figure 1 with controllers and actuators for changing the position of the reamer cutting frames. The wired reamer 100 further comprises controller-actuator assemblies 170 located between the reamer body 105 and cutting frames 113. Each controller-actuator assembly 170 further comprises a controller and an actuator, wherein a controller, upon receipt of a signal. via the power and / or communications drill cable 125, the actuator actuates to modify the position of the cutting frames 113, for example, to retract the cutting frames 113 to reduce the borehole diameter or to expand the drilling structures. 113 cut to increase the borehole diameter.

Similarly, Fig. 19 shows the wired reamer 100 of Fig. 2 with controller and actuators for changing the position of the reamer cutting structures. In this embodiment, the passage 120 for the power and / or communications drill cable 125 passes through the reamer body 105. Because the drill cable 125 passes through the reamer body 105, rather than through the flow hole 110, a junction between controller-actuator assemblies 170 and drill cable 125 is not required.

As in the previously described embodiments, power and / or communication need not be contiguous via a reamer, as they are depicted in Figures 18 and 19. Instead, power or communication may be provided through the reamer. Also, power and / or communication need not pass through the reamer as depicted in figures 18 and 19, but instead can only be provided to the reamer or contained entirely in the reamer. Also, as with the previously described embodiments, the wired reamer may be a fixed-bladed reamer, as shown in Figures 18 and 19, an adjustable bladed reamer, or another type of reamer.

In other embodiments of the wired reamer with controllers and actuators, the controllers may actuate the actuators in receiving a signal originating from the processor. As described above, a sensor-wired reamer and access to a processor through its through-tool communication is a "smart reamer". In some embodiments of an intelligent reamer, controllers and actuators may be located over the reamer, and the controllers may be actuated by a direct command originating from the processor. Direct command can originate from the intelligent reamer operator. Alternatively, the direct command may be a signal or feedback generated by an algorithm developed as a measured data function and stored in the processor. Sensors located over the other downhole tools can measure data, in particular data that relates to the reamer's operating parameter and the forming characteristics of the surrounding formation being drilled. The measured data may be transmitted to the processor for use as feed to the algorithm. Upon receipt of the measured data, the processor may then execute the algorithm to generate feedback based on the measured data. Feedback can be transmitted as a signal to the smart reamer through its tool-based communication. The signal may direct a controller over the smart reamer to actuate an actuator, causing the smart reamer to react in a desired manner. Figure 20 shows the intelligent reamer 100 of figure 15

with controllers and actuators to change the position of the reamer cutting frames. Intelligent reamer 100 further comprises controller-actuator assemblies 170 located between reamer body 105 and cutting frames 113. Each controller-actuator assembly 170 further comprises a controller and an actuator, where a controller, upon receipt of a signal from processor 165 through the power and / or communications drill cable 125, the actuator actuates to modify the position of the cutting frames 113, for example to retract the cutting frames 113 to reduce the borehole diameter or to expand the cutting frames 113 to increase the borehole diameter.

Similarly, Fig. 21 shows the wired reamer 100 of Fig. 16 with controller and actuators for changing the position of the reamer cutting structures. In this embodiment, the passage 120 for the power and / or communications drill cable 125 passes through the reamer body 105. Because the drill cable 125 passes through the reamer body 105, rather than the reamer flow hole 110, a junction between a controller-actuator assembly 170 and the drill cable 125 is not required.

As in the previously described embodiments, power and / or communication need not be contiguous via a reamer, as they are depicted in Figures 20 and 21. Instead, power or communication may be provided through the reamer. Also, power and / or communication need not pass through the reamer as depicted in figures 20 and 21, but instead can only be provided to the reamer or contained entirely within the reamer. Also, as in the previously described embodiments, the wired reamer may be a fixed blade reamer as shown in Figures 20 and 21, an adjustable blade reamer, or another type of reamer. In embodiments of the smart reamer having communication through or to the reamer, the processor may be located on the surface, over another downhole tool, or over the reamer itself. In embodiments of the smart reamer having communication contained within the reamer, the processor is necessarily located over the reamer itself. As yet another alternative, direct command can be

a signal or feedback generated by an algorithm developed as a sensor-measured data function located on the smart reamer. In these embodiments, control of the smart reamer components is actuated in response to sensor data in a closed loop manner. The components may be such devices as adjustable stabilizing shoes (located before and after the reamer blades), Subs to control excessive torque applied to the reamer cutters, axial force applied to the reamer cutters, or tool RPM control. Sensors monitor reamer conditions such as vibration, drill torque, drill weight, forming characteristics, and RPM, and a controller and actuator can activate the appropriate stabilizer or Sub to control (limit or regulate) the forces on the tool. For example, a controller and actuator may extend or retract the stabilizer shoe to minimize tool vibration. As another example, a controller and actuator may allow a clutch to allow the column to rotate, or an under spring to temporarily absorb high torque in situations where the reamer experiences high torque or high RPM. As yet another example, a controller and actuator may cause a sub to extend or retract to change the weight on the reamer cutters. As yet another example, in response to data from an imaging device on a reamer arm indicating that the reamer cutters are not cutting the forming walls, a controller and actuator may cause the reamer arm to apply more pressure on the surrounding formation in the cutters.

Fig. 22 shows the smart reamer 100 of Fig. 20, wherein the data measured by sensors 140 is used as power to a stored algorithm and executed by processor 165 to generate feedback or a signal. The signal is subsequently transmitted to intelligent reamer controller-actuator assemblies 170, which direct controller-actuator assemblies 170 to modify the position of the cutting frames 113. In this way, the position of the cutting frames 113 is controlled until even optimized, in a closed-loop manner.

Similarly, Fig. 23 shows the smart reamer 100 of Fig. 21, also operating in a closed-loop manner to control the position of the cutting frames 113. In this embodiment, the passage 120 for the power piercing cable and / or communications 125 passes through the reamer body 105. Because the drill cable 125 passes through the reamer body 105, rather than through the reamer flow hole 110, a junction between a controller-actuator assemblies 170 and the drilling 125 is not required.

As in the previously described embodiments, power and / or communication need not be contiguous through a reamer, as they are depicted in Figures 22 and 23. Instead, power or communication may be provided through the reamer. Also, power and / or communication need not pass through the reamer as depicted in Figures 22 and 23, but instead can only be provided to the reamer or contained entirely in the reamer. Also, As in the previously described embodiments, the wired reamer may be a fixed-bladed reamer, as shown in Figures 22 and 23, an adjustable-bladed reamer, or another type of reamer. Embodiments of the smart reamer having communication through or to the reamer, the processor may be located on the surface, over another downhole tool, or over the reamer itself. In embodiments of the smart reamer having communication contained within the reamer, the processor is necessarily located over the reamer itself.

While preferred embodiments have been shown and described, modifications thereof may be made by one of ordinary skill in the art without departing from the scope or teachings given herein. The embodiments described herein are exemplary only and not limiting. Many variations and modifications of the system and apparatus are possible and are within the scope of the invention. For example, the relative dimensions of the various parts, the materials from which the various parts are made, and other parameters may be varied. Accordingly, the scope of protection is not limited to the embodiments described herein, but is only limited by the following claims, the scope of which should all include subject matter equivalents.

Claims (52)

Reamer for use in a down-hole drill string, characterized in that it comprises: a reamer body comprising a passage therethrough; and drill cable located within the passage to transmit at least one of power or communications. Reamer according to claim 1, characterized in that the reamer body passageway comprises a flow bore extending through the reamer body. Reamer according to Claim 2, characterized in that it further comprises a bypass feed assembly, the bypass feed assembly surrounding at least a portion of the drill cable. Reamer according to claim 1, characterized in that the reamer body further comprises a wall surrounding a flow bore extending through the reamer body and the passageway extending through the wall. Reamer according to Claim 1, characterized in that it further comprises a sensor being located within the reamer body, the sensor being connected with the drill cable to transmit data measured by the sensor through the drill cable. Reamer according to claim 5, characterized in that the sensor is selected from the group consisting of: a vibration sensor, a drill weight sensor, a drill torque sensor, a temperature sensor, a pressure-during-drilling sensor, a resistivity sensor, a nuclear sensor, an acoustic sensor, a nuclear magnetic resonance sensor, and a formation evaluation sensor. A reamer according to claim 5, characterized in that the reamer body further comprises a cutting frame and a sensor location is selected from the group consisting of: above the cutting frame, below the cutting frame. cut, and on the cut structure. Reamer according to Claim 5, characterized in that it further comprises the sensor being wirelessly connected with the drill cable. Reamer according to claim 5, characterized in that it further comprises a processor connected with the drill cable to receive data from the sensor. Reamer according to claim 9, characterized in that the sensor is connected wirelessly with the drill cable. Reamer according to claim 9, characterized in that the processor is located in one location, the location selected from the group consisting of: within the reamer body, on the surface, and on another downward drilling tool. A reamer according to claim 1, characterized in that it further comprises: wherein the reamer is an adjustable blade reamer comprising adjustable blades; an actuator operatively connected with the adjustable blades to adjust the position of the adjustable blades; and a controller operatively connected with the actuator to control the position of the adjustable blades. Reamer according to claim 12, characterized in that the controller is configured to change the cutting diameter of the adjustable blades. Reamer according to claim 12, characterized in that the actuator is selected from the group consisting of: an electric actuator, a mechanical actuator, and a hydraulic actuator. Reamer according to claim 12, characterized in that it further comprises a processor connected with the controller to transmit a signal to the controller, the signal directing the controller to actuate the actuator. Reamer according to claim 15, characterized in that the processor is located in one location, the location selected from the group consisting of: within the reamer body, on the surface, and over another downward hole tool. A reamer according to claim 12, characterized in that it further comprises: a sensor located within the reamer body, the sensor being connected with the drill cable to transmit data measured by the sensor through the drill cable; and a processor being connected with the drill cable to receive data from the sensor and with the controller to transmit a signal to the controller, the signal directing the controller to actuate the actuator. Reamer according to claim 17, characterized in that a controller is configured to change the cutting diameter of the adjustable blades. Reamer according to claim 17, characterized in that the actuator is selected from the group consisting of: an electric actuator, a mechanical actuator, and a hydraulic actuator. Reamer according to claim 17, characterized in that the processor is located in one location, the location selected from the group consisting of: within the reamer body, on the surface, and on another downward drilling tool. An amplifier according to claim 17, characterized in that the processor generates the signal as a function of the data received from the sensor. Reamer for use in a down-hole drill string, characterized in that it comprises: a reamer body comprising a passageway extending through at least a portion of the reamer body; and drill cable located within the passageway to transmit at least one of power or communications to or from the reamer. Reamer according to claim 22, characterized in that the reamer body passageway comprises a portion of a flow bore extending through the reamer body. Reamer according to Claim 23, characterized in that it further comprises a bypass feed assembly, the bypass feed assembly surrounding at least a portion of the drill cable. Reamer according to claim 22, characterized in that the reamer body further comprises a wall surrounding a flow bore extending through the reamer body and the passageway extending through a portion of the wall. Reamer according to claim 22, characterized in that it further comprises a sensor located within the reamer body, the sensor being connected with the drill cable to transmit data measured by the sensor through the drill cable. The reamer according to claim 26, characterized in that the reamer body further comprises a cutting frame and a sensor location is selected from the group consisting of: above the cutting frame, below the cutting frame. cut, and on the cut structure. Reamer according to claim 26, characterized in that it further comprises the sensor being wirelessly connected with the drill cable. Reamer according to claim 26, characterized in that it further comprises a processor connected with the drill cable to receive data from the sensor. Reamer according to Claim 29, characterized in that the sensor is connected wirelessly with the drill cable. Reamer according to claim 29, characterized in that the processor is located in one location, the location selected from the group consisting of: within the reamer body, on the surface, and over another downward hole tool. A reamer according to claim 22, further comprising: wherein the reamer is an adjustable blade reamer comprising adjustable blades; an actuator operatively connected with the adjustable blades to adjust the position of the adjustable blades; and a controller operatively connected with the actuator to control the position of the adjustable blades. Reamer according to claim 32, characterized in that the controller is configured to change the cutting diameter of the adjustable blades. Reamer according to claim 32, characterized in that the actuator is selected from the group consisting of: an electric actuator, a mechanical actuator, and a hydraulic actuator. Reamer according to claim 32, characterized in that it further comprises a processor connected with the controller to transmit a signal to the controller, the signal directing the controller to actuate the actuator. Reamer according to claim 35, characterized in that the processor is located in one location, the location selected from the group consisting of: within the reamer body, on the surface, and on another downward drilling tool. A reamer according to claim 32, further comprising: a sensor located within the reamer body, the sensor being connected with the drill cable to transmit measured data by the sensor through the drill cable; and a processor connected with the drill cable to receive data from the sensor and the controller to transmit a signal to the controller, the signal directing the controller to actuate the actuator. Reamer according to claim 37, characterized in that the controller is configured to change the cutting diameter of the adjustable blades. Reamer according to claim 37, characterized in that the actuator is selected from the group consisting of: an electric actuator, a mechanical actuator, and a hydraulic actuator. A reamer according to claim 37, characterized in that the processor is located in one location, the location selected from the group consisting of: within the reamer body, on the surface, and over another down hole tool. An extender according to claim 37, characterized in that the processor generates the signal as a function of the data received from the sensor. Reamer for use in a down-hole drill string, characterized in that it comprises: a reamer body comprising a passageway enclosed within the reamer body; drill cable located within the passage to transmit at least one of power or communications; a sensor located within the reamer body, the sensor being connected with the drill cable to transmit measured data by the sensor through the drill cable; and a processor located within the reamer body and connected with the drill cable to receive data from the sensor. A reamer according to claim 42, characterized in that the reamer body passageway comprises a flow bore extending through the reamer body. Reamer according to Claim 43, characterized in that it further comprises a bypass feed assembly, the bypass feed assembly surrounding at least a portion of the drill cable. A reamer according to claim 42, characterized in that the reamer body further comprises a wall surrounding a flow bore extending through the reamer body and the passageway extending through the wall. A reamer according to claim 42, characterized in that the reamer body further comprises a cutting frame and a sensor location is selected from the group consisting of: above the cutting frame, below the cutting frame. cut, and on the cut structure. A reamer according to claim 42, characterized in that the sensor is connected wirelessly with the drill cable. A reamer according to claim 42, further comprising: wherein the reamer is an adjustable blade reamer comprising adjustable blades; an actuator operatively connected with the adjustable blades to adjust the position of the adjustable blades; and a controller operatively connected with the actuator to control the position of the adjustable blades. Reamer according to claim 48, characterized in that the controller is configured to change the cutting diameter of the adjustable blades. Reamer according to claim 48, characterized in that the actuator is selected from the group consisting of: an electric actuator, a mechanical actuator, and a hydraulic actuator. An amplifier according to claim 48, characterized in that the processor is connected with the controller to transmit a signal to the controller, the signal directing the controller to actuate the actuator. Reamer according to claim 51, characterized in that the processor generates the signal as a function of the data received from the sensor.