Delivery device, system and method

Abstract

An apparatus may have a sealing module located at an upper portion thereof. The apparatus may also have a mud line formed through the upper portion of the apparatus and a mud outlet in fluid communication with the mud line. The apparatus may also include a mud pulser adjacent to the mud outlet, wherein the mud pulser is configured to be actuated to open, partially close, and close the mud outlet.

Description

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS

[0002] This article is based on and claims priority to U.S. Provisional Application Serial No.: 62 / 878,166 filed on July 24, 2019, which is incorporated herein by reference in its entirety. Background Art

[0003] The present disclosure generally relates to apparatus, systems and methods for delivering tool strings into a wellbore. Delivery of tool strings typically requires several pieces of equipment, including winches, cables, pulley systems and other wireline surface equipment to deliver wireline tool strings into the wellbore; however, deployment and setup of wireline surface equipment is typically time-consuming and inefficient.

[0004] Therefore, there is a need for apparatus, systems, and methods for delivering a tool string into a wellbore that reduce the amount of surface equipment required to deliver the tool string into the wellbore. Summary of the invention

[0005] A method of delivering a logging tool into a wellbore. The method may include placing the device in a drill pipe in the wellbore, wherein the device is configured to be delivered by pumping mud into the drill pipe. The method may also include adjusting a mud pulser on the device to selectively open or close a mud outlet in the device. The method may also include landing the device in a landing section.

[0006] A system for delivering a tool string into a wellbore may include the apparatus as described herein. The system may also include a logging tool string connected to a lower portion of the apparatus. The system may also include a drill pipe having a landing portion at its lower end.

[0007] In an embodiment, the apparatus may include a sealing module located on an upper portion of the apparatus. The apparatus may also have a lower portion configured to be connected to a tool column, and the apparatus may be configured to communicate with the surface.

[0008] In another embodiment, the device may include a sealing module located at an upper portion thereof and a mud pipeline formed through an upper portion of the device. The device may also include a mud outlet in fluid communication with the mud pipeline. The device may also include a mud pulser adjacent to the mud outlet, wherein the mud pulser is configured to be actuated to open, partially close, and close the mud outlet. The device may also include a mud pulser harness connected to the device between the mud pulser and a swivel, wherein the mud pulser harness is connected to the mud pulser and the swivel. The device may also include a control module adjacent to the swivel, wherein the swivel provides communication between the control module and the mud pulser harness. BRIEF DESCRIPTION OF THE DRAWINGS

[0009] Various aspects of the present disclosure may be better understood by reading the following detailed description and referring to the accompanying drawings, in which:

[0010] Figure 1 An example of an apparatus for conveying a tool string is depicted.

[0011] Figure 2 A schematic diagram of an apparatus for delivering a tool string delivered in a drill pipe is depicted.

[0012] Figure 3 Depicted is a schematic diagram of an apparatus for delivering a tool string landed in a drill pipe.

[0013] Figure 4 Embodiments of methods of transferring a tool string are described.

[0014] Figure 5 Depicted is a schematic diagram of an apparatus set in a setting section of a drill pipe, wherein the setting section and the apparatus are configured to allow for setting detection.

[0015] Figure 6 Embodiments of equipment that is recycled using a recycling operation are depicted.

[0016] Figure 7 Embodiments of an actuation system according to one or more embodiments are depicted.

[0017] Figure 8 Another embodiment of an actuation system according to one or more embodiments is depicted.

[0018] Fig. 9 A schematic diagram depicting a drilling rig delivering equipment and an attached tool string into a wellbore.

[0019] Fig.10 An embodiment of a speed reducer is depicted. DETAILED DESCRIPTION

[0020] One or more specific embodiments of the present disclosure are described below. These described embodiments are examples of the currently disclosed technology. In addition, in order to provide a concise description of these embodiments, features of actual implementations may not be described in the specification. It should be understood that in the development of any such actual implementation, as in any engineering or design project, many implementation-specific decisions may be made to achieve the developer's specific goals, such as complying with system-related and business-related constraints, which may vary from implementation to implementation. In addition, it should be understood that such development work may be complex and time-consuming, but will be a routine task of design, manufacturing, and fabrication for ordinary technicians who benefit from this disclosure.

[0021] In one or more embodiments, a method of delivering a tool string into a wellbore may include placing an apparatus having a tool string attached to an end thereof into a drill pipe in the wellbore. The apparatus may be used to deliver the attached tool string into the wellbore without being tethered to surface equipment, thereby allowing the tool string to be delivered without additional surface equipment and using standard equipment of a drilling rig used to deliver pipe into a wellbore, drill a wellbore, or a combination thereof. To achieve this, the apparatus is configured to be pumped down in a controlled manner using a standard mud pump used in a typical drilling operation.

[0022] The method may also include providing data to the surface. The data may be provided to the surface using mud pulse telemetry, electromagnetic telemetry, other types of telemetry, or a combination thereof.

[0023] In one or more embodiments of the method, the telemetry may be mud pulse telemetry and the method may further include adjusting a mud pulser on the device to selectively open, partially close, or close a mud outlet in the device. Selective operation of the mud pulser allows data to be transmitted to the surface for viewing or storage. Data collected during the delivery of the device using mud pulse communication and sent to the surface may include tool health data, delivery data, wellbore condition data, formation data, evaluation data, or a combination thereof. Tool health data may be the status of a power source communicating with the tool string, the status of components of the tool string, etc. Delivery data may use depth, acceleration data, delivery velocity data, etc. Wellbore condition data may include pressure, temperature, etc. In one or more embodiments, the delivery data may include data from one or more accelerometers on the tool string or device, for example, one or more triaxial accelerometers may be placed at different locations on the device and tool string, data may be uploaded to the surface using selective actuation of the mud pulser following the communication scheme, and rig sensors, such as sensors configured to measure riser pressure, may acquire mud pulse data and send it to the rig system, and external systems may be linked to the rig system. The external system may include one or more processors configured with computer instructions in communication with the processor to convert the accelerometer data into velocity (i.e., integrating the accelerometer data over time) and position (i.e., integrating the velocity data over time), and display the velocity and position of the device on a display. The processor may also be configured to form a trajectory of the path of travel of the device and provide to a map or model of the wellbore to be created during drilling to help fine-tune the map or model, issue an alarm if the axial velocity exceeds a predetermined value, issue an alarm if a lateral velocity or acceleration is detected at or above a predetermined value, issue a command to the rig system to adjust the mud pump rate if the velocity exceeds a predetermined value or falls below a predetermined value, issue an alarm if a displacement of the tool string is detected such that it approaches a setting portion of the drill pipe, use the accelerometer data and the displacement value to make a determination to detect that the device is set in the setting portion of the drill pipe, and when the device is confirmed to be set in the setting, use the displacement data to confirm, adjust, or confirm and adjust the depth data of the setting portion, and other determinations to determine expected values ​​by processing sensor data on the device or tool string. The device may also include sensors to detect shocks or forces applied to the device while the device is seated in the seating portion. In one or more embodiments, shocks or forces applied to the device during seating may be communicated to one or more processors along with a model of the tool to predict the health of the tool, simulate the motion of seating to determine if there is potential damage to any components, or predict how many more times the device can be seated before maintenance is required, etc.

[0024] The mud pulser may be selectively operated, as described in more detail below, to send data to the surface. The data may include tool string health data, evaluation data collected using one or more formation evaluation sensors or fluid test sensors on the tool string, operational data, or a combination thereof. In one or more embodiments, the operational data may be a signal that the memory is recording evaluation data, motor torque, pump pressure, actuation of an anchor or evaluation pad, mechanical intervention, or movement of a coring drill bit; a test pressure of a formation evaluation tool, a drilling pressure of a coring drill bit, or other operational data. The tool string health data may be a signal indicating that all major components have passed an operational check, a signal that certain components are not connected, or other tool string health data.

[0025] In one or more embodiments, the telemetry may be electromagnetic telemetry. The electromagnetic telemetry may use a currently known electromagnetic telemetry system or a future known electromagnetic telemetry. For example, the electromagnetic telemetry may use a TelePacer TM Modular MWD platform and from Schlumberger TM Express purchased TM Electromagnetic telemetry.

[0026] In one or more embodiments, the method may include acquiring assessment data while conveying the equipment and tool string to detect an increase in density, indicating that the equipment is passing through the drill pipe joint, and inferring the speed and position of the tool string during conveyance. The assessment data may be acquired using a logging tool string, a casing collar locator, or a combination thereof. For example, radioactive measurements, such as gamma measurements, neutron-gamma measurements, X-ray measurements, etc., or a combination thereof. The method may also include sending the assessment data to the surface and adjusting the mud flow in the borehole to optimize the delivery of the tool string.

[0027] In one or more embodiments, the method may include acquiring assessment data during delivery to detect density changes, processing the acquired data downhole to determine equipment speed, position, or a combination thereof, transmitting the determined speed, position, or a combination thereof to the surface, and adjusting the mud pump rate to the borehole based on the determined position, speed, or a combination thereof. The method according to claim 11 also includes processing the assessment data downhole to determine the speed, position, or a combination thereof, and transmitting the determined speed, position, or a combination thereof to the surface. In one or more embodiments, the determined speed, position, or a combination thereof is used to automatically adjust the mud pump flow. For example, the surface equipment may have a processor and a data acquisition system that is configured to receive the determined speed, position, or a combination thereof, and the processor may communicate with computer instructions that employ the determined speed, position, or a combination thereof and automatically determine an optimized pump rate, and control the mud pump to adjust the pump rate to the optimized pump rate. The optimized pump rate may be determined by a predetermined value based on position, speed, etc. For example, the computer instructions may include or communicate with a planner that assumes that at depth x the velocity should be n, and if the velocity of the device at depth x is greater than n, the computer instructions will instruct the processor to calculate a pump rate that will reduce the velocity to match n, and control the mud pump to adjust the pump rate accordingly, and if the velocity of the device at depth x is less than n, the computer instructions will instruct the processor to calculate a pump rate that will increase the velocity to match n, and control the mud pump to adjust the pump rate accordingly.

[0028] In one or more embodiments, the method may include providing automatic pump rate control based on downhole tool speed. Tool speed may be determined based on data obtained from a casing collar locator, a wheel on the equipment or tool string, an accelerometer on the equipment or tool string, and a pressure drop along the tool string.

[0029] In one or more embodiments, the pressure drop can be determined using pressure gauges located at the upper and lower parts of the equipment and tool string. The pressure difference between the two values ​​is equal to the pressure drop in the drill pipe between the two points of the tool string. This can give us an indication of pumping efficiency.

[0030] The control module described in detail below may include one or more additional modules that can be interconnected and communicated. In one or more embodiments, the control module or a module communicating with the control module may be configured to provide delivery monitoring and decision processing. The delivery monitoring and decision processing will receive inputs from: a casing collar locator, one or more accelerometers, one or more wheels that contact the drill pipe ID, a top pressure gauge, a bottom pressure gauge, or a combination thereof. The processor in the module will be constructed by computer instructions that communicate with the processor to process data to derive the downhole speed when deployed during pumping and the pressure drop along the column. The derived speed and pressure drop can be used to determine the recommended pump rate. The recommended pump rate can be transmitted to the surface via telemetry. For example, the recommended pump rate can be transmitted to the surface using a mud pulse method. Any type of mud pulse communication protocol can be used to communicate the recommended pump rate to the surface. For example, when the tool column speed approaches the desired pumping speed, the pressure pulse per minute; when the tool column speed is higher than the desired pumping speed, the pressure pulse frequency increases; when the tool column speed is lower than the desired pumping speed, the pressure pulse frequency decreases; and so on; or a combination thereof. The pressure pulses are interpreted at the surface and the pump rate is adjusted by either modulating the pump rate or diverting a portion of the flow.

[0031] Additionally, the top and bottom pressure sensor measurements can be matched to each other based on deviation, mud density, and distance between sensors, or when the deviation is 90 degrees. The pressure sensors can be used to obtain the pressure drop along the string (indicating the force exerted by the fluid on the string); receive downlink mud pump commands; shut down the tool after interval completion and before the tool string reaches the surface; or a combination thereof.

[0032] Figure 1 An example of an apparatus for conveying a tool string is depicted. The apparatus 100 includes a retrieval neck 110, one or more sealing modules 120, one or more mud lines 130, one or more mud outlets 140, one or more mud pulsers 150, one or more mud pulser harnesses 152, one or more speed reducers 160, one or more swivels 170, and one or more control modules 180.

[0033] The recovery neck 110 is located at one end of the device, and the tool column 190 is connected to the other end of the device 100. The recovery neck is configured to allow the device and the tool column to be recovered by a recovery operation when necessary. The recovery neck can be any recovery neck known now or in the future. The tool column 190 can be a logging tool column, a collar locator, an interference tool column, other known or future known tool columns, or a combination thereof. Examples of logging tool columns include nuclear logging tool columns, resistivity logging tool columns, nuclear magnetic resonance logging tool columns, dielectric logging tool columns, microresistivity logging tool columns, x-ray logging tool columns, other known or future known logging tool columns, or a combination thereof.

[0034] The sealing module is located near the recovery neck. One or more sealing modules 120 can be one or more scraper plugs, one or more scrubbing cups or one or more other devices to increase resistance and sealing on the drill pipe hole. The sealing module 120 can be made of any material, such as flexible rubber, flexible polymer or other flexible composite materials. The sealing module 120 provides sealing during deployment and provides substantially positive displacement, thereby allowing pumping delivery at low pump rates, medium pump rates or high pump rates. One or more mud pipelines shown as a mud pipeline 130 provide a flow path through the top of the device 100 to reach one or more mud outlets (depicted as a mud outlet 140).

[0035] One or more mud pulsers, depicted as a single mud pulser 150, may be located near the mud outlet 140. The mud pulser 150 may be connected to one or more mud pulser harnesses, depicted as a mud pulser harness 152. The mud pulser harness 152 may be connected to a swivel 170. The swivel 170 may be a multi-contact swivel that provides communication between one or more control modules (shown as control module 180). The multi-contact swivel may also accommodate rotation of the drill pipe when pulling out of the hole without causing a loss of communication between the pulser harness and the control module 180. The swivel 170 may also allow the tool string to self-position in the borehole wall independent of the drill pipe surface. The swivel 170 may have one or more rotatable electrical connections, such as one for communication signals and one for power. Thus, the mud pulser harness may allow communication between the mud pulser 150 and the control module 180, allowing power, signals, or a combination thereof to be sent between the mud pulser 150 and the control module 180. One or more speed reducers may be located on the device, with one speed reducer 160 being depicted as being disposed between the mud outlet 140 and the control module 180 .

[0036] The mud pulser 150 may be any known or future known mud pulser. In one or more embodiments, the mud pulser 150 may be a linear valve type. In one or more embodiments, it may include a plunger. The mud pulser 150 may be actuated by an actuation system, embodiments of which will be described in more detail below. Another example of a mud pulser is a rotary siren mud pulser, for example, a mud pulser may include a rotor working in conjunction with a stator to selectively at least partially restrict, fully restrict, or open a mud inlet. The mud pulser may include other flow control devices, such as solenoid valves, etc.

[0037] The speed reducer 160 may be a mechanical device that is configured to be self-actuated, actuated by a control system, or a combination thereof. For example, the speed reducer may have an electric actuator that is activated by the control module 180 when data from an accelerometer is above a predetermined value or range, such as approaching a landing portion and speed, etc.

[0038] The control module 180 may include one or more communication modules, one or more power modules, one or more microprocessors, one or more communication buses, or a combination thereof. The control module collects data from other tools on the tool string, aggregates the data, and generates a status word in the form of a predefined pulse communication pattern.

[0039] Figure 2 A schematic diagram of an apparatus for conveying a tool string conveyed in a drill pipe is depicted. The apparatus 100 may be conveyed into a wellbore through a drill pipe 200. Mud 210 may be pumped from the surface through the bore of the drill pipe 200, the mud enabling the apparatus to move within the drill pipe 200. The mud 210 may flow in a mud line 130 and exit a mud outlet 140. During pumping, a mud pulser may alternate to open or close the mud outlet 140, such that the pressure drop in the tool may take on all values ​​between a high pressure drop (i.e., tool string friction / pipe ID cross-sectional area) and a low pressure drop caused by mud flow in the bore of the mud line 130. For example, for a high pressure drop, the mud pulser is in a position to close the mud outlet 140, and for a low pressure drop, the mud pulser is in a position to open the mud outlet 140.

[0040] Figure 3 A schematic diagram depicting an apparatus for conveying a tool string that is set in a drill pipe. The drill pipe 200 can have a lower landing portion that is configured to grasp the apparatus, such as by having a landing shoulder having an inner diameter that grasps a portion of the tool. The landing portion can be connected to the lower end of the drill pipe, integrated into the lower portion of the drill pipe, etc. The inner profile of the landing portion can have flow bypasses 310 and 320. When the apparatus is set, the sealing module is adjacent to the flow bypass 310. The flow bypasses 310 and 320 allow continued pumping during downhole operations, even when the apparatus is set. An annular space is formed between the outer diameter of the apparatus near the mud pulser and the inner diameter of the landing portion. In operation, when the mud pulser valve is opened, mud will flow through the mud line with a small pressure drop, providing a low pressure communication state. When the pulser valve is closed, the mud flow through the mud line is zero, and the mud is forced to flow through the flow bypass 310 and the annular space formed between the outer diameter of the equipment near the mud pulser and the inner diameter of the landing part. This mud path produces a large pressure drop, which is the high pressure state of the communication scheme.

[0041] Figure 4An embodiment of a method of delivering a tool string is depicted. The method 400 includes placing the device and the attached tool string into a drill pipe in a wellbore 410. The method also includes pumping mud through the pipe hole and alternating the mud pulser to open, partially close, and close the mud outlet 412. The method also includes landing the device in the landing portion 414. The method may also include selectively activating the mud pulser to provide communication with the surface 416. The communication scheme may be, but is not limited to: pulse width modulation between the high pressure drop state and the low pressure drop state described above for each location. The communication scheme may allow visual or rig slow sampling rate of the riser pressure measurement sensor to obtain a near real-time data stream. For example, the drilling rig may be connected to a pressure sensor to monitor the riser pressure. Using a data exchange standard, such as the wellsite information transmission standard markup language, the data stream from the device is transmitted in near real time on the drilling rig. By connecting an external computer to the drilling rig communication system, pressure data can be enabled on the drilling rig, and the pressure modulation from the mud pulser can be acquired and decoded in real time.

[0042] The communication scheme may be pulse width modulation between a high pressure drop state and a low pressure drop state at each of the above positions. For example, a 15 second cycle means the tool string is functioning properly, while a 20 second cycle means there is a problem with the tool string.

[0043] Figure 5 A schematic diagram of an apparatus set on a setting section of a drill pipe is depicted, wherein the setting section and the apparatus are configured to allow for setting detection. The apparatus 100 and the tool string 190 may be located in whole or in part within a drill pipe 200. For example, the apparatus 100 may be located on a setting section of a drill pipe 200, and the tool string 190 may protrude from the drill pipe 200 into the wellbore. In another example, the apparatus 100 may be located on a setting section of a drill pipe 200, and the tool string 190 may also be located within the drill pipe 200.

[0044] Figure 6An embodiment of a device for recovery using a recovery operation is depicted. The device 100 can be recovered using a recovery operation. For example, a recovery tool 600 can be deployed into a drill pipe. The recovery tool can be delivered using a wire rope, a cable, etc. The recovery tool 600 can be engaged with the device 100 via a recovery neck. The recovery tool 600 can apply tension to the device 100, and the tension can open a flow path 605, which will allow mud to flow out of the device 100. Then, the recovery tool can be used to recover the device 100. For example, the flow line can be made of a coaxial and axially sliding tube, wherein the inner tube has a side opening that is usually closed by being blocked by the outer tube, and can be maintained in this position by a compression spring. During the pumping process, the thrust is in the same direction as the spring action, so the opening remains blocked. Unlike during recovery (no pumping), the only force acting on the system is the recovery tension that can overcome the spring force, which is lower than the buoyancy and friction of the tool string, and the side opening is opened.

[0045] Figure 7 An embodiment of an actuation system according to one or more embodiments is depicted.The mud pulser actuation system may include a BLDC motor connected to a gearbox that may drive a ball screw that moves the plunger position.

[0046] Figure 8 Another embodiment of an actuation system according to one or more embodiments is depicted. The mud pulser actuation system may include a motor connected to a pump that pressurizes hydraulic oil to move a piston. The piston may move a plunger to change its position.

[0047] When introducing elements of various embodiments of the present disclosure, the articles "a," "an," and "the" are intended to indicate that there are one or more elements. The terms "comprising," "including," and "having" are intended to be inclusive, and mean that there may be additional elements in addition to the listed elements. Furthermore, it should be understood that reference to "one embodiment" or "an embodiment" of the present disclosure is not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.

[0048] Fig. 9A schematic diagram of a drilling rig delivering a device and an attached tool string into a wellbore is depicted. The drilling rig 900 may be a drilling rig or other drilling rig used to deliver pipes, drill wellbores, or a combination thereof. The drilling rig has a sensor 910 for measuring pressure in a riser and a rig computer system 920 in communication with the sensor 910. The device may be deployed in a drill pipe 200, and the device uses a control module to operate a mud pulser, and data acquired from one or more sensors on the device or tool string may be sent to the surface using a standard mud pulse communication protocol, which is picked up by the sensor 910 and sent to the rig computer system 920. An external computer system 930 communicates with the rig computer system 920. The external computer system may be in the cloud, near the drilling rig, or a combination thereof. The external computer system may communicate with the rig computer system by wire, wirelessly, by Bluetooth, or other types of telemetry. The external computer system may include one or more processors and one or more computer instructions in communication with the one or more processors. The one or more processors may be configured by computer instructions to receive data sent by mud pulses from the rig computer system and process the data to present one or more parameters in near real time. Near real time means real time excluding processing time, signal propagation time, and other time delays typical in downhole communications and processing. The near real time data can be displayed on one or more graphical user interfaces 932 that communicate with the external system 930.

[0049] Fig.10 An embodiment of a speed reducer is depicted.

[0050] The reducer 1000 may have a fluid (not shown) of known properties, such as hydraulic fluid, oil, grease, or the like, trapped in the annular cavity 1040, and the volume of the annular cavity 1040 changes when the outer setting sleeve 1030 moves. For example, the outer setting sleeve 1030 may slide. The outer setting sleeve 1030 may be disposed around the device. The device may have a stopper 1060. The annular cavity 1040 may be sealed by one or more seals 1050.

[0051] Initially, during delivery, the annular chamber 1040 is filled with a fluid of known properties. During landing, the internal overpressure generated by the impact of the no-go against the sliding sleeve opens the pressure relief valve 1010, which allows the landing sleeve 1030 to slide and the contained hydraulic fluid to flow out.

[0052] During deceleration, the fluid of known characteristics is pushed out of the annular cavity 1040 through additional grooves on the inner wall of the setting sleeve 1030. When the specific volume of the mud increases due to the influence of pressure and temperature, the pressure relief valve 1010 is used to balance the pressure between the inside and outside of the annular cavity 1040. The energy absorbed in this process can be adjusted by: changing the properties of the fluid of known characteristics, the volume of the fluid of known characteristics, or a combination thereof; changing the valve opening threshold; changing the opening size of the cutout 1020 on the setting sleeve 1030, or a combination thereof.

[0053] Although example components, methods, and systems are described herein, the scope of coverage of this patent is not limited thereto. On the contrary, this patent covers every method, apparatus, and article of manufacture fairly falling within the scope of the appended claims either literally or under the doctrine of equivalents.

Claims

1. A method of delivering a tool string into a wellbore, wherein the method comprises: a. placing a device with a tool string attached to one end thereof into a drill pipe in a wellbore, wherein the device is configured to be delivered by mud pumped into the drill pipe, wherein the device comprises: a sealing module located at an upper portion of the apparatus, a mud line formed through the upper portion of the apparatus, a mud outlet in fluid communication with the mud line, a mud pulser adjacent to the mud outlet, wherein the mud pulser is configured to be actuated to at least open and close the mud outlet; b. Provide data to the ground; and c. Setting the device in a setting section at the lower end of the drill pipe, wherein the inner contour of the setting section has a flow bypass, forming an annular space between the outer diameter of the device near the mud pulser and the inner diameter of the setting section, In operation, when the mud pulser valve is open, mud will flow through the mud line with a small pressure drop, and when the pulser valve is closed, mud is forced to flow through the flow bypass and the annular space, and this mud path produces a large pressure drop.

2. The method according to claim 1, wherein: The seating portion is integral with the drill pipe, connected to the drill pipe, or a combination thereof.

3. The method according to claim 1, wherein: The tool string is a logging tool string.

4. The method according to claim 1, wherein: The method also includes receiving mud pulse data using one or more rig pressure sensors and transmitting the mud pulse data stream in near real time via a wellsite exchange communication standard to obtain a low rate uplink communication.

5. The method according to claim 1, wherein: The data includes tool health data, delivery data, or a combination thereof.

6. The method of claim 1 further comprises using a mud pulser to uplink data while the device is in place, the data comprising: tool string health data, evaluation data, operational data, or a combination thereof.

7. The method according to claim 1, wherein: The equipment is delivered to the setting portion within the drill pipe without the use of cables, wirelines, cables or other tethers connected to surface equipment.

8. The method according to claim 1, wherein: in, Providing data to the surface may include using mud pulse telemetry, electromagnetic telemetry, or a combination thereof.

9. The method according to claim 8, wherein: The telemetry is mud pulse telemetry and includes adjusting a mud pulser on the device to at least selectively open or close a mud outlet in the device, wherein adjusting the mud pulser includes selectively opening, partially closing, or closing the mud outlet.

10. The method according to claim 1, further comprising: acquiring evaluation data while the device and tool string are being conveyed into the wellbore to detect a density increase indicating that the device is passing through a drill pipe joint; and Based on the evaluation data, the velocity and position of the tool string are derived.

11. The method according to claim 10, wherein: Acquiring the evaluation data includes acquiring the evaluation data using a logging tool string, a casing collar locator, or a combination thereof.

12. The method of claim 10, further comprising sending the assessment data to a device at the surface of the wellbore, wherein pumping mud into a drill pipe to set the device further comprises regulating mud flow in the wellbore to optimize delivery of the tool string.

13. The method according to claim 10, further comprising: Processing the evaluation data downhole to determine velocity, position, or a combination thereof; and The determined velocity, position, or a combination thereof is transmitted to equipment at the surface of the wellbore.

14. The method according to claim 13, wherein: Pumping mud into the drill pipe to set the device includes automatically adjusting mud pump flow in the wellbore based on the determined speed, position, or a combination thereof.

15. A system for delivering a tool string into a wellbore, comprising: a. An apparatus configured to pump mud into a drill pipe in a wellbore, wherein the apparatus comprises: i. A sealing module located at the upper portion of the device; ii. a mud line formed through the upper portion of the device; iii. a mud outlet in fluid communication with a mud line; iv. a mud pulser adjacent to the mud outlet, wherein the mud pulser is configured to be actuated to at least open and close the mud outlet; v. a mud pulser harness connected to the device between the mud pulser and the swivel, wherein the mud pulser harness is connected to the mud pulser and the swivel; and vi. a control module adjacent to a swivel, wherein the swivel provides communication between the control module and a mud pulser harness; b. a tool column connected to the lower portion of the device; and c. A drill pipe having a landing section at its lower end, wherein the inner profile of the landing section has a flow bypass forming an annular space between the outer diameter of the device near the mud pulser and the inner diameter of the landing section, In operation, when the mud pulser valve is open, mud will flow through the mud line with a small pressure drop, and when the pulser valve is closed, mud is forced to flow through the flow bypass and the annular space, and this mud path produces a large pressure drop.

16. The system of claim 15, wherein: The device is configured to transmit data via mud pulses while being transported and while being set.

17. An apparatus configured to pump mud into a drill pipe, comprising: a. A sealing module located at the upper portion of the device; and b. a lower portion of the apparatus configured to be connected to a tool string, wherein the apparatus is configured to communicate with the surface in near real time, wherein the apparatus further comprises a mud line formed through the upper portion of the apparatus; a mud outlet in fluid communication with the mud line; a mud pulser adjacent the mud outlet, wherein the mud pulser is configured to be actuated to at least open and close the mud outlet; a mud pulser harness connected to the apparatus between the mud pulser and the swivel, wherein the mud pulser harness is connected to the mud pulser and the swivel; and a control module adjacent the swivel, wherein the swivel provides communication between the control module and the mud pulser harness; and c. A drill pipe having a landing section at its lower end, wherein the inner profile of the landing section has a flow bypass forming an annular space between the outer diameter of the device near the mud pulser and the inner diameter of the landing section, In operation, when the mud pulser valve is open, mud will flow through the mud line with a small pressure drop, and when the pulser valve is closed, mud is forced to flow through the flow bypass and the annular space, and this mud path produces a large pressure drop.

18. The apparatus according to claim 17, wherein: The equipment is configured to communicate with the surface in near real time using electromagnetic telemetry, mud pulse telemetry, or a combination thereof.

19. The apparatus of claim 17, further comprising a recovery neck at an upper portion of the apparatus above the sealing module, and wherein a portion of the apparatus below the sealing module is configured to open a flow path when tension from a recovery tool connected to the recovery neck is applied to the upper portion.

Images