TITLE

Digitally Controlled Agitation Switch

Smart Vibration Assembly for Lateral Well Access

INVENTOR

Stuart McLaughlin

CROSS-REFERENCE TO RELATED APPLICATIONS

Priority claimed to Provisional Application U.S. Serial No. 62/588,378 filed on November 19,

2017.

FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

Not Applicable INCORPORATION BY REFERENCE OF MATERIAL

SUBMITTED ON A COMPACT DISK

Not Applicable

BACKGROUND OF THF INVENTION

Field of the Invention

The present invention provides a novel apparatus and vibratory assemblage that initiates and maintains mechanical agitation within the horizontal (lateral) section of a wellbore by providing both low and high vibration, in multiple axis and planes, and pulsing of high-pressure fluids within the confines of the apparatus and drilling pipe. Through the judicious and conservative use of fluids, the present invention provides both rotationally accelerated vibration and high-intensity, directed and timed pressured fluid to reduce the cumulative friction between the drill string and bottom hole assembly on a wellbore. Additionally, the present apparatus can be preprogrammed to respond to specific commands, in response to certain predetermined conditions, to stop and start functioning at various times throughout the drilling process.

Manifestly, it is friction within the horizontal sections of a wellbore that ultimately leads to decreases in downhole advancement and overall decreases rate of penetration (ROP). In horizontal drilling, as the drill string transitions through the heal and begins a horizontal advancement down the wellbore, the forces upon the drill string and BHA experience mechanical drag due to frictional forces that work counter to the drill strings ability to advance.

Ultimately, the maximum reach of the drilling assembly is determined, jointly, by driving force and opposing axial frictional forces where these frictional forces consist primarily of torque and drag. While the application of more force results in more weight on bit (WOB), and thereby further advancement of the BHA, it also creates untoward string buckling (helically and/or sinusoidally) that (1) disallows increases in weight to be distributed to the bit proportionally with increased force and (2) unwanted tangential frictional forces along the preceding sections of the wellbore behind the BHA.

To overcome the limits of excess torque and drag, well operators and petroleum engineers have developed several methods to overcome these limitations in order to effectively reach greater and greater depths and lengths within the wellbore. As is the case with unconventional drilling and ultra-extended reach wells (u-ERW), chemical and mechanical methods have been employed to reduce the friction experiences between drill strings, bottom hole assemblies and wellbores. Yet, chemical lubricant additives carry with them excessive cost, both environmental and financial, that make their use untenable. Mechanical methods, though, have proven both cost effective and environmentally safe. By far the most utilized of the mechanical methods of reducing torque and drag is the employment of vibratory technologies. In addition, driller have increasingly turned to a fluid percussive means of advancing the drill string and BHA through the wellbore.

Mechanical systems to vibrate or agitate the pipe as it enters the well are known in the industry as agitators, vibratory or extended reach tools. These extended reach tools are typically attached near the end of the pipe that will be farthest in the well and are made to excite the distal portion of the drill string and bottom hole assembly to avoid or cure the consequences of frictional forces. The extended reach tools currently available, though, cannot be switched“On or Off’ when fluid is pumped through them and are designed such that when fluid enters the extended reach tool it automatically starts to vibrate downhole assemblies due to the binomial physical mechanics of the system. They have no“On or Off’ switch and no ability to be commanded to activate or deactivate.

Equally, there is also no ability in today’s extended reach tools to activate multiple assemblies at different depth in the well using different well bore conditions. The present invention eliminates automatic activation when fluids are pumped down the drill string and can be set up to be activated only when commanded through a programmable interface. The ability to achieve this configurable setup greatly enhances the ability to deliver pipe and bottom hole assemblies effectively and efficiently to even farther depths of an extended reach horizontal wellbore.

Clearly, there remains an unmet need for a downhole apparatus capable of effectively and efficiently utilizing fluid forces to induce both high and low vibratory forces, while harnessing fluid pressure, to create vibratory and percussive forces that advance a drill string in both a resource constrained and resource efficient manner. Moreover, there is a long-felt and unmet need in a vibratory assemblage that can have its functions initiated and ceased upon experiencing programmed parameters. The present invention seeks to remedy the aforementioned infirmities in the prior art.

SUMMARY OF THE INVENTION

The present invention offers vast improvements over that of today’s agitation, vibratory and extended reach tools by offering an ergonomic, uniquely ported valve and turbine-linked rotational shaft fluid system to provide pressurized fluid to achieve the dual function of rotational vibratory excitement of a tubular agitator and a timed, pressurized fluid jet to effectuate friction- freeing forces between a drill string and horizontal pipe. It is another goal of the inventor to incorporate an“On and Off’ programmable capability, unseen in today’s systems, to conserve the finite wear experienced by downhole tools and related bottom hole assemblies.

The present invention provides for a uniquely designed pressurized agitator exhibiting a digital programmable interface which is set to activate the vibratory assemblage only when wellbore or pipe conditions are met (such as well angle, well temperature, weight on bit, etc). Subsequently, once a set of conditions are met, a manual brake probe is commanded to unlock a shaft, allow pumped fluid to translocate through a series of rotationally accessible ports, rotate a set of shaft-affixed turbines (thereby permitting rotation of the shaft and a ported rotational plates), create an increasingly pressurized interior environment and to rotate a temporally operated aperture to allow for a forced pressurized exodus to attached bottom hole assemblies. The multi- axis vibration created by the rotation of the shaft and ported plates generates the vibration as well as the delivered fluid pressure jet necessary to deliver the bottom hole assemblies successfully to the end of the wellbore section of the well efficiently and effectively.

In detail, the vibratory assembly uses a series of valves and rotating turbines to induce vibration when fluid is pumped down the drill string and into the assembly where a turning the shaft, fueled via finned turbines, provides rotational movement, as well as pressurized fluid flow to a rotationally operable exit port, to create a high to low range intensity vibration combined with a high intensity fluid jet ahead of the assembly. This turbine-powered, rotationally operable shaft, which may include an integral offset weight, causes fluid-controlled circular rotation in the assembly to induce vibration on the first axis. In both the upper turbine housing and the bearing valve housing of the assembly, rotating plates exhibited circumferentially about the interior of each tubular, and perpendicular to the tubular annular flow direction, allows fluid to pass through reciprocal ports in a secondary static plate to create an environment of increasing pressure as fluid travels from the proximal end to the distal end of the assembly. As the fluid passes through the rotating plate, the ports open and close across the static plate. As will become clear from the present disclosure, differing the ports configuration by opening and occlusion of these ports can induce or relieve the pressure and rotational speed housed within the assembly. Once introduced, fluid entrance causes a momentary pressure increases within the each respective distal portions of both the upper turbine housing and the bearing valve housing of the assembly. This fluid pressure increase establishes (1) a retrograde pulse that is then directed back up the vibratory tool and along the pipe laying in the horizontal well section and (2) anticipates a forward timed jet of fluid pressure created through a shaft-controlled rotational uni-ported system, similar to the circumferentially designated plurality of ports about the interior of both the upper turbine housing and bearing valve housing, that creates one large egressing fluid pulse forward as a ported rotational disc comes into communicating with a stationary orifice. Vibration rate is controlled by fluid speed and pressure (i.e. as fluid is pumped through the tool at an increasing rate the higher and faster the fluid pulses travel along the pipe, the greater the rotational speed that is experienced by the shaft in revolutions and the rapidity with which exiting pulses is experienced). Further, the parameters of the rotating turbines (e.g. fin pitch, outer diameter, circumference, fin thickness etc..) can positively or negatively affect the frequency of the vibratory forces and the pressure created in the final fluid pressure force. Too, as alluded to, the diameter, shape, placement and number of circumferential ports can have correspondingly inhibitory and promotional influences on the creation of pressure within the agitator’s annulus. This pulsing effect causes the pipe to vibrate along its lateral length effecting not only the frictional forces created at the site of the bottom hole assembly but also in a retrograde manner up the drill string. Succinctly, as fluid is pumped down the drill string to the BHA, the rotational plates spins, the first rotational port of the first rotating plate align with the first static plate ports and the fluid is allowed to pass distally through to the assembly turbines which in turn rotates the centrally disposed shaft to propagate fluid flow down the assembly and create vibration, rotate an affixed rotational disc and to expel a concentrated, fluid jet to the forward attached assembly.

Similarly, in the case of an offset weight, as the fluid rate increases, the rotational speed of the turbines increase which in turns makes the weighted shaft rotate at a faster and faster rate. This increase in offset weighted shaft rotation causes the assembly to vibrate at higher rates of speed through increased rotation which in turn increases the vibratory force within the wellbore and reduces the pipe on pipe friction in the lateral direction of the horizonal section of the wellbore.

As above, the weighted shaft, turbines and rotational plate can be readily replaced with higher or lower ratios of weight, ports and propeller configurations to allow for far higher or far lower vibratory functions to be achieved (as well as lower to higher pressure jet pulses expelled distally from the assembly). The modular design, too, allows for inclusion and exclusion of communicating and noncommunicating ports, placement and replacement of differing sixes and shaped turbines and the inclusion, exclusion and sequential placement of complete sections of the assembly itself (e.g. turbine housings, bearing valve housings and vent sub housings)

In terms of conservation of equipment, the assembly that is the present invention can be made to exhibit an onboard digital assembly including a printed circuit board, electrical motor, brake probe, battery power section and onboard sensors to both determine if and when a set of preprogrammed determinates have been satisfied in actuating or stopping the functioning of the assembly. This digital component to the assembly a key feature unique to the operation of the vibratory assembly in that agitation tools typically cannot be turned“on and off’ in a wellbore. Customarily, as soon as fluid is pumped down the pipe, the agitation tool will start to vibrate the entire pipe string, pressure will begin to build and timed pressure pulses will begin to be expelled from the assembly. This agitation motion is not required in the vertical section of the well and provides unwanted wear and tear on both surface and downhole equipment unnecessarily.

This onboard digital assembly incorporated into the vibratory assembly allows for agitation to be commanded to start or stop by preprogramming specific instruction into the microprocessor within the tool via a printed circuit board. These programmed commands can follow any number of parameters, set of parameters or sets of parameters which when encountered can stop or start the functional operation of the assembly.

An example of these instructions is listed below which start and stop the agitation motion even when the pumps are switched on and fluid is flowing through the tools:

1. Apply Brake Probe when wellbore angle is between‘O’ and 69 degrees.

2. Release Brake Probe when wellbore angle is or exceeds 70 degrees.

Or

1. Apply brake probe when well bore angle is between‘O’ and‘69’ degrees and temperature is below 100 degrees centigrade.

2. Release Brake Probe when well bore angle is or exceeds 70 degrees and well bore temperature is or exceeds 100 degrees centigrade.

While the above or only examples of programmed commands to activate the vibratory tool from idle to agitation mode, these are two of the primary features that designate the proper section of the wellbore for initiation of agitation, vibration and fluid pulsation. This programmable configuration allows the tool to remain idle (i.e. not vibrate) in a predefined section of the well (e.g. lateral sections) thereby eliminating unwanted vibration and fatigue on the pipe string and attached tool string (BHA).

Other sensors can easily be incorporated into the assembly at the operators preference to provide alternate means of“On / Off’ activation deactivation commands and some of these would be as follows:

• Use of a weight on bit sensor to command the tool to turn on and off.

• Use of a torque sensor to command the tool to turn on and off.

· Use on a G force sensor to command the tool to turn on and off.

• Use of an inclination sensor to command the tool to turn on and off.

Therefore, as included above, it can be seen that a variety of sensors can be used as the‘trigger’ without departing from the scope and spirit of the onboard digital assembly and it is the interchangeable and additive predetermined“triggers” that add to the versatile operational selectivity of the various modes of operation and uses.

Structurally, the vibratory assembly is typically attached to the pipe or coiled tubing pipe and or snubbing pipe near the bottom hole assembly. This allows for the bottom hole assembly to be agitated both during deployment along the horizontal section of the well but also while drilling to enhance drilling operations. The agitation system when applied to jointed pipe can be used in multiple locations such as at the bottom hole assembly and along the end of the lateral wellbore, at the well section known as the heel or the lateral curve of the well, from horizontal to vertical and also in various portions of the vertical section as required by the operator. The key advantages of this multiple section vibratory assembly are that tools will activate when a preprogrammed well condition is present (such as well bore angle and well bore temperature) and each tool can be programmed to activate at different well bore conditions.

In opposite from direct drilling actives, upon the pipe and BHA recovery from the well, the preprogrammed vibratory tool can be programmed to again recognize wellbore conditions and or environmental factor (and once conditions are reached), the onboard digital assembly can deactivate the vibratory tool assembly. So in the above example, the tool will activate once 70 degrees deviation is achieved and 100 degree centigrade conditions are met and, conversely, the vibratory tool assembly will stop vibrating (deactivating) once the lesser of these two example conditions are seen (i.e. 69 degrees or less deviation is achieved and/or <100 degree centigrade is experienced). This again eliminates vibration of the entire pipe and bottom hole assembly in the vertical section and greatly reduces wear and tear on surface and downhole equipment.

BRIEF DESCRIPTION OF THE DRAWINGS

The advantages and other aspects of the invention will be readily appreciated by those of skill in the art and better understood with further reference to the accompanying drawings in which like reference characters designate like or similar elements throughout the several figures of the drawings and wherein: Drawings

Fig 1 shows an exploded view of the entire vibratory assembly.

Fig 2 illustrates a side view of the exterior of the vibratory tool system assembly in series.

Fig 3 shows the vibratory tool system dissected along the midline.

Fig 4 depicts the lower vent sub and bearing valve housing of the present invention.

Fig 5 shows the twin turbine propulsion system and interior of the lower vent sub with stationary orifice.

Fig 6 depicts an exploded view of the vibratory tool system sections.

Fig 7 shows a representation of the digital assembly and brake probe

Fig 8 illustrates a diagrammatical representation of the brake probe and turbine-shaft assembly. Fig 9 is a perspective view of the functional components of the bearing valve housing

Fig 10 shows a flow diagram of the printed circuit board, microprocessor, sensors, electrical motor, brake probe and power section.

Fig 11 is a flow diagram of the operational elements of the present invention.

Fig 12 is a flow diagram of the primary“triggers” single and in combination.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

The present invention allows for pipe vibration to be applied to any joint, seamless, coiled or snubbed pipe configuration whether threaded or not. The present invention allows for pipe to be delivered to lateral sections of a well with the aid of a vibratory tools that excites the pipe in multiple axis. This agitation process is achieved by pumping fluids through a series of ported discs and turbine-exhibiting shafts that oscillate the assembly 10 and creates both vibration of the pipe and fluid pulses within the pipe to reduce friction between similar and dissimilar materials.

As depicted in FIG. 1, the vibratory assembly 10 that is the present system uses a series of valves and rotating turbines wherein the vibratory assembly 10 induces vibration when fluid is pumped down the drill string and into the vibratory assembly 10 thereby turning the shaft 36, via finned turbines 32,34, that provide rotational movement, as well as pressurized fluid flow to a rotationally operable exit port 56, to create a variable high to low range intensity vibration combined with a high intensity fluid jet ahead of the assembly. This turbine-powered, rotationally operable shaft 36, which may include an integral offset weight (not shown), causes fluid-controlled circular rotation in the assembly 10 to induce vibration on the first axis. In both the upper turbine housing 20 and the bearing valve housing 40 of the assembly, rotating plates 3, 43 exhibited circumferentially about the interior of each tubular 20, 40 and perpendicular to the tubular annular fluid flow direction, allows fluid to pass from rotational inlet flow ports 4, 47 in rotational plates 3, 43 through reciprocal stationary ports 15, 46 in stationary plates 5,45 to create an avenue and environment of increasing pressure as fluid travels from the proximal end 10 of the vibratory assembly, through the upper turbine housing 20, through the bearing valve housing 40, into the lower vent sub 60 and to the distal end 80 of the assembly.

As the fluid energizes and passes through each rotating plate 3, 43, the rotating plate ports 4, 47 of rotating plates 3, 43 come into communication with stationary plate ports 15, 46 which open and close across each static plate 5, 45. Each rotating plate being affixed to shaft 36 further potentiating rotational movement. This fluid entrance causes a sudden, momentary pressure increase within the each respective distal portion 24, 44 of both the upper turbine housing 20 and the bearing valve housing 40 of the assembly 10. This fluid pressure increase is experienced rearward as well as forward where increased pressure establishes (1) a retrograde pulse that is then directed back up the vibratory tool and along the pipe laying in the lateral well section (with the uncommunication of rotational inlet flow ports 4, 47 and stationary inlet flow ports 15, 46) and (2) anticipates a forward timed“jet” of fluid pressure created through a turbine-shaft controlled 30 rotational uni-ported system (created via a temporal, rotational communication between aperture 55 and orifice 56), similar to the circumferentially designated plurality of inlet flow ports 15, 47 made to communicate and uncommunicated with inlet flow ports 15, 46 and about the interior of both the upper turbine housing 20 and bearing valve housing 40, where each smaller inlet flow port 4,15,46, and 47 creates incrementally larger increases in internalized tubular pressure, aperture 55 and orifice 58 creates one large egressing fluid pulse forward as the ported rotational disc 50 rotates, through rotational locomotion of the turbine-shaft assembly 30, and comes into communication with a stationary orifice 56 in stationary plate 58 that exists perpendicular to the annular tubing that is the lower vent sub 60. In sum, each rotating plate 3, 43 and 50 creates a retrograde and forward pulsation experienced through closure and opening of ports 4, 46 and 56, respectively.

It should be noted that variations of number, configuration and placement of circumferentially located rotating inlet ports 4, 47 of rotating plates 3, 43 and stationary inlet ports 15, 46 of stationary plates 5, 45, fluid pressure regulation of rotating plates 3, 43 and their temporal communication with corresponding receiving orifices in reciprocating stationary plates 5, 45 and 58, variations of number, configuration and placement of circumferentially located a rotating port 55 (or ports - not shown) in disc 50 (as seen in FIG. 4) and or orifice 56 (or orifices - not shown) (as seen in FIG. 5) in stationary plate 58 can be augmented to either increase or decrease the pressure pulses and vibratory forces the vibratory assembly is capable of producing.

As well, the configuration of the turbines 32, 34, in terms of turbine blade length, blade pitch, blade circumference and blade thickness, among other physical features, may be modified to (1) increase or decrease pressure or flow within the vibratory assembly 10, increase or decrease vibratory intensity within the vibratory assembly 10 and/or increase or decrease the pressure pulse expressed through the most distal opening 64 of the vibratory assembly 10. And, their placeable and replaceable“keyed” inclusion upon the assembly shaft 36 more readily lends itself to a easily and readily modifiable configuration for different and differing vibration intensities and fluid pressure creation.

Turbines

The use of a fluid powered turbine is a simple and reliable method for rotation of a drive shaft 36 to operate a valve or other devices. However, a single turbine 32 may require a speed controller to prevent revolutions exceeding the limits of the turbine given a certain flow rate through the turbine. Various methods of speed control exist but can be both complex and expensive such (e.g. magnetic speed controllers). To alleviate thus issue, the present invention utilizes a reverse pitch on the second turbine

34 in the tandem series. Further, a variable diameter turbine 32,34 is used in the current embodiment to provide speed control of the upper/primary turbine 32 within each power section (upper turbine 32 and lower turbine 34) of the entire assembly. By changing the pitch, diameter, number of blades and/or thickness of blades (or a combination of all) the operator can alter the revolutions per second of the turbine assembly. Individually, only one turbine requires pitch and or diameter change within the upper and lower power sections, though, and by changing the dimensions of one of the turbines, for example turbine 34, this will provide the required drag to be placed on the other turbine, or example turbine 32, thereby slowing turbine 32 down - each keyed into the same drive shaft.

Too, upper power section turbines 32 can be set up with a different pitch and diameter turbines from the lower power section turbines 34 where the rotational direction of each turbine 32,34 are opposite from one another. For example, if turbine 32 is designed for a clockwise rotation, turbine 34 is designed for a counterclockwise rotation and, conversely, if turbine 32 is designed for a counterclockwise rotation, turbine 34 is designed for a clockwise rotation. Therefore, turbine 34 is creating the necessary deleterious function of retarding the spin of turbine 32 (as shown in FIG. 5). By constructing each turbine 32 and 34 with a different directional flow and a difference in pitch and diameter, an operator can create a power section that can be manipulated to rotate at a various and variable revolutions per second.

In addition, because all the turbines are individually attached to the drive shaft they can be manufactured (3D metal printed) with a combination of pitch and diameter to provide for an array of turbine speed and provide a vast combination of revolution per second variables and with the durable thickness and durability required by all downhole equipment. It is this ability to use modular turbines located in series on a primary drive shaft 36 which makes for a truly versatile, variable speed controller. FIG. 2 depicts the outer shell and FIG. 3 the inner function components of the present invention that is the vibratory assembly system 100 which is run in series (tandem) where the vibratory agitator device 10 is connected in the following manner: upper turbine housing 20 to an upper bearing valve housing 29 to a lower turbine housing 39 to a lower bearing valve housing 49 to a lower vent sub 60. FIG. 6 further shows an exploded view of the conjunction of the individual subunits of vibratory assembly 100

In FIGS. 2, 3 and 6 the vibratory assembly system 100 can be seen to run in tandem or series wherein the upper turbine housing 20 can be made to function at a high vibratory intensity (e.g. 40 Hz) and the lower turbine housing 39 can be made to function at a low vibratory intensity (e.g. 10 Hz). Alternatively, the upper turbine housing 20 can be made to function at a low vibratory intensity and the lower turbine housing 39 can be made to operate at a high vibratory intensity. Through this combination of vibratory assemblies 10 into a sequential vibratory system 100, the present invention is capable of simultaneously generated high and low frequency vibration. What’s more, the vibratory system 100 can be placed at various location above the drill bit to facilitate rate and depth of penetration.

Plainly, each turbine housing 20 and 39 is made up of a ported housing that permits control of fluids to each power section 20 and 39. Each of the individual flow ports 4,15 and 46, 47, within either turbine housing 20 and 39 and bearing housing 29 and 49, respectively, can be threaded to allow for isolation of a number of ports to reduce or increase the rate of flow through the upper, lower or both upper and lower power sections. The ability to control flow into each power section 20 and 39 and bearing valve housing 29 and 49 allows for variable pressure pulse heights to be readily achieved thereby creating a higher or lower“water hammer” or pulse jet effect. This will also allow for variable pressure drops across the tools that can be readily changed with reconfiguration of the components, of both the vibratory assembly 10 and the sequential vibratory assembly 100, by closing off of ports in the event that higher or lower flow rates require rate and adjusting pressure and pulse intensities to achieve desired vibration generation together with maximum pressure pulse effect as the fluid passes through the lower turbines and exits the 'foot' valve 64 in the lower sub (as seen FIG. 4).

Moreover, just as vibration rate is controlled by fluid speed and pressure (i.e. as fluid is pumped through the tool at an increasing rate the higher and faster the fluid pulses travel along the pipe, the greater rotational speed is experienced by the shaft in revolutions and the rapidity with which exiting pulses is experienced) so too is flow further augmented within the vibratory assembly 10 and the sequential vibratory system 100. It is the case that the parameters of the rotating turbines 32, 34 (e.g. fin pitch, outer diameter, circumference, etc..) can positively or negatively affect the frequency of the vibratory forces and the pressure created in the final fluid pressure force. Too, the diameter, shape, placement and number of circumferential ports 4,15,46, 46 can have correspondingly inhibitory and promotional influences on the creation of pressure within the agitator’s annulus.

In addition to the vibratory forces, pulsing effect cause the pipe to vibrate along its lateral length effecting not only the frictional forces created at the site of the bottom hole assembly but also in a retrograde manner up the drill string. Succinctly, as fluid is pumped down the drill string to the BHA, pressurized fluid contact and rotate rotational plates 3 and 43, the first rotational ports 4 of the first rotating plate 3 align with the first static plate 5 ports 15 and the fluid is allowed to pass distally, when such ports 4, 15, 46 and 46 are aligned, through to the assembly turbines 32, 34 which in turn rotates the centrally disposed shaft 36 to propagate fluid flow down the assembly and create vibration, rotate an affixed perpendicularly appended rotational disc 50 and to expel a concentrated, fluid jet through the communication of aperture 55 through orifice 56 of stationary plate 58 that itself is disposed perpendicular to the annular flow of fluid in the lower vent sub 60. Fluid is then expelled force fully through the most distal portion 64 of the lower vent sub 60 to a forward attached assembly or corresponding downhole device.

As depicted in FIGS. 1 and 9, a seal 37 and bearing 38 combination can be seen to provide occlusion of the centrally deposed pathway running centrally through the rotating plate 43 and stationary plate 45 thereby obstructing flow and redirecting fluid flow into rotating inlet ports 47, through corresponding stationary inlet ports 46 and into the distal chamber of the bearing valve housing 40.

As well as novel and ergonomic mechanical inventive features, as depicted in FIG. 7, the present invention allows for programming of the assembly to control“on and off’ vibration of the tool via communications port 115. The communications port 115 programs the assembly via a laptop computer. The communications port 115 attaches to the microprocessor 114 through the printed circuit board assembly 113 which accepts the codes from the Laptop computer to command the tool to operate with specific parameters.

FIG. 8 provides for sensors sensing and memory capacity to hold and store relevant commands that once certain wellbore conditions or command parameters are met, the tool will activate (or deactivate trough brake probe 111 introduction) . The brake probe assembly 120 brake probe 111 is attached to a motor 112 that allows the brake probe 113 to move into the“on and off’ position to activate and de-activate the brake probe 113 through either an inlet port orifice 4,15, 47 or 46 or through the aperture 56 and orifice 55 of the vibratory assembly 10 or vibratory assembly system 100. The motor 112 is attached to a condition determining sensor 113 or sensors that provide the stored commands to activate the tools brake probe 111. The brake probe assembly 120 can be powered by various means such as a turbine or batteries (not shown). In the attached drawings the power supply 114 is assumed to be a battery assembly. The power supply 114 provides the necessary power to power sensors 113, activate the motor 112 and initiates the brake probe 111. The power supply 114 also provides power to the onboard sensors 113 that provide the trigger instructions to operate the brake probe 113.

The Brake Probe 113 when in the On’ position locates into the brake plate 104 preventing the brake plate 104 (fixed permanently to shaft 36) from rotating even as fluid is pumped through the assembly 10 and/or the assembly system 100. The brake plate 104 is attached to a rotatable plate via the bearing assembly 105 and assembly shaft 36. With the Brake Probe 111 in the On’ position the bearing assembly 105 and the shaft 36 (depicted here as a weighted shaft) cannot rotate and does not allow the assembly 10,100 to vibrate. However, the flow of fluid to the equipment below the most terminal and distal portion of the assemble 80, such as a mud motor, drill bit or combination of multiple drilling tools known to those in the art (not shown), is unimpaired and unhampered.

Diagrammatically, the shaft 36 is attached to the lower end of the assembly via the lower bearing section. A shear plate 109 (in the form of a stationary, rotating or combination) is atop the lower bearing section 37 and each has multiple through inlet ports 4,15,46,47 (collectively 111) to allow the flow of fluid. These inlet ports 4,15,46,47 (collectively 111) can be of various shapes and sizes to provide variable measures of fluid to pass. A second rotating shear plate 108 is attached to shaft 36. As the rotating shear plate 108 rotates, the rotating shear plate 108 ports pass over the ports on the lower shear plate 109 to align the ports thereby allowing the flow of fluid through the entire assembly 10 and 100 and into the tools below. As the rotating shear plate 108 continues to revolve the ports move to a closed position preventing fluid from passing through the assembly. The closure of these ports between the rotating shear plate 108 and the non-rotating shear plate 109 create back pressure within the assembly which causes lateral movement along the length of the pipe forward and back. By rotating the shear plate 108 at high revolutions per minute, the number of pressure pulses increases to a point where the assembly 10 or assembly system 100 and wellbore pipe is constantly vibrating. As detailed above, the higher the volume of fluid pumped through the turbine 106 the faster the turbine 106 spins the shaft 36 and the more pressure pulses are created at the shear plates 108 and 109. This provides for a multi- axis lateral and axial vibration effect to occur thereby reducing pipe to pipe friction contact along the length of the pipe and bottom hole assembly via the agitator vibratory assembly as shown and described.

Fig. 10 shows a flow diagram of the printed circuit board, microprocessor, sensors, electrical motor, brake probe and power section as described in the preceding paragraphs.

Fig. 11 is a flow diagram of the operational elements of the present invention describing the functional features as described and depicted in the present application. The diagrams and features, though, are merely representational of the primary features if the vibratory assembly and digital circuit assembly and are not drawn to scale or are they meant to provide a direct representation of each defining feature. Augmenting and changing of these features may be attempted without changing the scope or intent of the present application.

Fig. 12 is a flow diagram of the primary“triggers” single and in combination. Although, degree and temperature have been proved, and are two of the primary triggers, their inclusion is a practical representation of two of many sensor programs that may be included in the present invention which are variable without departing from the spirit of the invention.