Patent Publication Number: US-10329842-B2

Title: System for generating a hole using projectiles

Description:
CROSS-REFERENCE TO RELATED APPLICATION 
     This patent application claims priority to the U.S. provisional application for patent, having application Ser. No. 62/255,161, filed on Nov. 13, 2015, entitled “Down-Hole Hyperdrill”. Application 62/255,161 is incorporated by reference herein in its entirety. 
     INCORPORATION BY REFERENCE 
     In addition to Application 62/255,161, which is incorporated by reference in its entirety above, the following are incorporated by reference for all that they contain: 
     U.S. provisional patent application 62/253,228, filed on Nov. 10, 2015, entitled “Pressurized Ram Accelerator System”. 
     U.S. patent application Ser. No. 15/340,753, filed on Nov. 1, 2016, entitled “Projectile Drilling System”. 
     U.S. patent application Ser. No. 13/841,236, filed on Mar. 15, 2013, entitled “Ram Accelerator System”. 
     U.S. patent application Ser. No. 15/292,011, filed on Oct. 12, 2016, entitled “Ram Accelerator System”. 
     U.S. provisional patent application 61/992,830, filed on May 13, 2014, entitled “Ram Accelerator System with Endcap”. 
     U.S. patent application Ser. No. 14/708,932, now U.S. Pat. No. 9,458,670, filed on May 11, 2015, entitled “Ram Accelerator System with Endcap”. 
     U.S. patent application Ser. No. 15/246,414, filed on Aug. 24, 2016, entitled “Ram Accelerator System with Endcap”. 
     U.S. provisional patent application 62/067,923, filed on Oct. 23, 2014, entitled “Ram Accelerator System with Rail Tube”. 
     U.S. patent application Ser. No. 14/919,657, filed on Oct. 21, 2015, entitled “Ram Accelerator System with Rail Tube”. 
     U.S. provisional patent application 62/150,836, filed on Apr. 21, 2015, entitled “Ram Accelerator System with Baffles”. 
     U.S. patent application Ser. No. 15/135,452, filed on Apr. 21, 2016, entitled “Ram Accelerator System with Baffles”. 
     U.S. provisional patent application 393,631, filed on Sep. 12, 2016, entitled “Augmented Drilling System Using Ram Accelerator Assembly”. 
    
    
     BACKGROUND 
     One concern relating to use of rotary, impact, or percussive drilling methods when forming a wellbore is well control. A weighted or pressurized drilling fluid, such as drilling mud, may be used to provide pressure control against pressures encountered in a geological formation. Drilling mud is typically pumped toward the bottom of a wellbore using a single tubular string, then returned to the surface via the outer annulus between the tubular string and the walls of the wellbore. 
    
    
     
       BRIEF DESCRIPTION OF DRAWINGS 
       Certain implementations and embodiments will now be described more fully below with reference to the accompanying figures, in which various aspects are shown. However, various aspects may be implemented in many different forms and should not be construed as limited to the implementations set forth herein. The figures are not necessarily to scale, and the relative proportions of the indicated objects may have been modified for ease of illustration and not by way of limitation. Like numbers refer to like elements throughout. 
         FIG. 1  is a series of diagrams illustrating a process for extending a wellbore using perforating charges. 
         FIG. 2  illustrates an implementation of a system for forming a wellbore using perforating charges. 
         FIG. 3  is a diagram illustrating an implementation of a bottom hole assembly. 
         FIG. 4  is a diagram illustrating an implementation of a bottom hole assembly including a ram acceleration assembly for accelerating perforating charges into a wellbore. 
         FIG. 5  is a diagram illustrating an implementation of a perforating charge. 
         FIG. 6  illustrates an implementation of a system for providing components to a bottom hole assembly. 
         FIG. 7  is a series of diagrams illustrating a first portion of a process for forming a wellbore using perforating charges. 
         FIG. 8  is a series of diagrams illustrating a second portion of a process for forming a wellbore using perforating charges. 
         FIG. 9  is a flow diagram illustrating a process for providing perforating charges into association with a surface of a hole. 
     
    
    
     While implementations are described in this disclosure by way of example, those skilled in the art will recognize that the implementations are not limited to the examples or figures described. It should be understood that the figures and detailed description thereto are not intended to limit implementations to the particular form disclosed but, on the contrary, the intention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope as defined by the appended claims. The headings used in this disclosure are for organizational purposes only and are not meant to be used to limit the scope of the description or the claims. As used throughout this application, the word “may” is used in a permissive sense (i.e., meaning having the potential to) rather than the mandatory sense (i.e., meaning must). Similarly, the words “include”, “including”, and “includes” mean “including, but not limited to”. 
     DETAILED DESCRIPTION 
     Some conventional drilling techniques for forming a wellbore include rotary, impact, or percussive drilling methods. Resources, such as water, gas, oil, and so forth, may be present in a geologic formation, such as rock. The resources in the geologic formation may be under pressure. To provide pressure control against the pressures within the formation, a weighted or pressurized drilling fluid, such as drilling mud, may be pumped into the wellbore. Drilling muds may be water-based, carbon dioxide-based, petroleum-based, oil-based, or may include other liquids, gasses, or fluids. Typically, a wellbore is formed using a single tubular string, through which drilling mud may be pumped to the bottom of the hole, where drilling operations occur. The drilling mud then flows from the bottom of the hole toward the surface through the outer annulus surrounding the tubular string. In addition to resisting the formation pressures within the wellbore, drilling fluids may also stabilize the wellbore, reduce friction during the drilling operation, and remove cuttings or other debris from the wellbore. 
     This disclosure relates to techniques for drilling, in a downhole environment, using explosive perforating charges in conjunction with a tubular string. The perforating charges may include detonable (e.g., explosive) material. In some cases, the tubular string may include elements associated with a drilling system, which may be operated in series or in parallel with the use of the perforating charges. For example, an existing tubular string used during conventional drilling techniques may be equipped with a specialized drill bit that may be used in conjunction with perforating charges. An at-surface or above-ground loading mechanism and pump mechanism may be used to move perforating charges, which may be more dense than the drilling mud, through the tubular string. The fluid motion of the drilling mud or other materials and the weight of the charges may facilitate movement of the charges through the tubular string, while the pressure of the drilling mud and the weight of the charges may maintain pressure control of the wellbore. 
     A charge unit, which in some implementations may be formed from metallic and explosive components, may be flowed through a portion of the tubular string to impact the bottom of the hole, eroding both a portion of the geologic formation and the charge unit itself. In some cases, the charge unit may be accelerated to a high speed, such as through use of a mass and shock driving mechanism. In other cases, the charge unit may be moved through the tubular string using the flow of drilling fluid or other materials. The particles resulting from the interaction between the charge unit and the geologic material may be returned to the surface using the flow of the drilling mud, in the manner associated with typical transport of cuttings. In some implementations, the perforating charges may be accelerated using chemical energy. However, in other implementations, perforating charges may be accelerated using components of a hypersonic-augmented drilling system, impact (e.g., using pneumatic or mechanical force), or rotational energy. In some implementations, a charge unit may include multiple parts which may be separable or integral. For example, a charge unit may include a penetrator section configured to penetrate or erode the geological material. In one implementation, the penetrator section may include a shape similar to that of a drill bit. The charge unit may also include one or more separation stages that create barriers between different portions thereof. Additionally, a charge unit may include one or more propellant generating materials. Propellant generating materials may include a solid, liquid, or gas that under specific conditions (e.g., mechanical, electrical, or pressure-based conditions) may provide a force to the charge unit, such as a mass-based force, a pressure, a shock wave, and so forth. For example, actuation of a propellant generating material may cause generation of gas or another fluid, which may accelerate the perforating charge to penetrate through geologic material. In some implementations, generated propellant materials may also act as diluents. 
     In one implementation, the tubular string may be provided with a heavy, steel bottom hole assembly, such as a bottom hole assembly having a length of 50 feet. Perforating charges may be provided with a shape that facilitates transport and embedding of the charges, such as the shape of a chip or puck. For example, the charges may be shaped in a manner that facilitates nesting or stacking of the charges on top of one another, or transporting through the tubular string, one after the other. Individual perforating charges, or stacks thereof, may be released through an opening, such as a port accessible using a ball valve or other closure element, to position the charges in the drilling mud, between a surface of the wellbore and the bottom hole assembly. In some cases, the perforating charges may be passed through an opening without use of a closure element. The charges may then be detonated, which in some implementations, may create a Monroe jet or similar movement of explosive gas, shock waves, and particles of metal or other materials that may penetrate and erode the geologic formation and the charge itself. The perforating charges may be configured to direct the energy from detonation thereof as a shock wave, causing very little bulk gas movement. In some cases, materials generated through combustion or erosion of the charge or geologic material may be condensed or suspended within the drilling mud. The drilling mud may provide a barrier between the formation and the ball valve or other closure or separator mechanism in the bottom hole assembly through which the charges may be accelerated. In some implementations, the closure mechanism may include a floating ball or endcap. In other implementations, the pressure of the drilling mud may function to restrict backflow or ingress of material in place of or in addition to an endcap or other closure mechanism. Additionally, the drilling mud may function as a recoil mechanism against which the force from the perforating charge may push against to direct the charge toward the geologic material at the bottom of the hole. 
     The perforating charges may be used continuously, or semi-continuously, to bore through geologic material using the perforating charges, in the manner of a percussive perforation gun, that may be operated nearly entirely below the surface (e.g., in a downhole environment near the working face of a wellbore). Use of a single column in conjunction with fluid and charge units may facilitate well pressure control and limit the energy losses associated with long transits through tubular strings. In some implementations, in situ propellant materials may be used to accelerate the perforating charges. Propellant materials may include pressurized or combustible gasses, diesel, or similar components that may be used to impart a force to a perforating charge. For example, structures containing propellant materials may be pumped into a tubular string. As another example, propellant materials, such as gasses, may be entrained within the drilling mud, which may enable the materials to be transported toward the bottom of the hole without use of additional fluid connections. Propellant materials may be encapsulated in small pellets or dissolved or suspended into the drilling mud. In some implementations, the drilling mud may also contain one or more of fuel or oxidizer for use accelerating perforating charges, such as through use of a portion of the tubular string or bottom hole assembly as a ram accelerator or gas gun. Components entrained or suspended in the drilling mud may be separated from the drilling mud using a downhole mechanism. In some cases, the acceleration or impact of a perforating charge may initiate a mechanism for the release and capture of fluids or gasses used for the acceleration process. As yet another example, material within the charge unit, itself, may include a propellant material or a material that can be used to generate propellant material in the downhole environment. Use of in situ propellant materials may enable movement of surface components, such as the rotation of a drilling rod that provides energy to a downhole assembly, to be converted into chemical energy, which may then be used to provide energy to the perforating charges by providing linear velocity thereto. 
     In some implementations, radio frequency identification (RFID) chips, microchips, or similar communication components, materials, or devices may be suspended within the drilling fluid. The detectable materials may be used to communicate, via communication signals, with components of the downhole assembly, such as downhole logging equipment. Communication between devices, such as chips, within the drilling fluid may be used to provide data to computing devices at the surface or to communicate with downhole components. Such devices may also receive data from surface devices and transport the data to one or more downhole components. 
       FIG. 1  is a series of diagrams  100  illustrating a process for extending a wellbore  102  using perforating charges  104 . The depicted diagrams  100  illustrate the process at a first time T 1 , a second time T 2  subsequent to the first time T 1 , a third time T 3  subsequent to the second time T 2 , and a fourth time T 4  subsequent to the third time T 3 . A tubular string  106  within the wellbore  102  may have a bottom hole assembly  108  engaged to a lower end thereof. During operations, drilling fluid  110 , such as drilling mud or other materials, may be circulated within the wellbore  102 , such as by flowing the drilling fluid  110  from the surface toward the bottom of the wellbore  102  through the tubular string  106 . The drilling fluid  110  may then return to the surface by flowing upward from the bottom of the wellbore  102  through an annulus  112  between the walls of the wellbore  102  and the outer surface of the tubular string  106 . In some implementations, the drilling fluid  110  may flow through ports or fluid pathways located external to the inner bore of the bottom hole assembly  108 , while the inner bore of the bottom hole assembly  108  may be used for the passage of perforating charges  104 . For example, the bottom hole assembly  108  may include one or more closure elements  114 , such as ball valves, which may be opened and closed to control the times at which single perforating charges  104  or groups of perforating charges  104  may be projected toward the bottom of the wellbore  102 . Continuing the example,  FIG. 1  depicts the bottom hole assembly  108  including two closure elements  114  proximate to the upper and lower ends of the inner bore of the bottom hole assembly  108 , respectively. 
     As illustrated at the second time T 2 , the flow of drilling fluid  110  or other materials, such as propellant materials or other substances entrained in the drilling fluid  110 , may urge at least one perforating charge  104  into the inner bore of the bottom hole assembly  108 . For example, a closure element  114  may be opened to permit passage of the perforating charge  104  into the bottom hole assembly  108 . Within the bottom hole assembly  108 , the perforating charge  104  may be accelerated toward the bottom of the wellbore  102 , such as through actuation of one or more propellant materials. In some implementations, a closure element  114  at the lower end of the bottom hole assembly  108  may be opened to permit passage of the perforating charge  104 . The perforating charge  104  may at least partially penetrate, erode, or otherwise interact with geologic material at the bottom of the wellbore  102 , and detonation  116  of the perforating charge  104  may further erode or displace geologic material, creating a region of eroded formation  118  at the bottom of the wellbore  102 . Creation of the region of eroded formation  118  may extend at least one dimension of the wellbore  102 , such as by increasing the length (e.g., depth) thereof. 
     The process illustrated at the first time T 1  and second time T 2  may be repeated using successive perforating charges  104 . For example, at the third time T 3 , a subsequent perforating charge  104  may be urged into the bottom hole assembly  108 , such as by the flow of the drilling fluid  110 . At the fourth time T 4 , the perforating charge  104  may be accelerated to contact the bottom of the region of eroded formation  118 , where a subsequent detonation  116  may further erode or displace geologic material from the wellbore  102 . 
     In some implementations, use of perforating charges  104  to generate a wellbore  102  may eliminate the need for a separate circulating tube, which may increase the circulating area for drilling fluid  110  and other materials in the annulus  112 , improving the removal of cuttings. For example, in one implementation, a generated wellbore  102  may have a diameter that is 2.75 times as large as that of the tubular string  106  used to provide the perforating charges  104  to the bottom of the wellbore  102 . Use of a single tubular string  106  and movement of drilling fluid  110  to provide components into and from the wellbore  102  may improve well pressure control, efficiency, depth, lateral reach, and steering capability when compared to conventional drilling techniques. Additionally, use of the tubular string  106  and drilling fluid  110  may eliminate the need for separate lines or other conduits for providing materials to or removing materials from the wellbore  102 . 
       FIG. 2  illustrates a system  200  for forming a wellbore  102  using perforating charges  104 . A loading mechanism  202  may be located at or above the surface, such as in association with a top drive engaged with the tubular string  106 . The loading mechanism  202  may be engaged with a source of perforating charges  104  and may orient and pump the perforating charges  104  into the tubular string  106 . For example, a loading mechanism  202  may automatically move perforating charges  104  from a rig floor into the tubular string  106 . Drilling fluid  110  may move the perforating charges  104  through the tubular string  106 . In some implementations, at least a portion of the drilling fluid  110  may flow around the perforating charges  104  to exit the lower end of the tubular string  106  and flow upward through the annulus  112 . The movement of the perforating charges  104 , by the drilling fluid  110 , into a rotating portion of the tubular string  106  may actuate an electrical generator  204 . In some implementations, the electrical generator  204  may be configured to engage and disengage from the wall of the wellbore  102 . Torque applied to the electrical generator  204  by rotation of the tubular string  106  relative to the wall of the wellbore  102  may generate power. Power from the electrical generator  204  may be provided to portions of the bottom hole assembly  108  or other components used in association with generation of the wellbore  102 , such as measurement or logging components, vacuum generating components, and so forth. In some implementations, the electrical generator  204  may be used to power a laser or other element that may be used to remove geologic material from the bottom of the wellbore  102 . 
     The bottom hole assembly  108  may be engaged with the lower end of the tubular string  106 . The bottom hole assembly  108  may include a launch tube  206  through which perforating charges  104  may be passed, and one or more closure elements  114 , such as ball valves, that separate particular portions of the bottom hole assembly  108  from other portions. As described with regard to  FIG. 1 , drilling fluid  110  may be diverted away from the inner bore of the bottom hole assembly  108 , while perforating charges  104  pass therethrough. In some implementations, perforating charges  104  may carry one or more of diluent, vacuum generating materials, fuel, oxidizer, gas or liquid-generating components, or additional gasses or liquids. The closure elements  114  may be sequentially operated to permit a single perforating charge  104  to pass through successive sections of the bottom hole assembly  108 . For example, a first closure element  114 ( 1 ) may be opened to permit entry of a perforating charge  104  into an upper portion of a launch tube  206 . The first closure element  114 ( 1 ) may be closed and a second closure element  114 ( 2 ) opened to permit passage of the perforating charge  104  to a second portion of the launch tube  206 . The second closure element  114 ( 2 ) may then be closed and a third closure element  114 ( 3 ) opened to permit passage of the perforating charge  104  to a lower portion of the bottom hole assembly  108 . Operation of the closure elements  114  may enable queuing and sequencing of perforating charges  104  for successive acceleration toward the bottom of the wellbore  102 . 
     In some implementations, the lower portion of the bottom hole assembly  108  may include a ram accelerator for accelerating the perforating charges  104  toward the bottom of the wellbore  102 . The ram accelerator may include internal baffles or rails, dampers for affecting the movement of the perforating charges  104 , and may include single or multiple stages. In some cases, the drilling fluid  110  or other substances proximate to the lower end of the bottom hole assembly  108  may prevent ingress of materials into the bottom hole assembly  108  from the lower end thereof. For example, the ram accelerator may be pressurized to a pressure equal to or greater than that of the wellbore  102  to provide well control. In other implementations, the bottom hole assembly  108  may include or be engaged with measurement while drilling equipment, a rotatable reamer or drill bit, such as a polycrystalline diamond compact or tri cone drill bit, or other equipment. 
       FIG. 3  is a diagram  300  illustrating an implementation of a bottom hole assembly  108 . As described with regard to  FIGS. 1 and 2 , the bottom hole assembly  108  may be engaged with a tubular string  106  extending between the bottom of a wellbore  102  and the surface. The bottom hole assembly  108  may be configured to move perforating charges  104  received from the tubular string  106  toward the bottom of the wellbore  102 . For example,  FIG. 3  depicts the bottom hole assembly  108  including a first closure element  114 ( 1 ) positioned above a second closure element  114 ( 2 ), which is proximate to the lower end of the bottom hole assembly  108 . In some implementations, the closure elements  114  may include ball valves. As drilling fluid  110  pushes perforating charges  104  through the tubular string  106  into the bottom hole assembly  108 , the first closure element  114 ( 1 ) may be opened to permit a single perforating charge  104  or group of perforating charges  104  to enter the inner bore  302  of the bottom hole assembly  108 . After entry of the perforating charge  104  into the inner bore  302 , the first closure element  114 ( 1 ) may be closed to isolate the perforating charge  114 ( 1 ) and inner bore  302  from the tubular string  106 . At least a portion of the drilling fluid  110  may be diverted through one or more ports  304  external to the inner bore  302 , to enable the drilling fluid  110  to exit the lower end of the bottom hole assembly  108  for circulation to the surface, which in some implementations, may facilitate evacuation or preparation of the inner bore  302  for acceleration of the perforating charge  104 . For example, one or more propellant materials may be entrained in the drilling fluid  110 , associated with the body of the perforating charge  104 , or separately provided to the bottom hole assembly  108 . The propellant material(s) may be actuated within the inner bore  302  to accelerate the perforating charge  104  toward the lower end of the bottom hole assembly  108 . In other implementations, the first closure element  114 ( 1 ) may be omitted, and the inner bore  302  of the bottom hole assembly  108  may be filled with drilling fluid  110 . In some implementations, the drilling fluid  110  may include propellant material, water or other fluids for electrolysis, fuel, oxidizer, inert gas, and so forth. The second closure element  114 ( 2 ) may be opened to permit the accelerated perforating charge  104  to exit the lower end of the bottom hole assembly  108  and impact the bottom of the wellbore  102 . In some implementations, the lower portion of the bottom hole assembly  108  may include one or more mechanisms to align, capture, or support the perforating charges  104  that are transported into the inner bore  302 . 
       FIG. 4  is a diagram  400  illustrating an implementation of a bottom hole assembly  108  including a ram acceleration assembly  402  for accelerating perforating charges  104  into a wellbore  102 . As described with regard to  FIGS. 1-3 , perforating charges  104  may enter the inner bore  302  of the bottom hole assembly  108  via movement of drilling fluid  110 , as a closure element  114  is opened to enable passage of the perforating charge  104 . A perforating charge  104  may pass through a seal  404  between an upper portion of the bottom hole assembly  108  and the ram acceleration assembly  402 . In some implementations, the seal  404  may include one or more cup-type seals  404 . In other implementations, the ram acceleration assembly  402  may include one or more internal baffles  406 , such as annular baffles  406 . In still other implementations, the ram acceleration assembly  402  may include internal rails. One or more of the seal  404  or the baffle(s)  406  may capture or separate gas or other propellant materials contained in the drilling fluid  110  that may be used to accelerate the perforating charge  104  through the ram acceleration assembly  402 . In other implementations, propellant material, such as a gas generating or fluid carrying material, may be included in the body of the perforating charge  104  or within the bottom hole assembly  108 . Passage of the perforating charge  104  through each region of the ram acceleration assembly  402  defined by the baffles  406  may accelerate the perforating charge  104  through the bottom hole assembly  108  toward the bottom of the wellbore  102 . In some implementations, the bottom hole assembly  108  may be constructed from stiff or heavy materials, such as steel, and may be of a significant size, such as 50 feet, to resist movement of the bottom hole assembly  108  that may be caused by detonation  116  of the perforating charge  104 . The stiff nature of the bottom hole assembly  108  may facilitate direction of energy from the detonation  116  toward the geologic material at the bottom of the wellbore  102 . 
       FIG. 5  is a diagram  500  illustrating an implementation of a perforating charge  104 . The perforating charge  104  may include a front endcap  502  located at a front end thereof. The front endcap  502  may have a triangular, conical, pyramid, wedge, chisel, or drill-bit shape configured to penetrate at least partially into geologic material of the formation upon impact between the perforating charge  104  and the formation. In some implementations, the front endcap  502  may be formed from one or more metallic materials. A charge unit  504  that includes one or more combustible materials, explosive materials, pressure-generating materials, or other materials that may be detonated or otherwise used to impart a force to the geologic material may be positioned behind the front endcap  502 . An obturator  506  may be positioned behind the charge unit  504 . The obturator  506  may include a plate or disc shape configured to receive a force applied by the drilling fluid  110 , one or more propellant materials, and so forth, to accelerate the perforating charge  104  toward the geologic material. For example, force applied to the obturator  506  by one or more propellant materials may accelerate the perforating charge  104  through a ram acceleration assembly  402 . In some implementations, the perforating charge  104  may include a primer  508  positioned behind the obturator  506 . The primer  508  may function as a propellant material, catalyst, reactant, fuel, oxidizer, and so forth, to cause acceleration of the perforating charge  104 . In other implementations, other portions of the body of the perforating charge  104  may include one or more propellant materials, fuels, oxidizers, and so forth. In still other implementations, drilling fluid  110  may provide at least a portion of the propellant material, fuel, oxidizer, and so forth to the perforating charge  104 . 
       FIG. 6  illustrates one implementation of a system  600  for providing components to a bottom hole assembly  108 . The system  600  may include portions positioned above the surface  602  as well as portions positioned below the surface  602  within a wellbore  102 . In some implementations, the surface  602  may include a rig floor. For example, one or more blowout preventers  604  or other components may be positioned at the surface  602  near the upper end of the wellbore  102 . A top drive connection  606  may engage an upper end of the system  600  to a top drive or other source of motive force. One or more feed lines  608  may be used to provide propellant materials, gas, fluid, or other sources of force into a chamber  610 , which may impart a force to perforating charges  104  or other materials to propel the materials toward the bottom hole assembly  108 . In some implementations, a separator  612  may separate the chamber  610  from other portions of the system  600 . For example, the system  600  may include an inner tube  614  positioned within an outer tube  616 . A fluid path  618  extending external to the inner tube  614  may direct fluid from a fluid source toward the bottom hole assembly  108 . 
       FIG. 7  is a series of diagrams  700  illustrating a first portion of a process for forming a wellbore  102  using perforating charges  104 . Specifically,  FIG. 7  includes diagrams  700  illustrating a system at a first time T 1 , a second time T 2  subsequent to the first time T 1 , and a third time T 3  subsequent to the second time T 2 . At the first time T 1 , drilling fluid  110  in a tubular string  106  may move a perforating charge  104  toward a bottom hole assembly  108 . In some implementations, the tubular string  106  may include drill pipe. The bottom hole assembly  108  may include a tubular element positioned above a ram acceleration assembly  402  which, as described with regard to  FIG. 4 , may include baffles  406  in some implementations.  FIG. 7  depicts the bottom hole assembly  108  including three closure elements  114  above the ram acceleration assembly  402 , which may be operated sequentially to control the passage of a perforating charge  104  into different portions of the bottom hole assembly  108 . A fourth closure element  114 ( 4 ) is also shown at the lower end of the bottom hole assembly  108 , which may be opened to permit a perforating charge  104  to exit the bottom hole assembly  108  and impact the bottom of the wellbore  102 . In some implementations, an end cap may be positioned at or near the lower end of the bottom hole assembly  108 . 
     At the second time T 2 ,  FIG. 7  illustrates movement of the perforating charge  104  into an upper portion of the bottom hole assembly  108 , subsequent to opening of the first closure element  114 ( 1 ). Movement of drilling fluid  110  in the tubular string  106  and bottom hole assembly  108  in and around the perforating charge  104  may push the perforating charge  104  through the first closure element  114 ( 1 ) into the bottom hole assembly  108 . As described with regard to  FIGS. 1 and 3 , in some implementations, at least a portion of the drilling fluid  110  may be diverted away from the interior of the bottom hole assembly  108 , such as through use of one or more ports  304 . The first closure element  114 ( 1 ) may then be closed to isolate the perforating charge  104  from the tubular string  106  and prevent passage of additional perforating charges  104  or other materials beyond the first closure element  114 ( 1 ). At the third time T 3 ,  FIG. 7  illustrates movement of the perforating charge  104  into a middle portion of the bottom hole assembly  108 , subsequent to opening of the second closure element  114 ( 2 ). After passage of the perforating charge  104 , the second closure element  114 ( 2 ) may be closed. The third closure element  114 ( 3 ) may then be opened, to permit passage of the perforating charge  104  into a lower portion of the bottom hole assembly  108 . 
       FIG. 8  is a series of diagrams  800  illustrating a second portion of a process for forming a wellbore  102  using perforating charges  104 . Specifically,  FIG. 8  includes diagrams illustrating the system  700  of  FIG. 7  at a fourth time T 4  subsequent to the third time T 3 , a fifth time T 5  subsequent to the fourth time T 4 , and a sixth time T 6  subsequent to the fifth time T 5 . At the fourth time T 4 ,  FIG. 8  illustrates movement of the perforating charge  104  into a lower portion of the bottom hole assembly  108 . Primer  508  associated with an upper end of the perforating charge  104  may be used to prepare a detonation or other type of reaction for initiation in the middle portion of the bottom hole assembly  108 . A first seal  404 ( 1 ) at the upper end of the ram acceleration assembly  402  and a second seal  404 ( 2 ) at the lower end of the ram acceleration assembly  402  may be loaded to enable propellant material  802  to be provided into the ram acceleration assembly  402 . In some implementations, isolation of the ram acceleration assembly  402  may enable the propellant material  802  to be pressurized independent of the pressure of the wellbore  102 , tubular string  106 , or other portions of the bottom hole assembly  108 . For example, the propellant material  802  may include one or more pressurized gasses. A third seal  404 ( 3 ) may be positioned above the primer  508  to contain and direct force from the detonation  116  or other reaction in a downhole direction to propel the perforating charge  104 . 
     At the fifth time T 5 ,  FIG. 8  illustrates motion of the perforating charge  104  after initiation of the detonation reaction and actuation of at least a portion of the propellant material  802  within the ram acceleration assembly  402 . The propellant materials  802 , in conjunction with the position of the perforating charge  104  relative to the baffles  406  or other features of the ram acceleration assembly  402  may facilitate acceleration of the perforating charge  104 . At the sixth time T 6 ,  FIG. 8  illustrates the perforating charge  104  having passed through the open fourth closure element  114 ( 4 ) to impact the bottom of the wellbore  102 , where a detonation  116  may displace at least a portion of the geologic material located at the bottom of the wellbore  102 . Subsequent to the exit of the perforating charge  104  from the bottom hole assembly  108 , high speed gasses may refill the ram acceleration assembly  402  at well pressure. Subsequent perforating charges  104  may be moved into the bottom hole assembly  108  in a similar manner. 
     Energy for the detonation  116  of the perforating charge  104  may be obtained using one or more explosive compounds, such as Research and Development Formula X (RDX), octogen (e.g., cyclotetramethylene-tetranitramine, known as HMX), PYX explosive (e.g., 2,6-Bis(picrylamino)-3,5-dinitropyridine), hexanitrostilbene (HNS or JD-X), and so forth. In some implementations, hydrocarbons or other sources of energy, such as gelled diesel fuel or fertilizer, may be provided into a downhole environment by encapsulating such materials within drilling fluid  110 . In some implementations, materials provided into the downhole environment may be mixed in situ (e.g., into a cake layer) and detonated. 
       FIG. 9  is a flow diagram  900  illustrating a process for providing perforating charges  104  into association with a surface of a hole, such as a wellbore  102  or other type of geological or manmade feature. Association between the perforating charges  104  and the surface of the hole may include impact or contact between a perforating charge  104  and the surface of the hole, or proximity between the perforating charge  104  and the surface without contact. Block  902  provides a perforating charge  104  into a tubular string  106  positioned within the hole, the perorating charge  104  including a detonable material. For example, at least a portion of the body of the perforating charge  104  may include an explosive material, a material that generates a force, pressure, or shock wave when actuated, and so forth. 
     Block  904  provides fluid, such as drilling fluid  110 , into the tubular string  106  to move the perforating charge  104  through the tubular string  106  into a portion of a bottom hole assembly  108 . As described with regard to  FIG. 5 , in some implementations, the perforating charge  104  may include an obturator  506  or other portion that may be shaped to receive force from the fluid to facilitate movement of the perforating charge  104  through the tubular string  106 . In some implementations, at least a portion of the fluid may flow past or around the perforating charge  104 . For example, drilling fluid  110  circulated through the tubular string  106  may both move the perforating charge  104  and perform other functions within a wellbore  102 , such as pressure control, circulation of cuttings, cooling and lubrication of a drill bit or other components, and so forth. 
     Block  906  isolates the portion of the bottom hole assembly  108  containing the perforating charge  104  from the tubular string  106  and the hole. For example, one or more seals  404 , such as cup-type seals  404 , closure elements  114 , such as ball valves or end caps, or other types of separation mechanisms may be used to at least partially enclose the portion of the bottom hole assembly  108 . Continuing the example, the bottom hole assembly  108  may include a ram acceleration assembly  402  that may be sealed to enable pressurization of one or more propellant materials  802 , such as gasses, contained therein. 
     Block  908  actuates a propellant material  802  within one or more of the fluid, the perforating charge  104 , or the bottom hole assembly  108  to move the perforating charge  104  through the bottom hole assembly  108 . In some implementations, propellant material  802  may be entrained within the fluid and provided into the portion of the bottom hole assembly  108  concurrent with the perforating charge  104 . In other implementations, the perforating charge  104  may include propellant material  802  in the body thereof. In still other implementations, propellant material  802  may be generated in situ within the bottom hole assembly  108  or another portion of the tubular string  106 , such as through use of gas or fluid generating components contained in the perforating charge  104 , fluid, or bottom hole assembly  108 . In yet another implementation, propellant material  802  may be positioned in the bottom hole assembly  108  prior to entry of the perforating charge  104  or may be separately flowed to the bottom hole assembly  108  using one or more fluid conduits. Actuation of the propellant material  802  may include pressurization or combustion of the propellant material  802 . In some implementations, interactions between the perforating charge  104 , the propellant material  802 , and the interior of a ram acceleration assembly  402  may generate a ram effect that accelerates the perforating charge  104  through the bottom hole assembly  108 . 
     Block  910  permits the perforating charge  104  to exit the bottom hole assembly  108  and move into association with a surface of the hole. For example, a closure element  114 , such as a ball valve, may be opened to permit the perforating charge  104  to pass through a lower orifice of the bottom hole assembly  108 . In other implementations, the closure element  114  may include an endcap or floating ball. In still other implementations, pressure within the bottom hole assembly  108  may prevent the ingress of material from the hole into the bottom hole assembly  108 , and use of a closure element  114  may be omitted. In some implementations, the perforating charge  104  may include a front endcap  502  or other structure shaped to at least partially penetrate into the surface of the hole. 
     Block  912  detonates the detonable material in the perforating charge  104  to displace, stress, or fracture material in the hole. For example, the perforating charge  104  may include an explosive material that detonates upon impact with the surface of the hole, or upon a separate triggering event. In some implementations, detonation of the perforating charge may extend at least one dimension of the hole. 
     Block  914  removes detonated material from the hole using movement of the fluid. For example, detonation of the perforating charge  104  may fill at least a portion of the hole with material removed from the surface of the hole and portions of the detonated perforating charge  104 . Movement of the fluid in an uphole direction may move such materials away from the surface of the hole. For example, circulation of drilling fluid  110  in a downhole direction through a tubular string  106 , then in an uphole direction through an annulus  112  may remove the detonated material from a wellbore  102 . 
     The following clauses provide additional description of various embodiments and structures: 
     1. A method comprising: 
     providing a detonable material into a tubular string positioned within a wellbore; 
     moving the detonable material through the tubular string and into association with a surface of the wellbore; and 
     detonating the detonable material to one or more of displace, stress, or fracture geologic material of the surface of the wellbore. 
     2. The method of clause 1, wherein the detonable material is contained within a charge assembly including: 
     a first end; 
     a second end opposite the first end; 
     an endcap at the first end having a shape configured to at least partially penetrate into the surface of the wellbore; and 
     an obturator at the second end having a shape configured to receive a force from at least one material within the tubular string to accelerate the charge assembly. 
     3. The method of one or more of clauses 1 or 2, further comprising providing a drilling fluid into the tubular string, wherein the drilling fluid moves the detonable material through the tubular string. 
     4. The method of clause 3, further comprising moving displaced geologic material and detonated detonable material away from the surface of the wellbore using movement of the drilling fluid. 
     5. The method of clause one or more of clauses 3 or 4, further comprising: 
     providing a plurality of communication components into the drilling fluid; and 
     providing one or more communication signals from a first device associated with the tubular string to a second device associated with the tubular string, wherein the one or more communication signals are transmitted via the plurality of communication components. 
     6. The method of one or more of clauses 1 through 5, further comprising: 
     moving the detonable material through the tubular string to an interior of a bottom hole assembly; 
     isolating the bottom hole assembly from the tubular string; and 
     actuating one or more propellant materials in the bottom hole assembly to move the detonable material through the bottom hole assembly and into association with the surface of the wellbore. 
     7. The method of clause 6, further comprising: 
     entraining at least a portion of the one or more propellant materials within drilling fluid; and 
     providing the drilling fluid to the bottom hole assembly through the tubular string. 
     8. The method of one or more of clauses 1 through 7, further comprising: 
     providing a drilling fluid into the tubular string, wherein the drilling fluid moves the detonable material through the tubular string; 
     moving the detonable material through the tubular string to an interior of a bottom hole assembly; 
     isolating the bottom hole assembly from the tubular string; and 
     diverting at least a portion of the drilling fluid through a fluid path in the bottom hole assembly, wherein the fluid path is located outside of the interior. 
     9. The method of one or more of clauses 1 through 8, further comprising moving the detonable material past an electrical generator associated with a wall of the wellbore, wherein the moving of the detonable material causes the electrical generator to generate power. 
     10. A system comprising: 
     a tubular string positioned within a hole, the tubular string having a first end and a second end opposite the first end; 
     a bottom hole assembly engaged with the second end; 
     a fluid source configured to move fluid through the tubular string toward the second end; 
     a perforating charge moved by the fluid through the tubular string toward the second end, wherein the fluid moves the perforating charge into the bottom hole assembly; and 
     a propellant material, wherein actuation of the propellant material moves the perforating charge through the bottom hole assembly into association with a surface of the hole. 
     11. The system of clause 10, wherein the propellant material is contained within the perforating charge. 
     12. The system of one or more of clauses 10 or 11, wherein the propellant material is entrained within the fluid in the tubular string. 
     13. The system of one or more of clauses 10 through 12, wherein the perforating charge includes: 
     an endcap at a first end, the endcap shaped to at least partially penetrate the surface of the hole; and 
     an obturator at a second end opposite the first end, the obturator shaped to receive a force from one or more of the fluid or the propellant material. 
     14. The system of one or more of clauses 10 through 13, wherein the bottom hole assembly includes a ram acceleration assembly having an interior with one or more of a plurality of baffles or a plurality of rails, wherein an interaction between the perforating charge, the propellant material, and the one or more of the plurality of baffles or the plurality of rails accelerates the perforating charge through the bottom hole assembly. 
     15. The system of clause 14, wherein the bottom hole assembly further includes a tubular member having an inner bore in communication with the ram acceleration assembly and a plurality of closure elements for controlling access to one or more of the inner bore or the ram acceleration assembly. 
     16. The system of one or more of clauses 14 or 15, wherein the ram acceleration assembly further comprises a first seal proximate to a first end and a second seal proximate to a second end, the first seal and the second seal configured to isolate the ram acceleration assembly from the tubular string for pressurizing of the propellant material. 
     17. A method comprising: 
     providing a perforating charge into a tubular string, wherein the tubular string is positioned within a hole; 
     providing a fluid into the tubular string to move the perforating charge through the tubular string into a portion of a bottom hole assembly; and 
     actuating a propellant material to move the perforating charge through the bottom hole assembly and into association with a surface of the hole. 
     18. The method of clause 17, wherein the portion of the bottom hole assembly includes a ram acceleration assembly, the method further comprising pressurizing the propellant material within the ram acceleration assembly, wherein an interaction between the perforating charge, the propellant material, and the ram acceleration assembly accelerates the perforating charge through the bottom hole assembly. 
     19. The method of one or more of clauses 17 or 18, further comprising: 
     providing a plurality of communication components into the fluid; and 
     communicating one or more signals between a first device proximate to a first end of the tubular string and a second device proximate to a second end of the tubular string by transmitting the one or more signals via the plurality of communication components. 
     20. The method of one or more of clauses 17 through 19, further comprising: 
     providing the propellant material into the fluid; and 
     transporting the propellant material to the bottom hole assembly using movement of the fluid. 
     Those having ordinary skill in the art will readily recognize that certain steps or operations illustrated in the figures above can be eliminated, combined, subdivided, executed in parallel, or taken in an alternate order. Moreover, the methods described above may be implemented using one or more software programs for a computer system and are encoded in a computer-readable storage medium as instructions executable on one or more hardware processors. Separate instances of these programs can be executed on or distributed across separate computer systems. 
     Although certain steps have been described as being performed by certain devices, processes, or entities, this need not be the case, and a variety of alternative implementations will be understood by those having ordinary skill in the art. 
     Additionally, those having ordinary skill in the art readily recognize that the techniques described above can be utilized in a variety of devices, environments, and situations. Although the present disclosure is written with respect to specific embodiments and implementations, various changes and modifications may be suggested to one skilled in the art, and it is intended that the present disclosure encompass such changes and modifications that fall within the scope of the appended claims.