Patent Publication Number: US-10316237-B2

Title: Drilling fluid for downhole electrocrushing drilling

Description:
RELATED APPLICATIONS 
     This application is a U.S. National Stage Application of International Application No. PCT/US2016/037841 filed Jun. 16, 2016, which designates the United States, and is incorporated herein by reference in its entirety. 
     TECHNICAL FIELD 
     The present disclosure relates generally to a drilling fluid for downhole electrocrushing drilling. 
     BACKGROUND 
     Electrocrushing drilling uses pulsed power technology to drill a borehole in a rock formation. Pulsed power technology repeatedly applies a high electric potential across the electrodes of an electrocrushing drill bit, which ultimately causes the surrounding rock to fracture. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       For a more complete understanding of the present disclosure and its features and advantages, reference is now made to the following description, taken in conjunction with the accompanying drawings, in which: 
         FIG. 1  is an elevation view of a downhole electrocrushing drilling system used in a wellbore environment; and 
         FIG. 2  illustrates exemplary components of a bottom hole assembly for a downhole electrocrushing drilling system. 
     
    
    
     DETAILED DESCRIPTION 
     Electrocrushing drilling may be used to form wellbores in subterranean rock formations for recovering hydrocarbons, such as oil and gas, from these formations. Electrocrushing drilling uses pulsed-power technology to repeatedly fracture the rock formation by repeatedly delivering high-energy electrical pulses to the rock formation. The fractured rock is removed from the vicinity of the electrocrushing drill bit by drilling fluid. Although drilling fluids used in conventional mechanical drill bit drilling methods also remove fractured rock from the vicinity of the drill bit, thereby allowing drilling to progress downhole, drilling fluids suitable for use with a conventional mechanical drill bit are typically not suitable for use with an electrocrushing drill bit. Electrocrushing drilling fluids have a sufficiently high frequency dependent dielectric constant (also referred to as dielectric constant herein) and dielectric strength, and a sufficiently low electrical conductivity to allow an electrocrushing drill bit to direct an arc of electric current through a portion of the rock in the formation, heating water and other materials in the rock and causing that rock and surrounding rock to fracture. 
     For a given electrocrushing drill bit, the dielectric constant and dielectric strength of the drilling fluid are sufficiently high if electric fields generated by the electrocrushing drill bit are directed away from the drilling fluid and into the rock formation, the rock formation is still fractured, the drilling operation proceeds downhole at at least a set rate, the drilling operation is economically viable, or any combination of these parameters. 
     For a given electrocrushing drill bit, the electrical conductivity of a drilling fluid is sufficiently low if leakage current from the electrocrushing drill bit into the drilling fluid is sufficiently low that the rock formation is still fractured, the drilling operation proceeds downhole at at least a set rate, the drilling operation is economically viable, or any combination of these parameters. 
     Typically, an electrocrushing drilling fluid will have both sufficient dielectric and electric conductivity properties. 
     Furthermore, some electrocrushing drilling fluids and electrocrushing drilling systems using such fluids additionally differ from conventional drilling fluids and systems by being more resistant to cavitation caused by electrocrushing drilling or by better mitigating cavitation effects. 
     One electrocrushing drilling fluid of the present disclosure includes a base fluid containing a polar oil, an alkylene carbonate, or water, or any combination thereof. The polar oil may be an ester oil and may be present in a base fluid. The electrocrushing drilling fluid may further contain a non-polar oil, water, glycerin, or a combination thereof in an invert emulsion. This base fluid may be formed by adding whatever the non-polar oil, water, glycerin, or combination thereof, whichever is present, to a mixture of polar oil and alkylene carbonate, or one of these components if both are not present. 
     Another electrocrushing drilling base fluid contains non-polar oil, water, and glycerin, but not additionally both polar oil and alkylene carbonate. 
     The electrocrushing drilling fluid may also contain additives. 
     Drilling System using an Electrocrushing Drill Bit and Electrocrushing Drilling Fluid 
     Embodiments of the present disclosure and its advantages may be understood by referring to  FIGS. 1 and 2 , where like numbers are used to indicate like and corresponding parts. 
       FIG. 1  is an elevation view of an exemplary electrocrushing drilling system used to form a wellbore in a subterranean formation. Although  FIG. 1  shows land-based equipment, downhole tools incorporating teachings of the present disclosure may be satisfactorily used with equipment located on offshore platforms, drill ships, semi-submersibles, and drilling barges (not expressly shown). Additionally, while wellbore  116  is shown as being a generally vertical wellbore, wellbore  116  may be any orientation including generally horizontal, multilateral, or directional. 
     Drilling system  100  includes drilling platform  102  that supports derrick  104  having traveling block  106  for raising and lowering drill string  108 . Drilling system  100  also includes pump  104 , which circulates electrocrushing drilling fluid  122  through feed pipe  124  to kelly  110 , which in turn conveys electrocrushing drilling fluid  122  downhole through interior channels of drill string  108  and through one or more orifices in electrocrushing drill bit  114 . Electrocrushing drilling fluid  122  then circulates back to the surface via annulus  126  formed between drill string  108  and the sidewalls of wellbore  116 . Typically, during use of drilling system  100 , electrocrushing drilling fluid  122  carries fractured rock formed by electrocrushing drill bit  114  back to the surface with it. 
     Electrocrushing drill bit  114  is attached to the distal end of drill string  108 . In some embodiments, electrocrushing drill bit  114  may be supplied power from the surface. For example, generator  140  may generate electrical power and provide that power to power-conditioning unit  142 . Power-conditioning unit  142  may then transmit electrical energy downhole via surface cable  143  and a sub-surface cable (not expressly shown in  FIG. 1 ) contained within drill string  108 . A pulse-generating circuit within bottom-hole assembly (BHA)  128  may receive the electrical energy from power-conditioning unit  142 , and may generate high-energy pulses to drive electrocrushing drill bit  114 . 
     For example, pulsed-power technology may be utilized to repeatedly apply a high electric potential, for example up to or exceeding 150 kV, across the electrodes of electrocrushing drill bit  114 . Each application of electric potential is referred to as a pulse. When the electric potential across the electrodes of electrocrushing drill bit  114  is increased enough during a pulse to generate a sufficiently high electric field, an electrical arc forms through a rock formation at the bottom of wellbore  116 . The arc temporarily forms an electrical coupling between the electrodes, allowing electric current to flow through the arc inside a portion of the rock formation at the bottom of wellbore  116 . The arc greatly increases the temperature and pressure of the portion of the rock formation through which the arc flows and the surrounding formation and materials. The temperature and pressure is sufficiently high to break the rock itself onto small bits or cuttings. 
     As electrocrushing drill bit  114  repeatedly fractures rock and electrocrushing drilling fluid  122  moves the fractured rock uphole, wellbore  116 , which penetrates various subterranean rock formations  118 , is created. Wellbore  116  may be any hole drilled into a subterranean formation or series of subterranean formations for the purpose of exploration or extraction of natural resources such as, for example, hydrocarbons, or for the purpose of injection of fluids such as, for example, water, wastewater, brine, or water mixed with other fluids. Additionally, wellbore  116  may be any hole drilled into a subterranean formation or series of subterranean formations for the purpose of geothermal power generation. 
       FIG. 2  illustrates exemplary components of a bottom hole assembly for downhole electrocrushing drilling system  100 . Bottom-hole assembly (BHA)  128  may include pulsed-power tool  230 . BHA  128  may also include electrocrushing drill bit  114 . For the purposes of the present disclosure, electrocrushing drill bit  114  may be referred to as being integrated within BHA  128 , or may be referred to as a separate component that is coupled to BHA  128 . 
     Pulsed-power tool  230  may be coupled to provide pulsed power to electrocrushing drill bit  114 . Pulsed-power tool  230  receives electrical energy from a power source via cable  220 . For example, pulsed-power tool  230  may receive power via cable  220  from a power source on the surface as described above with reference to  FIG. 1 , or from a power source located downhole such as a generator powered by a mud turbine. Pulsed-power tool  230  may also receive power via a combination of a power source on the surface and a power source located downhole. Pulsed-power tool  230  converts the electrical energy received from the power source into high-power electrical pulses, and may apply those high-power pulses across electrodes of electrocrushing drill bit  114 . For the purposes of the present disclosure, ground ring  250  may also be referred to generally as an electrode or more specifically as a ground electrode. In one example, pulsed-power tool  230  may apply the high-power pulses across electrode  208  and ground ring  250  of electrocrushing drill bit  114 . Pulsed-power tool  230  may also apply high-power pulses across electrode  210  and ground ring  250  in a similar manner as described herein for electrode  208  and ground ring  250 . 
     Pulsed-power tool  230  may include a pulse-generating circuit. Such a pulse-generating circuit may include high-power capacitors and which may include fuse-protection. 
     Referring to  FIG. 1  and  FIG. 2 , electrocrushing drilling fluid  122  may exit drill string  108  via openings  209  surrounding each electrode  208  and each electrode  210 . The flow of electrocrushing drill fluid  122  out of openings  209  allows electrodes  208  and  210  to be insulated by the electrocrushing drilling fluid. In some embodiments, electrocrushing drill bit  114  may include a solid insulator (not expressly shown in  FIG. 1 or 2 ) surrounding electrodes  208  and  210  and one or more orifices (not expressly shown in  FIG. 1 or 2 ) on the face of electrocrushing drill bit  114  through which electrocrushing drilling fluid  122  may exit drill string  108 . Such orifices may be simple holes, or they may be nozzles or other shaped features. Because fines are not typically generated during electrocrushing drilling, as opposed to mechanical drilling, electrocrushing drilling fluid  122  may not need to exit the drill bit at as high a pressure as the drilling fluid in mechanical drilling. As a result, nozzles and other features used to increase drilling fluid pressure may not be needed. However, nozzles or other features to increase electrocrushing drilling fluid  122  pressure or to direct electrocrushing drilling fluid may be included for some uses. 
     Drilling fluid  122  is typically circulated through drilling system  100  at a flow rate sufficient to remove fractured rock from the vicinity of electrocrushing drill bit  114  in sufficient quantities within a sufficient time to allow the drilling operation to proceed downhole at least at a set rate. In addition, electrocrushing drilling fluid  122  may be under sufficient pressure at a location in wellbore  116 , particularly a location near a hydrocarbon, gas, water, or other deposit, to prevent a blowout. 
     Electrodes  208  and  210  may be at least 0.4 inches apart from ground ring  250  at their closest spacing, at least 1 inch apart at their closest spacing, at least 1.5 inches apart at their closest spacing, or at least 2 inches apart at their closest spacing. If drilling system  100  experiences vaporization bubbles in electrocrushing drilling fluid  122  near electrocrushing drill bit  114 , the vaporization bubbles may have deleterious effects. For instance, vaporization bubbles near electrodes  208  or  210  may impede formation of the arc in the rock. Electrocrushing drilling fluids  122  may be circulated at a flow rate also sufficient to remove vaporization bubbles from the vicinity of electrocrushing drill bit  114 . 
     In addition, electrocrushing drill bit  114  may include ground ring  250 , shown in part in  FIG. 2 . Although not all electrocrushing drill bits  114  may have ground ring  250 , if it is present, it may contain passages  260  to permit the flow of electrocrushing drilling fluid  122  along with any fractured rock or bubbles away from electrodes  208  and  210  and uphole. 
     Referring again to  FIG. 1 , at the surface, recirculated or spent electrocrushing drilling fluid  122  exits annulus  126 . Recirculated or spent electrocrushing drilling fluid  122  may simply be directed back into drill string  108  or may otherwise be processed using only some of the equipment shown in  FIG. 1 . However, in the drilling system  100 , electrocrushing drilling fluid  122  is conveyed to one or more fluid processing units  150  via an interconnecting flow line  130 . After passing through fluid processing units  150 , cleaned electrocrushing drilling fluid  122  is deposited into retention pit  132 . Although fluid processing unit  150  is illustrated in  FIG. 1  near the outlet of the wellbore  116 , fluid processing unit  150  may be located at a distance from the outlet of wellbore  116 . 
     Drilling system  100  may further include mixing hopper  134  communicably coupled to or otherwise in fluidic communication with retention pit  132 . Mixing hopper  134  may include, but is not limited to, mixers and related mixing equipment. Mixing hopper  134  may be used to add additives to electrocrushing drilling fluid  122 . 
     Drilling fluid  122  is typically circulated through drilling system  100  at a flow rate sufficient to remove fractured rock from the vicinity of electrocrushing drill bit  114  in sufficient quantities within a sufficient time to allow the drilling operation to proceed downhole at at least a set rate. 
     In addition, electrocrushing drilling fluid  122  may be under sufficient pressure at a location in wellbore  116 , particularly a location near a hydrocarbon, gas, water, or other deposit, to prevent a blowout. 
     If drilling system  100  experiences cavitation in electrocrushing drilling fluid  122  near electrocrushing drill bit  112 , the may have various deleterious effects. For instance, cavitation bubbles near electrodes  208  and  210  may impede formation of the arc in the rock. Electrocrushing drilling fluids  122  may be circulated at a flow rate also sufficient to remove cavitation bubbles from the vicinity of electrocrushing drill bit  114  in sufficient quantities within a sufficient time to allow the drilling operation to proceed downhole at at least a set rate and to avoid damage to drill bit  112  from the cavitation bubbles, for instance damage resulting from the cavitation bubbles reentering drill bit  112 . 
     Electrocrushing Drilling Fluid 
     To limit discharge of the electric field through electrocrushing drilling fluid  122  and allow more electrical current to flow into the rock at the end of wellbore  116 , an electrically insulating electrocrushing drilling fluid  122  with a high dielectric constant and a high dielectric strength at a particular operating frequency may be used. An electrically insulating electrocrushing drilling fluid  122  restricts the movement of electrical charges, and therefore, the flow of electrical current through the electrocrushing drilling fluid  122 . A high dielectric constant and high dielectric strength decrease electrical discharge through electrocrushing drilling fluid  122 . The dielectric constant of the downhole fluid indicates the ability of the electrocrushing drilling fluid to store electrical energy when exposed to an electric field, such as the potential created by electrocrushing drill bit  114 , while the dielectric strength of the downhole fluid indicates a voltage level to which electrocrushing drilling fluid  122  may be exposed before experiencing electrical breakdown, or a loss of its electrically insulating properties. 
     Electrocrushing drilling fluid  122  may be formulated to have: 
     i) at least a set dielectric constant, such as at least 6, at least 10, at least 12, or at least 13 (at 100 kHz frequency), 
     ii) at least a set dielectric strength, such as at least 100 kV/cm, at least 150 kV/cm, or at least 330 kV/cm (at 10 microseconds rise time), 
     iii) less than a set electric conductivity, such as less than 10 −4  mho/cm, or less than 10 −5  mho/cm, 
     or any combinations thereof. 
     Electrocrushing drilling fluid  122  includes an electrocrushing drilling base fluid and may include one or more additives. Generally, the electrocrushing drilling base fluid may be present in an amount sufficient to form a pumpable electrocrushing drilling fluid. 
     By way of example, the electrocrushing drilling base fluid may be present in electrocrushing drilling fluid  122  in an amount in the range of from 20% to 99.99, by volume of electrocrushing drilling fluid  122 . 
     One electrocrushing drilling base fluid includes a polar oil and an alkylene carbonate as well as a non-polar oil, water, glycerin, or any combinations thereof in an invert emulsion. The polar oil:alkylene carbonate ratio may be between 75:25 to 85:15, particularly 80:20 (v:v). The non-polar oil:polar oil and alkylene carbonate mixture ratio may be between 25:75 to 35:65, particularly 30:60 (v:v). The oil:water ratio may be between 40:60 and 99:1, between 50:50 and 90:10, or less than 75:25 (v:v). The glycerin:polar oil and alkylene carbonate mixture ratio may be between 5:95 and 15:85, particularly 10:90 (v:v). 
     Another electrocrushing drilling base fluid includes non-polar oil, water, and glycerin without both a polar oil and an alkylene carbonate or without any polar oil or alkylene carbonate. The non-polar oil:water ratio may be between 75:25 and 85:15, particularly 80:20 (v:v). The non-polar oil:glycerin ratio may be between 60:40 and 70:30, particularly 66:33 (v:v). The water:glycerin ratio may be between 25:75 and 35:65, particularly 30:60 (v:v). 
     Polar oil, if present, may include a combination of polar oils. Polar oils may include a vegetable oil, such as castor oil, a ester oil, such as a polyol ester or monoester oil, or any combination thereof. Polyol ester and monoester oils may provide greater hydrolytic stability, lower viscosity, or both as compared to vegetable oils. 
     A polar oil may include any ester of a carboxylic acid, such as a carboxylic acid with between 8 and 20 carbons, and 0, 1, or 2 moles of unsaturation. The carboxylic acid may be esterified using an alcohol, such as methanol, isopropanol, or 2-ethylhexanol. 
     A polar vegetable oil may include esters of vegetable oils such as esters of palm oil, palm kernal oil, rape seed oil, soybean oil, steric acid, oleic acid, and linoleic acid, and any combinations thereof. 
     A polyol ester oil may include a glycol ester oil, such as a neopentyl glycol diester. 
     A monoester oil may include hexanyl propanoate and isomers, hexanyl butyrate and isomers, hexanyl hexanoate and isomers, hexanyl octanoate and isomers, hexanyl decanoate and isomers, hexanyl laureate and isomers, hexanyl palmitate and isomers, hexanyl hexadecanoate and isomers, hexanyl stearate and isomers, octanyl propanoate and isomers, octanyl butyrate and isomers, octanyl hexanoate and isomers, octanyl octanoate and isomers, octanyl decanoate and isomers, octanyl laureate and isomers, octanyl palmitate and isomers, octanyl hexadecanoate and isomers, octanyl stearate and isomers, decanyl propanoate and isomers, decanyl butyrate and isomers, decanyl hexanoate and isomers, decanyl octanoate and isomers, decanyl decanoate and isomers, decanyl laureate and isomers, decanyl palmitate and isomers, decanyl hexadecanoate and isomers, decanyl stearate and isomers, dodecanyl propanoate and isomers, dodecanyl butyrate and isomers, dodecanyl hexanoate and isomers, dodecanyl octanoate and isomers, dodecanyl decanoate and isomers, dodecanyl laureate and isomers, dodecanyl palmitate and isomers, dodecanyl hexadecanoate and isomers, dodecanyl stearate and isomers, tetradecanyl propanoate and isomers, tetradecanyl butyrate and isomers, tetradecanyl hexanoate and isomers, tetradecanyl octanoate and isomers, tetradecanyl decanoate and isomers, tetradecanyl laureate and isomers, tetradecanyl palmitate and isomers, tetradecanyl hexadecanoate and isomers, tetradecanyl stearate and isomers, hexadecanyl propanoate and isomers, hexadecanyl butyrate and isomers, hexadecanyl hexanoate and isomers, hexadecanyl octanoate and isomers, hexadecanyl decanoate and isomers, hexadecanyl laureate and isomers, hexadecanyl palmitate and isomers, hexadecanyl hexadecanoate and isomers, hexadecanyl stearate and isomers, octadecanyl propanoate and isomers, octadecanyl butyrate and isomers, octadecanyl hexanoate and isomers, octadecanyl octanoate and isomers, octadecanyl decanoate and isomers, octadecanyl laureate and isomers, octadecanyl palmitate and isomers, octadecanyl hexadecanoate and isomers, octadecanyl stearate and isomers, icosanyl propanoate and isomers, icosanyl butyrate and isomers, icosanyl hexanoate and isomers, icosanyl octanoate and isomers, icosanyl decanoate and isomers, icosanyl laureate and isomers, icosanyl palmitate and isomers, icosanyl hexadecanoate and isomers, icosanyl stearate and isomers, docosanyl propanoate and isomers, docosanyl butyrate and isomers, docosanyl hexanoate and isomers, docosanyl octanoate and isomers, docosanyl decanoate and isomers, docosanyl laureate and isomers, docosanyl palmitate and isomers, docosanyl hexadecanoate and isomers, docosanyl stearate, and any combinations thereof. 
     Specific suitable non-polar oils include PETROFREE® (Halliburton, Tex., US), which is an ester of 2-ethylhexanol reacted with palm kernel fatty acid, and PETROFREE LV® (Halliburton, Tex., US), which is an ester of 2-ethylhexanol reacted with C6 to C10 fatty acids. 
     Non-polar oils typically have a high dielectric strength and a low electric conductivity, making them a suitable replacement for alkylene carbonate in electrocrushing drilling base fluids. However, non-polar oils have a low dielectric constant, may be included with other components with a higher dielectric constant in an electrocrushing drilling base fluid. A non-polar oil suitable for use in an electrocrushing drilling base fluid of the present disclosure includes combinations of non-polar oils. Suitable non-polar oils include mineral oils, diesel oils or fuels, paraffin-based oils, oils containing branched and linear aliphatic hydrocarbons having between 8 and 26 carbon atoms and a boiling point in the range of 120° C. to 380° C., oils containing hydrocarbons having between 10 and 16 carbon atoms and a viscosity of 1.5 to 2 cSt at 40° C. Any of the non-polar oils or combinations thereof may have a viscosity of less than 4 cSt at 40° C. 
     Combinations of polar oils and non-polar oils may also be used. The polar oil, non-polar oil, or combination thereof may have a viscosity of less than 4 cSt at 40° C. 
     The electrocrushing drilling base fluid also contains water. Water has a low viscosity and a high dielectric strength, but it also has a high electric conductivity, thus potentially limiting its proportional volume in an electrocrushing drilling fluid or base fluid. The electric conductivity of water further increases if salts are dissolved in the water, a frequent occurrence during drilling. 
     Water also has a highly temperature-variable dielectric constant that decreases with temperature and thus which may also limit water&#39;s proportional volume in an electrocrushing drilling fluid or base fluid because the electrocrushing drilling fluid typically experiences high temperatures in the vicinity of the electrocrushing drill bit. 
     Polar oils tend to have dielectric constants or dielectric strengths that are too low for electrocrushing drilling. As a result, an alkylene carbonate may be added to the electrocrushing drilling fluid or base fluid, particularly if it contains a polar oil, to the improve these properties because alkylene carbonates has a high dielectric constant and moderate dielectric strength. However, the amount of alkylene carbonate in the electrocrushing drilling base oil may be limited by their electric conductivity. Butylene carbonate, propylene carbonate, glycerine carbonate, and combinations thereof may be used. 
     The electrocrushing drilling fluid or base fluid may further include glycerin. Glycerin has a high dielectric constant and low electric conductivity, but also low dielectric strength, thus potentially limiting its proportional volume in an electrocrushing drilling fluid or base fluid. 
     Glycerin, water, and non-polar oil may be mixed in any order. However, electrocrushing drilling base fluids containing a mixture of polar oil and alkylene carbonate along with glycerin, water, non-polar oil, or any combination thereof may exhibit different electrical properties depending on the order in which components are mixed. These electrocrushing drilling base fluids may be formed by first mixing the polar oil and alkylene carbonate, then adding the glycerin, water, non-polar oil, or any combinations thereof. If a combination of any of glycerin, water, and non-polar oil is added, the combination may be added as a mixture or sequentially. In particular, a combination of non-polar oil, water, and glycerin may be added in that order. 
     One or more electrical additives may change one or more electrical properties of the electrocrushing drilling base fluid. For instance, an electrical additive may change a dielectric property of the electrocrushing drilling base fluid. Such additives may include mica in any of its various forms such as muscovite, phlogopite, leidolite, fluorophlogopite, glass-bonded mica, and biotite, polytetrafluoroethylene, other chemical variants of tetrafluoroethylene, glass or a composition of glass including fused silica and alkali-silicate, polystyrene, polyethylene, diamond, lead zirconate titanate (PZT), sodium chloride crystalline, potassium bromide crystalline, silicone oil, benzene, and any combinations thereof. The electrical additive may be present in an electrocrushing drilling fluid in an amount sufficient for a particular drilling system, formation, or combination thereof. The type of electrical additive or combination of electrical additives in an electrocrushing drilling fluid may also be based at least partially upon a particular drilling system, formation, or combination thereof. 
     The electrocrushing drilling fluid may further include additives used in conventional drilling fluids. These additives may provide properties to the electrocrushing drilling fluid similar to the properties they provide to conventional drilling fluids. However, some additives used in conventional drilling fluids may not be suitable for an electrocrushing drilling fluid due to their effects on dielectric constant, dielectric strength, or electric conductivity, or because they are not compatible with an electrocrushing drill bit. 
     Additives may include a lost circulation prevention material, such as a bridging material or a fluid loss control agent, a rheology modifier, such as a viscosifier or a thinner, a weighting agent, a solids wetting agent, an acid or H 2 S scavenger, a lubricant other additives, and any combinations thereof. 
     Lost circulation materials are capable of reducing the amount of whole drilling fluid that is lost to fractures and natural caverns during the drilling process. Lost circulation materials include mica, fibers, and hard organic materials, such as nutshells. The lost circulation material may be present in an electrocrushing drilling fluid in an amount sufficient for a particular drilling system, formation, or combination thereof. The type of lost circulation material or combination of lost circulation materials in an electrocrushing drilling fluid may also be based at least partially upon a particular drilling system, formation, or combination thereof. 
     Lost circulation materials include bridging materials, which bridge across pores and fractures in the formation and help prevent loss of drilling fluid into the formation. Bridging materials may include calcium carbonate, salt supensions, resins, BARACARB® (Halliburton, Tex., US) size-ground marble, N-SEAL™ (Halliburton, Tex., US) extrusion spun mineral fiber or similar materials. 
     Fluid loss control agents, which help control loss of the liquid portion of the drilling fluid into the formation, may also be used in the electrocrushing drilling fluid. Fluid loss control agents include clays and polymers, such as synthetic polymers or natural polymers, such as lignitic polymers. 
     Rheology modifiers change the flow properties of the electrocrushing drilling fluid. Rheology modifiers may, for instance, change the shear properties or viscosity of the drilling fluid. The rheology modifier may be present in the electrocrushing drilling fluid in an amount sufficient for a particular drilling system, formation, or combination thereof. The type of rheology modifier or combination of rheology modifiers in the electrocrushing drilling fluid may also be based at least partially upon a particular drilling system, formation, or combination thereof. 
     Thinners are a type of rheology modifier that decrease the viscosity of a drilling fluid. In drilling fluids that experience flocculation, such as drilling fluids containing some clays, thinners may also be deflocculants. Electrocrushing drilling may benefit from a low viscosity drilling fluid, such that thinners may be a particularly useful additive. 
     Viscosifiers increase the viscosity of a drilling fluid. A viscosifier may be used in the drilling fluid to impart a sufficient carrying capacity or thixoropy or both to the drilling fluid, enabling the drilling fluid to transport and prevent settling of fractured rock or weighting materials, or both. Suitable viscosifiers include organophilic clays such as GELTONE® II viscosifier (Halliburton, Tex., US), polymeric viscosifiers, such as BARARESIN® VIS viscosifier (Halliburton, Tex., US), long chain fatty acids, dimer/trimer/tetramer fatty acids (RM-63™ viscosifier, Halliburton, Tex., US), and any combinations thereof. 
     The electrocrushing drilling fluid may have a viscosity at surface temperature and pressure sufficient to allow it to suspend any particles additives, such as barite or a dielectric modifier, while still allowing it to be pumped downhole. In the wellbore, the drilling fluid may maintain a viscosity sufficient to allow it to suspend any particle additives, while still allowing it to circulate through and out of the wellbore. The electrocrushing drilling fluid may further maintain a viscosity upon return to surface pressure or temperature sufficient to allow it to exit the wellbore. The electrocrushing drilling fluid may also further maintain its viscosity to allow it to continue to suspend any particles additives, such as barite, until it reaches a holding tank, through any cleaning or testing process, or until it is returned to a wellbore, as applicable. 
     Emulsifiers help create a mixture of two immiscible liquids, such as an oil-based liquid and an aqueous liquid. Suitable emulsifiers include polyaminated fatty acids. Electrocrushing drilling fluid  122  is an invert emulsion and thus may particularly benefit from an emulsifier. The emulsifier may be present in electrocrushing drilling fluid  122  in an amount sufficient for a particular drilling system, formation, or combination thereof. The type of emulsifier or combination of emulsifier in electrocrushing drilling fluid  122  may also be based at least partially upon the immiscible components of electrocrushing drilling fluid  122 , a particular drilling system, formation, or combination thereof. 
     Weighting agents increase the density of an electrocrushing drilling fluid without being dissolved in it. Suitable weighting agents include barite, hematite, ilmenite, manganese tetraoxide, and any combinations thereof. The weighting agent may be present in an electrocrushing drilling fluid in an amount sufficient for a particular drilling system, formation, or combination thereof. The type of weighting agent or combination of weighting agents in an electrocrushing drilling fluid may also be based at least partially upon a particular drilling system, formation, or combination thereof. Typically, for electrocrushing drilling, the amount of weighing agent present is sufficient to maintain an electrocrushing drilling fluid density between 8 lb/gallon and 21 lb/gallon. 
     Other additives may include corrosion inhibitors, defoamers, shale stabilizers, lubricants, wetting agents, dispersing agents, shale inhibitors, pH-control agents, filtration-control agents, alkalinity sources such as lime and calcium hydroxide, salts, foamers, viscosifiesr, thinners, deflocculents, or any combinations thereof. The other additives may be present an electrocrushing drilling fluid in an amount sufficient for a particular drilling system, formation, or combination thereof. The type of other additives or combination of other additives in an electrocrushing drilling fluid may also be based at least partially upon a particular drilling system, formation, or combination thereof. 
     Some additives, such as lignitic fluid loss control agents and polaminated fatty acid emulsifiers, may have synergistic effects. 
     In addition to conventional uses for additives, some additives may have a further effect or may be added solely for the effect of rendering the electrocrushing drilling fluid or the drilling system more resistant to cavitation caused by electrocrushing drilling or by better mitigating cavitation effect as compared to conventional drilling fluids or electrocrushing drilling fluids without the additive. 
     EXAMPLES 
     The following examples are provided to further illustrate certain aspects of the invention and should not be interpreted as disclosing the invention as a whole. In particular, substitutions within these examples in accordance with the above disclosure are also encompassed by the invention. 
     Example 1 
     Electrocrushing Drilling Fluid with Base Fluid Containing Polar Oil, Alkylene Carbonate, Non-Polar Oil, Water, and Glycerin 
     The following components were mixed at high shear:
         Polyol ester—220 g (253.1 ml) LEXOLUBE® 21-214 (Innolex, Pennsylvania, US) (neopentyl glycol diester, 6 cSt at 40° C.)   Alkylene carbonate—72.4 g (63.3 ml) butylene carbonate   Organophilic clay—15 g Geltone® II (Halliburton, Tex., US)   Fluid loss control agent—12 g Duratone® HT (Halliburton, Tex., US) (modified lignitic product)   Weighting agent—150 g barite   Emulsifier—0.45 g (5 ml) LE Supermul® (Halliburton, Tex., US) (polyaminated fatty acid).       

     The mixture had a dielectric constant of 14.8 at 100 kHz. 
     160 ml of this mixture mixed with 90 ml of Saraline 185V® (Shell Oil, Tex., US) (paraffin-based oil). The dielectric constant of the resulting mixture was 7.7. 
     10 ml of tap water and an additional 5 ml of LE Supermul® were then added to the mixture (10 ml of LE Supermul® could alternatively have been added to the original mixture). The resulting mixture had a dielectric constant to 10.0. 
     Finally, 30 ml of glycerin was added to the mixture. The resulting mixture had a dielectric constant of 13.2. 
     Thus, an electrocrushing drilling fluid containing only polar oil and alkylene carbonate in its base fluid has a dielectric constant of 14.6, but non-polar oil, water, and glycerin could be added to produce an electrocrushing drilling base fluid with a dielectric constant of 13.2, which is nearly as high. However, the cost per unit volume of the polar oil/alkylene carbonate/non-polar oil/water/glycerin base fluid is much less than that of the polar oil/alkylene carbonate base fluid. 
     Example 2 
     Electrocrushing Drilling Fluid with Base Fluid Containing Non-Polar Oil, Water, and Glycerin 
     The following components were mixed at high shear:
         Non-polar oil—139.1 g (180.9 ml) Saraline 185V®   Glycerin—69.7 g (32.6 ml)   Water—32.6 g (32.6 mL)   Lime—1.7 (g)   Organophilic clay—7 g Geltone® II   Weighting agent—100 g barite   Emulsifier—9 g (10 ml) LE Supermul®.   Simulated drilling solids—calcium carbonate, 50 μm particles—16.7 g       

     The resulting electrocrushing drilling base fluid had a dielectric constant of 6.6. 
     Example 3 
     Effect of Mixing Order on Electrocrushing Drilling Fluid with Base Fluid Containing Polar Oil, Alkylene Carbonate, Non-Polar Oil, Water, and Glycerin 
     40 ml of a monoester polar oil and 10 ml of butylene carbonate were added to 200 ml of the electrocrushing drilling fluid of Example 2 and mixed at high shear. The resulting mixture had a dielectric constant of 7.0. This is very low compared to the dielectric constant of 13.2 obtained for a similar mixture in Example 1. The primary difference between the drilling fluid of Example 3 and that of Example 1 is the order of addition of components. 
     Example 4 
     Methods of Measuring Dielectric Constant and Electric Conductivity of an Electrocrushing Drilling Fluid 
     The dielectric constant and electric conductivity of an electrocrushing drilling fluid, such as one disclosed herein, may be measured using a network analyzer or inductance, capacitance and resistance (LCR) meter equipped with a particular fixture, such as a liquid test fixture, to allow the measurement. Suitable measurement equipment includes that produced by Agilent (Santa Clara, Calif.) and Keysight (Santa Rosa, Calif.), particularly the Keysight 16452A Liquid Text Fixture and the Agilent E4991B Impedance Analyzer. Such equipment may be used in accordance with manufacturer instructions. 
     One of ordinary skill in the art may determine how to determine the frequency dependent dielectric constant and the electric conductivity of an electrocrushing drilling fluid using the above-identified or similar equipment by applying the following principles, typically as implemented in a programmed computer receiving data from equipment. 
     The frequency dependent complex dielectric constant of a fluid may be determined by the following equation, which includes its real and imaginary parts: 
               ɛ   ⁡     (   ω   )       =           ɛ   r   ′     ⁡     (   ω   )       +     j   ⁢           ⁢       ɛ   r   ″     ⁡     (   ω   )           =           ɛ   r     ⁡     (   ω   )       ⁢     ɛ   0       +     j   ⁢       σ   ⁡     (   ω   )       ω                 
where:
     ε(ω) is the frequency dependent complex dielectric constant   ε r ′(ω) is the real part of the dielectric constant   ε r ″(ω) is the imaginary part of the dielectric constant   and j=√{square root over (−1)}.   

     In addition, 
                 ɛ   r   ′     ⁡     (   ω   )       =         ɛ   r     ⁡     (   ω   )       ⁢     ɛ     0   ⁢                               so   ⁢           ⁢   that   ⁢           ⁢       ɛ   r     ⁡     (   ω   )         =         ɛ   r   ′     ⁡     (   ω   )         ɛ   0             
where:
     ε r (ω) is the frequency dependent dielectric constant of the fluid   and ε 0  is the permittivity of free space=8.85418782×10 −12  Farads/Meter.   

     Additionally, 
                     ⁢         ɛ   r   ″     ⁡     (   ω   )       =       σ   ⁡     (   ω   )       ω             
and therefore,
 
σ(ω)=ωε r ″(ω)
 
Where σ(ω) is the frequency dependent electric conductivity of the fluid.
 
     Example 5 
     Methods of Measuring Dielectric Strength of an Electrocrushing Drilling Fluid 
     Equipment suitable to measure the dielectric strength of an electrocrushing drilling fluid over a given rise time is generally not commercially available, but it may be constructed by attaching an adjustable voltage supply to electrodes immersed in the fluid and otherwise electrically insulated from one another such that an electric field ({right arrow over (E)}) may be created between the electrodes using the adjustable voltage supply when it applies a voltage (V) across the electrodes. The electrodes may be any shape, such as spheres or plates. The electrodes are separated by a distance D. An ammeter is located in the circuit between the adjustable voltage supply and the negative electrode. The adjustable voltage supply may be used to provide high voltage pulses with an adjustable peak voltage and rise time. 
     {right arrow over (E)} is determined using the following equation: 
     
       
         
           
             
               E 
               → 
             
             = 
             
               V 
               D 
             
           
         
       
     
     {right arrow over (E)} electric field is a vector quantity and the direction of the electric field goes from the positive electrode toward the negative one. One may alter the electric field by adjusting either V or D. 
     For a given rise time, for a series of voltage pulses across the electrodes and through the electrocrushing drilling fluid under test, the peak electric field ({right arrow over (E)}) for each pulse is increased until conduction current is observed in the ammeter. Conduction current indicates electrical breakdown of the liquid. For a given rise time, the electric field the electrocrushing drilling fluid can support without breakdown (and hence measurement of a current by ammeter) is its dielectric strength for that rise time. By varying the rise time and electric field and noting the electric field/rise time combinations where breakdown occurs, one may determine the dielectric strength of the electrocrushing drilling fluid as a function of rise time. 
     The disclosure provides at least three embodiments, A, B and C: 
     A. An electrocrushing drilling fluid including a electrocrushing drilling base fluid comprising at least one of water, an alkylene carbonate, and a polar oil, wherein the electrocrushing drilling base fluid has a dielectric constant of at least 6 at 100 kHz frequency. 
     B. An electrocrushing drilling fluid including a electrocrushing drilling base fluid comprising at least one of a non-polar oil, water, and glycerin, wherein the electrocrushing drilling base fluid has a dielectric constant of at least 6 at 100 kHz frequency. 
     C. An electrocrushing drilling system including a drill string, an electrocrushing drill bit attached to the downhole end of the drill string for fracturing rock in a formation, and an electrocrushing drilling fluid that circulates downhole through the drill string and then moves the fractured rock uphole. The electrocrushing drilling fluid includes an electrocrushing drilling base fluid comprising at least one of water, an alkylene carbonate, and a polar oil, a non-polar oil, and glycerin wherein the electrocrushing drilling base fluid has a dielectric constant of at least 6 at 100 kHz frequency. 
     D. A method of forming an electrocrushing drilling fluid using an electrocrushing drilling base fluid that includes at least one of water, an alkylene carbonate, and a polar oil. A non-polar oil is added to the electrocrushing drilling base fluid to form a first intermediate electrocrushing drilling fluid. Next water is added to the first intermediate electrocrushing drilling fluid to form a second intermediate electrocrushing drilling fluid. Finally, gylcerin is added to the second intermediate electrocrushing drilling fluid to form an electrocrushing drilling fluid. Each of embodiments A, B, C, and D may have one or more of the following additional elements in any combination, unless clearly mutually exclusive: i) the electrocrushing drilling fluid further includes non-polar oil, glycerin, or a combination thereof; ii) the electrocrushing drilling base fluid may have a dielectric strength of at least 100 kV/cm, at least 150 kV/cm, or at least 330 kV/cm at 10 microseconds rise time; iii) the electrocrushing drilling base fluid may have an electric conductivity of less than 10 −4  or less than 10 −5  mho/cm; iv) the electrocrushing drilling base fluid may have an oil:water ratio between 50:50 and 99:1 (v:v); v) the polar oil may include a vegetable oil, an ester oil, or any combinations thereof, vi) the alkylene carbonate may include butylene carbonate, propylene carbonate, or any combinations thereof; vii) the non-polar oil may include a mineral oil, a diesel oil or fuel, a paraffin-based oil, an oil containing branched and linear aliphatic hydrocarbons having between 8 and 26 carbon atoms and a boiling point in the range of 120° C. to 380° C., an oil containing hydrocarbons having between 10 and 16 carbon atoms and a viscosity of 1.5 to 2 cSt at 40° C., or any combinations thereof; viii) the electrocrushing drilling fluid may, further include at least one additive comprising an electrical additive, a lost circulation material, a rheology modifier, a weighting agent, an emulsifier, a corrosion inhibitor, a defoamer, a shale stabilizer, a lubricant, a wetting agent, a dispersing agent, a shale inhibitor, a pH-control agent, a filtration-control agent, an alkalinity source, or any combinations thereof; ix) the electrocrushing drilling base fluid may have a non-polar oil:water ratio between 75:25 and 85:15 (v:v); x) the electrocrushing drilling fluid may have a dielectric constants of at least 13 at 100 kHz; xi) no additional non-polar oil may be added after adding water or glycerin; xii) no additional water may be added after adding glycerin; xii) the electrocrushing drilling fluid maybe formed be adding, at any time, at least one additive comprising an electrical additive, a lost circulation material, a rheology modifier, a weighting agent, an emulsifier, a corrosion inhibitor, a defoamer, a shale stabilizer, a lubricant, a wetting agent, a dispersing agent, a shale inhibitor, a pH-control agent, a filtration-control agent, an alkalinity source, a foamer, a viscosifier, a thinner, a deflocculent or any combinations thereof. 
     Although the present disclosure has been described with several embodiments, various changes and modifications may be suggested to one skilled in the art. It is intended that the present disclosure encompasses such various changes and modifications as falling within the scope of the appended claims.