Abstract: The present invention generally relates to controlling the flow of fluids in a wellbore. In one aspect, a valve for selectively closing a flow path through a wellbore in a first direction is provided. The valve includes a body and a piston surface formable across the flow path in the first direction. The piston surface is formed at an end of a shiftable member annularly disposed in the body. The valve further includes a flapper member, the flapper member closable to seal the flow path when the shiftable member moves from a first position to a second position due to fluid flow acting on the piston surface. In another aspect, a valve for selectively closing a flow path through a wellbore in a single direction is provided. In yet another aspect, a method for selectively closing a flow path through a wellbore in a first direction is provided.

Abstract: A flowbore fluid temperature control system comprising a valve mechanism that adjusts the flow of a fluid through a flowbore. The flowbore fluid temperature control system also comprises an actuator that adjusts the valve mechanism. The flowbore fluid temperature control system also comprises an operating system that operates the actuator and controls the flowbore fluid pressure. The flowbore fluid temperature control system selectively controls the temperature of the flowbore fluid by adjusting the flow of the fluid through the flowbore. The control system controls the actuator and also controls the flowbore fluid pressure to affect the temperature of the flowbore fluid.

Abstract: A roller cone drill bit for drilling earth formations includes a bit body having at least one roller cone rotably attached to the bit body and a plurality of cutting elements disposed on the at least one roller cone in a plurality of rows arranged circumferentially around the at least one roller cone, wherein at least one cutting element in the gage row, the heel row, or a surface of the at least one roller cone bounded by the gage and heel rows comprises thermally stable polycrystalline diamond or a thermally stable polycrystalline diamond composite. The at least one cutting element may be a TSD insert or a TSD composite insert and may be formed by brazing, sintering, or bonding by other technologies known in the art a thermally stable polycrystalline diamond table to a substrate. The interface between the diamond table and the substrate may be non-planar.

Abstract: A method and apparatus for sealing a wellbore is described herein. A convertible seal includes a sealing element and a valve. The sealing element is in fluid communication with the valve and fluidly blocks a bore of the convertible seal. The sealing element prevents fluid from flowing through the bore until desired. When desired, the sealing element is removed to allow fluid to flow through the bore. Fluid flow in the bore is controlled by the valve. As a result, the convertible seal has been converted to a flow control seal.

Abstract: A well downhole liquid dispenser is disclosed in which an inlet/discharge port assembly is provided having an inlet port in fluid communication with the shoulders of a conical piston. The point of the conical piston is in physical contact with the discharge channel leading from the center of the inlet/discharge port assembly to the discharge ports on the exterior of the inlet/discharge port assembly. The piston is held in place by an adjustable tensioning mechanism by which the pressure required to depress the piston may be varied to match the hydrostatic column pressure of a liquid column connected to the inlet port of the dispenser such that when the hydrostatic column pressure reaches a desired level, the piston is depressed, allowing fluid to flow from the liquid column regardless of the exterior downhole pressure exerted on the point of the piston through the discharge ports.

Abstract: Access to a downhole tool through a tubular wall is created with a penetration tool into a surrounding annular chamber. The chamber is disposed around a tool joint between the end connection leaving an annular chamber that is of considerable length and allowing penetration anywhere along such length. The need to precisely position the penetration tool, as in past designs of annular chambers disposed within a pin and box connection is eliminated. Landing shoulders for the penetrating tool are also not required as the long length of the annular chamber allows surface personnel to sufficiently and accurately place the penetration tool somewhere along the length of the annular chamber.

Abstract: A technique that is usable with a well includes providing a sequencing valve to in a first state to communicate a first flow through a first port of the valve and in a second state close fluid communication through the first port. The technique includes communicating a second flow through an orifice of the sequencing valve during the second state of the valve and using a pressure drop across the orifice to bias the sequencing valve to remain in the second state.

Abstract: An interventionless actuator for oil well tools is described wherein the actuator comprises at least one floating piston adapted to equalize a pressure differential and lock onto an actuating member. An interventionless actuator is described that is charged to an initial energy level less than the expected at-depth well pressure and then recharged down hole to approximately the at-depth well pressure by a floating piston. At the time of desired interventionless actuation, the actuator is overcharged to a pressure greater than the at-depth well pressure, which pressure is reacted by an actuating piston to generate an actuating movement.

Abstract: A downhole apparatus such as multi-cycle circulating subs used during downhole drilling operations includes a piston (42) slidably mounted in a body (4) between positions in which at least one aperture (40) in the body is opened and closed. Movement of the piston (42) is controlled by a pin (86) secured to one of the body and a control member, and a control groove (52) in which a portion of the pin is received formed in the other of the body and control member. An arrangement of elements (32,76) respectively connected to the control member and body is such that, as the control member moves axially, increasing lengths of the elements locate adjacent one another so as to provide resistance to relative rotation in at least one direction of the control member and body. The relative rotation is rotation which presses the control member against the control groove. The risk of damage to the control pin is thereby reduced.

Abstract: The present invention provides for a valve in a tubing string that allows the tubing string to fill with well fluids as the string is assembled and lowered into a well bore, but can be used to check pressure integrity of the tubing string during various stages of the assembly.

Abstract: The present invention is a method and apparatus for a one trip completion of fluid production wells. A completion tool string includes a pressure activated cementing valve, an external casing packer, a pressure activated production valve, an opening plug and a plug landing collar and a closing plug and seat. This tool series is assembled near the end of a production tube string upstream of the well production screen.

Abstract: According to one embodiment of the invention, a flow switchable check valve includes a housing, a guide member having a bore extending therethrough disposed within the housing, and a poppet having a head and a stem. The head has an upstream surface engaged with a seating surface on the housing when the poppet is in a first position. A pin extends into a groove such that the pin follows a pattern of the groove when the poppet is translated within the housing. The pattern is configured to direct the poppet from the first position to a second position when a force is applied to the head, and further configured to direct the poppet from the second position to a third position when the force is removed from the head, in which the third position is downstream from the first position.

Abstract: An isolation string having an upper packer and an isolation pipe in mechanical communication with the upper packer, the isolation pipe comprises an operable valve and an object activated valve. An object holding service tool is adapted to release an object to activate the object activated valve. A method of running-in an isolation string, comprising an operable valve and an object activated valve, with an object holding service tool having an object held therewith; setting the isolation string in the casing adjacent perforations; pressurizing the object to cause a release from the object holding service tool, whereby the object travels to the object activated valve; closing the object activated valve with the released object; and withdrawing the object holding service tool from the well.

Abstract: A valve with the following components: a pipe; an inner sub connected to the pipe; an outer sub connected to the pipe, wherein the inner and outer subs are concentric and define a sub annulus; a conduit between the sub annulus and an inside diameter of the inner sub; a sleeve slideably positioned within the pipe such that in at least one position the sleeve closes the conduit, wherein the sleeve comprises a section of relatively larger outside diameter and a section of relatively smaller outside diameter which define a pressure area on the sleeve between the diameters; and a lock of the sleeve in a position which closes the conduit.

Abstract: A method and apparatus for controlling inflation and deflation of spaced inflatable packer elements of a straddle stimulation tool within a well casing of a well. A straddle stimulation tool is positioned by tubing at a desired location within the well casing. Fluid is pumped through the tubing and tool at a rate inflating the spaced inflatable packer elements within the well casing and establishing an annulus interval. The inflation control retains pressure within the inflated packer elements and permits the flow of stimulation fluid into the annulus interval for stimulation of the formation. After completion of well stimulation, the packer element pressure control is moved to a packer equalizing position by tension applied via the tubing to equalize packer pressure with casing annulus pressure, deflating the packer elements and permitting conveyance of the straddle stimulation tool within the well casing by the tubing string.

Abstract: A system and method is provided for integrated control of multiple well tools. Predetermined pressure levels are utilized in independently actuating specific well tools from a plurality of well tools. The number of well tools independently controlled may be greater than the number of fluid control lines that cooperate with the well tools to control tool actuation.

Abstract: The present invention is directed to a system for controlling a hydraulic actuator, and various methods of using same. In one illustrative embodiment, the system comprises a first hydraulic cylinder, an isolated supply of fluid provided to the first hydraulic cylinder, the isolated supply of fluid positioned in an environment that is at a pressure other than atmospheric pressure, an actuator device coupled to the first hydraulic cylinder, the actuator device adapted to drive the first hydraulic cylinder to create the sufficient pressure in the fluid, and at least one hydraulic line operatively intermediate the first hydraulic cylinder and the hydraulic actuator, the hydraulic line supplying the sufficient pressure in the fluid to the hydraulic actuator in the remote locale.

Abstract: A downhole tool has at least one diverter valve. The at least one diverter valve is used to reduce pressure in a wellbore caused by frictional resistance to fluid flow during a gravel pack operation. The increased pressure tends to be created as the beta wave of the gravel pack operation makes its way up the wellbore.

Abstract: An isolation string having: an upper packer; and an isolation pipe in mechanical communication with the upper packer, wherein the isolation pipe comprises a pressure activated valve and an object activated valve. A method having: running-in an isolation string on a service tool, wherein the isolation string comprises a pressure activated valve and a object activated valve; setting the isolation string in the casing adjacent perforations in the casing; releasing an object from the service tool, whereby the object travels to the object activated valve; closing the object activated valve with the released object; and withdrawing the service tool from the well.

Abstract: A system and method is provided for artificially lifting fluids from a formation. The system utilizes a production control unit having a jet pump assembly and valving to both lift the desired fluids and to provide well control.

Abstract: The present invention provides for a valve in a tubing string that allows the tubing string to fill with well fluids as the string is assembled and lowered into a well bore, but can be used to check pressure integrity of the tubing string during various stages of the assembly.

Abstract: The present invention relates to a well safety valve set in a production tubing, comprising a body (17) including shutoff means (18) for shutting off a passage inside the body, anchor means (19) for anchoring the body in the tubing, sealing means (20) between the body and the wall of the tubing, the valve comprising communication means (14) for a hydraulic pressure between the valve and the surface of the well. According to the invention, the shutoff, anchor and sealing means include hydraulic activation means such that the hydraulic pressure transmitted from the surface activates the means so as to open the passage, anchor the valve in the tubing and activate the sealing means on the wall of the tubing. The invention also relates to a method for setting the valve.

Abstract: Fluid setting pressure is delivered to a hydraulically set well packer through an external conduit strapped to the exterior of a well workstring above the packer assembly. The continuity of the external conduit is continued past the packer assembly by following a flow channel along the mandrel sleeve thickness. Representatively, the external conduit may serve a primary well function other than packer setting (e.g. well chemical delivery). A calibrated rupture element in the external conduit is disposed to initially obstruct external conduit flow past the packer element. Consequently, fluid pressure transferred down the external conduit is first channeled to the packer setting pressure chamber. After setting, the fluid pressure in the external conduit is increased to rupture the calibrated element. When the external conduit flow channel is opened by rupture of the calibrated element, and the additional well service function may be accomplished.

Abstract: A multi zone isolation tool (50) for use in a subterranean wellbore includes a first tubular and a second tubular disposed within the first tubular forming an annular flow path (110a, 110b) therebetween and a central flow path (70a, 80a, 80b) through the second tubular. An annular valving assembly (90, 80) is positioned in the annular flow path (110a, 110b) and a central valving assembly (148, 186) is positioned in the central flow path (70a, 80a, 80b). The central valving assembly (186) is operably coupled to the annular valving assembly (90) such that when the central valving assembly (148, 186) is in a closed position, a pressure variation in the central flow path (70a, 80a, 80b) will operate the annular valving assembly (90, 80) from a closed position to an open position.

Abstract: A dirty fluid valve for sealing high differential fluid pressures in a drilling environment and methods for using such a valve is disclosed. One embodiment of the valve includes a seal cartridge having several openings for directing a fluid path through the cartridge, a spring connected at one end of the seal cartridge and extending through the fluid path, and a seal member connected to the other end of the spring. The seal is actuatable between an open position and a closed position so that it covers one of the openings in the seal cartridge when it is in the closed position, thereby sealing off the fluid flow through the seal cartridge fluid path. The spring provides a pre-loading force to the seal member so that the seal member always has sufficient contact with the surfaces surrounding the opening that the seal covers.

Abstract: A valve for use in a wellbore, the valve having a compensating secondary sealing system for misalignments that inevitably occur in sealing subsurface valves, particularly subsurface safety valves. A sealing system can include a dynamic sealing system and a static sealing system, where the static sealing system establishes one or more line contact surfaces. The line contact surfaces can be leading, in that the forward edge of the seal faces a corresponding engagement portion of the actuator. The actuator can include at least two spherical engagement portions where one of the spherical engagement portions engages resilient and non-resilient seals with line contact surfaces on a downstroke and the other spherical engagement portion engages resilient and non-resilient seals with line contact surfaces on an upstroke. Further, a bearing disposed above seals on a piston of the actuator assists in keeping contaminants out of the seal area of the piston.

Abstract: A petroleum well having a communication system and a hydraulic system is provided. The petroleum well includes a borehole and a piping structure positioned within the borehole. The communication system supplies a time varying electric current downhole along the piping structure. The hydraulic system, which is positioned downhole proximate the piping structure, receives the time varying current to operate an electric motor. The motor drives a pump which pressurizes hydraulic fluid to selectively drive an actuator. The actuator is operably connected to a downhole device, such as a shutoff valve, and operates the downhole device as the actuator is driven by the pressurized hydraulic fluid.

Abstract: A fluid flow actuated downhole tool is configurable in at least a first tool configuration and a second tool configuration. The tool comprises a tubular housing and an activating sleeve, the housing being adapted to catch the sleeve when the sleeve is dropped from surface and the engagement of the sleeve with the housing permitting actuation.of the tool between the first and second tool configurations. A flow restriction is provided for permitting fluid flow actuation of the tool when the activating sleeve has been caught in the body.

Abstract: A method and apparatus for propelling a tool having a body within a passage. The tool includes a gripper including at least a gripper portion which can assume a first position that engages an inner surface of the passage and limits relative movement of the gripper portion relative to the inner surface. The gripper portion can also assume a second position that permits substantially free relative movement between the gripper portion and the inner surface of the passage. The tool includes a propulsion assembly for selectively continuously moving the body of the tool with respect to the gripper portion while the gripper portion is in the first position. This allows the tool to move different types of equipment within the passage. For example, the tool advantageously may be used in drilling processes to provide continuous force to a drill bit. This enables the drilling of extended horizontal boreholes.

Abstract: According to the present invention, the flow-activated valve assembly is a fluid-driven tool for use in various down hole drilling and fishing operations, which is activated by the introduction of fluid into an enclosed assembly, whereby fluid forces a movable portion of such assembly to slide until it engages a stationary portion, where an impact is realized, and at which time the fluid is permitted to exhaust. Upon this impact, another valve is opened to permit fluid to flow in another channel, moving the assembly in the opposite direction until it reaches a second stationary portion, at which point another impact is realized in the opposite direction. This creates a bi-directional hammering effect for each cycle of the tool, which can be utilized in various applications, either for the jarring effect, the linear motion, or a combination of both.

Abstract: A downhole well valve having a variable area orifice (26) is flow area adjusted by a sliding sleeve (20) that is axially shifted along a tubular housing (12) interior in a finite number of increments. A hydraulic actuator (60) displaces a predetermined volume of hydraulic fluid with each actuator stroke. An actuator displaced volume of fluid shifts the flow control sleeve by one increment of flow area differential. An indexing mechanism (40) associated with the sleeve provides a pressure value respective to each increment in the increment series.

Abstract: The down hole motor is a self-contained radial drive unit that is driven by a linear input, which can be supplied from various sources. As linear motion is applied to the input of the tool, drive pins on a drive shaft follow a helical path, converting the linear motion into radial motion at the attached mandrel end. This may then be utilized in various activities such as drilling, boring and obstruction removal. This tool may also be used in conjunction with jarring mechanisms in order to create an impact drilling device, or a percussion motor.

Abstract: The invention provides a running tool for a wellbore component. In one aspect, the tool includes a body having a longitudinal bore therethrough with an upper end for connection to a tubular run-in string and a selective attachment assembly for a wellbore component therebelow. A flow directing member is disposed in the bore and is movable between a first and second position. At a predetermined flow rate through the member, the member moves to the second position and directs fluid towards the selective attachment assembly, thereby causing the running tool to become disengaged from the wellbore component after the wellbore component has been actuated and fixed in the wellbore.

Abstract: The down hole jar tool is a tool used to apply jarring forces to objects that may be obstructing the path of a down hole, or above-ground operation that requires a repetitive jarring action to dislodge or remove such objects. The tool is used by providing a linear input to a mandrel portion that draws back against a compressible unit of predetermined resistance until a releasing means abruptly releases the mandrel portion. The mandrel portion then rapidly moves in the direction of the linear input until it encounters a stationary anvil, which produces the desired jarring action. This tool may also be combined with accelerators and/or valves, as well as other tools, to create a more substantial jarring impact.

Abstract: A string for completing a well, the string having several parts including: a base pipe with a hole; a packer in mechanical communication with the base pipe; a screen in mechanical communication with the base pipe, wherein the screen is proximate the hole in the base pipe; an isolation pipe concentric within the base pipe and proximate to the hole in the base pipe, wherein an annulus is defined between the base pipe and the isolation pipe; and an annular flow valve in mechanical communication with the base pipe and the isolation pipe, wherein the annular flow valve controls longitudinal fluid flow through the annulus.

Abstract: In carrying out the principles of the present invention, in accordance with an embodiment thereof, an annular choke apparatus, and methods of use, are provided for use within a subterranean well. In broad terms, a choke tool apparatus is provided which includes an outer housing having an outer housing wall with at least one flow port therethrough, and a variable annular flow-area choke disposed within the outer housing, the variable annular flow-area choke having a first generally tubular member sealingly disposed within the outer housing, the first tubular member having a shoulder with a sealing surface, a second generally tubular member slidingly and sealingly disposed within the outer housing, the second tubular member having a shoulder with a sealing surface, the second member movable between a sealed position wherein the sealing surfaces are in sealing abutment and an open position wherein the sealing surfaces are spaced apart. The sealing surfaces preferably provide a metal-to-metal seal.

Abstract: A system and method is provided for integrated control of multiple well tools. Predetermined pressure levels are utilized in independently actuating specific well tools from a plurality of well tools. The number of well tools independently controlled may be greater than the number of fluid control lines that cooperate with the well tools to control tool actuation.

Abstract: A unitary, forward buckling rupture disc is provided that is adapted to be mounted in a holder in which the disc is in closing relationship to a tubing string in an oil well and has greatest utility for testing the integrity of the connection between the sections of oil well tubing strings. The disc is designed to withstand the fluid pressure head in the string and a leak test pressure, and to then burst and fully open under a predetermined overpressure. The concavo-convex bulged section of the disc has a non-circular, continuous score line formed in the concave face thereof. The score line is of continuously varying depth around its circumference and includes an outwardly projecting cam segment which is of greatest depth that ruptures first and is in direct opposition to a lesser depth score line portion forming a hinge area for the burst region of the disc.

Abstract: An assembly that is usable in a subterranean well includes a valve, a sleeve and an index mechanism. The valve is adapted to selectively isolate a region of the well, and the sleeve is adapted to be moved by a downhole tool to cause the valve to transition from a first state to a second state. The index mechanism prevents the valve from transitioning from the first state to the second state until after a position of the sleeve follows a predefined pattern.

Abstract: A valve with the following components: a pipe; an inner sub connected to the pipe; an outer sub connected to the pipe, wherein the inner and outer subs are concentric and define a sub annulus; a conduit between the sub annulus and an inside diameter of the inner sub; a sleeve slideably positioned within the pipe such that in at least one position the sleeve closes the conduit, wherein the sleeve comprises a section of relatively larger outside diameter and a section of relatively smaller outside diameter which define a pressure area on the sleeve between the diameters; and a lock of the sleeve in a position which closes the conduit.

Abstract: The present invention provides a method and an apparatus for use in a wellbore tool. The apparatus includes a body and a sliding member, wherein the sliding member and a mechanical portion moves between a first position and a second position. A valve assembly causes the sliding member and mechanical portion to shift to its second position at a predetermined flow rate of fluid through the body. The invention also provides an apparatus for a downhole tool that includes a mandrel and a sliding member disposed on the mandrel. The sliding member including a plurality of fingers and a plurality of heads, wherein the plurality of fingers are slideably recessed within a plurality of longitudinal grooves. The invention further provides a collet assembly that includes a body and at least two extendable members, whereby as the members extend outward, the members are rotated.

Abstract: An apparatus and method for enhancing oil recovery through improved injection well performance is provided, wherein a fluid is injected into the well bore at a pressure Pi, and a downhole fluid-actuated engine and pump assembly is employed as a booster in order to generate a high pressure output at pressure Ph greater than Pi and a low pressure output at pressure Pl lower than Pi; the respective output streams are directed to lower and higher permeability geological strata adjacent the well bore in order to increase production.

Abstract: A method of progressively gravel packing is provided which enables individual sections of a continuous wellbore portion to be gravel packed in succession. In a described embodiment, multiple well screens are positioned in a wellbore. A continuous portion of the wellbore is isolated using, for example, one or more packers, with the well screens being disposed in the isolated portion. The isolated wellbore portion is then progressively gravel packed in successive individual predetermined sections of the isolated wellbore portion.

Abstract: Plunger lift operations are difficult to optimize due to lack of knowledge of tubing pressure, casing pressure, bottom-hole pressure, liquid accumulation in the tubing and location of the plunger. Monitoring the plunger position in the tubing helps the operator (or controller) to optimize the removal of liquids and gas from the well. The plunger position can be tracked from the surface by monitoring acoustic signals generated as the plunger falls down the tubing. When the plunger passes by a tubing collar recess, an acoustic pulse is generated that travels up the gas within the tubing. The acoustic pulses are monitored at the surface, and are converted to an electrical signal by a microphone. The signal is digitized, and the digitized data is stored in a computer. Software processes this data along with the tubing and casing pressure data to display plunger depth, plunger velocity and well pressures vs. time.

Abstract: The present invention generally relates to a flow-actuated valve for use in a wellbore. The invention includes a body having a closing member and a seat. The closing member and seat are separable to open and close the valve, thereby allowing the flow of fluid through the valve. The invention further includes a retainer to initially retain the valve in the open position absent a predetermined fluid flow rate in a first direction for a predetermined time period. A biasing member thereafter urges the valve to the closed position, absent another fluid flow rate in the first direction.

Abstract: A drill bit guide is mounted in a wellhead in place of a wear bushing. The bit guide is capable of guiding strings and tools through the wellhead without damage to the wellhead or string while drilling. In one version of the bit guide, a pair of linear actuators radially extend and retract separate halves of the bit guide to conform to the size of the object located between them. In another version of the bit guide, a set of interlocking arms and wear bars are articulated to form a circular opening having a variable inner diameter. A drill string may be lowered through a fully open bit guide or landed on top of a fully closed bit guide. The bit guide also can be moved to more closely receive the drill string passing through it to prevent damage to the drill string and the wellhead.

Abstract: A pressure reducing apparatus and a method of operating a pressure reducing apparatus are provided. The apparatus is operable to reduce the pressure and flow rate of oil being discharged from a well head to downstream processing equipment. The device has central flow channel configured to receive a flow of oil and reduce the pressure in the oil. The apparatus has internal components formed of a ceramic material that resists erosion and wear caused by sand and other debris in the oil. In one embodiment of the invention, a ceramic outer sleeve is disposed in the central flow channel and cooperates with a ceramic inner sleeve having an orifice. The ceramic inner sleeve is interchangeable with other ceramic sleeves having different orifices to modify the pressure and flow characteristics of oil as it is discharged to the downstream processing equipment.

Abstract: A hydraulically operated fluid metering apparatus provides discharge of a known volume of fluid to an actuator of a well tool. In one described embodiment, the fluid metering apparatus is connected to a hydraulic input of a well tool actuator. Discharge of the known volume of fluid to the actuator input causes a piston of the actuator to displace a known distance, thereby producing a known increment of actuation of the well tool. The discharge of the known volume of fluid may be repeated to produce a desired total degree of actuation of the well tool.

Abstract: A device and method for selectively controlling the flow of production fluid through a tubing string in an oil and gas well according to which a housing is connected to a tubing string for insertion into the well, and well fluid is passed from the ground surface into the housing. The housing is provided with a plug to establish well fluid pressure in the housing to actuate a packer and/or other ancillary devices. The plug can be removed from the hosing by increasing the pressure of the well fluid in the housing above a predetermined value, thus permitting the flow of production fluid from the formation zone, through the housing and the tubing string, and to the ground surface.

Abstract: A multi-valve well testing system adapted to be disposed downhole in a borehole, includes a plurality of valves and a plurality of well tool control systems connected, respectively, to the plurality of valves and further includes an automatic control mode feature. The well testing system includes a controller board which comprises a microprocessor and a read only memory (ROM). The ROM has encoded therein a set of microcode which, when executed by the microprocessor, causes the various plurality of valves in the well testing system to be opened and closed automatically, without intervention from the operator at the well surface. A kickoff stimulus is required in order to begin execution of the microcode by the microprocessor. This kickoff stimulus could include a sensing, by a pressure transducer, of a predetermined bottom hole pressure, or a sensing, by a strain gauge, of a predetermined set down weight of the well testing system.