Abstract:
A rotating tool combinable with other downhole tools into a tool string, where the rotating tool is capable of imparting a rotational force onto the tool string. The tool string is suspendable from a threaded lead screw. Optionally, a gyroscope can be included to generate azimuthal readings and confirm the azimuthal orientation of the tool string. The rotating tool includes a compression assembly, a hydraulic assembly, and a stationary assembly. Actuation of a valve on the hydraulic assembly provides for the release of fluid therein that allows for movement of a rotating piston. Rotation of the piston is produced as it travels axially along the threaded lead screw, the rotation of the piston is subsequently transferred to the rotating tool.

Description:
BACKGROUND OF THE INVENTION  
       [0001]     1. Field of the Invention  
         [0002]     The invention relates generally to the field of exploration and production of hydrocarbons from wellbores. More specifically, the present invention relates to a method and apparatus to provide for controlled rotation of a downhole tool. Yet even more specifically, the present invention relates to a method and apparatus to control the rotation of a downhole tool within a wellbore in order to orient the downhole tool in a designated azimuthal direction.  
         [0003]     2. Description of Related Art  
         [0004]     Of the many tools used in conjunction with downhole wellbore operations, the function of some of these tools can be optimized by orienting the specific tool in a certain radial position about the tool&#39;s axis. Often times however the tools are suspended within the wellbore only by a wireline, which makes it virtually impossible in vertical sections of the wellbore to place the downhole tool in a specific orientation.  
         [0005]     Others have attempted to solve the problem of orienting downhole tools within a wellbore that are inserted into the wellbore by wireline. These attempts include integrating motors with the downhole tool that are designed to rotate the tool into a desired orientation. Other attempts involve setting an anchor within the wellbore, measuring the azimuth of a reference within the anchor, and then adjusting a downhole tool such that when it is mated with the anchor, the downhole tool is oriented in the desired azimuthal setting. Yet other attempts include utilizing an indexing tool comprising a mandrel with “J” slots formed on its outer radius and a corresponding outer sleeve with set pins that travel within the “J” slots. Repeated upward and downward movement of the mandrel with respect to the sleeve produces radial rotation of the tool. Examples of these devices and other apparatus and methods for azimuthally orienting downhole tools can be found in U.S. Pat. No. 5,010,965, U.S. patent application Ser. No. 2003/0111235 A1, U.S. Pat. No. 6,223,824, U.S. Pat. No. 5,360,066, and U.S. Pat. No. 6,003,599.  
         [0006]     Various shortcomings however are present in each of these aforementioned devices for evaluating and affecting the azimuthally orientation of downhole tools. For example, many wellbores, especially hydrocarbon producing wellbores, experience high pressures at depths within the wellbore. It is doubtful that the tools utilizing motors would rotate at the desired rate and distance because of the effect the high pressure pushing inward on the seals on the rotating members of the tool. As far as azimuthally orienting a tool with an anchor and corresponding reference marks, this requires the additional costly and time consuming steps of retrieving a portion of the tool from the wellbore, adjusting the corresponding marks on the downhole tool, and then inserting the tool into the wellbore. Further, with respect to implementing indexing tools to affect radial rotation, the slots in the tool can become clogged with wellbore debris such as proppant, sand, and other solids.  
         [0007]     Therefore, there exists a need for azimuthally orienting devices within wellbores that can allow the tools to be rotated at any pressure within the wellbore, requires a minimum number of steps, and will not be affected by solid particulate within wellbore fluid.  
       BRIEF SUMMARY OF THE INVENTION  
       [0008]     The present invention includes a rotating tool comprising a body, a compression assembly, a hydraulic assembly, and a lead screw. The compression assembly comprises a selectively compressible compression element and the hydraulic assembly comprises a reservoir having an open end and a closed end. The reservoir is fillable with fluid and formed to receive a piston within its open end. The piston is threadingly coupled with the lead screw and slidingly coupled with the body such that movement of the piston towards the closed end causes rotation of the piston that correspondingly produces rotation of the body. Potential energy is capable of being stored within the compression element. Alternatively, the fluid is disposed within the reservoir between the piston and the closed end. The hydraulic assembly can be coaxial with the compression assembly and is capable of selectively providing a reactive force to maintain the compression element in a compressed state. The fluid from the reservoir removes the reactive force and enables movement of the piston towards the closed end.  
         [0009]     The compressive assembly further comprises a rotor provided on the end of the compressive element distal from the hydraulic assembly, and a thrust cup provided on the end of the compressive element proximate to the hydraulic assembly. The rotating tool of the present invention further comprises a collar coaxially connecting the hydraulic assembly to the compressive assembly. The compressive element can include a helical spring, at least one Bellville washer, a gas filled cylinder, and a coiled spring.  
         [0010]     The rotating tool of the present invention can further comprise an orifice formed on the hydraulic assembly providing fluid communication between the reservoir and the outside of the hydraulic assembly. Further included is a valve included with the orifice, the capable of valve selectively providing fluid flow through the orifice. Optionally included is an anchoring device capable of anchoring the rotating tool within a wellbore and stabilizing the lead screw during rotation of the body. The reservoir is preferably comprised of an elongated annulus and the piston comprises an elongated tube formed for insertion into the elongated annulus. The body comprises a sleeve that encompasses a portion of the rotating tool. The present invention can further comprise a gyroscope operatively connected to the rotating tool. A downhole tool can be operatively connected to the rotating tool of the present invention such that rotation of the rotating tool causes rotation of the downhole tool.  
         [0011]     The present invention includes a method of using the rotating tool, the method comprises, compressing the compression element, sealing the fluid within the reservoir thereby providing a reactive force to maintain the compression element in a compressed state, and removing the reactive force from the compression element thereby allowing the piston to be urged along the length of the lead screw towards the closed end of the reservoir by the decompression of the compression element. Whereby the threaded coupling of the piston with the lead screw produces rotation of the piston that in turn produces rotation of the body.  
         [0012]     With regard to the method of the present invention, the step of removing the reactive force from the compression element is accomplished by metering the fluid out of the reservoir. The method of the present invention can further comprise disposing the rotating tool within a wellbore as well as anchoring the lead screw within the wellbore. The method can further include adding a gyroscope to the rotating tool and calibrating the rotating tool. Optionally a downhole tool can be attached to the rotating tool of the present invention and azimuthally orienting the downhole tool by to a desired position by rotating the rotating tool a certain amount.  
         [0013]     Accordingly, one of the advantages provided by the present invention is the ability to orient a downhole tool deep within a wellbore, even when the downhole tool is suspended on a wireline. 
     
    
     BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWING.  
       [0014]      FIG. 1  depicts a cross section of a wellbore with one embodiment of the present invention in use with a perforating gun.  
         [0015]      FIG. 2  illustrates a partial cross sectional view of one embodiment of the present invention.  
         [0016]      FIG. 3  depicts a side view of one embodiment of the present invention.  
         [0017]      FIGS. 4   a  and  4   b  depict a cross sectional view of an embodiment of the present invention.  
         [0018]      FIG. 5  illustrates an embodiment of a solenoid assembly for use with the present invention. 
     
    
     DETAILED DESCRIPTION OF THE INVENTION  
       [0019]     With reference to the drawing herein, one embodiment of a rotating tool  10  is illustrated in  FIG. 1 . There the rotating tool  10  is shown within a wellbore  5  as part of a tool string  3  further including a gyroscope  56  and a perforating gun  80 . The combination of rotating tool  10  and perforating gun  80  is suspended within the wellbore  5  by a wireline  7 . As is well known, the wireline  7  can be suspended from a spool (not shown) and threaded through a series of pulleys  8  to guide it into the wellbore  5 . Preferably the wireline  7  is the well known variety capable of conveying data along its length from the earth&#39;s surface to and from the rotating tool  10 , however the wireline  7  can also comprise slickline, coiled tubing, and any other line capable of tethering a downhole tool within a wellbore  5 . It should also be pointed out that downhole tools other than the perforating gun  80  can be combined with the rotating tool  10 , such as logging devices and downhole production devices, among others.  
         [0020]     An anchor  60  is also shown in  FIG. 1  preferably secured to a shaft  62  extending from the upper portion of the rotating tool  10 . The anchor  60  should provide sufficient radial resistance to rotation such that when the rotating tool  10  rotates (as will be explained in more detail below), the anchor  60  remains in place thereby preventing any corresponding twisting or rotation of the wireline  7 . However the anchor  60  should not impart such a force onto the wellbore  5  such that the vertical travel of the rotating tool  10  within the wellbore  5  is not impeded. While the anchor  60  as illustrated in  FIG. 1  is a well known centralizer type anchoring device, any other anchoring device can be implemented, such as outwardly extending slips, nipple profiles within the wellbore, and any other now known or later developed device capable of suitably anchoring the rotating tool  10  at a certain location within the wellbore  5 .  
         [0021]     With reference now to  FIG. 2 , there is illustrated a partial cross sectional view of one embodiment of the rotating tool  10  within a wellbore  5 . The rotating tool  10  of  FIG. 2  is comprised primarily of a compression assembly  22 , a hydraulic assembly  30 , and a stationary assembly  50 . The compression assembly  22  of this embodiment comprises a rotor  12 , a spring  14  adjacent to the rotor  12 , and a collar  24 . The rotor  12  is preferably cylindrical with a substantially planer surface on the end of the rotor  12  distal from the spring  14 .  
         [0022]     The end of the rotor  12  generally projecting downward comprises a recessed ledge  15  having a smaller diameter than the diameter of the remaining portion of the rotor  12 . At least one bolt hole  23  is formed on the surface of the recessed ledge  15  to provide a manner of attaching a sleeve  26  to the rotor  12 . Preferably the at least one bolt hole  23  is threadingly formed to receive a bolt  25  or other threaded fastener thereby enabling relatively quick and easy attachment and detachment of the sleeve  26  to the rotor  12 . While the preferred manner of securing the sleeve  26  to the rotor  12  includes corresponding bolts  25  and bolt holes  23 , any other now know or later developed manner of mechanical attachment can be employed, such as rivets, threading the recessed ledge  15  and inner diameter of the sleeve, and pins among others.  
         [0023]     The terminal end of the rotor  12  proximate to the recessed ledge  15  can optionally be recessed inward along its diameter to provide a mating surface where the rotor  12  contacts the spring  14 . During operation of the rotating tool  12  the rotor  12  will be pushing against the spring  14  in order to compress it.  
         [0024]     An additional embodiment of the rotating tool  10  is shown in a cross-sectional view in  FIGS. 4   a  and  4   b  where additional detail of the rotor  12  and the lead screw  16  with the attached screw extension  74  is illustrated. The screw extension  74  is preferably an elongated member having a largely cylindrical cross section along its axis. A generally cup like socket  75  is disposed on the upper end of the screw extension  74  that is coaxial with the screw extension  74 . The socket  75  is upwardly facing with a cylindrically shaped hollowed out section, where the hollowed out section is mostly coaxial with the screw extension  74 . The socket  75  can be integrally formed with the screw extension  74 , or the socket  75  and screw extension  74  can be separately formed and joined by welds, threads, bolting, or any other known or later developed type of connection.  
         [0025]     A cocking bit  76  is situated within the hollowed out section of the socket  75 . Preferably the cocking bit  76  is threadingly connected within the socket  75  as shown, but can also be welded, bolted, connected with pins, or any other known or later developed connection method. A compression nut  21  is included on the cocking bit  76  adjacent to the upper end of the rotor  12 . The compression nut  21  is preferably integral with the cocking bit  76 , where the cocking bit  76  is rotatable with respect to the rotor  12 . Accordingly rotation of the compression nut  21  is capable of producing corresponding rotation of the lead screw  16  without causing subsequent rotation of the rotor  12 .  
         [0026]     Extending upward from the compression nut  21  is the upper tip  79  of the cocking bit  76  that terminates with a threaded fitting  19 . The upper tip  79  is generally cylindrical with an inner passage formed along its axis. Contained within the inner passage are a spring  65  and an electrical connector  64 . The spring  65  is capable of providing an outward pushing force against the electrical connector  64 . An electrical connection between the electrical connector  64  and a terminal (not shown) can be maintained by the pushing force of the spring  65  on the electrical connector  64 . Preferably a passage  13  is formed substantially along the entire length of the rotating tool  10 . The passage  13  can be used to contain a data transmitting wire and therefore should be of sufficient diameter to accommodate such a wire. The wire should be electrically connected with the electrical connector  64  thereby enabling electrical communication between the internal components of the rotating tool  10  and the surface of the wellbore  5 . Preferably the data transmitting wire is comprised of a coil spring wire that is capable of being rotated and twisted without being damaged.  
         [0027]     Threads (not shown) corresponding to the threaded fitting  19  are formed within a hollowed portion of the shaft  62  that enable a means to connect the shaft  62  to the cocking bit  76 . Since the shaft  62  is secured to the wireline  5  via a cablehead  63 , affixing the cocking bit  76  to the shaft  62  serves to suspend the cocking bit  76  (and thus the remainder of the rotating tool  10 ) within the wellbore  5 . Further, joining the cocking bit  76  to the shaft  62  effectively joins the lead screw  16  to the shaft  63 . This sequence of connections prevents rotation of the lead screw  16  when the rotating tool  10  is situated within the wellbore since the lead screw  16  is effectively attached to the anchor  60 .  
         [0028]     The inner bore of the rotor  12  and the outer diameter of the screw extension  74 , socket  75 , and cocking bit  79 , the rotor  12  must be able to rotate freely around these elements. To facilitate free rotation of the rotor  12  around the screw extension  74 , socket  75 , and cocking bit  79  bearings ( 77  and  78 ) are situated at certain locations along the inner circumference of the rotor  12 . More specifically, rotor bearings  77  included between the inner bore of the rotor  12  and the screw extension  74 , these bearings  77  are proximate the lower end of the rotor  12  and also proximate to the lower end of the socket  75 . Roller bearings  77  are also disposed between the inner bore of the rotor  12  and the cocking bit  76  proximate to the upper most end of the rotor  12 . Thrust bearings are located between the lower base of the socket  75  and a ledge  82  formed within the inner bore of the rotor  12 . The ledge  82  is included to supply an upward force against the base of the socket  75 .  
         [0029]     The rotor  12  is shown in  FIGS. 4   a  and  4   b  as being bored along its axis, where the bore is formed to circumferentially encompass the socket  75 , the lower portion of the cocking bit  76 , and a portion of the screw extension  74 . The portion of the screw extension  74  not circumscribed by the rotor  12  extends downward towards the lead screw  16  and is coaxially disposed within the spring  14 . Attachment of the lead screw  14  to the screw extension  74  preferably comprises a threaded connection, but can be of any other type of connection capable of securing these parts in a coaxial arrangement.  
         [0030]     A collar  24  is positioned on the end of the spring  14  opposite to where it contacts the rotor  12 . On its upper end, the collar  24  includes a thrust cup  20  that is an upwardly facing hollowed out cylinder formed to receive the lower end of the spring  14 .  
         [0031]     Also similar to the rotor  12 , an aperture is fashioned through the collar  24  along its axis formed to receive the lead screw  16 . The portion of the lead screw  16  positioned within the aperture of the collar  24  contains threads  17  on its outer surface. The lead screw  16  is designed to rotate within the aperture of the collar  24 ; bearings  27  are preferably included within this aperture to alleviate any resulting frictional forces between the lead screw  16  and the collar  24 . More preferably the bearings  27  are part of a re-circulating bearing mechanism. With reference now to  FIG. 2  more detail is provided for this embodiment of the invention; inside the collar  24  are numerous ball bearings  27  adjacent one another within the tube  25  along the length of the collar  24 . The ball bearings  27  become disposed within the trough along the threads  17 . As the lead screw  16  turns, the ball bearings  27  travel down the threads  17  along the length of the collar  24 . As each ball bearing  27  reaches the end of the collar  14 , it is forced up and over the top of the collar  24  through a tube  25  attached to the outer surface of the collar  24 . The other end of the tube  25  is attached at the upper end of the collar  24 , where the bearing  27  can be deposited back into the bearing trough for another trip through the collar  24 . Hence the term, “recirculation lead screw collar.” 
         [0032]     As previously noted, one embodiment of the hydraulic assembly  30  is located adjacent the compression assembly  22  and comprises a piston  32  combined with a hydraulic reservoir body  40 . The piston  32  includes a piston body  34  that is substantially tubular being open on one end and closed on the other by the presence of the piston head  34 . The piston head  34  is preferably disk like in shape and aligned coaxial with the piston  32 . Keys  35  are provided on the outer radius of the piston head  34  and formed to mate with a vertical slot (not shown) disposed on the inner radius of the sleeve  26 . The presence of the keys  35  combined with the vertical slot allow the piston head  34  (and thus the piston  32 ) to travel axially within the sleeve  26 , but prevent rotation of the piston  32  with respect to the sleeve  26 . A threaded aperture  36  is formed axially through the piston head  34  whose threads are shaped to mate with the threads formed on the lead screw  16 .  
         [0033]     The hydraulic reservoir body  40  comprises primarily a pair of sleeve like tubulars (inner tube  45  and outer tube  43 ) connected on their ends to the reservoir base  47 . The inner tube  45  should be disposed coaxial within the outer tube  43  thereby forming an annulus  49  between these two tubes. To ensure that the width of the annulus  49  is substantially constant along its radius, the axes of the inner tube  45  and of the outer tube  43  should be closely aligned. The dimensions of the annulus  49  should match the dimensions of the piston body  38 , such that the open end of the piston body  38  can be easily urged in and out of the annulus  49 . Preferably at least one O-ring  53  is included on the outer wall of the piston body  38  and at least one other O-ring  53  is also included on the inner wall of the piston body  38 . These O-rings  53  provide a sealing contact between the piston body  38  and the annulus  49 .  
         [0034]     A hydraulic reservoir  42  is situated within the reservoir base  47 . While the hydraulic reservoir should  42  should be capable of storing fluid within without leakage, it is in fluid communication with the annulus  49  via at least one opening  55  through the housing of the hydraulic reservoir  42 . Attached to the reservoir base  47  opposite to the inner and outer tubes ( 43  and  45 ) is a valve assembly  59  having a solenoid valve  85  and a reservoir orifice  44 . Actuation of the solenoid valve  85  is accomplished by the attached solenoid  46 . The hydraulic reservoir  42  can be in fluid communication with the valve assembly  59  through a port  57  located on the wall of the reservoir base  47  where it is attached to the valve assembly  59 . An inlet channel  84  and an outlet channel  88  within the valve assembly  59 , in combination with the reservoir orifice  44  and the solenoid valve  85 , provides selective fluid communication between the outside of the valve assembly  59  to the hydraulic reservoir  42 . Selective fluid communication through the valve assembly  59  is accomplished by positioning the solenoid valve  85  so that the elastic rings  86  disposed on the outer circumference of the solenoid valve  85  coincide at the points where the inlet and outlet channels ( 84  and  88 ) enter the solenoid chamber  89 .  
         [0035]     In more detail, the solenoid chamber  89  within the valve assembly  59  should be formed for insertion of the solenoid valve  85  and also provide a fluid flow path over the solenoid valve  85  when it is in the open position and the elastic seals  86  are not plugging the inner or outlet channels ( 84  and  88 ). As can be readily understood by those skilled in the art, translational actuation of the solenoid valve  85  in and out of the solenoid channel  89  can in turn provide for fluid flow, or block fluid flow, through the valve assembly  59 . Although not shown in  FIG. 5 , the outlet channel  88  is in fluid communication with the reservoir orifice  44 . Similarly, the inlet channel  84  is in fluid communication with the hydraulic reservoir  42 .  
         [0036]     The embodiment of the rotating tool  10  of  FIG. 2  terminates with a stationary assembly  50 . The stationary assembly  50  comprises a pressure equalizing system and a connection point between the rotating tool  10  and remaining components of the tool string  3 . A pair of cascading surfaces ( 66  and  68 ) provides connection points for connecting the stationary assembly  50  to the rotating tool  10  and for securing one end of the sleeve  26 . The first cascading surface  66  should extend away from the stationary assembly  50  up towards the hydraulic assembly  30 . Like the recessed ledge  15  of the rotor  12 , the outer radius of the first cascading surface  66  should be recessed inward from the outer circumference of the rest of the stationary assembly  50  so that the inner circumference of the sleeve  26  can snugly fit over the outer surface of the first cascading surface  66 . Further, also similar to the recessed ledge  15 , the first cascading surface  66  should include at least one bolt hole  23  so that a fastener (not shown) can be used to secure the sleeve  26  to the stationary assembly  50 . Like the first cascading surface  66 , the second cascading surface  68  should extend away from the stationary assembly  50  up towards the hydraulic assembly  30 . Preferably at least two connector rods  48  are connected to the second cascading surface  68  and the outer radius of the hydraulic reservoir  42 . To accommodate the presence of the connector rods  48 , the radius of the second cascading surface  68  should be sized to prevent the connector rods  48  from interfering with placement of the sleeve  26  onto the rotating tool  10 .  
         [0037]     Optionally, stator pistons  54  can be included with the stator  51  inside of stator pressure ports  52 . Preferably the stator pistons  54  are disk like in shape and have a circular outer surface. Consequently the pressure ports  52  should be formed with corresponding circular walls to allow free travel of the stator pistons  54  along the respective lengths of the pressure ports  52 . The pressure ports  52  should be formed within the stator  51  and along its axis.  
         [0038]     The stationary assembly  50  can provide a means for attaching remaining elements of a tool string  3  within a wellbore  5 . In the embodiment of  FIG. 2 a  connector  58  is illustrated that connects a gyroscope  56  to the rotating tool  10 . It is important that the connector  58  that secures the rotating tool  10  to the gyroscope  56  or other devices are rigid and not susceptible to any twisting, elongation, or contraction that might skew the gyroscope readings. Examples of suitable connectors  58  are any type of threaded connection, such as a threaded pipe, that is capable of providing a relatively stiff and unyielding connection between the gyroscope  56  and the rotating tool  10 .  
         [0039]     As far as the materials of the rotating tool  10 , most of the components can be made of  4140  carbon steel, or any number of other suitable alloys. However, due to the forces involved and the harsh downhole environment, it is preferred that the lead screw  16  be made from 5160 carbon steel, the spring  14  be made with chrome vanadium, and that the bearings, and associated races be made from Timken 52100. Timken 52100 is available from The Timken Company, 1835 Dueber Ave. SW, P.O. Box 6932, Canton, Ohio.  
         [0040]     In operation, before the rotating tool  10  is connected (or made up) to the tool string  3 , the compression assembly  22  is put into the cocked position. Cocking the compression assembly  22  involves urging the collar  24  upward towards the rotor  12  thereby contracting the spring  14  into a compressed position. This is accomplished by rotating the lead screw  16  that in turn draws the piston  32  upward towards the rotor  12  as the piston  32  rides on the threads of the lead screw  16 . The rotational movement of the lead screw  16  is converted into translational movement due to the interaction of the corresponding threads located on the lead screw  16  and the piston head  34 . Since the piston head  32  and the thrust cup  20  are attached on opposite ends of the collar  24 , upward movement of the piston head  32  produces upward movement of the thrust cup  20 . Thus urging the piston head  32  upward by rotating the lead screw  16  necessarily results in compression of the spring  14 . The compression nut  21  that is provided on the shaft of the lead screw  16  can be rotated with a wrench or other tool to manually rotate the lead screw  16 .  
         [0041]     The amount of compression applied to the spring  16  will depend on the particular spring employed and the application of the rotating tool  10 , however it is believed that the amount of compression can be determined by those skilled in the art without undue experimentation. When the cocking procedure has been completed and the spring  14  has been compressed to the desired amount, a signal is sent to the solenoid  46  that closes the solenoid valve within the valve assembly  59 . Once the solenoid valve is closed the fluid is sealed within the hydraulic assembly  30 . After the solenoid valve is fully closed, the cocking force applied to compress the spring  14  can be released. As long as the fluid is sealed within the hydraulic assembly  30  by the closed solenoid valve, the piston  32  is prevented from moving downward within the annulus  49 . Thus closing the solenoid valve also operates to maintain the spring  14  in the compressed state thereby storing potential mechanical energy within the spring  14 .  
         [0042]     To prevent producing a vacuum within the hydraulic assembly  30  during the cocking procedure, the solenoid valve should be put into the open position to allow fluid communication between the outside of the valve assembly  59  and the hydraulic reservoir  42 . This should be done prior to actuating the lead screw  16 . Fluid, preferably hydraulic fluid, is supplied to the reservoir orifice  44  as the piston  32  is drawn upward by the rotation of the lead screw  16 . The fluid supplied to the reservoir orifice  44  migrates through the valve assembly  59  and into the hydraulic reservoir  42  during the cocking procedure. From the hydraulic reservoir  42  the fluid can flow through the openings  55  in the reservoir base  47  into the annulus  49 . As previously noted, actuation of the solenoid valve is accomplished by energizing the solenoid  46 , preferably by the well known method of supplying an electrical current to the solenoid  46  through conducting wire  71  from an electrical current source (not shown). However, the manner of supplying current to the solenoid  46  can be any known or later developed method.  
         [0043]     After the rotating tool  10  is cocked, it can be combined with other devices in a tool string  3 . In the embodiment of rotating tool  10  displayed in  FIG. 1 , the rotating tool  10  can be combined with a gyroscope  56  and a perforating gun  80 . It is important though that the connectors  58  used to couple the tool string  3  be rigid and not susceptible to any twisting or elongation. Once the tool string  3  is assembled it can be deployed into the wellbore  5  to the depth where it is to be used.  
         [0044]     While the anchor  62  generally inhibits rotation of the tool string  3  within the wellbore  3 , the tool string  3  will experience some rotation during its descent into the wellbore  3 . As stated above, the effectiveness of some downhole tools is dependent upon their azimuthal orientation; which is especially true with perforating guns  80 . Rarely will the tool string  3  be in the desired azimuthal orientation when lowered to the depth for use of the particular downhole tool, thus the tool string  3  will typically require some rotating in order to position it in the desired orientation. Before the tool string  3  is rotated, the attached gyroscope  56  measures the actual azimuthal orientation of the tool string  3 . The orientation measurement is then transmitted via the wireline  7  to the surface. Surface personnel can then compare the actual orientation versus the desired orientation and determine the angular variance between the two orientations.  
         [0045]     Rotation of the rotating tool  10  can be initiated by energizing the solenoid  46  thereby opening the solenoid valve. When the solenoid valve is put into the open position, the fluid within the hydraulic assembly  30  can flow out of the annulus  49  and the hydraulic reservoir  42  through the reservoir orifice  44  into the space outside of the valve assembly  59  and within the sleeve  26 . Allowing the fluid to exit the hydraulic assembly  30 , combined with the mechanical energy stored in the spring  14 , produces movement of the piston  32  downward into the annulus  49  towards the reservoir base  47 . As the piston  32  moves downward the interaction of the threads  17  on the lead screw  16  with the threaded aperture  36  on the piston head  34  produces a rotation of the piston  32  with respect to the lead screw  16 . Since the lead screw  16  is held stationary by virtue of its connection to the anchor  62 , the piston  32  rotates as it moves along the threaded portion of the lead screw  16 . Further, as the piston  32  moves downward within the sleeve  26 , the keys  35  that jut radially outward from the piston head  34  impart a corresponding rotational force on the sleeve  26  while sliding downward within the vertical slot. The rotational force applied to the sleeve  26  by the piston head  34  and keys  35  is sufficient to rotate the sleeve  26 . Since the sleeve  26  is a mechanically fastened integral part of the rotating tool  10 , rotation of the sleeve  26  in turn causes rotation of the rotating tool  10 .  
         [0046]     While the solenoid valve is opened, a series of data pulses are transmitted to surface personnel that are operating the rotating tool  10 . Calibration of the rotating tool  10  can be accomplished in any one of a number of ways, such as by positioning the gyroscope  56  to point to a true north, rotating the rotating tool  10  until the gyroscope  56  is pointing to another known direction, such as east, and counting the number of data pulses received. Azimuthal orientation can be determined by the data being transmitted back to the surface or acquisition system and interpreted by a person skilled in the art. As soon as it is determined that the rotating tool  10  has rotated into the desired orientation, another command can be issued by the operational personnel to close the solenoid valve, thereby ceasing rotation. The orientation can be verified by taking another reading with the gyroscope  56  thereby ensuring that the downhole tool is oriented in the proper azimuthal angle. If the proper angle has been achieved, the downhole tool can be actuated, if not, the orientation process can be repeated.  
         [0047]     The present invention described herein, therefore, is well adapted to carry out the objects and attain the ends and advantages mentioned, as well as others inherent therein. While a presently preferred embodiment of the invention has been given for purposes of disclosure, numerous changes exist in the details of procedures for accomplishing the desired results. For example, the spring  14  can be replaced with some other device capable of imparting a pushing force against the piston. Examples include Bellville washers, a pressurized cylinder filled with gas or fluid, and a coiled spring. These and other similar modifications will readily suggest themselves to those skilled in the art, and are intended to be encompassed within the spirit of the present invention disclosed herein and the scope of the appended claims.