Patent Publication Number: US-7581601-B2

Title: Drill cuttings re-injection system

Description:
CROSS REFERENCE TO RELATED APPLICATION 
   This application is a non-provisional utility application claiming priority to U.S. Provisional patent application No. 60/684,099, entitled, “Drill Cuttings Re-injection Systems,” by Andy Dyson, Tom Robertson, and Marcio Laureano, filed May 24, 2005, incorporated by reference herein in its entirety. 

   BACKGROUND OF THE INVENTION 
   1. Field of the Invention 
   The present invention relates generally to a system used to re-inject drilling cuttings or drilling slurry into an annulus in a subsea well. The present invention provides a system for a providing an increased re-injection rate into a pressure containing conduit while minimizing erosion caused by the flow of the re-injected drill cuttings. The present invention discloses configuring the re-injection inlet into a pressure containing conduit such that a cyclone effect is produced in the flow path of the drill cuttings, which minimizes erosion and may eliminate the need to hard face components of the system. 
   2. Description of the Related Art 
   Environmental concerns can be an important issue in the drilling of subsea wells in different regions of the world. In particular, one environmental concern is the storage and safe disposal of cuttings produced during the drilling of subsea wells. Some regions with high particularly high environmental standards are the artic sector and the Norwegian sector of the North Sea. Regulatory requirements have been introduced in the Norwegian sector that would allow for the re-injection of drilling cuttings into the formation while the well is still being drilled. 
   When drilling a subsea well, drilling mud is used to bring the drill cuttings to the surface where the mixture of drilling mud and cuttings, or slurry, may be filtered and stored. After being filtered, the slurry must be stored or disposed in accordance with environmental regulations of the region. As discussed above, one acceptable form of storage is the re-injection of the slurry into the well formation. The re-injection of slurry can be a complex process and can greatly increase the drilling time, and thus increase the cost spent on drilling a well. 
   When re-injecting slurry into the well formation for storage the re-injection flow rate may be increased in an attempt to reduce the time that a drilling vessel needs to remain at a well. On disadvantage to increasing the re-injection flow rate is the increase in erosion of components used in the re-injection system. Slurry is a rather abrasive mixture as it contains drillings as well as potentially containing pieces broken off the drilling bit. Increased erosion decreases the useable life of a re-injection system and potentially could lead to failure during use. Although it is desirable to increase the re-injection flow rate, it must be balanced with the erosion caused by the re-injected slurry. 
   The re-injection of slurry into a well formation may also lengthen the overall drilling time if the well cannot be drilled simultaneous to the re-injection of the slurry. In this instance the re-injection of slurry may be too costly to the overall drilling of a well. The modification of an existing wellhead to enable the use of a re-injection system may also increase the drilling costs per well. The re-injection system may also require a special running tool to install the system onto a subsea wellhead. The special running tool would also be an additional cost to a drilling company as well as the additional time and cost to train personal to use the special running tool. For these reasons, drilling companies may not be interested in using a re-injection system. 
   The re-injection of slurry into an annulus of the well formation may cause undue wear on well components. For example, the slurry may be injected in an annulus that is between an inner casing and injection mandrel with the slurry being injected from the mandrel side towards the casing. The opening in the injection mandrel may cause the slurry to flow directly at the inner casing potentially causing erosion the inner casing. This possibility of erosion requires hard facing of the inner casing in an attempt to prevent undesirable erosion and possibly failure caused by the flow of the slurry. Hard facing of the casing is expensive and adds to the overall drilling costs associated with the well. 
   During the drilling stage, the primary function of the well formation is to allow the drilling of the well to begin the production of hydrocarbons. A re-injection system that also utilizes the well formation to store drill cuttings may interfere with the drilling process causing the operators to switch between the two functions. Doing so would lengthen the time required to drill the well, thus increasing the overall drilling costs. To minimize costs, it would be beneficial if the re-injection system allowed for the injection of cuttings for storage while the well was being drilled. One possible problem is the transfer of drilling mud to the drilling site. The mud may have to travel through the re-injection system. It would be beneficial if a re-injection system allowed for the re-injection of slurry into the well while allowing for the passage of drilling mud downhole. 
   In light of the foregoing, it would be desirable to provide a re-injection system that is adapted to store drill cuttings and/or slurry in an annulus of the well formation. It would further be desirable that the re-injection system may be connected to existing well head designs. It would also be desirable to provide a re-injection apparatus that provides for an increased diameter flow path thus allowing an increased flow of slurry, but also an apparatus that is configured such that the flow of slurry causes minimal erosion to the components of the apparatus. Additionally, it would be desirable to provide an injection system that has balanced injection ports that minimize the erosion on the boundary elements of the storage annulus. It would also be desirable to provide a re-injection system that may allow the drilling of the well concurrent to the injection of slurry within the well formation. Further, it would be desirable for the system to allow for the flow of material, such as drilling mud or cement, through the injection system to downhole locations without interrupting the re-injection of the slurry. 
   The present invention is directed to overcoming, or at least reducing the effects of, one or more of the issues set forth above. 
   SUMMARY OF THE INVENTION 
   The present application discloses a system or apparatus to re-inject drill cuttings into a well formation for storage. In particular, a pressure containing conduit is disclosed with the provision for a remotely operated subsea connection for the re-injection of drill cuttings. 
   In one embodiment, the system to re-inject cuttings comprises at least one injection inlet, a drilling guide base, an injection adapter ring within the drilling guide base, an injection mandrel within the injection adapter ring, and an inner casing. The at least one injection inlet is in fluid communication with at least one flow path of the drilling guide base, which in turn is in fluid communication with a circular gallery of the injection adapter ring. The injection mandrel includes at least one injection port that is in communication with the circular gallery. The inner casing of the system creates an annulus between the inner casing and the injection mandrel, wherein cuttings may be injected into the annulus through the at least one injection port. The injection inlet may be positioned relative to the circular gallery such that a cyclone effect is created within the gallery. The drilling guide base may be adapted to connect to a conventional subsea wellhead. This system may also be used to inject other materials or media for the storage and disposal as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. 
   The at least one injection port of the injection mandrel may be adapted to reduce erosion of the injection mandrel due to the flow of the drill cuttings. For example, the injection port may be angled to align with the flow of the drill cuttings. Additionally, the entrance into the injection port may include rounded corners. The injection mandrel may include at least one flow-by-port to allow the passage of material through the injection mandrel. The at least one flow-by port may allow the passage of cement and/or drilling mud through the injection mandrel without interfering with the re-injection of drill cuttings. 
   In one embodiment, the system includes multiple injection inlets and the injection mandrel includes multiple injection ports. The multiple injection inlets and multiple injection ports may be balanced to within the system to reduce erosion on the inner casing due to the re-injection of drill cutting and/or slurry. 
   The re-injection system may include an isolation sleeve that is positioned between the drilling guide base and the injection adapter ring. The isolation sleeve may be adapted to move from a first position to a second position, such that when in the second position the isolation sleeve blocks the fluid flow path between the drilling guide base and the circular gallery of the injection adapter ring. The sleeve may be used to block the fluid flow path into the injection adapter ring when the drilling of the well has been completed. Shear pins may be used to secure the isolation sleeve in both its first position and a detent ring may hold the isolation sleeve in its second position. 
   The injection system may include a second inner casing within the first inner casing that allows for the drilling to be performed simultaneous to the re-injection of drill cuttings in the annulus between the first inner casing and the injection mandrel. In one embodiment, the first inner casing may be a 13⅜″ casing and the second inner casing may be 10¾″ casing. The injection inlet may have at least a 4″ inner diameter. The injection mandrel may be an 18¾″ mandrel. The actual dimensions components of the re-injection system, such as the inner casings, injection inlet, and injection, could be varied depending on application and necessary flow rate as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. 
   In one embodiment, an apparatus is provided for the re-injection of drill cuttings into a well formation comprising a pressure containing conduit, means for injecting drill cuttings into a flow path of the pressure containing conduit, means for creating a cyclone effect within the flow path of the pressure containing conduit, a first annulus, a second annulus, and means for directing the flow of drill cutting into the first annulus. The means for injecting drill cuttings into a flow path of the pressure containing conduit may include a single injection inlet or multiple injection inlets. The injection inlets may be positioned at opposite sides of the pressure containing conduit. The means for injection drill cuttings includes injection inlets may be configured to have a large flow path such as having a four inch inner diameter. The large flow path of the apparatus may allow the apparatus to inject various materials or media into the well formation for storage and disposal. The pressure containing conduit may include a circular flow path around the conduit. The means for creating a cyclone effect may include the positioning of the means for injecting drill cuttings relative to the circular flow path such that a cyclone effect is created within the conduit. The second annulus of the pressure containing conduit is located within the first annulus of the pressure containing conduit. The means for directing the flow of drill cutting into the first annulus may include an injection mandrel contained within the pressure containing conduit. The injection mandrel may include at least one injection port, wherein the at least one injection port is in communication with the first annulus and the at least one injection port is configured to direct the flow of the drill cuttings into the first annulus. 
   The apparatus may further include means for the passage of material through the apparatus to a downhole location. The means may include by-pass ports located within the injection mandrel that allow for the passage of material through the injection mandrel without interrupting the injection of drill cuttings through the injection ports into the first annulus. The apparatus may further include means for preventing the injection of drill cuttings into the flow path of the pressure containing conduit. The means may include a sleeve that is positioned on the outside of the pressure containing conduit. The sleeve may be movable between a first position and a second position, wherein in the second position the sleeve blocks a flow inlet into the pressure containing conduit. 
   In another embodiment, a method is disclose to inject a slurry into a wellbore annulus comprising the steps of filtering the slurry of drilling mud and drill cuttings and pumping the filtered slurry through at least one injection inlet into a pressure containing conduit, the at least one inject inlet being in fluid communication with a flow path within a drilling guide base. The method further includes the steps of pumping the filtered slurry through the flow path of the drilling guide base to a circular gallery of an injection adapter ring and circulating the filtered slurry around the circular gallery, which is in fluid communication with at least one injection port of an injection mandrel. The method also includes the step of directing the filtered slurry through the at least one injection port to an annulus formed between the injection mandrel and an inner casing within the pressure containing conduit. 
   The method may further include the step of moving an isolation sleeve to block the fluid communication between the drilling guide base and the injection adapter ring. The method may include an injection inlet that is positioned relative to the circular gallery of the injector adapter ring such that a cyclone effect is created within the fluid flow path. The method may further include the step of drilling the wellbore while filtered slurry is re-injected into the annulus formed between the injection mandrel and an inner casing. The at least one injection port of the injection mandrel may be adapted to minimize erosion to the injection mandrel. The injection mandrel may include at least one bypass port and the method may further include the step of pumping material through the at least one bypass port. 
   Another embodiment disclosed is directed to a system for storing the drilling slurry from multiple subsea wells of a template or system. One well of the template or system may be adapted to store drilling slurry comprising at least one injection inlet, a template receptacle, a sliding sleeve bore protector, an injection adapter ring, an injection mandrel, and an inner casing that forms an annulus with the injection mandrel. Drilling slurry may enter the well through the at least one injection inlet. The template receptacle may include at least one flow path in communication with the at least one injection inlet and the injection adapter ring may include a circular gallery that is in fluid communication with the at least one flow path of the template receptacle, such that drilling slurry may flow from the at least one injection inlet to the circular gallery. The injection mandrel has at least one injection port that may be in fluid communication with the circular gallery and allows the injection of drilling slurry to be injected into the annulus between the inner casing and the injection mandrel. The sliding sleeve bore protector may be adapted to block fluid communication between the circular gallery of the injection adapter ring and the at least one flow path of the template receptacle. 
   The system may include at least a second well adjacent to the well adapted to store drilling slurry, wherein drilling slurry from the second well may be brought to the surface to be filtered. The system also includes a first fluid conduit for the transportation of the filtered drilling slurry to the at least one injection inlet of the well adapted to store the drilling slurry. The system may further comprise a second fluid conduit for the transportation of filtered drilling slurry from a third well to the at least one injection inlet for the re-injection of the filtered slurry. 
   Another embodiment of the present disclosure is a method of installing a re-injection system on a subsea wellhead. The method comprising connecting a sliding sleeve to an interior surface of an injection adapter ring, wherein the adapter ring has an interior bore and the sliding sleeve is movable from a first closed position to a second open position. The slidable sleeve protects the sealing surface on the interior bore of the injection adapter ring. The method may also include installing the injection adapter ring onto a template receptacle that includes an injection flow loop and a sliding sleeve, wherein the adapter ring moves the sliding sleeve to the open position. The method may also include using the slidable sleeve in the first position to pressure test the injection flow loop, running an injection mandrel down to the injection adapter, wherein the injection mandrel includes a test plug, and landing the injection mandrel on the slidable sleeve, wherein the slidable sleeve is moved to the second position. The method of installing a re-injection system on a subsea wellhead may further comprise the step of using the test plug to pressure test the injection mandrel. 
   Another embodiment of a method of installing a re-injection system on a subsea wellhead is disclosed. The method comprising connecting a sliding sleeve to an exterior surface of an injection adapter ring, wherein the adapter ring has an interior bore and the sliding sleeve is movable from a first closed position to a second open position. The method includes connecting a slidable sleeve to the interior bore of the adapter ring, wherein the slidable sleeve may be moved from a first position where it protects a sealing surface on the interior bore of the injection adapter ring to a second position. The method may also include installing the injection adapter ring onto a drilling guide base that includes an injection flow loop, wherein the exterior sliding sleeve of the injection adapter ring moves to the open position. The method may also include running the drilling guide base down to a conductor housing, installing the drilling guide base on the conductor housing, using the slidable sleeve in the first position to pressure test the injection flow loop, running an injection mandrel down to the injection adapter, wherein the injection mandrel includes a test plug, and landing the injection mandrel on the interior slidable sleeve of the injection adapter ring, wherein the interior slidable sleeve is moved to the second position. The method may also include the step of removing the drilling guide base from the wellhead, wherein the exterior sliding sleeve moves to the closed position. 
   In one embodiment, a network of multiple subsea wells may be adapted to re-inject drill cuttings into a pressure containing conduit of one of the wells that has been adapted to inject and store drill cuttings. The one well may include an injection inlet, a flow path through the well formation, and an annulus within the well, wherein the flow path connects the annulus to the injection inlet. The one well may also include an isolation sleeve that prevents the injection of drill cuttings when the isolation sleeve is in a closed position. The flow path of the one well may be maximized to accommodate the flow of drill cuttings from multiple wells from the network. Additionally, the configuration of the flow path may create a cyclone effect within the flow path to minimize erosion due to the re-injection of the drill cuttings. A second well of the network may also be adapted to store drill cuttings from the system. The second well would be adapted to comprise the same drill cutting re-injection system as the first adapted well. Each of the wells of the network may be fluid connected to the injection inlets of both the first and second adapted wells to allow for the re-injection of drill cuttings from the entire network into either the first or the second well. 

   
     BRIEF DESCRIPTION OF THE DRAWINGS 
       FIG. 1  is a top view cross-section of one embodiment of the re-injection system  150  of the present disclosure. 
       FIG. 2  is a side view cross-section of the one embodiment of the re-injection system  150  of the present disclosure. 
       FIG. 3  is a top view cross-section of an embodiment of the re-injection system  150  having two opposing injection inlets  10 . 
       FIG. 4  is an isometric cut-away view of one embodiment of an injection mandrel  50  of the present disclosure. 
       FIG. 5  is an isometric cut-away view of one embodiment of an injection adapter ring  20  of the present disclosure. 
       FIG. 6  is an isometric cut-away view of the re-injection system  150  with the isolation sleeve  40  in the closed position. 
       FIGS. 7A-7D  show the movement of the isolation sleeve  40  when the injection sleeve  5  of the drilling guide base is removed from the wellhead. 
       FIG. 8  is an isometric view one embodiment of the drilling guide base  200  of the present disclosure. 
       FIG. 9  shows an embodiment of the present disclosure that includes a sliding sleeve bore protector  320  in a satellite installation of the drilling guide base  200 . 
       FIG. 10  shows the embodiment of  FIG. 10  with the injection mandrel  50  landed within the re-injection system on the sliding sleeve bore protector. 
       FIG. 11  shows an embodiment of the present disclosure that includes a template receptacle sliding sleeve bore protector  330  as well as a sliding sleeve bore protector  320  in a template installation of the drilling guide base  200 . 
   

   While the invention is susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and will be described in detail herein. However, it should be understood that the invention is not intended to be limited to the particular forms disclosed. Rather, the intention is to cover all modifications, equivalents and alternatives falling within the spirit and scope of the invention as defined by the appended claims. 
   DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS 
   Illustrative embodiments of the invention are described below as they might be employed in the use a system to re-inject drilling cutting back into a subsea formation. In the interest of clarity, not all features of an actual implementation are described in this specification. It will of course be appreciated that in the development of any such actual embodiment, numerous implementation-specific decisions must be made to achieve the developers&#39; specific goals, such as compliance with system-related and business-related constraints, which will vary from one implementation to another. Moreover, it will be appreciated that such a development effort might be complex and time-consuming, but would nevertheless be a routine undertaking for those ordinary skill in the art having the benefit of this disclosure. 
   Further aspects and advantages of the various embodiments of the invention will become apparent from consideration of the following description and drawings. 
     FIG. 1  shows the top view cross-section of a re-injection system  150  of the present disclosure. The re-injection system  150  includes an injection sleeve  5  of a drilling guide base  200 . The drilling guide base  200  (shown in  FIGS. 2 and 9 ) is adapted to be connected to conventional well heads and does not require the re-design of a new well head. The drilling guide base includes an injection sleeve  5  and an injection inlet  10 . The injection inlet  10  includes a flow path  7  that allows for the flow of material from an injection source  8  through the injection inlet  10  and the injection sleeve  5 . The injection inlet  10  is connected to an injection source  8 , which may be in fluid communication with the surface to provide for the re-injection of filtered slurry, which includes drill cuttings. The drill cuttings may be filtered at a surface location by means known to those of ordinary skill in the art. Various means could connect the injection inlet  10  to a source of filtered slurry as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. The injection inlet  10  provides for the re-injection of the cutting into the remainder of the system through above referenced flow path  7 . 
   The flow path  7  of the injection sleeve  5  is in communication with an opening  15  of an injection adapter ring  20  positioned within the injection sleeve  5 . The opening  15  is in fluid communication with a circular gallery  25  of an injection adapter ring  20 . The circular gallery  25  circumscribes the inner diameter of the injection adapter ring  20  and provides a flow path for the re-injected slurry. As would be appreciated by one of ordinary skill in the art, the dimensions of the circular gallery could be varied depending on the desired flow rate of the slurry through the re-injection system. 
   The re-injection system of  FIG. 1  includes an isolation sleeve  40 . The operation of the isolation sleeve  40 , also referred to as a shut off sleeve, is described below in references to  FIGS. 7A-7D . The isolation sleeve  40  is adapted to move between a first position and a second position when the drilling guide base  200  is removed. In the second position, isolation sleeve  40  blocks flow path  7  from communication with the opening  15  in the injection adapter ring  20  preventing the re-injection of slurry into the re-injection system  150 . The isolation sleeve  40  may be moved into the second position to temporarily stop the re-injection of slurry or may be may be moved into the second position upon the completion of drilling the well bore by removal of the drilling guide base  200 . The isolation sleeve may be slidably connected to the injection sleeve  5  and/or the injection adapter ring  20 . 
   The injection adapter ring  20  is connected to the conductor housing and includes a circular gallery  25  that circumscribes the inner diameter of the injection adapter ring  20 . The circular gallery  25  is positioned to align with the flow path  7  of the injection sleeve  5 . The circular gallery  25  provides a flow path for the slurry around the inner portion of the injection adapter ring  20 . The shape and dimensions of the circular gallery may be varied to allow different flow rates of re-injected slurry as would be appreciated by one of ordinary skill in the art. In one embodiment, the injection adapter ring  20  may be a 30″ ring. 
   In the injection system  150  of  FIG. 1 , an injection mandrel  50  is located within the injection adapter ring  20 . The injection mandrel  50  includes injection ports  30 . As shown in  FIG. 1 , the injection mandrel may include two injection ports  30  that are in fluid communication with the circular gallery  25  of the injection adapter ring  20 . The injection ports  30  may be balanced around the perimeter of the injection mandrel  50  to help minimize the amount or erosion caused by the flow of slurry within the system. Additionally, the injection ports  30  may be configured to reduce erosion caused by the flow of slurry past the injection mandrel  50 . For example, the entrance into the injection ports may be rounded and/or the ports may be angled or aligned with the flow path to minimize erosion. The number and configuration of injection ports  30  may be varied to provide multiple injection points around the injection mandrel  50  as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. The injection mandrel  50  of  FIG. 1  includes flow-by ports  55  that allow for the passage of material, such as cement or drilling mud, to pass through the re-injection system  150  without interrupting the re-injection of slurry. 
   The injection ports  30  of the injection mandrel  50  are in communication with an annulus  57  between the injection mandrel  50  and an inner casing  60  (Shown in  FIGS. 3 and 4 ). The injection ports  30  are configured to direct the flow of slurry into the annulus  57 . The annulus  57  is used to store the slurry containing the drill cuttings in the well formation preventing potential environmental contamination by the drill cuttings. The opening size of the injection ports  30  could be varied to affect the flow rate into the annulus  57  as would be recognized by one of ordinary skill in the art having the benefit of this disclosure. 
     FIG. 2  shows a side view cross-section of an injection system  150  of the present disclosure. A drilling guide base  200  may be connected to the conductor housing. The drilling guide base  200  includes an injection sleeve  5 . An isolation sleeve  40  is positioned between the injection sleeve  5  and an adapter injection ring  20 . The isolation sleeve  40  may be movable connected to the injection sleeve  5  and the adapter injection ring  20  such that isolation sleeve may be moved to prevent fluid communication between a flow path in the injection sleeve  5  and a flow path in the injection adapter ring  20 . 
     FIG. 3  shows a top view cross-section of an embodiment of the re-injection system  150  wherein the injection mandrel  50  has four injection ports  30 . In this embodiment there are two injection inlets  10  from which slurry may enter into the system. The injection inlets  10  may be positioned on opposite sides of the re-injection system, thus injection slurry into the system  150  in opposite directions. The location of the injections inlets  10  creates a cyclone effect within the circular gallery  25  of the injection adapter ring  20 . The cyclone effect helps to minimize erosion as the slurry circles the gallery  25  and is directed into the annulus  57  by injection means. The injection means may be injection ports  30 . 
   As shown in  FIG. 3 , the injection mandrel  50  may include four injection ports  30  angled to direct the flow of slurry into the annulus  57 . The configuration of injection ports  30  may be balanced around the injection mandrel  50  to minimize erosion of the inner casing  60  due to the injection of slurry into the annulus  57 . As shown, the flow  35  of the slurry is directed into the annulus  57  by the injection ports  30 . A second inner casing  70  may be provided located within inner casing  60  creating a second annulus  58 . As shown, two bypass ports  55  may be provided between each of the injection ports  30 . The bypass ports  55  may allow the passage of material past the injection mandrel  50  without interruption to the injection of slurry into the annulus  57 . 
     FIG. 4  shows a cut-away view of one embodiment of an injection mandrel  50 . The injection mandrel  50  includes an injection port  30  which is in communication with a fluid flow path  31  around the injection mandrel  50 . The injection port  30  is also in fluid communication with the inner cavity  32  of the injection mandrel  50 . When installed in the re-injection system, the inner wall  33  of the injection mandrel  50  creates an annulus  57  with an inner casing  60 . The fluid flow path  31  of the injection mandrel  50  is in fluid communication with the circular gallery  25  of the injection adapter ring providing a flow path that allows the re-injected slurry to travel around the injection mandrel  50 . The injection port  30  may be adapted to direct flow of the slurry through the injection port and into the annulus  57 . The injection mandrel  50  also includes bypass ports  55  located around the perimeter. The bypass ports  55  allow for the passage of material past the injection mandrel  50  without interfering with the re-injection of slurry through injection ports  30  into the annulus  57 . Although only one injection port  30  is shown in  FIG. 4 , the number, location, and configuration of the injection ports  30  could be varied as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. The injection mandrel  50  also includes sealing means  51  to provide a sealing connection with the injection adapter ring  20  of the re-injection system  150 . 
     FIG. 5  shows one embodiment of the injection adapter ring  20  of the present disclosure. The injection adapter ring  20  includes opening  15 , which is in fluid communication with circular gallery  25  that circumscribes the perimeter of the injection adapter ring  20 . When assembled as part of the re-injection system  150 , the circular gallery  25  is in fluid communication with the fluid flow path  31  and injection ports  30  of the injection mandrel  50 . The opening  15  of the injection adapter ring  20  is also in fluid communication with the fluid flow path  7  of the injection sleeve  5  as discussed above. The injection adapter ring  20  includes sealing means  21  to provide a sealing connection with the injection sleeve  5  of the drilling guide base  200 . 
     FIG. 6  is a cross-section showing the isolation sleeve  40  in a closed position preventing the injection of slurry into injection adapter ring  20 . Isolation sleeve  40  includes an opening  45  and is slidable connected to the injection adapter ring  20 . When in the closed position, the opening  45  of the isolation sleeve  40  is no longer in fluid communication with the opening  15  of the injection adapter ring  20 . As shown in  FIG. 6 , the opening  15  of the injection adapter ring  20  is in fluid communication with a circular gallery  25  as well as an injection port  30  of an injection mandrel  50 . The isolation sleeve  40  may be held in to closed position by a detent ring, as shown in  FIG. 7D . 
     FIGS. 7A-7D  show the retrieval of the drilling guide base once the drilling operations are concluded and there is no further need to re-inject drill cuttings into the wellhead. The drilling guide base running tool  300  (shown in  FIG. 9 ) is run to retrieve the drilling guide base  200 . The running tool  300  unlatches the drilling guide base  200  from the conductor housing. As shown in  FIG. 7B , as the drilling guide base  200  moves upwards away from the wellhead the injection sleeve  5 , pulls the isolation sleeve  40  upwards. Shear pins  85  connect the isolation sleeve  40  to the injection sleeve  5 . The isolation sleeve  40  includes a recessed portion  86  adapted to receive a detent ring  90  positioned on the exterior of the injection adapter ring. Once the detent ring  90  engages with the recess  86 , the ring will close the sleeve and the sleeve shoulders out on an edge on the injection adapter ring allowing the shear pins to shear, thus releasing the drilling guide base  200  from the conductor housing. As shown in  FIG. 7C , the shear pin  85  breaks allowing the injection sleeve  5  to move upwards with respect to the isolation sleeve  40 , which remains connected to the injection adapter ring  20 . The isolation sleeve  40  seals the inlet in the injection adapter ring  20 , as discussed above. After the shear pin  85  has sheared the drilling guide base  200  may be removed from the wellhead as shown in  FIG. 7D . 
     FIG. 8  is an isometric bottom view of the drilling guide base  200 . The drilling guide base  200  includes an injection sleeve  5  that connects to the injection adapter ring when installed onto the wellhead. The drilling guide base  200  shown also includes two injection inlets  10  one the same side of the injection sleeve  5  that are in communication with a flow path through the injection sleeve  5 . The location and number of injection inlets may be varied within the invention as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure. The drilling guide base  200  also includes a slurry injection valve system to control the injection of slurry into the re-injection system. The valve may allow for the remote control of the re-injection system. The drilling guide base  200  also includes support legs  100  for support of the guide on the wellhead. The drilling guide base may be installed onto a wellhead in a number of different ways. 
   In a satellite application, the drilling guide base  200  may be previously installed onto an injector adapter ring  20  that then may be run to the wellhead. Alternatively, the drilling guide base may be run remotely and attached to the injector adapter ring  20 . In both instances, the drilling guide base  200  may be retrieved from the wellhead prior to completion of the well. 
   The pressure integrity of the injection adaptor ring  20  may be maintained by an external shut-off sleeve (see  FIGS. 7A-7D ) which seals the injection adapter ring inlet  15  when the drilling guide base  200  is no longer attached to the conductor housing. When the drilling guide base  200  is attached it pushes the external shut-off sleeve  40  to the open position providing communication between the injection inlet  10  and the circular gallery  25  of the injection adaptor ring  20 . The interface between the drilling guide base  200  and the injection adaptor ring  20  is such that the sleeve  40  is automatically opened when the drilling guide base  200  is installed and closed when the drilling guide base  200  is removed. This may be in conjunction with control valves positioned in the flow loop to control any pressure which may appear in the re-injection system  150 . 
   To prevent damage to the internal sealing surfaces on the injection adaptor ring  20 , a sliding sleeve bore protector (SSBP)  320  may be included in the system as shown in  FIG. 9 . The SSBP  320  is designed such that it is positioned to protect the seal surfaces during running the adaptor through to completion of drilling and remains in this position until the injection mandrel  50  is run. The injection mandrel lands on the top face of the SSBP  320  and slides it down thus exposing the sealing surfaces on the injection adaptor ring. When the injection mandrel is fully landed, the circular gallery  25  is formed with the seals on the injection mandrel  50  providing pressure containment. In the event that the injection mandrel  50  needs to be retrieved, the SSBP  320  will be automatically returned to it original position thus protecting the seal surface on the injection adaptor ring  20 . The SSBP  320  provides the ability to pressure test the injection flow loop and valves on the drilling guide base  200  if the injection adaptor ring  20  is pre-installed in the drilling guide base  200 . Further, SSBP  320  allows for pressure testing the seal between the injection adaptor ring  20  and the drilling guide base  200 . 
   The injection mandrel  50  may be run with a test plug  340  that seals on its bore as shown in  FIG. 10 . The test plug  340  allows for the pressure testing of the injection mandrel  50  prior to re-injection. When the injection mandrel  50  has been landed within the system a pressure test can be performed on the inner diameter of the injection mandrel  50  to test the integrity of the seals between the outer diameter injection mandrel  50  and the inner diameter of the injection adaptor ring  20 . 
   In another embodiment, a different SSBP  330  may be an integral part of a template receptacle as shown in  FIG. 11 . This allows for the pressure testing of the valves and injection flow loop by pressurising against the SSBP  330 . The SSBP  330  is locked in position during drilling operations and protects the sealing areas that will be used by the injection adaptor ring  20 . 
   In order to land the injection adaptor ring  20  into its final position within the re-injection system  150 , the SSBP  330  has to be first unlocked from its original position in the template receptacle. Typically, the SSBP  330  will be unlocked by a remote operated vehicle causing it to automatically move to the open position as shown in  FIG. 12 . If the injection adapter ring  20  needs to be retrieved from the re-injection system  150 , the SSBP  330  will automatically slide back to its original position thus protecting the seal surfaces. As with the above embodiment, a SSBP  320  may be prevent damage to the internal sealing surfaces of the injection adapter ring  20  providing the ability to pressure test the injection flow loop and valves on the template and the seals between the injection adaptor ring  20  and template receptacle  400 . The injection mandrel  50  of this embodiment is identical to above embodiment and as such may be run with a test plug  340  that seals on its bore. The test plug  340  allows for the pressure testing of the injection mandrel  50  prior to re-injection. When the injection mandrel  50  has been landed within the system a pressure test can be performed on the inner diameter of the injection mandrel  50  to test the integrity of the seals between the outer diameter injection mandrel  50  and the inner diameter of the injection adaptor ring  20 . 
   Although various embodiments have been shown and described, the invention is not so limited and will be understood to include all such modifications and variations as would be apparent to one skilled in the art.