Patent Document

CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application and U.S. Pat. No. 6,427,777 are commonly assigned to KMK Trust, a Trust Set Up under the Laws of the State of Texas, Robert C. Schick, Sole Trustee. 
    
    
     STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH 
     Not applicable. 
    
    
     FIELD OF THE INVENTION 
     The present invention is directed to an apparatus and method for improving the formation of multiple lateral wells in a new wellbore and positive, selective reentry of each lateral well. 
     BACKGROUND OF THE INVENTION 
     Several advantages are provided by drilling relatively high angle, deviated or lateral wells from a generally common wellbore such as a) access to the regular oil and gas reserves without additional wells being drilled from the surface, b) avoiding unwanted formation fluids, c) penetration of natural vertical fractures, and d) improved production from various types of formations or oil and gas reserves. Additionally, reentry of one or more lateral wells is often required to perform completion work, additional drilling, or remedial and stimulation work. Thus, lateral wells have become commonplace from the standpoint of new drilling operations and reworking existing wellbores. 
     Ordinarily, lateral well completion and/or reentry requires expensive downhole wireline surveys to accurately position the diverter or whipstock which is used to direct the boring or completion tool through a wall of a generally vertical wellbore into the adjacent formation. Without a survey, the lateral well formed may not be accurately recorded for purposes of reentry. For example, U.S. Pat. Nos. 4,304,299; 4,807,704; and 5,704,437 each describe a method and/or apparatus for producing lateral wells from a generally vertical common wellbore using conventional techniques and tools. In each instance, one or more lateral wells may be produced at a different depth and location in the common wellbore and reentered. Consequently, the whipstock must be repositioned at the new depth and location. Each time the whipstock is repositioned at a different depth and location, the change in depth and lateral orientation relative to a point of reference is recorded. In many applications using conventional threaded connections, the exact depth and location of each lateral well formed cannot be accurately or efficiently recreated using the same system and technique. As a result, a downhole directional survey is necessary to relocate the exact depth and location of each lateral well upon reentry. 
     Recognizing the disadvantages of the foregoing techniques, U.S. Pat. No. 2,839,270 and, more recently, U.S. Pat. No. 5,735,350 address the need for a more accurate method and/or apparatus for producing and reentering lateral wells without the need for a directional survey. For example, U.S. Pat. No. 2,839,270 describes a technique for selectively forming a lateral well through a wall of a common wellbore at a predetermined depth and lateral orientation by means of a supporting apparatus which includes apertures formed at predetermined locations in the supporting apparatus. The apertures determine the relative depth and lateral orientation of each lateral well and are prefabricated according to the particular common wellbore in which the supporting apparatus is installed. The whipstock is then positioned using one or more specially designed latches which engage a corresponding aperture designed for receipt of the respective latch. 
     Similarly, U.S. Pat. No. 5,735,350 describes a method and system for creating lateral wells at pre-selected positions in a common wellbore by means of a diverter assembly having a plurality of locator keys specially designed to engage a corresponding nipple formed in the wellbore casing having a unique profile. Although this technique may be employed in new and existing wells, it is expensive and, in some instances, inappropriate because the prefabricated keys and nipples are permanently and integrally formed according to the particular formation characteristics of the common wellbore in which the system is installed. 
     More recently, a system and method for use in a completed wellbore lined with casing was described in U.S. Pat. No. 6,427,777. This system uses a directional survey to position an anchor at a predetermined depth and lateral orientation relative to a longitudinal position and lateral position of the desired lateral well. Because a directional survey is used to position the anchor after the casing is set and secured, the exact location of a pre-formed opening in the casing is difficult to find. And, because the system is designed for completed wellbores, the system typically requires running equipment in the wellbore which is different than the equipment used to line and secure the wellbore with casing. Finally, the casing must be milled with a different type of bit than the bit used to drill through the formation when the system is used in a completed wellbore without pre-formed openings in the casing. As a result, the system must be run in the wellbore twice to form each lateral well. 
     SUMMARY OF THE INVENTION 
     It is therefore, an object of the present invention to provide an apparatus and method which can be used to secure the casing in a new wellbore and improve the formation of multiple lateral wells in a cost-efficient manner. 
     It is another object of the present invention to provide an apparatus and method which improves the formation and reentry of multiple lateral wells without the use of an anchor. 
     It is another object of the present invention to provide an apparatus and method which improves the accuracy of locating pre-formed openings in the casings. 
     It is an advantage of the present invention to provide an apparatus and method which reduces the time and cost associated with the formation of multiple lateral wells through the use of pre-formed openings in the casing. 
     It is an advantage of the present invention to provide an apparatus and method which can be used with conventional and/or standard equipment to secure the casing in a new wellbore and form multiple lateral wells. 
     It is another advantage of the present invention to provide an apparatus and method which is easy to install and operate within the wellbore. 
     In accordance with the foregoing objects and advantages, the present invention includes an apparatus, hereinafter referred to as an orienting sleeve, which is positioned in a wellbore lined with multiple casing segments. The orienting sleeve includes a first end connected to one of the casing segments, a second end, a longitudinal reference point and a lateral reference point. 
     A portion of the first end forms a seat. The valve is positioned in the second end of the orienting sleeve and permits movement of a fluid from the first end of the orienting sleeve to a second end of the orienting sleeve and restricts movement of the fluid from the second end of the orienting sleeve to the first end of the orienting sleeve. In order to improve the performance of the valve, the second end is connected to a float shoe which has another valve for permitting movement of the fluid from the first end of the orienting sleeve through the float shoe and restricting movement of the fluid from the wellbore through the float shoe. Alternatively, the second end of the orienting sleeve may be connected to a first end of another one of the casing segments which forms a reservoir for receipt of a portion of the fluid. A second end of the casing segment is connected to a float shoe having another valve for permitting movement of the fluid from the first end of the orienting sleeve through the float shoe and restricting movement of the fluid from the wellbore through the float shoe. As another alternative, the second end of the orienting sleeve includes another valve for permitting movement of the fluid from the first end of the orienting sleeve through the second end of the orienting sleeve and restricting movement of the fluid from the second end of the orienting sleeve to the first end of the orienting sleeve. Each valve utilized in the orienting sleeve or the float shoe is a plunger valve, however, may include any other type of valve capable of performing the function thus described. 
     A sealing member having a fluid passage therethrough is used to transfer the fluid from a surface above the wellbore through the orienting sleeve to a space between the casing segments and the wellbore. The fluid secures the casing segments to the wellbore. The orienting sleeve includes a seal to restrict the fluid from passing between the orienting sleeve and the scaling member. 
     The longitudinal reference point enables the location of a longitudinal position on at least one of the casing segments and the lateral reference point enables the location of a lateral position on the at least one of the casing segments. The lateral position and the longitudinal position define either an opening in at least one of the casing segments which is covered by a substantially impermeable material, or a desired region of interest in the formation adjacent to the lateral position and longitudinal position. 
     An orienting member and the orienting sleeve are used to effectively locate the lateral position and the longitudinal position of the opening in at least one of the casing segments. The sealing member and orienting member each include a shoulder which engages the seat on the orienting sleeve when the sealing member or orienting member is engaged with the orienting sleeve. 
     At least one of the sealing member and the orienting member includes a flange. The first end of the orienting sleeve includes a channel with an opening in the seat for receipt of the flange when the sealing member or the orienting member is aligned with the orienting sleeve. The channel extends toward the second end of the orienting sleeve. The flange substantially prevents rotational movement of the orienting member or the sealing member when the flange is disposed substantially within the channel. 
     The orienting sleeve includes a guide having a passage therethrough for receipt of a lower portion of the sealing member or the orienting member. The sealing member and the orienting member each include a reciprocating guide for alignment with the orienting sleeve when the guide and reciprocating guide are substantially engaged. In another embodiment, the orienting sleeve includes a key instead of a guide. Each of the respective sealing member and orienting member include a guide with a keyway for alignment with the orienting sleeve when the key enters the keyway. In either embodiment, the channel or the key defines the lateral reference point, and a portion of the orienting sleeve between the first end and the second end defines the longitudinal reference point. Preferably, the first end or the second end is chosen as the longitudinal reference point. 
     Thus, the sealing member and orienting sleeve are used to transfer the fluid, preferably cement, which secures the casing to the new wellbore. And, the orienting member and orienting sleeve are used to effectively form multiple lateral wells through the casing or pre-formed openings in the casing. 
     The present invention also includes a method to secure multiple casing segments within a new wellbore and improve the formation of multiple lateral wells through one or more of the casing segments, or one or more pre-formed openings in the casing segments, using the orienting sleeve, orienting member and sealing member thus described. 
     The method comprises the steps of: a) connecting the first end of the orienting sleeve to one end of a plurality of casing segments and connecting the second end of the orienting sleeve to a float shoe, b) lowering the casing segments, orienting sleeve and float shoe into the new wellbore until the orienting sleeve reaches a predetermined depth and lateral orientation, c) lowering the sealing member on a drill string until the sealing member is substantially engaged within the orienting sleeve, d) transferring a fluid through the drill string and sealing member from a surface above the wellbore to a space between the casing segments and the wellbore in order to secure the casing segments to the wellbore, e) removing the drill string and sealing member from the wellbore, f) lowering the orienting member on a drill string until the orienting member is substantially engaged within the orienting sleeve 
     Once the orienting member is substantially engaged within the orienting sleeve, the process of forming a lateral well may be performed using the connections and related components described in reference to U.S. Pat. No. 6,427,777, incorporated herein by reference. By replacing the anchor with the orienting sleeve, the lateral reference point and longitudinal reference point may be used to accurately locate a pre-formed opening in the casing for each respective lateral well. As a result, the process of forming a lateral well through the casing is reduced to a single step and the need to mill through the casing is eliminated. Alternatively, however, the lateral reference point and longitudinal reference point may be used to accurately locate the lateral position and longitudinal position of each respective lateral well. 
     Although the terms longitudinal and lateral are used herein for convenience, those skilled in the art will recognize that the apparatus and method of the present invention may be employed with respect to wells which extend in directions other than generally vertically or horizontally. 
     The foregoing has outlined rather broadly the objects and advantages of the present invention so that those skilled in the art may better understand the detailed description of the invention that follows. Additional objects and advantages of the invention, which form the subject of the claims of the invention, will be described below. Those skilled in the art should appreciate that they may readily use the concept and specific embodiment disclosed as a basis for modifying or designing other structures for carrying out the same purposes of the present invention. Those skilled in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the invention in its broadest form. 
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS 
     For a better understanding of the nature of the present invention, reference is made to the following detailed description taken in connection with the accompanying drawings in which: 
     FIG.  1 —is an elevational view of the orienting sleeve, shown in partial cross-section, and the sealing member. 
     FIG.  2 —is an elevational view of the orienting sleeve and orienting member. 
     FIG.  3 —is a detailed cross-sectional view of the orienting sleeve in substantial engagement with the sealing member shown in FIG.  1 . 
     FIG.  4 —is a cross-sectional view of the orienting sleeve and sealing member shown in FIG. 4 along  4 — 4 . 
     FIG.  5 —is a detailed cross-sectional view of the orienting sleeve in partial engagement with the orienting member shown in FIG.  2 . 
     FIG.  6 —is a detailed cross-sectional view of the orienting sleeve in further partial engagement with the orienting member shown in FIG.  2 . 
     FIG.  7 —is a detailed cross-sectional view of the orienting sleeve in substantial engagement with the orienting member shown in FIG.  2 . 
     FIG.  8 —is a cross-sectional view of the orienting sleeve and orienting member shown in FIG. 7 along  8 — 8 . 
     FIG.  9 —is a detailed cross-sectional view of another embodiment of the orienting sleeve in partial engagement with another embodiment of the orienting member. 
     FIG.  10 —is a detailed cross-sectional view of the orienting sleeve in substantial engagement with the orienting member shown in FIG.  9 . 
    
    
     DESCRIPTION OF PREFERRED EMBODIMENTS 
     In the description which follows, like parts are marked throughout this description in drawings with the same reference numerals, respectively. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated, in scale or in schematic form, and some details of conventional elements may not be shown in the interest of clarity and conciseness. 
     Referring now to FIG. 1, the orienting sleeve  122 , illustrated in partial cross-section, is shown substantially engaged with the sealing member  124 . In this embodiment, the orienting sleeve  122  is shown within a new wellbore  112  which extends vertically to a surface  114 . The wellbore  112  generally extends from the surface  114  through a formation region  116  where it may be desired to induce or inject fluids. The wellbore  112 , however, may extend in other non-vertical directions approaching horizontal. 
     The orienting sleeve  122  is connected to the lower end of the casing  118  before the casing and orienting sleeve  122  are lowered into position within the wellbore  112 . Generally, the casing is comprised of multiple segments which are connected at the surface  114  as the casing  118  is lowed into the wellbore  112 . Preferably, one or more of the segments include an opening  208  formed in a wall of the casing  118  as shown in FIG.  2 . The opening  208  is defined by a longitudinal position and a lateral position on the casing  118 . The opening  208  is covered by a fiberglass mesh  136  in FIG.  1 . This material, however, may be made of any other substantially impermeable material. 
     Determining where to position the orienting sleeve  122  at an appropriate depth and lateral orientation within the wellbore  112  is accomplished by any conventional survey means such as a directional downhole survey of the formation  116 . A conventional directional survey of the wellbore  112  generally will reveal the depth (longitudinal position) and lateral position of each region within the formation  116  where hydrocarbons may be found. Based upon the survey results, the appropriate number and location of lateral wells is determined and the segments comprising the casing  118  are made up to include one or more pre-formed openings—like the opening covered with fiberglass  136  in FIG.  1 . Each segment of the casing  118  is made up so that each opening therein may be aligned with a corresponding area in the formation  116  where a lateral well is desired. Thus, the casing  118  and orienting sleeve  122  are made up and lowered into the wellbore  112  to a predetermined depth and lateral orientation which places each opening in the casing  118  in general alignment with a corresponding area in the formation  116  where a respective lateral well is desired. Conversely, if openings are not included in the casing  118 , then the orienting sleeve  122  and casing  118  are made up and lowered to a predetermined depth and lateral orientation adequately below the area in the formation  116  where the lateral well furthest from the surface  114  is desired. 
     The orienting sleeve  122  includes a longitudinal reference point which is between the first end  134  and the second end  128  of the orienting sleeve  122 , and a lateral reference point as more particularly described in reference to FIGS. 3,  9  and  10 . The longitudinal reference point is preferably the first end  134  or the second end  128  of the orienting sleeve  122  which corresponds with the depth of the orienting sleeve  122  within the wellbore  112 . Once the orienting sleeve  122  is secured, its depth and lateral orientation are recorded using the longitudinal reference point and lateral reference point as initial coordinates to locate each opening in the casing  118  and/or area in the formation  116  where a lateral well is desired. Each lateral position and longitudinal position disclosed by the directional survey is measured from the lateral reference point and longitudinal reference point in the manner described in reference to FIG. 2 to locate each opening in the casing  118  and/or an area in the formation  116  where a lateral well is desired. 
     Once positioned, the orienting sleeve  122  and casing  118  are secured within the wellbore  112  using any hardenable fluid material such as cement, which forms a cement liner  120  around the casing  118 . The cement liner  120  is prepared at the surface  114  in a conventional manner and is transferred by means of a pump through a plurality of connected tubular components forming a drill string  138 . The components comprising the drill string  138  are generally connected by a standard threaded coupling  140 . The cement liner  120  is pumped through the drill string  138  and the sealing member  124 . As the cement liner  120  exits the sealing member  124 , it enters the orienting sleeve  122  and passes through a passage  130  which extends from the first end of the orienting sleeve  134  through the second end of the orienting sleeve  128 . A float shoe  126  is connected to the second end of the orienting sleeve  128  which includes a plunger valve (not shown) more particularly described in reference to FIG.  3 . After the cement liner  120  is pumped through the float shoe  126 , it is forced to the bottom of the wellbore  132  and around the orienting sleeve  122  in the direction shown by arrows  146  and  148 . Pressure from the pump forces the cement liner  120  to migrate up through the wellbore  112  in the direction indicated by arrows  150  and  152  until it reaches a desired position in the wellbore  112  relative to the surface  114 . Once the cement liner  120  reaches this position, it will harden over time and secure the casing  118  and orienting sleeve  122  within the wellbore  112 . The fiberglass cover  136  prevents the cement liner  120  from entering the opening  208  shown in FIG.  2 . 
     Referring now to FIG. 3, a detailed cross-sectional view of the orienting sleeve  122  is shown in substantial engagement with a sealing member  124 . The first end  134  of the orienting sleeve  122  includes external threads  310  for threaded engagement with the internal threads  312  of the casing  118 . Similarly, the second end  128  of the orienting sleeve  122  includes external threads  314  for threaded engagement with the internal threads  316  of the float shoe  126 . The first end  134  of the orienting sleeve  122  includes a channel  318  which extends toward the second end  128  of the orienting sleeve  122 . The seat  320  supports the sealing member  124  or the orienting member  210  shown in FIG.  2 . 
     The sealing member  124  includes a shoulder  322  for engagement with the seat  320 . The passage  130  includes an internal diameter  324  large enough to receive at least a portion of the sealing member  124  or orienting member  210  shown in FIG.  2 . The lower end  326  of the sealing member  124  includes a fluid passage  328  which opens into passage  130  of the orienting sleeve  122 . The drill string  138  in FIG.  1  and passage  130  form a conduit through which the cement liner  120  is pumped. 
     A valve  330  is secured within the passage  130  by a spring  332  which rests on support brackets  334  and  336 . A plate  338  is positioned in passage  130 . The plate  338  and brackets  334 ,  336  are attached to the inside diameter  324  of the orienting sleeve. 122  by any conventional means. The plate  338  includes an opening  340  for partial receipt of the valve  330 . And, the brackets  334 ,  336  include a plurality of openings (not shown) which allow the cement liner  120  to pass therethrough. Brackets  334  and  336  support the spring  332  and allow the valve  330  to depress between the brackets  334 ,  336 . The pressure of the cement liner  120  depresses valve  330 , causing the cement liner  120  to pass through opening  340 . 
     The float shoe  126  includes an opening  344  which communicates with passage  130 . The opening  344  is large enough for receipt of a portion of the valve  342 . The pressure of the cement liner  120  causes valve  342  to depress the spring  346 , permitting the cement liner  120  to pass through opening  344  into chamber  348 . Further pressure from the cement liner  120  causes cement contained in the chamber  348  to pass through openings  350 ,  352  in the float shoe  126  into the wellbore  112  as described in reference to FIG. 1. A portion of the float shoe  126  contains a bore  354  for receipt of a lower portion of the valve once the valve  342  is depressed and compresses the spring  346 . 
     Alternatively, the second end  128  of the orienting sleeve  122  may be connected to a first end of another one of the casing segments (not shown). A second end (not shown) of the other casing segment is connected to a float shoe similar to float shoe  126 . The other casing segment thus functions as a back-up reservoir for receipt of any excess portion of the cement liner  120  which may re-enter the float shoe from the wellbore  112 . As another alternative, the second end  128  of the orienting sleeve  122  includes another valve (not shown) similar to valve  330  to further restrict movement of the cement liner  120  from the second end  128  to the first end  134  of the orienting sleeve  122 . Each valve utilized in the orienting sleeve  122  or the float shoe  126  is a plunger valve, however, may include any other type of valve capable of performing the function thus described. 
     A guide  360  is positioned within the orienting sleeve  122  by heating the orienting sleeve  122 , inserting the guide  360  and cooling the orienting sleeve  122  to secure the guide  360  in position. The guide  360  may, however, be secured within the orienting sleeve  122  by any other conventional means. The guide  360  includes a passage (not shown) for receipt of the lower end  326  of the orienting sleeve  122 . Likewise, the lower end  326  is partially circumscribed by a reciprocating guide  364 . The guide  360  and reciprocating guide  364  each include an orienting surface  366  and  368 , respectively. Each orienting surface  366 ,  368 , commonly referred to as a muleshoe, has a curvilinear edge  367  and  369  that tapers to form a curved end  370  and  372 , respectively. The guide  360  is thus positioned within the orienting sleeve  122  to permit a portion of the fluid passage  368  to extend longitudinally beyond and below the guide  360  when the orienting surfaces  366  and  368  are substantially engaged. 
     Each curved end  370 ,  372  enables the sealing member  124  and orienting sleeve  122  to rotate as each curved end  370 ,  372  comes into contact with the corresponding orienting surface  366 ,  368  until substantially engaged as shown in FIG.  3 . When the guide  360  and reciprocating guide  364  are substantially engaged, the shoulder  322  of the sealing member  124  is substantially supported by the engaged seat  320  of the orienting sleeve  122 . 
     The primary function of the guide  360  is to align the orienting member  210  and orienting sleeve  122 , as described in reference to FIGS. 5,  6  and  7 . Although not typically required, however, the sealing member  124  and orienting sleeve  122  may be aligned when the orienting surfaces  366 ,  368  are substantially engaged. 
     A pair of o-ring seals  356  and  358  are positioned between the lower end  326  of the sealing member  124  and guide  360  in order to mitigate any back-flow of the cement liner  120  between the lower end  326  and guide  360 . Another o-ring seal  362  is positioned between the orienting sleeve  122  and reciprocating guide  364  in order to mitigate any back-flow of the cement liner  120  between the orienting sleeve  122  and the reciprocating guide  364  as shown in reference to FIG.  4 . 
     Referring now to FIGS. 5,  6  and  7 , an orienting member  210  is shown in various positions relative to a cross-sectional view of the orienting sleeve  122 . The orienting member  210  includes a flange  511  which substantially prevents rotational movement of the orienting member  210  when the flange  511  is disposed substantially within the channel  318  as shown in to FIG. 7 In FIG. 7, the orienting sleeve  122  and orienting member  210  are shown aligned. Although it is not always necessary to restrict rotational movement of the sealing member  124  shown in FIG. 3, a flange (not shown) may be attached by any conventional means to the sealing member  124  in order to restrict rotational movement of the sealing member  124  in the manner thus described. 
     The orienting member  210  includes a stinger  513  which is used to stab and locate the orienting sleeve  122 . Typically, the stinger  513  contacts the seat  320  of the orienting member  210  causing the stinger  513  to align within the passageway  130  in the first end  134  of the orienting sleeve  122 . The orienting member  210  also includes a reciprocating guide  510  which partially circumscribes the stinger  513 . The reciprocating guide  510  includes an orienting surface  512  commonly referred to as a muleshoe. The orienting surface  512  has a curvilinear edge  514  that tapers to form a curved end  516 . The curvilinear edge  514  and curved end  516  guide the orienting member  210  into alignment with the orienting sleeve  122  as shown in FIG.  7 . The curved end  516  contacts a portion of the orienting surface  366  which causes the orienting member  210  to rotate counterclockwise as shown in FIG.  6 . If the curved end  516  meets the curved end  370  on the guide  360 , then the orienting member  210  is forced to rotate in either direction (clockwise or counterclockwise) as it is forced toward the second end  128  of the orienting sleeve  122 . As the reciprocating guide  510  traverses down through the passage  130 , the stinger  513  enters passage  518  in the guide  360  shown in FIG.  5 . 
     In FIG. 7, the orienting surface  512  traverses the orienting surface  366  until the guide  360  and reciprocating guide  510  are substantially engaged. Once the guide  360  and reciprocating guide  510  are substantially engaged, the flange  511  will be substantially disposed within the channel  318  and a shoulder  518  on the orienting member  210  will be substantially supported by the engaged seat  320 . Once the flange  511  is substantially disposed within the channel  318 , the orienting member  210  and orienting sleeve  122  are aligned and the orienting member  210  is oriented in a predetermined lateral position relative to a lateral position on the casing  118  which defines the lateral position of the opening  208  shown in FIG.  2 . 
     Referring now to FIG. 8, the channel  318  is slightly larger than the flange  511  which enables the flange  511  to enter the channel  318  before the guide  360  and reciprocating guide  510  are substantially engaged. Consequently, nominal rotational movement of the orienting member  210  will occur once the guide  360  and reciprocating guide  510  are substantially engaged, however, will not compromise the ability to locate the lateral position of the opening  208  shown in FIG.  2 . In FIGS. 5-7, the channel  318  defines the lateral reference point and a portion of the orienting sleeve  122  between the first end  134  and the second end  128  defines the longitudinal reference point. Preferably, the first end  134  or the second end  128  is chosen to define the longitudinal reference point. 
     Referring now to FIGS. 9 and 10, another embodiment of an orienting member  910  is shown in various positions relative to another embodiment of an orienting sleeve  912 . In this embodiment, the orienting sleeve  912  includes a key  914  instead of the guide  360  shown in FIG.  3 . The key  914  acts as a guide for the orienting member  910 . The orienting sleeve  912  is identical in all other respects to the orienting sleeve  122  in FIG. 3, except that it includes a pair o-ring seals  916  and  918  above the key  914  which restrict the cement liner  120  from passing between the orienting sleeve  912  and the sealing member  124  described in reference to FIG.  3 . Accordingly, the orienting sleeve  912  includes a channel  920  for receipt of a flange  922  attached to the orienting member  910  by any conventional means. The orienting sleeve  912  includes a seat  924  to support the orienting member  910  when the seat  924  and a shoulder  926  on the orienting member  910  are engaged. 
     The orienting member  910  is similar in most respects to the orienting member  210  described in reference to FIG. 5, except that a channel forming a keyway  930  is positioned in a lower end  928  of the orienting member  910 . The lower end  928  partially circumscribes a stinger  948 . The keyway  930  includes an end stop  932  which contacts an upper surface  934  of the key  914  when the orienting member  910  and orienting sleeve  912  are aligned as shown in FIG.  10 . The lower end  928  includes an orienting surface  936  similar to that described in reference to FIG. 5, except that the curvilinear edge  938  tapers to form a pointed tip  940  which prevents jamming the orienting member  910  when the tip  940  meets the upper surface  934 . 
     As shown in FIG. 9, the curvilinear edge  938  transitions into the keyway  930  through a transition surface  942  which permits the key  914  to traverse the orienting surface  936  and keyway  930  as the orienting member  910  passes through the first end  944  toward the second end  946  of the orienting sleeve  912 . The stinger  948  is used to stab and locate the orienting sleeve  912  in order to position the orienting member  910 . 
     In FIG. 10, the orienting member  910  is substantially engaged with the orienting sleeve  912  as shown by contact between the shoulder  926  and seat  924  of the orienting sleeve  912 . At this position, the orienting member  910  is aligned with the orienting sleeve  912  and substantially free from rotational movement. Accordingly, the key  914  is engaged with the end stop  932  at this position. The end stop  932  is positioned at a distal end of the keyway  930  so that when the key  914  contacts the end stop  932 , the flange  922  should be substantially disposed within the channel  920 . 
     In FIGS. 9-10, the channel  920  or the key  914  defines the lateral reference point and a portion of the orienting sleeve  912  between the first end  944  and the second end  946  defines the longitudinal reference point. Preferably, the first end  944  or the second end  946  is chosen to define the longitudinal reference point. 
     Referring now to FIG. 2, an elevational view of the orienting sleeve  122  is shown in connection with the orienting member  210  and other components needed to locate the lateral position and longitudinal position of an opening  208 . Once the casing  118  has been secured within the wellbore  112 , the sealing member  124  shown in FIG. 1 is removed from wellbore  112  and replaced with the components shown in FIG.  2 . 
     The components shown in FIG. 2 include a diverter  234 , an extension member  216 , and the orienting member  210 . These components are lowered into the casing  118  using the drill string  138  which is operatively and releaseably connected to the diverter  234 . Because a directional survey has already been performed to position the orienting sleeve  122  at a predetermined depth and lateral orientation within the wellbore  112 , another directional survey is unnecessary. 
     Before these components are lowered into the casing  118 , the face  232  of the diverter  234  is aligned with the first lateral position and the first longitudinal position which define the opening  208  next to a desired area of the formation  214 . As described in reference to FIG. 1, the exact longitudinal position and lateral position of the opening  208  are determined before the casing  118  is secured to the wellbore  112 . Thus, the longitudinal position and lateral position of the opening  208  can be measured from the predetermined longitudinal reference point ( 128  or  134  in FIG. 5) and lateral reference point ( 318  in FIG.  5 ), respectively. The diverter  234  is aligned with the longitudinal position of the opening  208  using the extension member  216  and the face  232  of the diverter  234  is aligned with the lateral position of opening  208  using unilateral connections and a multilateral connection, in the manner described in reference to U.S. Pat. No. 6,427,777. The length of the extension member  216  can be varied by using shorter or longer components  218 ,  220  and  236 . Each unilateral connection  222  maintains alignment between the orienting member  210  and the face  232  of the diverter  234  in a single lateral direction. The multilateral connection  230  permits the alignment maintained by the unilateral connections to be adjusted in pre-selected increments. 
     Once the components in FIG. 2 are made up in the manner thus described, the components are lowered into the wellbore  112  until the orienting member  210  substantially engages the orienting sleeve  122  and the face  232  of the diverter  234  is aligned with the opening  208 . An anchor  238  may be used when the extension member  216  is extremely long and needs additional support. The drill string  138  is disconnected from the diverter  234  by compressing the system. Once disconnected, the probe  242  engages the face  232  of the diverter  234  causing the probe  242  to bore through the fiberglass mesh  136 , cement liner  120  and desired formation  214 . 
     The present invention may also be used in applications where there is no opening  208  in the casing  118  and the lateral well  212  is formed in two separate runs because two different probes  240  are used. Two separate runs are required because the first probe used to mill through the casing  118  must be removed at the surface  114  and replaced with another probe used to drill to drill through formation  214 . In this event, the directional survey results are used to generally determine the lateral position and longitudinal position of a desired area in the formation  214  relative to the longitudinal reference point and lateral reference point on the orienting sleeve  122 . In this manner, the face  232  of the diverter  234  can be aligned with these coordinates to begin formation of the lateral well. 
     Once the lateral well  212  is formed, the drill string  138  and probe  242  are removed from the wellbore  112 , and the orienting member  210 , extension member  216 , and diverter  234  are retrieved. The process is repeated for each desired lateral well. Accordingly, another lateral well may be formed by simply adjusting the length of the extension member  216  and lateral orientation of diverter  234 . For example, if another opening (not shown) in the casing  118  is used to form another lateral well (not shown), the extension member  216  may be shortened or lengthened to align the face  232  of the diverter  234  with the longitudinal position of the new opening relative to the longitudinal reference point and the multilateral connection  230  may be adjusted to align the face  232  of the diverter  234  with the lateral position of the new opening relative to the lateral reference point. Alternatively the extension member  216  may be shortened or lengthened to align the face  232  of the diverter  234  with the longitudinal position of the new opening relative to the longitudinal position of the opening  208  and the multilateral connection  230  may be adjusted to align the face  232  of the diverter  234  with the lateral position of the new opening relative to the lateral-position of the opening  208 . 
     Because the orienting sleeve  122  is designed for receipt of the sealing member  124  in FIG.  3  and the orienting member  210  in FIG. 5, the wellbore  112  and a lateral wellbore  212  may be completed in a more economic and efficient manner—particularly when one or more openings like the opening  208  are utilized to eliminate the step of milling through the casing  118 . Moreover, the orienting sleeve  122  provides a lateral reference point and longitudinal reference point to locate the longitudinal position and lateral position of the opening  208  in the casing  118  which cannot be accurately located using other conventional methods and equipment. 
     Although the objects and advantages of the present invention have been described in detail, those skilled in the art should understand that they can make various changes, substitutions and alterations herein without departing from the spirit and scope of the present invention in its broadest form.

Technology Category: 0