Abstract:
An apparatus and methods are disclosed for using optical sensors to determine the position of a movable flow control element in a well control tool. A housing has a movable element disposed within such that the element movement controls the flow through the tool. An optical sensing system senses the movement of the element. Optical sensors are employed that use Bragg grating reflections, time domain reflectometry, and line scanning techniques to determine the element position. A surface or downhole processor is used to interpret the sensor signals.

Description:
CROSS-REFERENCE TO RELATED APPLICATION  
       [0001]    This application claims the priority of U.S. Provisional Application No. 60/332,478 filed on Nov. 14, 2001. 
     
    
     
       BACKGROUND OF THE INVENTION  
         [0002]    1. Field of the Invention  
           [0003]    This invention relates generally to a method for the control of oil and gas production wells. More particularly, it relates to an optical position sensor system for determining the position of movable elements in well production equipment.  
           [0004]    2. Description of the Related Art  
           [0005]    The control of oil and gas production wells constitutes an on-going concern of the petroleum industry due, in part, to the enormous monetary expense involved as well as the risks associated with environmental and safety issues.  
           [0006]    Production well control has become particularly important and more complex in view of the industry wide recognition that wells having multiple branches (i.e., multilateral wells) will be increasingly important and commonplace. Such multilateral wells include discrete production zones which produce fluid in either common or discrete production tubing. In either case, there is a need for controlling zone production, isolating specific zones and otherwise monitoring each zone in a particular well. Flow control devices such as sliding sleeve valves, packers, downhole safety valves, downhole chokes, and downhole tool stop systems are commonly used to control flow between the production tubing and the casing annulus. Such devices are used for zonal isolation, selective production, flow shut-off, commingling production, and transient testing.  
           [0007]    These tools are typically actuated by hydraulic systems or electric motors driving a member axially with respect to a tool housing. Hydraulic actuation can be implemented with a shifting tool lowered into the tool on a wireline or by running hydraulic lines from the surface to the downhole tool. Electric motor driven actuators may be used in intelligent completion systems controlled from the surface or using downhole controllers.  
           [0008]    The surface controllers are often hardwired to downhole sensors which transmit information to the surface such as pressure, temperature and flow. With multiple production zones intermingled in the single well bore, it is difficult to determine the operation and performance of individual downhole tools from surface measurements alone. It is also desirable to know the position of the movable members, such as the sliding sleeve in a sliding sleeve valve, in order to better control the flow from various zones. Originally, sliding sleeves were actuated to either a fully open or fully closed position. Surface controlled hydraulic sliding sleeves such as Baker Oil Tools Product Family H81134 provides variable position control of the sleeve which allows for continuous flow control of the zone of interest. In order to efficiently utilize this control capability, a sensor system is needed to determine the position of the sleeve. Position data is then processed at the surface by the computerized control system and is used for control of the production well. Similar position data will enhance the efficient flow control of the other downhole tools mentioned. In addition, for critical tools, such as downhole safety valves, indication of the position, or setting, of the valve is desired to ensure that the valve is operating properly.  
           [0009]    Thus there is a need for a position sensing system which can monitor the operating configuration of downhole tools by measuring the position of a movable member over a large displacement range.  
         SUMMARY OF THE INVENTION  
         [0010]    The methods and apparatus of the present invention overcome the foregoing disadvantages of the prior art by providing a reliable method of sensing the position of a movable member in a downhole tool including, but not limited to, a sliding sleeve production valve, a safety valve, and a downhole choke.  
           [0011]    The present invention contemplates an apparatus for and method of using optical position sensors to determine the position of a movable flow control member in a downhole flow control tool such as a sliding sleeve, production valve safety valve, or the like.  
           [0012]    In one preferred embodiment, this invention provides a system for controlling a downhole flow, comprising a flow control device in a tubing string in a well. The flow control device has a first member engaged with the tubing string and a second member moveable with respect to the first member, and acting cooperatively with the first member for controlling the downhole flow through the flow control device. An optical position sensing system acts cooperatively with the first member and the second member for detecting a position of the second member relative to the first member and generating at least one signal related thereto. A controller receives the at least one signal and determines, according to programmed instructions, the position of the second member relative to the first member and controls the downhole flow in response thereto.  
           [0013]    A method is provided for determining the position of a movable flow control member in a well flow control tool, comprising sensing the position of the flow control member using an optical position sensing system and generating a signal related to the flow control member position. The signal is transmitted to a controller. The position of the flow control member is determined according to programmed instructions.  
           [0014]    Examples of the more important features of the invention thus have been summarized rather broadly in order that the detailed description thereof that follows may be better understood, and in order that the contributions to the art may be appreciated. There are, of course, additional features of the invention that will be described hereinafter and which will form the subject of the claims appended hereto. 
       
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0015]    For detailed understanding of the present invention, references should be made to the following detailed description of the preferred embodiment, taken in conjunction with the accompanying drawings, in which like elements have been given like numerals, wherein:  
         [0016]    [0016]FIG. 1 is a diagrammatic view depicting a multizone completion with an optical position sensing system according to one embodiment of the present invention;  
         [0017]    [0017]FIG. 2 is a diagrammatic view of a section of a sliding sleeve valve with fiber optic sensors according to one embodiment of the present invention;  
         [0018]    [0018]FIGS. 3 a - d  is a schematic diagram of a Bragg grating disposed in an optical fiber according to one embodiment of the present invention;  
         [0019]    [0019]FIG. 4 is a schematic diagram of a sliding sleeve valve two position fiber optic position sensor using Bragg gratings according to one embodiment of the present invention;  
         [0020]    [0020]FIG. 5 is a schematic diagram of a sliding sleeve valve multiple position fiber optic position sensor using Bragg gratings according to one embodiment of the present invention;  
         [0021]    [0021]FIG. 6 is a schematic diagram of an alternative sliding sleeve valve multiple position fiber optic position sensor using Bragg gratings according to one embodiment of the present invention;  
         [0022]    [0022]FIG. 7 is a schematic diagram of a second alternative sliding sleeve valve multiple position fiber optic position sensor using Bragg gratings according to one embodiment of the present invention;  
         [0023]    [0023]FIG. 8 is a schematic diagram of a sliding sleeve valve multiple position fiber optic position sensor using optical time domain reflection techniques according to one embodiment of the present invention;  
         [0024]    [0024]FIG. 9 is a schematic diagram of an alternative sliding sleeve valve multiple position fiber optic position sensor using optical time domain reflection techniques according to one embodiment of the present invention;  
         [0025]    [0025]FIG. 10 is a schematic diagram of a well control tool with an optical senor system, according to one embodiment of the present invention;  
         [0026]    [0026]FIG. 11 is a schematic of a preferred marking pattern for determining position according to one embodiment of the present invention;  
         [0027]    [0027]FIG. 12 is a schematic of an preferred grating pattern according to one embodiment of the present invention; and,  
         [0028]    [0028]FIG. 13 is a schematic showing an optical-magnetic technique fiber optic position sensing technique according to one embodiment of the present invention. 
     
    
     DESCRIPTION OF PREFERRED EMBODIMENTS  
       [0029]    As is known, a given well may be divided into a plurality of separate zones which are required to isolate specific areas of a well for purposes of producing selected fluids, preventing blowouts and preventing water intake. A particularly significant contemporary feature of well production is the drilling and completion of lateral or branch wells which extend from a particular primary wellbore. These lateral or branch wells can be completed such that each lateral well constitutes a separable zone and can be isolated for selected production.  
         [0030]    With reference to FIG. 1, well  1  includes three zones, namely zone A, zone B and zone C. Each of zones A, B and C have been completed in a known manner.  
         [0031]    In zone A, a slotted liner completion is shown at  69  associated with a packer  71 . In zone B, an open hole completion is shown with a series of packers  71  and sliding sleeve  75 , also called a sliding sleeve valve. In zone C, a cased hole completion is shown again with the series of packers  71 , sliding sleeve  75 , and perforating tools  81 . The packers  71  seal off the annulus between the wellbores and the sliding sleeve  75  thereby constraining formation fluid to flow only through an open sliding sleeve  75 . The completion string  38  is connected at the surface to wellhead  13 .  
         [0032]    In a preferred embodiment, hydraulic fluid is fed to each sliding sleeve  75  through a hydraulic tube bundle(not shown) which runs down the annulus between the wellbore  1  and the tubing string  38 . Each of the packers  71  is adapted to pass the hydraulic lines while maintaining a fluid seal. Likewise, at least one optical fiber  15  is run in the annulus to each of the sliding sleeves  75 . The optical fibers may be run in a separate bundle or they may be included in the bundle with the hydraulic lines. The optical fiber  15  is termninated, at the surface in an optical system  17  which contains the optical source and analysis equipment as will be described. In one preferred embodiment, the optical system  17  comprises a light source and a spectral analyzer (see FIGS.  4 - 7 ). In another preferred embodiment, the optical system  17  comprises an optical time domain reflectometer (see FIGS.  8 - 9 ). The optical system  17  outputs a conditioned signal to a controller  100  which uses the information to control the well. The controller  100  contains a microprocessor and circuitry to interface with the optical system  17  and to control the hydraulic system  109  according to programmed instructions for positioning the sliding sleeves and other flow control devices as desired in the multiple production zones to achieve the desired flows. Such other devices include, but are not limited to, downhole safety valves, downhole chokes, and downhole tool stop systems and are described in U.S. Pat. No. 5,868,201, assigned to the assignee of this application, and is hereby incorporated herein by reference.  
         [0033]    It will be appreciated by those skilled in the art that, in another preferred embodiment, an intelligent well control system controls the flow control devices such as sliding sleeve  75 . In such a system, the flow control devices are powered by a downhole electromechanical driver (not shown) and the optical system  17  may be contained in a downhole controller (not shown). Such a downhole control system is described in U.S. Pat. No. 5,975,204, assigned to the assignee of this application, and is hereby incorporated herein by reference.  
         [0034]    [0034]FIG. 2 is a schematic section of sliding sleeve valve assembly, also commonly referred to as a sliding sleeve,  75 . Housing  110  is attached on an upper end to the production string (not shown). As previously indicated in FIG. 1, the production string is sealed to the wellbore above and below the sliding sleeve by packers  71 . In this preferred embodiment, housing  110  has multiple slots  135  arranged around a section of the housing  110 . A flow control member, or sliding spool,  155  is disposed inside of housing  110  and has multiple slots  120 . Spool  155  has elastomeric seals  125  arranged to seal off flow of formation fluids  145  when spool  155  is in the shown closed position. Spool  155  is driven by a surface controlled hydraulic powered shifting mechanism (not shown). Such hydraulic shifting devices are common in downhole tools and are not discussed further. Alternatively, spool  155  may be driven by an electromechanical actuator (not shown).  
         [0035]    Housing  110  has an internal longitudinal groove  130 . Disposed in longitudinal slot  130  is optical fiber  15  and microbend elements  31  and  32 . The optical fiber  15  has Bragg gratings written onto the fiber  15  at positions of interest. The operation of the Bragg gratings and microbend elements is discussed below. The optical fiber  15  and microbend elements  31 , 32  are potted in groove  130  using a suitable elastomeric or epoxy material. The potted groove is blended with the internal diameter of housing  110  such that seals  125  effect a fluid seal with the housing  110 . Microbend elements  31  and  32  induce a microbend in the optical fiber  15  when the elements are actuated. This microbend creates a optical loss at the point of the microbend which can be detected using optical techniques as will be discussed below in more detail. Microbend elements can be mechanically and magnetically actuated devices. Mechanical microbend elements are known in the art of fiber optic sensors and will not be discussed further. A type of magnetically actuated microbend element is discussed later. The elements  31 , 32  are actuated by engagement with an external member, also termed an actuator,  30  attached at a predetermined location on the periphery of spool  155 . External member  30  may be a continuous annular rib or, alternatively, a button type attachment to spool  155 . In a preferred embodiment, the external member  30  engages only one microbend element at a time. In another preferred embodiment, external member  30  extends longitudinally along spool  155  such that external member  30  continues to engage each previously engaged microbend element as the spool  155  moves from the closed position to the open position. It will be appreciated that as many microbend elements may be disposed along the optical fiber  15  as there are positions of interest of spool  155 .  
         [0036]    In another preferred embodiment, optical time domain reflection techniques are used to determine the location of the microbend. Optical time domain reflection techniques are discussed below.  
         [0037]    Referring to FIGS. 2 and 4 an optical fiber  15  is embedded in the housing  110  with microbend elements  31  and  32  located at positions along the fiber  15  corresponding to positions of interest of the spool  155 . A Bragg grating is written into the fiber  15  next to each of the microbend elements  31  and  32  using techniques known in the art. A person skilled in the art would appreciate how the optical fiber Bragg grating is used as a sensor element. Each fiber Bragg grating is a narrowband reflection filter permanently imparted into the optical fiber. The filter is created by imparting gratings formed by a periodic modulation of the refractive index of the fiber core. The techniques for modulating the index are known in the art. The reflected wavelength is determined by the internal spacing of the grating as seen generally in FIGS. 3 a - 3   d . Light is partially reflected at each grating, with maximum reflection when each partial reflection is in phase with its neighbors. This occurs at the Bragg wavelength, W b =2nd, where n is the average refractive index of the grating and d is the grating spacing. In this invention, each grating has a different predetermined spacing and therefore each grating will reflect a different predetermined wavelength of light. Such gratings are commercially available. By using a different predetermined wavelength for each grating, the reflected light can be spectrally analyzed to determine the wavelength and amplitude of the reflected signal from each grating along the optical fiber.  
         [0038]    In general, the microbend elements are actuated by an external member, which may be an annular band or alternatively a button, on the sliding spool  155  as it passes each microbend element. As the microbend element is actuated it imparts a bend in the optical fiber  15 , creating an optical power loss through the optical fiber  15  at the point of the bend. By analyzing the amplitude and wavelength of the reflected light from the various gratings, the position of the actuated microbend element can be determined.  
         [0039]    [0039]FIGS. 2 and 4 shows a preferred embodiment of a two position sensor for determining if a sliding sleeve is opened or closed. An optical fiber  15  is disposed in a tubular housing  110  containing sliding spool  155  and external member  30 . Microbend element  31  is located along the optical fiber  15  and is positioned to indicate one limit of the travel of spool  155  when engaged by external member  30 . External member  30  is sized to engage only one microbend sensor at a time. Similarly, microbend element  32  is located to indicate the other limit of the travel of spool  155 .  
         [0040]    Bragg gratings  20  and  21  are written onto the optical fiber  15  proximate microbend element  31 . Bragg grating  20  is located between light source  10  and microbend element  31  and acts as a baseline reference for indicating the baseline optical power reflection without the effects of the microbend elements. Grating  21  is written on the optical fiber  15  just downstream of the microbend element  31 . As used herein, upstream refers to the direction towards the light source  10 , and downstream refers to the direction away from the light source  10 . Grating  22  is located proximate to and downstream of microbend element  32 . The fiber end  25  of optical fiber  15  is terminated in an anti-reflective manner so as to prevent interference with the reflective wavelengths from the Bragg gratings. The fiber end  25  may be cleaved at an angle so that the end face is not perpendicular to the fiber axis. Alternatively, the fiber end  25  may be coated with a material that matches the index of refraction of the fiber, thus permitting light to exit the fiber without back reflection. Light reflected from the gratings travels back toward the light source  10  and is input to spectral analyzer  11  by fiber coupler  12 . Spectral analyzer  11  determines the reflected optical power and wavelength of the reflected signals.  
         [0041]    Still referring to FIG. 4, it can be seen that external member  30  is engaged with microbend element  32  thereby creating a bend in the optical fiber  15  at that location. The bend at the location of element  32  causes a loss in optical power transmitted downstream of element  32 . In operation light source  10  transmits a broadband light signal down optical fiber  15 . The signal is reflected by grating  20  at wavelength  20   w  and power level  20   p  thereby establishing a baseline for comparison with the downstream grating reflections. Since microbend element  31  is not actuated the light travels relatively undiminished to grating  21  where wavelength  21   w  is reflected at power level  21   p . In FIG. 4, the power levels  20   p  and  21   p  are essentially equal. The light signal continues down the optical fiber  15  and encounters actuated microbend element  32  which causes an attenuated light signal to be transmitted downstream to grating  22 . Grating  22  reflects wavelength  22   w  at a diminished power level  22   p , relative to power levels  20   p  and  21   p . The reflected signals are analyzed by spectral analyzer  11  and the resulting signals are shown in FIG. 4 where the engaged power level  22   p  from grating  22  is measurably less than the power levels  20   p  and  21   p  from gratings  20  and  21  respectively. The relative power levels and wavelengths are sent to a processing unit  100  which determines according to programmed instructions and the predetermined locations of the microbend elements and the gratings, the spool  155  position.  
         [0042]    [0042]FIG. 5 shows a preferred embodiment for determining multiple positions of a sliding spool. This embodiment is similar to the two position system. As shown in FIG. 5, microbend elements  31 ,  32 ,  33  and  34  with associated gratings  21 ,  22 ,  23  and  24  respectively, each with a unique predetermined wavelength  21   w - 24   w  are disposed at predetermined positions of interest along optical fiber  15 . Note that a greater or fewer number of pairs of microbend elements and gratings could be located along the optical fiber  15 .  
         [0043]    Bragg grating  20  is placed upstream of element  31  and serves as a baseline reference of reflected power. As shown in FIG. 5, external member  30  on sliding spool  155 , is engaged with microbend element  33  thereby bending optical fiber  15  at that location. As previously indicated, the bending of optical fiber  15  by microbend element  33  causes a loss of optical power to be transmitted downstream of element  33 . Therefore, as shown in FIG. 5, the optical power  23   p  and  24   p  reflected from the gratings  23  and  24 , which are downstream of element  33  are measurably lower than the power levels  20   p ,  21   p  and  22   p  measured upstream of element  33 . The reflected signals are analyzed with spectral analyzer  11  and the resulting power levels at the predetermined wavelengths are sent to a processing unit which determines the location of the sliding spool  155  from the predetermined locations of the microbend elements and gratings.  
         [0044]    [0044]FIG. 6 shows another preferred embodiment for determining multiple positions of a sliding sleeve. In this preferred embodiment, multiple microbend elements  31 ,  32 ,  33  and  34  are disposed at predetermined positions of interest along optical fiber  15 . Each microbend element is adapted to induce a unique microbend in optical fiber  15 . Each microbend element, therefore, has associated with it a unique optical power loss. Reference grating  20  with wavelength  20   w  is located along the optical fiber  15  upstream of the microbend elements. Grating  24  is located downstream of the microbend elements.  
         [0045]    As shown in FIG. 6, the sliding spool external member  30  is engaged with microbend element  33 . Element  33  imposes a unique microbend on optical fiber  15  resulting in a uniquely measurable power transmission which is detected by measuring the reflected power from grating  24  at wavelength  24   w  as shown by reflected signal  24   r  in FIG. 6. The amplitude of signal  24   r  corresponds to the unique characteristic transmission of element  33 . Note that while the unique power levels shown for each microbend element are monotonically decreasing, this is not a requirement. It is only necessary that each microbend element have a transmission loss that is measurably unique.  
         [0046]    [0046]FIG. 7 shows yet another preferred embodiment for determining multiple positions of a sliding sleeve. Here, each of microbend elements  131 ,  132 ,  133  and  134  creates a uniform optical loss in optical fiber  15  when actuated by spool external member  30 . Spool external member  30  is adapted to continue to engage each microbend element after the sleeve has passed said element. As shown in FIG. 7, sleeve external member  30  is engaging microbend element  133  and continues to engage element  134 . Each engaged element uniformly decreases the optical power transmitted down the optical fiber  15  and hence decreases the optical power reflected by grating  24  and sensed by analyzer  11 . The power level detected is transmitted to processor  100  which determines the sleeve location from the predetermined positions of the microbend elements  131 ,  132 ,  133 ,  134  and predetermined uniform loss through each actuated microbend element. It will be appreciated that a greater or fewer number of microbend elements may be employed depending on the number of sliding spool positions of interest to be detected.  
         [0047]    [0047]FIG. 8 shows a preferred embodiment of a fiber optic sliding sleeve position indicator using optical time domain reflection techniques to measure the time of flight of an optical signal as it is reflected from a microbend in an optical fiber. The physical arrangement is similar to the previously described position indicators, however, no Bragg gratings are used to characterize the reflected signal. As shown, microbend elements  31 ,  32 ,  33 ,  34  are disposed along optical fiber  15  at predetermined locations of interest, with element  33  engaged and actuated by spool external member  30 . Element  33  creates a microbend in optical fiber  15 . As is known in the art, the microbend in optical fiber  15  will generate a reflection point for light traveling along optical fiber  15 . Optical time domain reflectometer (OTDR)  90  generates a light signal which travels down the optical fiber  15  and a portion of the light signal is reflected by the microbend created at element  33 . The reflected signal is sensed at OTDR  90  and the time for the signal to reach the microbend and return is measured. This time of flight and the predetermined optical properties of optical fiber  15  are input to processor  100  which determines according to programmed instructions which microbend element has been actuated. Optical time domain reflectometers are commercially available and are used extensively in determining the position of anomalies in fiber optic transmission lines.  
         [0048]    [0048]FIG. 9 shows another preferred embodiment using a fiber optic technique to determine the position of a sliding sleeve. Optical fiber  15  is directly engaged by spool external member  30  which creates an optical microbend  91  in optical fiber  15 . The microbend  91  causes a discrete reflection of light traveling down the optical fiber  15 . OTDR  90  generates a light signal which travels down optical fiber  15  and is partially reflected at microbend  91 . The reflected signal is detected by OTDR  90  and the time of flight to the reflection point at microbend  91  and back is determined. The time of flight and the predetermined optical properties of optical fiber  15  are input to processor  100  which determines the location of the microbend  91  along the optical fiber  15 .  
         [0049]    [0049]FIG. 10 shows another preferred embodiment using an optical encoding technique to determine the position of a sliding sleeve valve. Encoding reader  220  is disposed in housing  200  such that it scans the outer surface of flow control member, or spool,  210  as spool  210  moves axially relative to housing  200 . A predetermined pattern of position encoding marks  215  are disposed on the outer surface of spool  210  and are detected by reader  220  as the spool  210  moves. Signals from reader  220  are transmitted to the surface processor  100  for determining the spool  210  position. FIG. 11 shows one preferred pattern of linear encoding marks  230 - 235  axially disposed on the outer surface of spool  210 . Marks  230 - 235  may be disposed on the outer surface of spool  210  by machining techniques, photo-etching techniques, or photo-printing techniques common in the manufacturing arts. Marks  230 - 235  may be protrusions from the outer surface of spool  210 , depressions in the surface, or essentially even with the surface. Marks  230 - 235  may be coated with reflective materials or paints to enhance detection by reader  220 . The marks  230 - 235  are positioned to pass through the scanning view of reader  220  as spool  210  moves axially. The overlapping of the marks  230 - 235  result in the discrete position readings  241 - 150  as indicated in FIG. 11. It will be appreciated that different numbers and overlapping patterns of marks can result in different numbers of discrete positions. The position of the spool  210  can be determined to within the resolution of the encoding pattern used.  
         [0050]    [0050]FIG. 12 shows another preferred embodiment using an optical encoding technique to determine the position of a sliding sleeve valve. An optical grating  325  is disposed on the outer surface of spool  310 . The spacing “L” between adjacent grating lines changes with axial location along the spool  310 . An optical source  315  illuminates the gratings  325  and the reflected pattern is read by optical detector  320  mounted in the wall of housing  300 . Optical source  315  and optical detector  320  may be integrated into a single module or alternatively may be separate modules. The variation in spacing L may be continuous or, alternatively, discrete sections (not shown) of spool  310  may each have a unique spacing (not shown).  
         [0051]    [0051]FIG. 13 shows another preferred embodiment using an optical-magnetic technique to determine the position of a sliding sleeve valve. Using a physical configuration as shown in FIG. 2, magnetic responsive elements  420 ,  421 ,  422 ,  423 , and  424  are located at predetermined positions along and are engaged with optical fiber  415 . A magnet  430 , such as a rare-earth magnet is mounted on sliding sleeve spool  155 . Magnetic responsive microbend elements  420 - 424  are constructed of magneto-strictive materials such that the elements  420 - 424  create a microbend in optical fiber  415  when an element is juxtaposed with magnet  430 . In one embodiment, each of the elements  420 - 424  is sized to create a unique microbend and hence a unique optical reflection from each of the elements  420 - 424  which is detected by measuring the reflected power signal. Alternatively, the elements  420 - 424  may be adapted to provide an essentially uniform optical reflection from each element. The reflected signal is transmitted to processor  100  which determines the spool location from the predetermined position of the elements  420 - 424  and the unique reflection associated with each element. The magnetic responsive elements  420 - 424  can be used as microbend elements for all of the techniques described in FIGS.  4 - 9  using Bragg gratings or time domain reflectometry.  
         [0052]    It will be appreciated that the described fiber optic position sensing techniques may be incorporated in other downhole tools where position or proximity sensors are required to indicate the axial motion of one member relative to a second member where the axial motion enables the control of the well. These tools may include, but are not limited to, inflation/deflation tools for packers, a remotely actuated tool stop, a remotely actuated fluid/gas control device, a downhole safety valve, and a variable choke actuator. These tools are described in U.S. Pat. No. 5,868,201 previously incorporated herein by reference.  
         [0053]    The foregoing description is directed to particular embodiments of the present invention for the purpose of illustration and explanation. It will be apparent, however, to one skilled in the art that many modifications and changes to the embodiment set forth above are possible. It is intended that the following claims be interpreted to embrace all such modifications and changes.