Patent Abstract:
A seismic streamer includes a jacket covering an exterior of the streamer. At least one strength member extends along the length of the streamer and is disposed inside the jacket. At least one seismic sensor is disposed in a sensor spacer affixed to the at least one strength member. An encapsulant is disposed between the sensor and the sensor spacer. The encapsulant is a substantially solid material that is soluble upon contact with a void filling material. A void filling material is disposed in the interior of the jacket and fills substantially all void space therein. The void filling material is introduced to the interior of the jacket in liquid form and undergoing state change to substantially solid thereafter.

Full Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
       [0001]    This application is a divisional application of, and claims priority from, U.S. Nonprovisional Patent Application No. 11/472,974 filed on Jun. 22, 2006, the entirety of which is incorporated herein by reference. 
     
    
     STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT 
       [0002]    Not applicable. 
       BACKGROUND OF THE INVENTION 
       [0003]    1. Field of the Invention 
         [0004]    The invention relates generally to the field of marine seismic data acquisition equipment. More specifically, the invention relates to structures for a marine seismic streamer, and methods for making such streamers. 
         [0005]    2. Background Art 
         [0006]    Marine seismic surveying is typically performed using “streamers” towed near the surface of a body of water. A streamer is in the most general sense a cable towed by a seismic vessel. The cable has a plurality of seismic sensors disposed thereon at spaced apart locations along the length of the cable. The seismic sensors are typically hydrophones, but can also be any type of sensor that is responsive to the pressure in the water, or in changes therein with respect to time. The seismic sensors may also be any type of particle motion sensor or acceleration sensor known in the art. Irrespective of the type of such seismic sensors, the sensors generate an electrical or optical signal that is related to the pressure-related or motion-related parameter being measured by the sensors. The electrical or optical signals are conducted along electrical conductors or optical fibers, respectively, carried by the streamer to a recording system. The recording system is typically disposed on the seismic vessel, but may be disposed elsewhere. 
         [0007]    In a typical marine seismic survey, a seismic energy source is actuated at selected times, and a record, with respect to time, of the signals detected by the one or more sensors is made in the recording system. The recorded signals are later used for interpretation to infer structure of, fluid content of, and composition of rock formations in the Earth&#39;s subsurface. Structure, fluid content and mineral composition are typically inferred from characteristics of seismic energy that is reflected from subsurface acoustic impedance boundaries. One important aspect of interpretation is identifying those portions of the recorded signals that represent reflected seismic energy and those portions which represent noise. 
         [0008]    In order to improve the quality of seismic data interpretation, one goal of marine seismic streamer design is to reduce the various forms of noise detected by the seismic sensors. A typical marine seismic streamer can be up to several kilometers in length, and can include thousands of individual seismic sensors. Because of the weight of all of the materials used in a typical marine seismic sensor, because of the friction (drag) caused by the streamer as it is moved through the water, and because of the need to protect the seismic sensors, electrical and/or optical conductors and associated equipment from water intrusion, a typical seismic streamer includes certain features. First, the streamer includes one or more strength members to transmit axial force along the length of the streamer. The strength member is operatively coupled to the seismic vessel and thus bears all the axial loading caused by drag (friction) of the streamer in the water. The streamer also includes, as previously explained, electrical and/or optical conductors to carry electrical power and/or signals to the various sensors and (in certain streamers) signal conditioning equipment disposed in the streamer and to carry signals from the various sensors to a recording station. The streamer also typically includes an exterior jacket that surrounds the other components in the streamer. The jacket is typically made from a strong, flexible plastic such as polyurethane, such that water is excluded from the interior of the jacket, and seismic energy can pass essentially unimpeded through the jacket to the sensors. A typical streamer also includes buoyancy devices at spaced apart locations along its length, so that the streamer is substantially neutrally buoyant in the water. The interior of the jacket is typically filled with oil or similar electrically insulating fluid that is substantially transparent to seismic energy. 
         [0009]    The typical fluid-filled streamer structured as described above is well proven and has been used in the seismic surveying industry for a considerable time. However, there are some disadvantages to the fluid-filled streamer structure described above. One such disadvantage is leakage of the fluid into the surrounding water when a streamer section is damaged or the outer jacket is cut. This allows water to enter interstices of a streamer cable and cause electrical failure of components in the streamer. At the same time, the streamer buoyancy is compromised. Because the fluid in the streamer is typically a hydrocarbon-based fluid, such as kerosene or light oil, such leakage can cause environmental damage. Damage to the streamer can occur while the streamer is being towed through the water or it can occur while the streamer is being deployed from or retrieved onto a winch on which streamers are typically stored on the seismic tow vessel. 
         [0010]    Another disadvantage to using fluid-filled streamers is that detectable noise can be generated by vibrations resulting from the streamer being towed through the water. 
         [0011]    Such vibrations can cause internal pressure waves that travel through the fluid inside the streamer, such waves often being referred to as “bulge waves” or “breathing waves.” Such noise is described, for example, in S. P. Beerens et al.,  Flow Noise Analysis of Towed Sonar Arrays,  UDT 99—Conference Proceedings Undersea Defense Technology, Jun. 29-Jul. 1, 1999, Nice, France, Nexus Media Limited, Swanley, Kent. Noise in the form of pressure waves can be detected by the seismic sensors, making identification of reflected seismic energy in the recorded signals more difficult. 
         [0012]    Still another disadvantage to fluid-filled seismic streamers known in the art is that transient motion of the various components of the streamer can induce detectable noise in the streamer. Ideally, during a seismic survey the entire streamer would move through the water at substantially constant velocity, and all the streamer components (i.e., the outer jacket, connectors, spacers, strength members, and filling fluid) would also move at the same constant velocity and thus not move with respect to each other. Under actual seismic survey conditions, however, motion of the seismic streamer is not uniform throughout the streamer, and this lack of uniform motion can lead to transient motion of various components, most notably the strength members. Transient motion can be caused by events such as pitching and heaving of the streamers; strumming of towing cables attached to the streamers (the strumming caused by vortex shedding on the cables), and operation of depth-control devices located on the streamers. 
         [0013]    Transient motion of the strength members can cause transient longitudinal displacement of the spacers or connectors, causing pressure fluctuations in the fluid that are detected by the seismic sensors. Pressure fluctuations in the fluid that radiate away from the spacers or connectors can also cause the flexible outer jacket to bulge in and out as a traveling wave, giving this phenomenon its name. So called “bulge waves” can be detected by the seismic sensors. Another type of noise that can be caused by transient motion of the strength members will be further discussed below. 
         [0014]    Other types of noise, generally called “flow noise”, can also affect the signals detected by the seismic sensors. For example, vibrations in and along the seismic streamer can cause extensional waves in the outer jacket and can cause resonance transients to travel along the strength members. A turbulent boundary layer created around the outer jacket of the streamer by the act of towing the streamer in the water can also cause pressure fluctuations in the fluid filling the streamer. 
         [0015]    In fluid-filled streamers, extensional waves in the jacket, resonance transients, and turbulence-induced noise are typically smaller in amplitude than bulge waves. Bulge waves are usually the largest source of vibration noise because these waves travel within the fluid core material filling the streamer and thus act directly on the seismic sensors. Nonetheless, all of these noise sources cumulatively can affect the detection of reflected seismic energy from the Earth formations below the water bottom, and thus affect the quality of seismic surveys. 
         [0016]    Several methods and structures for streamers have been devised to reduce the foregoing types of noise. One such structure includes compartment isolation blocks within a fluid-filled streamer section to stop the vibration-caused bulge waves from traveling continuously along the entire length of the streamer. Another such noise reducing structure includes open-cell foam disposed in the interior of the streamer. The open-cell foam restricts the movement of the fluid in response to transient pressure changes and causes transient pressure energy to be dissipated into the outer jacket and the foam over a shorter longitudinal distance. Another structure used to reduce noise includes combining (summing) the signals from several longitudinally spaced apart seismic sensors to attenuate effects of relatively slow-moving bulge waves or similar noise. In such structures, an equal number of seismic sensors are positioned between or on both sides of each of the spacers in a streamer segment so that longitudinally equally spaced apart (from the spacer) pairs of seismic sensors detected equal yet opposite polarity pressure changes. Summing the signals from all the sensors in such a group can thus effectively cancel some of the noise. 
         [0017]    Another approach to reducing the effects of bulge waves is to eliminate the fluid from the streamer sections entirely, so that no medium exists in which bulge waves can propagate. This approach is exemplified by so-called “solid” streamers, in which each streamer section is filled with a solid core material instead of a fluid. However, in any solid material, some shear waves will develop, which can increase some types of noise detected by the seismic sensors. Shear waves, of course, for the most part cannot propagate in a fluid filled streamer because fluids have substantially zero shear modulus (at least as compared with typical solid materials). Additionally, many conventional solid core materials are not substantially acoustically transparent to pressure waves, thus reducing the sensitivity of such streamers to reflected seismic energy. To deal with the foregoing limitations of using solid fill material in a streamer, another approach to reducing noise in streamers has been developed, which is to replace the fluid with a semi-solid or gelatin-like filler material. Such semi-solid filler material is flexible and acoustically transparent to seismic energy. The use of semi-solid material may reduce the development of bulge waves as compared to those in a fluid filled streamer, because the semi-solid material has much lower compressibility than fluid and thus reduces longitudinal displacement of the spacers. A semi-solid material may also reduce the transmission of shear waves as compared with that of a solid streamer. 
         [0018]    Using a semi-solid material as described above substantially attenuates bulge waves, but noise resulting from the so called “Poisson Effect” from the strength members can actually increase as compared to fluid filled streamers. The Poisson Effect is characterized by a change in diameter of the strength member as the tension applied to the strength member changes. The diameter change will be related to the magnitude of the tension change and to Poisson&#39;s ratio of the material used for the strength member. As previously explained, various effects on the streamer can cause tension transients along the strength members. Tension transients typically propagate along the length of the strength member at a velocity related to the elastic modulus of the material used to make the strength member. As such tension transients travel along the strength member, a corresponding change in diameter of the strength member occurs. Changes in diameter of the strength member can induce compressional waves in the media that fills the streamer. In streamers which use a semi-solid material filler, the amplitude of such induced compressional waves may be greater than in a fluid filled streamer because the compressibility of fluid is typically lower than the compressibility of the semi-solid material. In a typical streamer, seismic sensors are each disposed within a suitable opening in a sensor spacer. Each sensor spacer is adhesively coupled to the strength members, wherein the strength members pass through suitable openings in the spacers. Sensor spacers are typically made from dense, rigid plastic to protect the sensor from damage during handling and use. While effective at reducing damage to the sensors, the sensor spacers also effectively couple Poisson Effect noise, among other types of noise, from the strength members to the sensors. 
         [0019]    It is desirable to have a seismic streamer that takes advantage of the benefits of semi-solid filling materials, while having reduced amplitude of compressional waves (Poisson Effect waves) resulting from tension transients and other types of noise passing along the strength members. 
       SUMMARY OF THE INVENTION 
       [0020]    A seismic streamer according to one aspect of the invention includes a jacket covering an exterior of the streamer. At least one strength member extends along the length of the streamer and is disposed inside the jacket. At least one seismic sensor is disposed in a sensor spacer affixed to the at least one strength member. An encapsulant is disposed between the sensor and the sensor spacer. The encapsulant is a substantially solid material that is soluble upon contact with a void filling material. A void filling material is disposed in the interior of the jacket and fills substantially all void space therein. The void filling material is introduced to the interior of the jacket in liquid form and undergoing state change to substantially solid thereafter. 
         [0021]    A method for making a seismic streamer according to another aspect of the invention includes encapsulating at least one seismic sensor with a material that undergoes state change from solid to liquid upon contact with a void filling material. The encapsulated seismic sensor is inserted into an opening in a seismic sensor spacer. The sensor spacer is affixed to at least one strength member. The at least one strength member and the at least one sensor spacer affixed thereto are inserted into an acoustically transparent jacket. The jacket is filled with a void filling material. The void filling material is introduced in liquid form and undergoes state change to substantially solid thereafter. The void fill material dissolves the encapsulant. 
         [0022]    Other aspects and advantages of the invention will be apparent from the following description and the appended claims. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS  
         [0023]      FIG. 1  shows typical marine seismic data acquisition using a streamer according to one embodiment of the invention. 
           [0024]      FIG. 2  shows a cut away view of one embodiment of a streamer segment according to the invention. 
           [0025]      FIG. 3  shows a prior art assembly of a seismic sensor to a spacer. 
           [0026]      FIG. 4  shows one embodiment of assembly of a seismic sensor to a spacer according to the invention. 
       
    
    
     DETAILED DESCRIPTION  
       [0027]      FIG. 1  shows an example marine seismic data acquisition system as it is typically used on acquiring seismic data. A seismic vessel  14  moves along the surface of a body of water  12  such as a lake or the ocean. The marine seismic survey is intended to detect and record seismic signals related to structure and composition of various subsurface Earth formations  21 ,  23  below the water bottom  20 . The seismic vessel  14  includes source actuation, data recording and navigation equipment, shown generally at  16 , referred to for convenience as a “recording system.” The seismic vessel  14 , or a different vessel (not shown), can tow one or more seismic energy sources  18 , or arrays of such sources in the water  12 . The seismic vessel  14  or a different vessel tows at least one seismic streamer  10  near the surface of the water  12 . The streamer  10  is coupled to the vessel  14  by a lead in cable  26 . A plurality of sensor elements  24 , or arrays of such sensor elements, are disposed at spaced apart locations along the streamer  10 . The sensor elements  24 , as will be explained in more detail below with reference to  FIG. 4 , are formed by mounting a seismic sensor inside a sensor spacer. 
         [0028]    During operation, certain equipment (not shown separately) in the recording system  16  causes the source  18  to actuate at selected times. When actuated, the source  18  produces seismic energy  19  that emanates generally outwardly from the source  18 . The energy  19  travels downwardly, through the water  12 , and passes, at least in part, through the water bottom  20  into the formations  21 ,  23  below. Seismic energy  19  is at least partially reflected from one or more acoustic impedance boundaries  22  below the water bottom  20 , and travels upwardly whereupon it may be detected by the sensors in each sensor element  24 . Structure of the formations  21 ,  23 , among other properties of the Earth&#39;s subsurface, can be inferred by travel time of the energy  19  and by characteristics of the detected energy such as its amplitude and phase. 
         [0029]    Having explained the general method of operation of a marine seismic streamer, an example embodiment of a streamer according to the invention will be explained with reference to  FIG. 2 .  FIG. 2  is a cut away view of a portion (segment)  10 A of a typical marine seismic streamer ( 10  in  FIG. 1 ). A streamer as shown in  FIG. 1  may extend behind the seismic vessel ( 14  in  FIG. 1 ) for several kilometers, and is typically made from a plurality of streamer segments  10 A as shown in  FIG. 2  connected end to end behind the vessel ( 14  in  FIG. 1 ). 
         [0030]    The streamer segment  10 A in the present embodiment may be about 75 meters overall length. A streamer such as shown at  10  in  FIG. 1  thus may be formed by connecting a selected number of such streamer segments  10 A end to end. The segment  10 A includes a jacket  30 , which in the present embodiment can be made from 3.5 mm thick transparent polyurethane and has a nominal external diameter of about 62 millimeters. In each streamer segment  10 A, each axial end of the jacket  30  may be terminated by a coupling/termination plate  36 . The coupling/termination plate  36  may include rib elements  36 A on an external surface of the coupling/termination plate  36  that is inserted into the end of the jacket  30 , so as to seal against the inner surface of the jacket  30  and to grip the coupling/termination plate  36  to the jacket  30  when the jacket  30  is secured by and external clamp (not shown). In the present embodiment, two strength members  42  are coupled to the interior of each coupling/termination plate  36  and extend the length of the segment  10 A. In a particular implementation of the invention, the strength members  42  may be made from a fiber rope made from a fiber sold under the trademark VECTRAN, which is a registered trademark of Hoechst Celanese Corp., New York, N.Y. The strength members  42  transmit axial load along the length of the segment  10 A. When one segment  10 A is coupled end to end to another such segment (not shown in  FIG. 2 ), the mating coupling/termination plates  36  are coupled together using any suitable connector, so that the axial force is transmitted through the coupling/termination plates  36  from the strength members  42  in one segment  10 A to the strength member in the adjoining segment. 
         [0031]    The segment  10 A can include a number of buoyancy spacers  32  disposed in the jacket  30  and coupled to the strength members  42  at spaced apart locations along their length. The buoyancy spacers  32  may be made from foamed polyurethane or other suitable, selected density material. The buoyancy spacers  32  have a density selected to provide the segment  10 A preferably with approximately the same overall density as the water ( 12  in  FIG. 1 ), so that the streamer ( 10  in  FIG. 1 ) will be substantially neutrally buoyant in the water ( 12  in  FIG. 1 ). As a practical matter, the buoyancy spacers  32  provide the segment  10 A with an overall density very slightly less than that of fresh water. Appropriate overall density may then be adjusted in actual use by adding selected buoyancy spacers  32  and void fill materials having suitable specific gravity. 
         [0032]    The segment  10 A includes a generally centrally located conductor cable  40  which can include a plurality of insulated electrical conductors (not shown separately), and may include one or more optical fibers (not shown separately). The cable  40  conducts electrical and/or optical signals from the sensors (which will be further explained below with reference to  FIGS. 3 and 4 ) to the recording system ( 16  in  FIG. 1 ). The cable  40  may in some implementations also carry electrical power to various signal processing circuits (not shown separately) disposed in one or more segments  10 A, or disposed elsewhere along the streamer ( 10  in  FIG. 1 ). The length of the conductor cable  40  within a cable segment  10 A is generally longer than the axial length of the segment  10 A under the largest expected axial stress on the segment  10 A, so that the electrical conductors and optical fibers in the cable  40  will not experience any substantial axial stress when the streamer  10  is towed through the water by a vessel. The conductors and optical fibers may be terminated in a connector  38  disposed in each coupling/termination plate  36  so that when the segments  10 A are connected end to end, corresponding electrical and/or optical connections may be made between the electrical conductors and optical fibers in the conductor cable  40  in adjoining segments  10 A. 
         [0033]    Sensors, which in the present embodiment may be hydrophones, can be disposed inside sensor spacers, shown in  FIG. 2  generally at  34 . The hydrophones in the present embodiment can be of a type known to those of ordinary skill in the art, including but not limited to those sold under model number T-2BX by Teledyne Geophysical Instruments, Houston, Tex. In the present embodiment, each streamer segment  10 A may include 96 such hydrophones, disposed in arrays of sixteen individual hydrophones connected in electrical series. In a particular implementation of the invention, there are thus six such arrays, spaced apart from each other at about 12.5 meters. The spacing between individual hydrophones in each array should be selected so that the axial span of the array is at most equal to about one half the wavelength of the highest frequency seismic energy intended to be detected by the streamer ( 10  in  FIG. 1 ). It should be clearly understood that the types of sensors used, the electrical and/or optical connections used, the number of such sensors, and the spacing between such sensors are only used to illustrate one particular embodiment of the invention, and are not intended to limit the scope of this invention. In other embodiments, the sensors may be particle motion sensors such as geophones or accelerometers. A marine seismic streamer having particle motion sensors is described in U.S. patent application Ser. No. 10/233,266, filed on Aug. 30, 2002, entitled,  Apparatus and Method for Multicomponent Marine Geophysical Data Gathering,  assigned to an affiliated company of the assignee of the present invention and incorporated herein by reference. 
         [0034]    At selected positions along the streamer ( 10  in  FIG. 1 ) a compass bird  44  may be affixed to the outer surface of the jacket  30 . The compass bird  44  includes a directional sensor (not shown separately) for determining the geographic orientation of the segment  10 A at the location of the compass bird  44 . The compass bird  44  may include an electromagnetic signal transducer  44 A for communicating signals to a corresponding transducer  44 B inside the jacket  30  for communication along the conductor cable  40  to the recording system ( 16  in  FIG. 1 ). Measurements of direction are used, as is known in the art, to infer the position of the various sensors in the segment  10 A, and thus along the entire length of the streamer ( 10  in  FIG. 1 ). Typically, a compass bird will be affixed to the streamer ( 10  in  FIG. 1 ) about every 300 meters (every four segments  10 A). One type of compass bird is described in U.S. Pat. No. 4,481,611 issued to Burrage and incorporated herein by reference. 
         [0035]    In the present embodiment, the interior space of the jacket  30  may be filled with a void filling material  46  such as “BVF” (Buoyancy Void Filler), which may be a curable, synthetic urethane-based polymer. The BVF  46  serves to exclude fluid (water) from the interior of the jacket  30 , to electrically insulate the various components inside the jacket  30 , to add buoyancy to a streamer section and to transmit seismic energy freely through the jacket  30  to the sensors  34 . The BVF  46  in its uncured state is essentially in liquid form. Upon cure, the BVF  46  no longer flows as a liquid, but instead becomes a substantially gel-like substantially solid. Thus, the BVF  46  upon cure retains some flexibility to bending stress, substantial elasticity, and freely transmits seismic energy to the sensors  34 . It should be understood that the BVF used in the present embodiment only is one example of a gel-like substance that can be used to fill the interior of the streamer segment  10 A. For purposes of the invention, it is only necessary that the BVF  46  have the capacity to dissolve a material that encapsulates the seismic sensors (explained further below) prior to assembly of the streamer segment  10 A and cure of the BVF  46 . 
         [0036]    The sensor spacers  34 , as explained in the Background section herein, are typically molded from a rigid, dense plastic to better protect the seismic sensors therein from damage during handling and use. While effective in reducing incidence of damage to the seismic sensors, the rigid plastic used in the sensor spacers  34  also efficiently couples noise from the strength members  42  to the seismic sensor therein. Also as explained in the Background section herein, one source of noise is the Poisson Effect, wherein stretching of the strength members  42  under axial tension causes them to undergo a reduction in diameter. When the axial tension is reduced on the strength members  42 , they increase diameter. The strength members  42  are typically tightly fit in, and adhesively bonded to through passages ( 52  in  FIGS. 3 and 4 ) in the sensor spacers  34 , and thus diameter changes in the strength members  42  are efficiently transferred to the sensor spacers  34 , thus providing a source of noise that can be detected by the seismic sensors. 
         [0037]      FIG. 3  illustrates the manner known in the art prior to the present invention in which seismic sensors are mounted in the sensor spacers. The spacer  34  includes an opening  50  shaped to accept a seismic sensor  56 . The sensor  56  in this embodiment can be the model number T-2BX hydrophone made by Teledyne Geophysical Instruments, explained above with reference to  FIG. 2 . The housing of the sensor  56  includes ribs  56 A on its lateral edges, such that when the sensor  56  is inserted into the opening  50 , the sensor  56  is retained in the opening  50  by interference fit. The spacer  34  also includes through passages  52  through which the strength members ( 42  in  FIG. 2 ) are inserted. An adhesive port  54  is provided on the spacer  34 , and into which adhesive (not shown) is injected after the strength members ( 42  in  FIG. 2 ) are inserted into the through passages  52 . 
         [0038]    In making a streamer according to the invention, and referring to  FIG. 4 , the sensor  56  may be made such that its housing no longer includes the external ribs ( 56 A in  FIG. 3 ). Generally, the sensor  56  housing is smaller in dimension than the corresponding dimensions in the opening  50  in the sensor spacer  34 , such that there is substantially no interference between the sensor  56  and the spacer  34 . In the present embodiment the sensor  56  can be mounted and retained in the spacer  34  by using an encapsulant  46 A formed from a material that changes state from substantially solid to liquid when the encapsulant  46 A comes into contact with the gel ( 46  in  FIG. 2 ). Examples of such materials can include paraffin of a sufficient molecular weight to be substantially solid at ordinary ambient temperatures (0 to 40 degrees C.), yet remain soluble in, for example, certain hydrocarbon-based solvents and/or oils. The material used for the encapsulant  46 A may also be paraffin hardened using stearic acid, or a semi-solid hydrocarbon composition similar in consistency to household petroleum jelly. 
         [0039]    The sensor  56  having the solid phase encapsulant  46 A surrounding it can be placed in the opening  50  in the sensor spacer  34 . The sensor spacer  34  may be assembled to the strength member(s)  42  and inserted into the jacket ( 30  in  FIG. 2 ). Gel ( 46  in  FIG. 2 ) may then be inserted into the interior of the jacket  30  in its liquid form. Upon contact with the uncured gel  46 , the encapsulant  46 A will begin dissolve so as to change state to liquid form, leaving the sensor  56  surrounded by a liquid film. Substantially contemporaneously, the gel  46  will undergo cure, such that the liquid film (liquefied encapsulant  46 A) surrounding the sensor  56  is effectively trapped in place in the cured gel  46 . 
         [0040]    Noise induced in the spacer  34  such as from Poisson Effect in the strength members ( 42  in  FIG. 2 ) will be efficiently isolated from the sensor  56  by the liquefied (dissolved) encapsulant  46 A. By acoustically isolating the sensor  56  from the spacer  34 , Poisson Effect noise and other forms of noise are less likely to be coupled from the spacer  34  to the sensor  56 . Preferably the liquefied encapsulant  46 A has acoustic properties sufficiently different from the BVF and the spacers  34  such that substantial acoustic isolation is attained between the spacer  34  and the sensor  56 . 
         [0041]    In making a streamer according to the invention, seismic sensors are assembled to respective sensor spacers as explained above with reference to  FIG. 4 . The sensor spacers are then positioned along the strength members ( 42  in  FIG. 2 ) at their desired positions. Buoyancy spacers ( 32  in  FIG. 2 ) are also typically assembled to the strength members ( 42  in  FIG. 2 ) at spaced apart locations to provide the streamer with a selected overall density. The cable ( 40  in  FIG. 2 ) may then be coupled as required to the individual sensors ( 56  in  FIG. 4 ). The assembled sensors  56 , sensor spacers  34 , buoyancy spacers  32  and strength members  42  are then inserted into the jacket ( 30  in  FIG. 2 ). Termination plates ( 36  in  FIG. 2 ) are then affixed to the streamer segment ends. The interior of the jacket  30  may then be filled with the gel ( 46  in  FIG. 2 ). 
         [0042]    Streamers and streamer segments made according to the various aspects of the invention may have reduced noise resulting from transient tension of the strength members, for increased accuracy in seismic surveying. 
         [0043]    While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.

Technology Classification (CPC): 8