You are an expert at summarizing long articles. Proceed to summarize the following text:

You are an expert at summarizing long articles. Proceed to summarize the following text: 
CROSS REFERENCE TO RELATED APPLICATIONS 
       [0001]    This application claims the benefit of U.S. Provisional Application No. 61/831,911, filed Jun. 6, 2013, which is incorporated herein by reference. 
     
    
     BACKGROUND 
       [0002]    The present disclosure relates generally to jumper line configurations. More specifically, in certain embodiments the present disclosure relates jumper line configurations for hydrate inhibition and associated methods. 
         [0003]    The extraction of hydrocarbons from deepwater oil and gas reservoirs requires the transportation of a production stream from the reservoirs to facilities for processing. Water, along with oil and gas, may be included in these production streams. During transportation, if the temperature of the production stream is low and the pressure is high, the system can enter the hydrate region where gas hydrates form. Gas hydrates are solids and behave like ice and, if formed in large quantities, may plug the pipeline. Hydrates may also plug or cause malfunction of other units, such as valves, chokes, separators, and heat exchangers. 
         [0004]    Jumper lines are flowlines that are commonly used to connected subsea units together. Conventional jumper line configurations often incorporate a valley and a bend in order to provide flexibility to the jumper line. During shut ins, liquids may settle and segregate in the lower middle section of these jumper lines. During shut in restart cycles, these jumper lines are often at risk of forming gas hydrates. 
         [0005]    It is desirable to develop a jumper line configuration that aids in preventing the formation of gas hydrates. 
       SUMMARY 
       [0006]    The present disclosure relates generally to jumper line configurations. More specifically, in certain embodiments the present disclosure relates jumper line configurations for hydrate inhibition and associated methods. 
         [0007]    In one embodiment, the present disclosure provides a jumper line system comprising: a first subsea device; a second subsea device; and a jumper line providing fluid communication between the first subsea device and the second subsea device, wherein the jumper line does not comprise a valley. 
         [0008]    In another embodiment, the present disclosure provides a method of transporting hydrocarbons from a subsea well comprising: providing a subsea well; providing a manifold; connecting the subsea well to the manifold via a jumper line, wherein the jumper line does not comprise a valley; and flowing hydrocarbons from the subsea well to the manifold via the jumper line. 
         [0009]    In another embodiment, the present disclosure provides a method of connecting two subsea devices comprising: providing a first subsea device; providing a second subsea device; providing a jumper line, wherein the jumper line comprises a first end section and a second end section and does not comprise a valley; connecting the first end section of the jumper line to the first subsea device; and connecting the second end section of the jumper line to the second subsea device. 
         [0010]    The features and advantages of the present disclosure will be readily apparent to those skilled in the art. While numerous changes may be made by those skilled in the art, such changes are within the spirit of the invention 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0011]    So that the above recited features and advantages of the disclosure may be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to the embodiments thereof that are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are, therefore, not to be considered limiting of its scope. The figures are not necessarily to scale, and certain features and certain views of the figures may be shown exaggerated in scale or in schematic in the interest of clarity and conciseness. 
           [0012]      FIG. 1  is a side view illustration of a typical M-shaped jumper line geometry. 
           [0013]      FIG. 2  is a side view illustration of a jumper line geometry in accordance with an embodiment of the present disclosure. 
           [0014]      FIGS. 3A and 3B  are top and side view illustrations of a jumper line geometry in accordance with an embodiment of the present disclosure. 
       
    
    
     DETAILED DESCRIPTION 
       [0015]    The present disclosure relates generally to jumper line configurations. More specifically, in certain embodiments the present disclosure relates jumper line configurations for hydrate inhibition and associated methods. 
         [0016]    The description that follows includes exemplary apparatuses, methods, techniques, and instruction sequences that embody techniques of the inventive subject matter. However, it is understood that the described embodiments may be practiced without these specific details. 
         [0017]    Referring now to  FIG. 1 ,  FIG. 1  illustrates a conventional jumper line configuration  100 . As can be seen in  FIG. 1 , conventional jumper line configuration  100  may comprise a first subsea device  110 , a second subsea device  120 , and a jumper line  130 . Jumper line  130  may comprise one or more straight sections  131 , one or more elbows  132 , one or more peaks  133 , one or more valleys  134 , and one or more end sections  135 . In certain embodiments, the one or more peaks  133  are comprised of one or more elbows  132 . In certain embodiments, the one or more peaks  133  define the one or more valleys  133 . 
         [0018]    In this conventional configuration, the valleys  134  and elbows  132  may provide flexibility to the jumper line. However, during shut ins, liquids may settle and segregate in the valleys  134 , as well as end sections  135 , of the jumper lines  130  thus increasing the risk of hydrates forming in the valleys  134  during shut in-restart cycles. 
         [0019]    In certain embodiments, the present disclosure provides jumper line configurations that aid in the prevention of hydrate blockages. Examples of such jumper line configurations are illustrated in  FIG. 2  and  FIGS. 3A and 3B . 
         [0020]    Referring now to  FIG. 2 ,  FIG. 2  illustrates jumper line configuration  200 . As can be seen in  FIG. 2 , jumper line configuration  200  may comprise a first subsea device  210 , a second subsea device, and a jumper line  230 . 
         [0021]    In certain embodiments, first subsea device  210  and second subsea device  220  can comprise any type subsea equipment. Examples of suitable subsea devices include subsea Christmas trees, well heads, and manifolds. In certain embodiments, first subsea device  210  may comprise a well head. In certain embodiments, second subsea device  210  may comprise a manifold. 
         [0022]    Jumper line  230  may be constructed out of any material suitable for use as a jumper line. Examples of suitable materials include carbon steel, allows of titanium and chrome, flexible pipes, or composite materials. 
         [0023]    Jumper line  230  may comprise one or more straight sections  231 , one or more elbows  232 , peak  233 , and one or more end sections  235 . In certain embodiments, the one or more straight sections  231  may be horizontal or vertical along a primary axis. In certain embodiments, the primary axis is defined as the horizontal line that is in line with the overall flow of hydrocarbons from first subsea device  210  to second subsea device  220 . In certain embodiments, the one or more straight sections  231  may be inclined from 0 degrees to 90 degrees from the primary axis. In certain embodiments, the one or more straight sections  231  may be straight along the primary axis while incorporating a number of straight sections and elbows along a perpendicular axis. In certain embodiments, peak  233  is comprised of the one or more elbows  232 . In certain embodiments, the one or more elbows  232  may comprise one or more connectors. Unlike jumper line configuration  100  of  FIG. 1 , jumper line configuration  200  does not comprise a valley defined by one or more peaks  233 . Rather, in certain embodiments, the maximum elevation of jumper line configuration  200  occurs at peak  233 , and no local maximum elevation occurs on either side of peak  233 . 
         [0024]    In certain embodiments, jumper line  230  may further comprise one or more injection ports  236  wherein a hydrate inhibitor may be injected into the jumper line  230 . In certain embodiments, the one or more injection ports  236  may be disposed on the one or more end sections  235 . 
         [0025]    In certain embodiments, jumper line  230  may further comprises one or more valves  237  that allow the end sections of jumper line  230  to be drained or provide means to move gas from the first subsea device  210  to the second subsea device  220 . In certain embodiments, the one or more valves  237  may be disposed on the one or more end sections  235  above the one or more injection ports  236 . In other embodiments, the one or more valves  237  may be disposed on the one or more ends sections  235  below the one or more injection ports  236 . In certain embodiments, the one or more valves  237  may be tree valves. 
         [0026]    In certain embodiments, during shut ins, gas may segregate into the one or more peaks  233  of the jumper lines  230  and water may segregate into the one or more end sections  235  of jumper lines  230 . The one or more valves  237  may be manipulated to drain the water from the one or more end sections  235 , thus lowering the risk of forming hydrates when the lines are restarted. 
         [0027]    Referring now to  FIG. 3 ,  FIG. 3A  illustrates a side view of jumper line configuration  300  and  FIG. 3B  illustrates a top view of jumper line configuration  300 . As can be seen in  FIG. 3A , jumper line configuration  300  may comprise a first subsea device  310 , a second subsea device  320 , and a jumper line  330 . Jumper line  330  may comprise straight section  331 , one or more elbows  332 , peak  333 , and one or more end section  335 . Jumper line  330  may further comprise one or more injection ports  336  and one or more valves  337 . 
         [0028]    In certain embodiments, straight section  331  may be inclined with respect to the primary axis. In  FIG. 3 , peak  333  is comprised of a single elbow  332 . Similar to jumper line configuration  200 , jumper line configuration  300  does not comprise a valley defined by one or more peaks  333 . Rather, in certain embodiments, the maximum elevation of jumper line configuration  300  occurs at peak  333 , and no local maximum elevation occurs on either side of peak  333 . However, as shown in  FIG. 3B , jumper line  330  may comprise one or more secondary elbows  338 . The one or more secondary elbows  338  may be arranged in a configuration that does not result in the formation of a valley in jumper line  330  along the primary axis. For example, in certain embodiments, the one or more secondary elbows  338  may be in an axis perpendicular to the primary axis and produce one or more bends  339  in jumper line  330  in the same plane as the flow within the jumper line  330 . In certain embodiments, the one or more secondary elbows  338  may provide flexibility to the jumper line configuration  300 . 
         [0029]    The jumper line configuration discussed herein may have several advantages. One advantage is that the jumper line configurations discussed herein are able to provide bends without having valleys, thus increasing the flexibly while limiting the formation of hydrates. Another advantage is that using the jumper line geometry discussed herein, gas may segregate into the higher part so of the jumper line and water may segregate in the low sections, thus allowing water to be drained during shut ins. 
         [0030]    While the embodiments are described with reference to various implementations and exploitations, it will be understood that these embodiments are illustrative and that the scope of the inventive subject matter is not limited to them. Many variations, modifications, additions and improvements are possible. 
         [0031]    Plural instances may be provided for components, operations or structures described herein as a single instance. In general, structures and functionality presented as separate components in the exemplary configurations may be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component may be implemented as separate components. These and other variations, modifications, additions, and improvements may fall within the scope of the inventive subject matter.

Summary:
A jumper line system comprising: a first subsea device; a second subsea device; and a jumper line providing fluid communication between the first subsea device and the second subsea device, wherein the jumper line does not comprise a valley.