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RELATED APPLICATIONS 
       [0001]    This application is related to and claims priority to U.S. provisional application No. 61/360,235 filed on Jun. 30, 2010. 
     
    
     FIELD OF THE INVENTION 
       [0002]    The present invention is generally related to hydrocarbon production, and more particularly, to producing hydrocarbons with the assistance of artificial lift. 
       BACKGROUND OF THE INVENTION 
       [0003]    Two forms of artificial lift that help prolong the life of hydrocarbon wells are the use of gas lift and well unloading units. These two forms of artificial lift are common knowledge in the industry and are applied around the world. Moreover, each have inherent challenges, particularly in offshore environments where cost and space become important limitations. 
         [0004]    As reservoir pressure declines due to depletion, the lift performance of oil wells suffers and at a certain point the well is no longer able to produce liquids to the surface naturally or economically because the pressure at the reservoir is not large enough to overcome the hydrostatic head of the fluids between it and the production tree at the platform. To increase the hydrocarbon production, the lift performance or inflow performance must be enhanced. If the inflow performance cannot be changed, which is typically the case, then the vertical lift performance must be improved to allow the well to flow. Two effective ways to do this are to reduce the wellhead flowing pressure at the surface or to reduce the hydrostatic head of fluid in the production tubing. Reducing the pressure at the surface can be achieved by using a Well Unloading Unit (WUU). This involves the use of pumping equipment on the surface to reduce backpressure of the well thus allowing flow up the well to surface. The fluids are subsequently pumped into the production pipeline at higher pressure. The problem associated with the conventional well unloading unit process is that any gas produced is vented to the atmosphere and lost. This is both an environmental concern and a lost production/revenue opportunity as the gas has value and could be sold. 
         [0005]    Gas lift is another widely used and effective form of artificial lift applied in the industry. Gas lift involves the process of injecting gas at high pressure into the annulus of a well, typically an annulus between the production tubing and the innermost well casing. The gas enters the production tubing several thousand feet below the surface through a check valve and has the desired effect of reducing the fluid gradient in the tubing and thus lowering the wellbore flowing pressure. This increases the drawdown on the well and increases both liquid rates and reserves. 
         [0006]    The major problem with applying gas lift to a well is that high pressure gas is required, typically greater than 1000 psi. This gas source can come from other high pressure gas wells being produced on the platform or by installing a compressor to take low pressure gas, compress it, and use it for gas lifting. 
         [0007]    Oftentimes, using high pressure gas from other wells is not an option for operations. Additionally, even if there is a well with high pressure gas, it is only a short-term solution as reservoir pressures decline quickly and the gas pressure soon reaches a point where it is not adequate for gas lifting. The other option is to install a gas lift compressor. This is preferred as the pressure can be regulated and a stable supply of gas can be achieved. However, the problem with this option is the high cost, large footprint and immobility of compressors. A gas lift compressor typically requires an investment of more than US$ 2 million. Additionally, the units are immobile—the cost to move a gas lift compressor from one platform to another is more expensive than the compressor itself. A gas lift compressor also has a large foot print and takes up a big portion of the deck space on an offshore platform. If a platform does not warrant the installation of a gas lift compressor due to economics or spacial limitations, then hydrocarbons are typically left behind in the reservoir. 
       SUMMARY OF THE INVENTION 
       [0008]    The present invention provides a well unloading unit and compressor system and an associated method for producing hydrocarbons from a well in fluid communication with a reservoir formation. According to one embodiment, the system includes an unloading unit that is configured to receive a produced fluid having hydrocarbons from the well via a production tree and separate the produced fluid into a liquid fluid and a gas fluid. For example, the unloading unit can be a three-phase separator configured to separate water from the produced fluid, and/or the unloading unit can include a kinetic separator such as a gas-liquid cylindrical cyclone. A compressor in fluid communication with the unloading unit is configured to receive the gas fluid from the unloading unit and compress the gas fluid to a predetermined pressure so that the gas fluid can be re-injected into the well to help lift the produced fluid from the reservoir formation to the production tree. A gas manifold is configured to receive the compressed gas fluid from the compressor and distribute the gas fluid to at least one production tree and at least one corresponding well. A pump is configured to receive the liquid fluids from the unloading unit, increase the fluid pressure of the liquid fluid, and deliver the liquid fluid to a pipeline. For example, the pump, which can be located at an off-shore topside facility, can be configured to deliver the liquid fluid to a subsea pipeline located on a seafloor so that the liquid fluid can be transported through the pipeline to a remote location, such as an on-shore processing facility. 
         [0009]    The unloading unit, compressor, and gas manifold can be configured to operate as a substantially closed gas lift system, such that the unloading unit receives the gas fluid previously injected into the well. 
         [0010]    In some cases, the system can be provided as a modular system that can be relocated depending on the needs of the reservoir. In particular, the unloading unit, compressor, gas manifold, and pump can be disposed on one or more skids, so that each skid can easily be transported and re-used for producing hydrocarbons from different reservoir formations. 
         [0011]    According to another embodiment, a method includes receiving in an unloading unit a produced fluid from the well and separating the produced fluid into a liquid fluid and a gas fluid. For example, the produced fluid can be separated kinetically, such as by a gas-liquid cylindrical cyclone, and/or water can be separated from the gas and liquid fluids. The gas fluid from the unloading unit is compressed to a predetermined pressure and distributed to at least one production tree and corresponding well. From the manifold, the gas fluid is re-injected into the well to help lift the produced fluid from the reservoir. Also, the fluid pressure of the liquid fluid is increased in a pump, and the liquid fluid is delivered to a pipeline, such as a subsea pipeline located on a seafloor. The effect of receiving the produced fluid and increasing the pressure of the liquid fluid can be to reduce the backpressure at the well. 
         [0012]    The unloading unit, a compressor for performing the compressing step, a gas manifold for performing the distributing step, and the pump can be provided on one or more skids. Each skid can be transported from a location proximate the reservoir formation to a location proximate a second reservoir formation, and the unloading unit, the compressor, the gas manifold, and the pump can then be re-used for producing hydrocarbons from the second reservoir formation. 
         [0013]    In some cases, the step of re-injecting the gas fluid is performed while the unloading unit is receiving the produced fluid from the well, such that the well is producing while being subjected to a gas lift operation. The step of receiving the produced fluid can include receiving gas fluid that was previously injected into the well such that the gas fluid is re-used in a substantially closed gas lift cycle. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0014]      FIG. 1  is an environmental view of an offshore production platform receiving hydrocarbons from a plurality of subsea wells and delivering hydrocarbons to a pipeline, in accordance with an embodiment of the present invention. 
           [0015]      FIG. 2  is a schematic illustration of a well unloading unit and compressor system, in accordance with an embodiment of the present invention. 
           [0016]      FIG. 3  is a schematic process and flow diagram of a well unloading and compressor system, in accordance with an embodiment of the present invention. 
       
    
    
     DETAILED DESCRIPTION 
       [0017]    The present invention now will be described more fully hereinafter with reference to the accompanying drawings, in which some, but not all embodiments of the invention are shown. Indeed, this invention may be embodied in many different forms and should not be construed as limited to the embodiments set forth herein; rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art. Like numbers refer to like elements throughout. 
         [0018]    Referring to  FIG. 1 , an offshore oil production platform  11  is shown at the surface  13  of the sea. Platform  11  is shown as a floating platform, but is merely meant to be representative for any offshore oil platform known in the art, such as jack-up or tension leg platforms. Risers  15  extend from platform  11  to subsea wellheads  17 . Wellheads  17  are located at the sea floor  19 . Wellheads  17  are positioned above, and in fluid communication with, a string of production tubing  21 . Tubing  21  typically extends axially through a series of casing  22  extending below sea floor  19  at least to a depth such that casing is positioned within a reservoir formation  23  having hydrocarbons therein. Perforations  25  extend through casing  22  so that production tubing  21  is in fluid communication with reservoir  23 . 
         [0019]    A production flowline  27  extends from platform  11  toward sea floor  19 . Flowline  27  connects to a pipeline terminal  29  positioned on sea floor  19 . Pipeline terminal  29  is in fluid communication with a pipeline  31 . 
         [0020]    Hydrocarbons from reservoir  23  enter casing  22  through perforations  25  and flow up tubing  21  to subsea wellhead  17  at sea floor  19 . Hydrocarbons then flow up riser  15  to platform  11 . Typically, the hydrocarbons go through initial processing, such as separating gas and liquid, so that the liquid hydrocarbons can then flow down flowline  27  for delivery into pipeline  31 . Typically, pipeline  31  is flowing at a predetermined pressure. Therefore, a pump is usually utilized to bring the liquid hydrocarbons to a sufficient pressure for entering pipeline  31 . 
         [0021]    Referring to  FIG. 2 , a well unloading unit and compressor system  33  comprises a production tree  35 . Production tree  35  can be conventional surface production tree that is located on platform  11  and receives the produced hydrocarbons from riser  15 . As will be readily appreciated by those skilled in the art, typically, there are a plurality of production trees  35  that are each associated with a riser  15  and subsea wellhead  17 . System  33  also includes an unloading unit  37  positioned on platform  11 . Unloading unit  37  receives fluids from production tree  35  and separates the liquid and gas fluids. In an embodiment of the invention, the produced fluids from production tree  35  enter unloading unit  37  at less than 50 psi. Unloading unit  37  can include a static separator, such as a vessel, which lets the gas and liquid phases separate over time. In a preferred embodiment, a three-phase separator is used such that produced water is also separated from the produced fluids. Alternatively, unloading unit  37  can also be a kinetic separator that uses centrifugal forces to help separate the gas and liquid fluids. Such a kinetic separator can be a gas-liquid cylindrical cyclone (GLCC), which is passive in that it does not require any moving parts or motors to create the centrifugal forces. 
         [0022]    A compressor  39  in fluid communication with unloading unit  37  receives gas fluids from unloading unit  37 . Compressor  39  compresses the produced gases to a predetermined pressure so that the gases can be re-injected into the well to help lift the hydrocarbons from reservoir formation  23  ( FIG. 1 ) to production tree  35 . A gas manifold  41  receives the compressed gas from compressor  39  and distributes the gas to each production tree  35  corresponding with subsea wellheads  17 . In an embodiment of the invention, the compressed gas flows down the annulus between production tubing  21  and casing  22  for delivery in the well near the depth of reservoir formation  23 . As can be readily appreciated by one skilled in the art, gas can also be delivered through dual tubing or concentric tubing extending into the well, wherein a portion of the tubing delivers gas while another portion receives the produced hydrocarbons. 
         [0023]    System  33  includes a pump  43  that can be positioned on platform  11 . Pump  43  receives liquids from unloading unit  37  and increases the fluid pressure of the liquids. The liquids are then communicated to pipeline  31 . 
         [0024]    Referring to  FIG. 3 , system  33  is illustrated showing the process flow of an embodiment of system  33  in more detail. A manifold skid assembly  45  includes a production manifold  47 . Production manifold  47  is in fluid communication with a plurality of production trees  35 . Production manifold  47  collects the produced fluids from each of the plurality of production trees  35  prior to separation. Manifold skid assembly  45  preferably has production manifold  47  mounted to a skid with piping inlets, controls and valves already assembled. Therefore, when manifold skid assembly  45  is installed, all that is necessary once the skid is in place, is to align piping from production trees  35  with the piping inlets associated with manifold skid assembly  45 . 
         [0025]    In an embodiment of the invention, a shut down skid assembly  49  is positioned downstream of manifold skid assembly  45 . Shut down skid assembly  49  preferably includes a shut down valve assembly  51  for controlling fluid flow from production manifold  47 . Shut down skid assembly  49  preferably includes shut down valve assembly  51  and associated inlet and outlet piping mounted to a common skid. Therefore, when shut down skid assembly  49  is in place, all that is needed is to install and align piping from one skid assembly to another, such as between the outlet piping from manifold skid assembly  45  with the inlet piping of shut down skid assembly  49 . In a preferred embodiment, shut down valve assembly  51  can be remotely activated in case of an emergency. 
         [0026]    System  33  also includes a separator skid assembly  53  having a separator  55  mounted thereon, and a liquid surge skid assembly  57  having a liquid surge tank  59  mounted thereon. In the embodiment shown in  FIG. 3 , unloading unit  37  comprises separator skid and liquid surge skid assemblies  53 , 57 . Separator skid assembly  53  is positioned downstream of manifold skid assembly  45 . Separator skid assembly  53  is preferably also positioned downstream of shut down skid assembly  49  so that shut down valve assembly  51  can control fluid flow prior to it being received by separator skid assembly  53 . Separator  55  can be a static or kinetic separator as discussed above herein. Separator skid assembly  53  preferably includes separator, piping, valves and controls mounted to a common skid, so that connecting of piping inlets and outlets is all that is required once separator skid assembly  53  is positioned in place on platform  11 . 
         [0027]    In a preferred embodiment, separator  55  is a three-phase separator having gas, water and oil outlets. After separation, water is conveyed from separator skid assembly  53  for treatment or further production utilization, if water flooding is being performed. The oil liquids are conveyed from separator skid assembly  53  to liquid surge tank  59  of liquid surge skid assembly  57 . Liquid surge tank  59  is typically a vessel. Collecting the oil liquids in liquid surge tank  59  provides a way to help maintain a constant flow rate and pressure of the oil to be pumped to pipeline  31  ( FIGS. 1 &amp;2 ). Additionally, liquid surge tank  59  can act as a second stage separator to further separate gaseous particles from the oil liquids received from separator  55 . Liquid surge tank skid assembly  57 , which includes liquid surge tank  59 , associated piping inlets and outlets, valves and controls, are preferably pre-mounted on a common skid so that connecting of piping inlets and outlets is all that is required once liquid surge tank skid assembly  57  is positioned on platform  11 . 
         [0028]    System  33  includes a pump skid assembly  61  having pump  43  mounted thereon. Pump  43  is preferably a positive displacement pump, such as a reciprocal pump. Pump  43  increases the pressure of the liquid from separator  55  and liquid surge tank  59  so that it can enter pipeline  31  ( FIGS. 1&amp;2 ) at the predetermined pressure for the pipeline  31 . Pump skid assembly  61  preferably includes pump  43 , an engine or motor, associated inlet and outlet piping, valves and controls pre-mounted on a common skid so that connecting of piping inlets and outlets and fuel or power supply is minimal once in position on platform  11 . In an embodiment of the invention, an additional shutdown skid assembly  63  having shut down valve  65  is positioned downstream of pump skid assembly  61  so that flow to pipeline  31  can be controlled in case of an emergency. In a preferred embodiment, shut down valve  65  can also be a remote-actuated valve. 
         [0029]    A compressor skid assembly  67  is also positioned downstream of separator skid assembly  53 . Compressor  39  is mounted on the skid of compressor skid assembly  67 . Compressor  39  is a compressor capable of compressing the separated gas from an inlet pressure of less than 50 psi to approximately 1100-1200 psi, which is then sent to gas manifold  41  ( FIG. 2 ) for distribution to the production wells for gas lifting. In a preferred embodiment, compressor  39  can handle 2 million standard cubic feet per day (MMSCF/D), which is suitable for gas lifting four or five wells. Additional compression stages, or an additional compressor skid assembly can be utilized when gas lifting more than five wells. 
         [0030]    In a preferred embodiment compressor  39  is a three stage reciprocating compressor assembly. Compressor assembly includes suction scrubbers or de-liquifiers to remove remaining liquid entrained in the gas after each stage of compression, a gas engine and fin-fan motor driven coolers to reduce temperature of compressed gas after each stage of compression. A separate fuel gas skid can be utilized to supply fuel to the gas engine. Liquids from the scrubbers can be conveyed from compressor skid assembly  67  to liquid surge tank  59 . Compressor skid assembly  67  preferably includes compressor  39  with its associated equipment, piping, valves and controls pre-mounted on a common skid so that minimal installation work is necessary after the compressor skid assembly  67  is in place on platform  11 . Excess gas from compressor  39  can be diverted to a closed-drain scrubber, which can also receive the gas separated from separator  55  and liquid surge tank  59 . 
         [0031]    As discussed in the Background, one problem associated with conventional well unloading units or processes is that the produced gas that is separated is vented to the atmosphere and lost. System  33  advantageously solves this problem by collecting the produced gas after separation for re-injection into the well for gas lifting application. 
         [0032]    System  33  combines two key forms of artificial lift—1) reduction of backpressure at the surface and 2) gas lift to increase production rates and reserves from underground oil reservoirs. System  33  allows wells to be gas lifted while simultaneously flowing to a very low surface pressure (&lt;30 psi) because unloading unit  37  and pump  43  prevent the buildup of backpressure on production trees  35 . Unloading unit  37  also provides the gas utilized for the gas lift. System  33  has the additional benefit of capturing what would otherwise be vented hydrocarbons, and thus reducing greenhouse gas emissions and utilizing it for artificial lift. 
         [0033]    Additionally, the wells can be both producing production fluid to unloading unit  37  and gas lifted at the same time because the injected gas is injected through the annulus between tubing  21  and casing  22  or through a dual string of tubing. This creates a closed loop gas lift system and the gas is re-used for lifting, making it fully optimized to maximize production. No conventional artificial lift systems have accomplished this closed loop gas lift, while reducing the backpressure at the surface. Moreover, no other conventional artificial lift system does this while also capturing the otherwise vented gaseous produced fluids. 
         [0034]    Another advantageous aspect of system  33  is its mobility. System  33  includes manifold skid assembly  45 , unloading unit  37  with separator skid and liquid surge tank skid assemblies  53 , 57 , pump skid assembly  61  and compressor skid assembly  67 . Because each of these components can include pre-mounted and installed equipment and piping, system  33  is modular and can be rigged up or down in a single 12 hour shift offshore. Such mobility enables system  33  to service multiple platforms for maximum usage. System  33  also requires much less capital investment as compared to standard gas lift operations which require the upfront cost of a gas lift compressor on each platform. When system  33  has extracted suitable reserves from a first platform  11  and it is no longer economical to keep the system running, system  33  can be rigged down and mobilized to another platform  11  to continue operation because of its modular nature. 
         [0035]    Such mobility and flexibility to service multiple platforms is not known to exist for any other systems, which also provides a unique opportunity to effectively and economically extract reserves that would otherwise not be produced after the well productivity declines. 
         [0036]    Another aspect is that system  33  has a small space requirement or “footprint” on an offshore platform deck as compared with conventional gas lift assemblies. Having such a small footprint further allows well work operations, such as slick line and electric line operations, to take place simultaneously with system  33 . This is advantageous in several offshore environments where frequent well interventions are required. 
         [0037]    While the invention has been shown in only some of its forms, it should be apparent to those skilled in the art that it is not so limited, but susceptible to various changes without departing from the scope of the invention. For example, the compressor skid assembly  67  could also receive the separated gas from liquid surge tank  59  for compression and re-injection into the wells.

Summary:
A system for producing hydrocarbons from a well includes an unloading unit that receives fluids from a wellhead. The unloading unit separates the oil and gas, and the oil is pumped to a pipeline. Using the unloading unit and the pump helps to reduce the pressure at the wellhead which helps increase production. The gas separated by the unloading unit is compressed and re-injected into the well to create a gas lift which further helps increase production. Capturing and reinjecting the separated gas for gas lift operations reduces environmental damages associated with conventional unloading unit and pump assemblies. The unloading unit, compressor, and pump are modular for quicker installation and a smaller footprint. After increasing the productive life of a first reservoir, the system can be broken down and reassembled for use at another reservoir.