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This application is a continuation in part of U.S. patent application Ser. No. 12/853,296, filed Aug. 10, 2010 and incorporates that application by reference. 
    
    
     BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     Embodiments of the present invention relate to rapidly deployable flexible enclosure systems for the collection, containment and presentation of hydrocarbon emissions from compromised shallow or deepwater oil and gas well systems, pipelines, and subsea fissures. In particular, the invention relates to such systems used in conjunction with enclosures connected to floating platforms for separating and routing liquid and gaseous hydrocarbon products captured by the enclosure systems. 
     2. Discussion of Related Art 
     Oil leakage and or other environmentally sensitive hydrocarbon emissions originating from varied underwater compromised locations, including natural events, need to be addressed quickly and effectively to minimize damage. The longer the delay to respond and provide effective remediation for these situations, may cause unintended and exponential problems across economic, environmental and societal realms. 
     Current resources and technologies are limited to one incident at a time within the same response area. This is due to limited availability of an extensive required support infrastructure, the cost, and with few staged deployment locations. There were 1361 offshore projects active in 69 countries, operated by 198 companies as of Jul. 7, 2012. 
     The Deepwater Horizon oil spill (or BP oil spill) began gushing oil into the Gulf of Mexico on Apr. 20, 2010 after an explosion on the Deepwater Horizon oil rig killing 11 workers. It was not capped until Jul. 15, 2010, after 4.9 million barrels of crude oil were spilled into the Gulf. The economic and environmental devastation caused by this disaster are well known. 
     Government entities and regulators, as well as oil and gas companies, continue to search for improved methods to address future oil spills. There are a number of small to large scale Oil Spill Response Organizations (OSRO) all with inherent limitations in response times and capabilities. 
     In February of 2011, A group of oil companies led by Exxon formed a consortium called the Marine Well Containment Company MWCC and announced that they had developed a system that could stop an undersea oil spill in a matter of weeks, rather than the 85 days it took to cap the Deepwater Horizon oil spill. The system is designed to be assembled within two to three weeks after an oil spill begins. 
     Helix Energy Solutions, which assisted with the Deepwater Horizon oil spill, has developed a Fast Response System for future spills. Helix incorporates a number of deployed and operational resources that will stop work and redirect the vessels and required resources to the spill location. 
     BP recently constructed their own system weighing some 500 tonnes that requires 35 trailers, seven aircraft (Five Russian Antonov AN-124 and two Boeing 747-200s) to transport from storage to a major airport and then fly to the nearest airport that can handle such aircraft and equipment close to the spill location to start unloading for deployment. BP claims this system can be transported and deployed within ten days. 
     What is needed is a readily transportable, quickly deployable system to collect and contain hydrocarbon emissions from compromised shallow to ultra-deepwater oil and gas well systems, pipelines, and subsea fissures. 
     SUMMARY OF THE INVENTION 
     This summary is provided to introduce a selection of concepts in a simplified form that are further described in the detailed description of the invention and is not intended to limit the scope of the claimed subject matter. 
     One or more embodiments of the present invention are directed to a transportable, quickly deployable and operable system to collect and contain hydrocarbon emissions from compromised shallow to ultra-deepwater oil and gas well systems, pipelines, structures and subsea fissures. 
     The objective is to collect, contain and direct the compromised hydrocarbon emissions for proper presentation without requiring the use of dispersants or Hydrate inhibitors and associated support vessels, while significantly reducing the time to deploy and begin operations. 
     With a rapid deployment and versatile containment strategy provided by this invention commencing within a few days of a compromised emissions notification, other resources can focus on drilling a relief well or establishing other long term solutions including the initial spill remediation. 
     The system includes a self-supporting flexible containment enclosure (SSFCE) for capturing and containing leaking hydrocarbons and a floating platform, both providing for the separation and routing of liquid and gaseous hydrocarbon products. The separation of the gas, oil and water is performed within the uppermost portion of the SSFCE in conjunction with the floating platform in a controlled process using sensors and instrumentation to monitor and adjust the flow rates. The historical analogy is a “gun barrel separator”. 
     The system does not rely on sump or pumping of the product as a continuous method of removal. The gas is generally flared remotely under its own pressure and flow rate, and the liquid product is presented to the operators under its own pressure and flow rate. 
     The floating platform is attached to the SSFCE and together they separate liquid and gaseous products. The gaseous product may be burned at the platform or (more often) at a separate station, while the liquid product may be salvaged by a separate vessel via a pipeline. Burning the gaseous product at the floating platform requires a significantly large platform such as a vessel that could incorporate a flare system. Liquid product is generally salvaged by a separate vessel and/or temporarily stowed in floating assemblages awaiting offload or changeouts to a vessel/tanker. 
     Apparatus for collecting, separating, and delivering a combination of gaseous product and liquid product emitted into a liquid environment beneath the apparatus, includes a separator for separating the gaseous product and liquid product, the separator including a separator enclosure, a liquid product conduit for delivering liquid product to a liquid product destination, a gaseous product conduit for delivering gaseous product to a gaseous product destination, and a diverter within the separator enclosure for diverting gaseous product away from the liquid conduit. 
     The apparatus also includes a self-supporting flexible containment enclosure (SSFCE) forming a tube having a first end disposed at the source of the gaseous product and liquid product and having a second end disposed at the separator enclosure, such that the gaseous product and liquid product enter the SSFCE first end, rise within the SSFCE, and approach the SSFCE second end adjacent to and beneath the diverter. Note that the separator enclosure may include the top end of the SSFCE, and the diverter may be located partially or fully within the top end of the SSFCE or above it. 
     The liquid product conduit includes a first end above and adjacent to the diverter to collect the liquid product and above a second end spaced apart from the separator enclosure to deliver the liquid product. The gaseous product conduit includes a first end spaced apart from and above the diverter and the liquid product conduit first end to collect the gaseous product and a second end spaced apart from the separator enclosure to deliver the gaseous product. 
     As a feature, the apparatus may further include a control mechanism for determining volume of the liquid product and/or the gaseous product within the separator enclosure. The control system changes pressure within the separator enclosure based on the determined volume. For example, pressure within the separator enclosure could be controlled by affecting the flow rates of one or both of the products. 
     The SSFCE may comprise segments formed as elongated tubes, a loop material flap formed at one end of each segment, and a hook material flap formed at the other end of each segment, wherein the hook material flap on a segment engages with the loop material flap on an adjacent segment, forming a continuous tube, and subsea buoys attached to the segments for creating neutral buoyancy. 
     The hook flap may formed in an I shape and the loop flap formed in a V shape which is configured to engage both sides of the I shape, or vice versa. 
     Straps attached along the long sides of segments include connection points configured to allow a strap end to connect to the end of an adjacent strap. This provides structural support for the SSFCE. 
     A relief port having an opening configured to allow removal of a portion of SSFCE content (e.g. sea water, the combination of gaseous product and liquid product, solid particulates, or some combination of these). 
     As a feature SSFCE segments may form a Y shape such that one end of the Y allows for a single gaseous product and liquid product flow and the other end of the Y allows for two gaseous product and liquid product flows. In other words, one flow may be divided into two (or more) flows, or two flows may be combined into one flow, as needed. 
     The SSFCE preferably further included a terminator interface assembly configured to engage a targeted area of emissions. One sort of terminator interface assembly comprises a flaring canopy having a clamping mechanism for clamping the canopy to an underwater surface. This terminator is especially useful for covering extended areas of leakage, for example on the sea floor. Another sort of terminator interface assembly comprises a conduit and apparatus for engaging the conduit to an opening, such as a pipe end or a hole is a pipe or other surface. 
     As a feature, the gaseous product destination might be a flare platform configured to burn off gaseous product. In addition, the apparatus may further include a floating platform attached to the separator enclosure, the floating platform further including apparatus configured to selectively change platform buoyancy to change draft of the floating platform, partially or fully submerging it when advisable because of turbulence or the like. 
     The invention for the most part is a passively operated system except for the required flow controls, sensors, buoyancy operation functions and process control systems. Pumps used to manage the compromised emissions products would typically be located aboard Floating Production Storage Offloading (FPSO or FSO) vessels or shuttle tankers for receiving the products. 
     A method according to the present invention of collecting, separating, and delivering a combination flow of gaseous product and liquid product emitted into a liquid environment, includes the steps of providing a tubular self supporting flexible containment enclosure (SSFCE) having a bottom end disposed at a source of the emitted product flow and a top end above the source of the emitted product flow; allowing the emitted product flow to rise within the SSFCE, separating the gaseous product from the liquid product within a separator attached at the top end of the SSFCE, the separator comprising a diverter within a separator enclosure, presenting the separated gaseous product to a gaseous product destination; and presenting the separated liquid product to a liquid product destination. 
     The step of separating comprises the steps of introducing a closed concave diverter into the rising product flow, the closed side of the diverter disposed downward toward the emitted flow, diverting the flow around the diverter, allowing the liquid product to sink into the diverter upper open side, and allowing the gaseous product to rise above the diverter. 
     The method collects the liquid product within the diverter upper open side and passes it through a liquid conduit to the liquid product destination. The method also collects the gaseous product above the diverter and passes it through a gaseous conduit to the gaseous product destination. 
     The method also determines volume of at least one of either liquid product or gaseous product within the separator enclosure and changes pressure within the separator enclosure based on the determined volume. 
     The step of providing the SSFCE comprises the steps of forming segments formed as elongated tubes, forming a loop material flap at one end of each segment, forming a hook material flap at the other end of each segment, engaging the hook material flap on a segment with the loop material flap on an adjacent segment, forming a continuous tubular SSFCE, attaching the bottom end of the SSFCE adjacent to the source of the emitted product flow, partially filling the SSFCE with liquid from the liquid environment, and attaching the top end of the SSFCE to the separator. 
     The step of attaching the bottom end of the SSFCE adjacent to the source of the emitted product flow might comprise the step of providing a flaring canopy and clamping the canopy to an underwater surface or the step of attaching the bottom end of the SSFCE adjacent to the source of the emitted product flow further comprises the step of providing conduit and engaging the conduit to an opening. 
     The method may also burn off gaseous product at the gaseous product destination. 
     Those skilled in the art will appreciate that configurations similar to embodiments shown and described herein may be used. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIG. 1A  shows a top view of a floating platform according to the present invention,  FIG. 1B  shows a side view of the floating platform of  FIG. 1A , and  FIG. 1C  shows an isometric bottom view of the floating platform of  FIGS. 1A and 1B . 
         FIG. 1D  is a side cutaway view of one example of a bubble diverter according to the present invention. 
         FIGS. 2A ,  2 B,  2 C, and  2 D show detailed views of portions of the floating platform of  FIG. 1 .   
         FIG. 2A  is an isometric side view of a solar panel elevated assembly according to the present invention. 
         FIG. 2B  is an isometric side view of a manhole access port. 
         FIG. 2C  is an isometric side view of an ingress bulkhead port and door formed in a side wall of the rigid enclosure for the ingress of water from an external pump. 
         FIG. 2D  is an isometric side view of an outrigger pump assembly connected to the ingress bulkhead port shown in  FIG. 2C . The hinged door assembly of  FIG. 2C  is removed for clarity. 
         FIGS. 3A through 3L  show various views of SSFCE segments. 
         FIG. 3A  is a side view of a first embodiment of an SSFCE segment including support straps and strap termination points for connecting segments. 
         FIG. 3B  is a detailed view of one of connected strap termination points of  FIG. 3A . 
         FIG. 3C  is a detailed view of connected strap termination points as in  FIG. 3A , further including a protruding attachment point for connecting a buoy and/or other lines. 
         FIG. 3D  is a oblique detailed isometric wireframe view of a SSFCE Segment with hidden edges. 
         FIG. 3E  is an oblique detailed hidden isometric view of a second embodiment of an SSFCE segment as in  FIG. 3A , further including drag coefficient reduction panels and tail panels. 
         FIG. 3F  is a top view of the segment of  FIG. 3E . 
         FIG. 3G  is a top view and variation on the segment of  FIG. 3E  without the tail panels where the drag coefficient reduction panels are connected using both opposing edges of the SSFCE segment or in some cases opposing edges of two or more SSFCE segments. 
         FIG. 3H  is a side view of the segment of  FIG. 3E . 
         FIGS. 3I-L  show isometric views of another embodiment of a SSFCE segment including a relief port. 
         FIGS. 4A-4F  show detailed side views of various hook-and-loop connections between segments. 
         FIG. 4A  is a side view of a hook portion of a first embodiment of the connection, while  FIG. 4B  is a side view of the loop portion. 
         FIGS. 4C and 4D  (both side views) show a second embodiment of a hook-and-loop connection and  FIGS. 4E and 4F  (both side views) show a third embodiment of a hook-and-loop connection. 
         FIGS. 5A and 5B  illustrate an example of a deployment configuration of the SSFCE.  FIG. 5A  shows a side view of the deployment.  FIG. 5B  shows the connection between a Positive Offset Neutral Buoyancy Attachment Device (PONBAD) and a strap termination point. 
         FIGS. 6A ,  6 B,  6 C, and  6 D illustrate connections between the SSFCE and leak sources. 
         FIG. 6A  is a side view of a first embodiment of a subsea terminator interface. 
         FIG. 6B  is a side view of a terminator lower conduit assembly. 
         FIG. 6C  is a top view of compression and strap plates for connection of frustum panel enclosure section to terminator conduit to complete the assembly as shown in side view  FIG. 6A . 
         FIG. 6D  is a side view of a second embodiment of a subsea terminator interface, configured to connect to dual SSFCE segments  300 . 
         FIGS. 7A and 7B  illustrate an SSFCE tee assembly  300 B.  FIG. 7A  is a side view of the assembly, and  FIG. 7B  is bottom isometric view of the assembly. 
         FIG. 7C  illustrates an outer side view of a canopy terminator assembly.  FIG. 7D  illustrates a side view of a skirt assembly. 
         FIGS. 8A-8E  illustrate a floating flare assembly according to the present invention.  FIG. 8A  an isometric view of the floating flare assembly,  FIG. 8B  is a side view of the floating flare assembly,  FIG. 8C  is a stern side isometric view of the floating flare assembly,  FIG. 8D  is a bottom isometric view of the floating flare assembly and  FIG. 8E  is a detailed hidden isometric view of a thermal block used in the floating flare assembly. 
         FIG. 9  illustrates buoyancy control logic for the floating platform flotation vessels. 
         FIG. 10  is a flow chart illustrating product flow from origination to potential destinations, 
         FIG. 11  is a block diagram illustrating a majority of the Process Control System  950  operations performed on the Floating Platform  100   
         FIG. 12  is a block diagram illustrating a majority of the Process Control System  850  operations performed on the Floating Flare  800 . 
         FIG. 13  illustrates an example of the fluid flow control portion of the control system. 
         FIG. 14  illustrates a 4 phase solid, liquid and gas model of the Floating Platform Rigid Enclosure, Self-Supporting Flexible Containment Enclosure (SSFCE) and Bubble Diverting Assembly. 
         FIG. 15  illustrates communication pathway options. 
     
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
     The following table lists elements of the illustrated embodiments of the invention and their associated reference numbers for convenience. 
     
       
         
               
               
             
           
               
                   
               
               
                 Ref. No. 
                 Element 
               
               
                   
               
             
             
               
                 100 
                 Floating platform 
               
               
                 100A 
                 Aft position (Stern) 
               
               
                 100B 
                 Bow position (Fore) 
               
               
                 100P 
                 Port position (Left side) 
               
               
                 100S 
                 Starboard position (Right side) 
               
               
                 101 
                 Mooring point 
               
               
                 102 
                 Flotation vessel 
               
               
                 103 
                 Cleat 
               
               
                 104 
                 Flotation platform upper deck 
               
               
                 105 
                 Support block 
               
               
                 106 
                 Drilled and Tapped Mounting Block 
               
               
                 107 
                 Drilled and Tapped Solid Vertical and Horizontal Bars 
               
               
                 108 
                 Exterior structural beam assembly 
               
               
                 110 
                 Locator buoy support enclosure 
               
               
                 112 
                 Locator buoy 
               
               
                 120 
                 Valve assembly (121 and 122) 
               
               
                 121 
                 Valve (¼ turn Butterfly Valve) 
               
               
                 122 
                 Electrically controlled valve actuator 
               
               
                 123 
                 Pipe assembly 
               
               
                 124 
                 Liquid product port 
               
               
                 125 
                 Pipe segments 
               
               
                 126 
                 Gaseous product port 
               
               
                 127 
                 Flange 
               
               
                 128 
                 Elbow 
               
               
                 129 
                 Tee 
               
               
                 130 
                 Compressed air tank cascade array enclosure 
               
               
                 131 
                 Compressed air tanks 
               
               
                 132 
                 Regulator 
               
               
                 140 
                 Watertight equipment enclosures 
               
               
                 150 
                 Outrigger pump assembly 
               
               
                 151 
                 Outrigger pump assembly frame 
               
               
                 152 
                 Outrigger pump 
               
               
                 154 
                 Outrigger pump discharge pipe assembly 
               
               
                 155 
                 Outrigger pump discharge port flange 
               
               
                 156 
                 Hydraulic Pump 
               
               
                 157 
                 Hydraulic Motor 
               
               
                 158 
                 Hydraulic Lines (supply, return and drain lines) 
               
               
                 159 
                 Diesel Power Unit 
               
               
                 200 
                 Rigid enclosure 
               
               
                 201 
                 Rigid enclosure wall 
               
               
                 202 
                 Manhole entry w/bolted hatch cover 
               
               
                 203 
                 Flow pump bulkhead connection w/bolted hatch cover 
               
               
                 204 
                 Rigid enclosure upper deck 
               
               
                 205 
                 Interior instrument sensor watertight enclosure 
               
               
                 206 
                 Gaseous product port connection 
               
               
                 208 
                 Interior structural beam assembly 
               
               
                 210 
                 Lower perimeter mating assembly 
               
               
                 220 
                 Liquid product port bulkhead connection 
               
               
                 225 
                 Lateral conduit 
               
               
                 230 
                 Internal tee 
               
               
                 235 
                 Downward submerged conduit 
               
               
                 240 
                 Bubble diverting assembly 
               
               
                 245 
                 Stays 
               
               
                 250 
                 Elevated solar panel structure 
               
               
                 252 
                 Watertight solar panels with adjustable angle assembly 
               
               
                 255 
                 Navigation lighting aids 
               
               
                 260 
                 Antennas and support structure 
               
               
                 265 
                 Lightning arrester 
               
               
                 276 
                 Outrigger pump discharge external bulkhead port &amp; hinged 
               
               
                   
                 door 
               
               
                 278 
                 Outrigger pump discharge port internal bulkhead flange 
               
               
                 280 
                 Rigid enclosure bubble diverter 
               
               
                 282 
                 Bubble diverter interior wall 
               
               
                 283 
                 Bubble diverter exterior wall 
               
               
                 284 
                 Bubble diverter upper opening 
               
               
                 286 
                 Bubble diverter closed bottom 
               
               
                 288 
                 Bubble diverter fin standoffs 
               
               
                 290 
                 Bubble diverter fin (paired dashed lines represent front 
               
               
                   
                 and rear fins/slats) 
               
               
                 300 
                 Self-supporting flexible containment enclosure (SSFCE) 
               
               
                   
                 segment 
               
               
                 300A 
                 Segment with drag coefficient reduction elements (302A, 
               
               
                   
                 302B, 308) 
               
               
                 300B 
                 SSFCE tee assembly 
               
               
                 300C 
                 Canopy Terminator 
               
               
                 300D 
                 Segment with relief port 
               
               
                 302 
                 Panel 
               
               
                 302A 
                 Leading edge panel 
               
               
                 302B 
                 Tail panel 
               
               
                 302C 
                 Frustum panel segment 
               
               
                 303 
                 Loop flap (Female Connector or Connection) 
               
               
                 303A 
                 Loop Flap Connection Double Flap 
               
               
                 303B 
                 Loop Flap Connection Quad Flap 
               
               
                 304 
                 Loop material 
               
               
                 305 
                 Hook flap (Male Connector or Connection) 
               
               
                 305A 
                 Hook Flap Single-Hook 
               
               
                 305B 
                 Hook Flap Tri-Hook 
               
               
                 306 
                 Hook material 
               
               
                 308 
                 Support strap 
               
               
                 310 
                 Eyelets 
               
               
                 312 
                 Strap termination connection point 
               
               
                 314 
                 Protruding attachment point 
               
               
                 330 
                 Interior membrane 
               
               
                 332 
                 Exterior membrane 
               
               
                 344 
                 Lateral sleeve 
               
               
                 345 
                 Skirt assembly 
               
               
                 352 
                 Switchable Magnet or other clamping device 
               
               
                 354 
                 Weighted anchoring object 
               
               
                 370 
                 One-way Relief port 
               
               
                 371 
                 One-way Relief port assembly upper terminus 
               
               
                 372 
                 One-way Relief port assembly lower terminus 
               
               
                 373 
                 One-way Relief port panel assembly 
               
               
                 374 
                 One-way Relief port panel assembly flanges 
               
               
                 375 
                 One-way Relief port membrane valve assembly 
               
               
                 380 
                 External membrane gasket panel 
               
               
                 381 
                 Internal membrane gasket panel 
               
               
                 376 
                 Slotted semi-flexible plate 
               
               
                 377 
                 Membrane flaps 
               
               
                 382 
                 Flexible membrane material 
               
               
                 383 
                 Flexible membrane material battens 
               
               
                 378 
                 One-way Relief port lower opening 
               
               
                 384 
                 One-way Relief port lower opening exterior seal perimeter 
               
               
                   
                 connection 
               
               
                 379 
                 One-way Relief port lower opening exterior flap seal 
               
               
                 385 
                 Exterior flap seal perimeter connection 
               
               
                 500 
                 Self-supporting flexible containment enclosure (SSFCE) 
               
               
                 502 
                 Waterline 
               
               
                 503 
                 Seawater 
               
               
                 504 
                 Seafloor 
               
               
                 510 
                 Mooring lines 
               
               
                 516 
                 Anchorage points 
               
               
                 518 
                 Tethered cable connection lanyard. 
               
               
                 520 
                 Subsea buoy 
               
               
                 522 
                 Eye hook 
               
               
                 550 
                 Targeted area of hydrocarbon emissions (leak source) 
               
               
                 564 
                 Liquid Hydrocarbon Emissions (Liquid Product or Crude 
               
               
                   
                 Oil) 
               
               
                 566 
                 Gaseous Hydrocarbon Emissions (Gas Product or Methane 
               
               
                   
                 Gas) 
               
               
                 567 
                 Methane Hydrates (Methane clathrate or Clathrate hydrate) 
               
               
                 568 
                 Reservoir Water 
               
               
                 570 
                 Elevated temperature ascending material 
               
               
                 572 
                 Lower temperature ascending material 
               
               
                 574 
                 Cooler Seawater Descending 
               
               
                 576 
                 Equal interior and exterior pressure. @ 100 feet = 44.5 
               
               
                   
                 psi gauge 
               
               
                 577 
                 Equal interior and exterior pressure. @ 2000 feet = 890 
               
               
                   
                 psi gauge 
               
               
                 578 
                 Equal interior and exterior pressure. @ 5000 feet = 2225 
               
               
                   
                 psi gauge 
               
               
                 600 
                 Subsea terminator interface assembly 
               
               
                 600A 
                 Dual subsea terminator interface assembly 
               
               
                 604 
                 Termination Points 
               
               
                 605 
                 Frustum panel enclosure section (302, 308, 310) 
               
               
                 606 
                 Panel terminator plate 
               
               
                 607 
                 Lower conduit section 
               
               
                 608 
                 Handles 
               
               
                 609 
                 Eye Bolts 
               
               
                 610 
                 Tapered pointed set bolts 
               
               
                 611 
                 Bolt strip 
               
               
                 612 
                 Mounting positions 
               
               
                 613 
                 Fasteners for compression straps 
               
               
                 614 
                 Split plates 
               
               
                 615 
                 Compression straps 
               
               
                 616 
                 Connector plate 
               
               
                 620 
                 Guy lines 
               
               
                 622 
                 Guy lines 
               
               
                 625 
                 Terminator section 
               
               
                 650 
                 Combined terminator tee assembly 
               
               
                 652 
                 Horizontal manifold tee section 
               
               
                 654 
                 Valves 
               
               
                 656 
                 Manifold port 
               
               
                 658 
                 Flanged port 
               
               
                 700 
                 Towable Bladder Bag 
               
               
                 701 
                 Flexible Marine Hose 
               
               
                 702 
                 Shuttle Tanker Vessel or other vessel to present the product to 
               
               
                 750 
                 Ancillary Sensors (Sensors including as an example 751-779) 
               
               
                 751 
                 Pulsed radar liquid level sensor 
               
               
                 752 
                 Laser liquid level sensor 
               
               
                 753 
                 Ultrasonic liquid level sensor 
               
               
                 754 
                 Ultrasonic gas flow sensor 
               
               
                 765 
                 Ultasonic liquid flow sensor 
               
               
                 766 
                 Mechanical vane liquid flow sensor 
               
               
                 767 
                 Multi-point liquid level sensor switch 
               
               
                 768 
                 Pressure sensor 
               
               
                 769 
                 Pressure sensor switch 
               
               
                 770 
                 Load Cell sensor (strain gauge) 
               
               
                 771 
                 Tri-axial accelerometer, rate gyro and magnetometer 
               
               
                 772 
                 Thermocouple sensor 
               
               
                 773 
                 Voltage and current sensor 
               
               
                 774 
                 Photoelectric cell sensor 
               
               
                 775 
                 Moisture detection sensor 
               
               
                 780 
                 Ancillary Equipment (For example 781-799) 
               
               
                 781 
                 Batteries 
               
               
                 782 
                 Charge Controller and Regulators 
               
               
                 783 
                 Solid State IGBT Relays 
               
               
                 784 
                 Snubber and Polarity Protection Diodes 
               
               
                 785 
                 Water to Air Heat Exchanger 
               
               
                 786 
                 Water Pump 
               
               
                 787 
                 Solenoid Operated Valve 
               
               
                 788 
                 Video Camera (internal or external) 
               
               
                 789 
                 LED Lighting 
               
               
                 790 
                 Polycarbonate Lexan ™ MR-10 
               
               
                 791 
                 Digital controlled rotary or linear actuator 
               
               
                 794 
                 Subsea qualified cables, connectors, etc 
               
               
                 796 
                 Water and Gas (high and low pressure) hoses, bulkhead 
               
               
                   
                 fittings, etc. 
               
               
                 799 
                 Electronic Modules 
               
               
                 800 
                 Floating flare platform 
               
               
                 800A 
                 Aft position (Stern) 
               
               
                 800B 
                 Bow position (Fore) 
               
               
                 800P 
                 Port position (Left side) 
               
               
                 800S 
                 Starboard position (Right side) 
               
               
                 801 
                 Lower horizontal structural beam assembly 
               
               
                 802 
                 Floating flare upper deck 
               
               
                 804 
                 Condensate collection enclosure 
               
               
                 805 
                 Chemical pump (Condensate collection enclosure) 
               
               
                 806 
                 Flashback enclosure - seal enclosure 
               
               
                 807 
                 Water pump (Flashback enclosure) 
               
               
                 810 
                 Vertical corner support assembly 
               
               
                 812 
                 Upper horizontal structural beam assembly 
               
               
                 814 
                 Exterior horizontal single support assembly 
               
               
                 816 
                 Exterior horizontal corner support assembly 
               
               
                 820 
                 Radiant panels 
               
               
                 821 
                 Radiant panel flare flange access plates 
               
               
                 822 
                 Thermal block 
               
               
                 824 
                 Thermal block base material 
               
               
                 825 
                 Countersunk fastener hole for base material 
               
               
                 826 
                 High temperature and high strength bonding material 
               
               
                 828 
                 Thermal block insulator material 
               
               
                 829 
                 Countersunk fastener hole for insulator material 
               
               
                 830 
                 Flare assembly (832, 834, 836} 
               
               
                 832 
                 Barrel 
               
               
                 834 
                 Arms 
               
               
                 836 
                 Orifice 
               
               
                 840 
                 Suspended counterweight 
               
               
                 842 
                 Cables 
               
               
                 850 
                 Process Control System 
               
               
                 852 
                 Flare Ignition Controller System 
               
               
                 854 
                 Flare igniter 
               
               
                 856 
                 Flare ignition fuel 
               
               
                 858 
                 Flare ignition purge gas 
               
               
                 902 
                 Top interior surface of flotation vessel 
               
               
                 904 
                 Bottom interior surface of flotation vessel 
               
               
                 906 
                 Air port via bulkhead 
               
               
                 908 
                 Water port via bulkhead 
               
               
                 910 
                 Air vent outlet 
               
               
                 912 
                 Ballast blow out port and inline check valve 
               
               
                 914 
                 Gross/Fine Filter Water Inlet 
               
               
                 918 
                 Water Pump 
               
               
                 920 
                 Electronic liquid level sensor 
               
               
                 921 
                 Surfacing logic 
               
               
                 922 
                 Compressed air inlet solenoid valve 
               
               
                 924 
                 Water outlet solenoid valve 
               
               
                 925 
                 Submerging logic 
               
               
                 926 
                 Air outlet solenoid valve 
               
               
                 928 
                 Water inlet solenoid valve 
               
               
                 935 
                 Buoyancy control system 
               
               
                 950 
                 Process Control System 
               
               
                 951 
                 Electronic Modules 
               
               
                 954 
                 Floating platform product flow system 
               
               
                 958 
                 External Operators 
               
               
                 970 
                 Fluid Flow In 
               
               
                 971 
                 Desired Liquid Level Reference Set Point SP 
               
               
                 972 
                 Liquid Level Sensors Process Variable PV 
               
               
                 973 
                 Offset (+ or −) 
               
               
                 974 
                 PID Controllers 
               
               
                 975 
                 Manipulated Variable MV 
               
               
                 976 
                 Gas Pressure Inputs Process Variable PV 
               
               
                 977 
                 Fluid Flow Out 
               
               
                 980 
                 Ground Radio Data Link (Digital Link Transceiver and 
               
               
                   
                 antenna) 
               
               
                 982 
                 External Operator (Local Site Deployment Group) 
               
               
                 984 
                 External Operator (Remote Spill Management and 
               
               
                   
                 Engineering 
               
               
                 986 
                 Internet Network 
               
               
                 988 
                 Satellite Data Link (Satellite transceiver and antenna) 
               
               
                 990 
                 Satellite Network 
               
               
                   
               
             
          
         
       
     
     For convenience, in the following description the term “FIG.  1 ” is used to refer collectively to  FIGS. 1A-C . There is no separate  FIG. 1  apart from  FIGS. 1A-C . Similarly, “FIG.  2 ” is used to refer collectively to  FIGS. 2A-2D , “FIG.  3 ” is used to refer collectively to  FIGS. 3A-3L , “FIG.  4 ” is used to refer collectively to  FIGS. 4A-4F , “FIG.  5 ” is used to refer collectively to  FIGS. 5A-5B , “FIG.  6 ” is used to refer collectively to  FIGS. 6A-6D , “FIG.  7 ” is used to refer collectively to  FIGS. 7A-7C , and “FIG.  8 ” is used to refer collectively to  FIGS. 8A-8E . 
     The subsea hydrocarbon collection and containment system of the present invention comprises a self-supporting flexible containment enclosure (SSFCE)  500  for capturing the leaking hydrocarbons, and a floating platform  100  having a rigid enclosure  200  in which gaseous and liquid products from the captured hydrocarbons are separated. Floating platform  100  routes the liquid and gaseous products for further handling.  FIGS. 1 and 2  illustrate floating platform  100 .  FIGS. 3-5  illustrate SSFCE  500 .  FIGS. 6 and 7  show examples of connections between SSFCE  500  and leak sources  550  (such as sea floor fissures or broken wellheads).  FIG. 8  shows a floating flare platform  800  capable of burning off gaseous product provided by floating platform  100 .  FIG. 9  is a block diagram illustrating buoyancy control logic for floating platform  100  flotation vessels  102 .  FIG. 10  provides a flowchart of product flow from origination to potential destinations.  FIG. 11  is a flow diagram showing an example of a Process Control System  950  form monitoring and controlling operations.  FIG. 12  is a flow diagram showing an example of a Process Control System  850  for monitoring and controlling operations.  FIG. 13  is a flow diagram and illustrates an example of the fluid flow control portion of the control system.  FIG. 14  illustrates a 4 phase solid, liquid and gas model of the Floating Platform  100  Rigid Enclosure  200 , Self-Supporting Flexible Containment Enclosure (SSFCE)  500  and Bubble Diverting Assembly  240 .  FIG. 15  illustrates communication pathway options. 
       FIG. 1  comprises  FIG. 1A , showing a top view of floating platform  100 ,  FIG. 1B , showing a side view of floating platform  100 ,  FIG. 1C , showing an isometric bottom view of floating platform  100 , and  FIG. 1D , showing a side view of a Rigid Enclosure Bubble Diverter  280  an extension of the Rigid enclosure  200  and containing within a Bubble Diverter  280 . Floating platform  100  includes flotation vessels  102 , rigid enclosure  200  (in which liquid and gaseous products from the captured hydrocarbons are separated), and various piping and valves for handling liquid and gaseous products from self-supporting flexible containment enclosure (SSFCE)  502  shown in  FIGS. 3-5  after they are separated within rigid enclosure  200 . 
       FIG. 1A  shows floating platform  100  from the top (including some perspective), showing floating platform upper deck  104 , upper deck  204  of rigid enclosure  200 , flotation vessels  102 , and various ports, enclosures and hardware. Flotation vessels  102  support the structure, and allow it to float or submerge as desired.  FIG. 9  shows buoyancy control logic controlling floating platform  100  draft via flotation vessels  102 .  FIG. 11  shows Process Control System  950  which monitors and controls draft, flow control, buoyancy and other operations. 
     This submergence capability provides an increased level of reliability for floating platform  100 , avoiding heaving seas prior to and during hurricanes as well as other surface disturbances or threats such as above surface flammable situations. Floating platform  100  may be partly or fully submerged to a depth at which there is minimal turbulence, protecting it from excessive mechanical loading and or stresses. Floating platform  100  can continue its functions of separating liquid and gaseous products from captured hydrocarbons in conjunction with attached SSFCE  500  while partly or fully submerged. 
       100 A is the “Aft” or rear end of platform  100  looking forward,  100 B is the “Bow” or front end,  100 P is the “Port” or left side, and  100 S is the “Starboard” or right side. 
     The system is able to direct the output products concurrently to multiple ports with, for example the gaseous product output ported between the  100 A aft port and  100 B Bow port and the liquid product output directed among two  100 B Bow ports and one  100 A Aft port. 
     Locator buoys  112  are attached to Locator buoy support enclosures  110 , which are attached to Flotation vessel  102   
     Liquid products are removed from Rigid enclosure  200  bulkhead flange Gaseous product port connection  206  via Valve assembly  120 . The liquid products then pass through Pipe assembly  123  to liquid product port  124 . Pipe assembly  123  comprise “Stubs with Flanges”—pipe extenders used for both gas and liquid products and consisting of a pipe assemblage with pipe flanges and welded flanges for bolting onto welded plates. Five of these are common and are shown in  FIG. 1A  (for liquid ports  124  and gas ports  126 ). A double ended pipe with flanges and with two sets of support base mounting flanges form this Pipe assembly  123 . For example Pipe Assembly  123  might be a custom fabricated dual square base flanged mounting for a pipe segment with pipe flanges on each end. 
     Gaseous product is removed from rigid enclosure  200  via port connections  206  on Rigid enclosure upper deck  204  and passes via pipe segments  125 , through Valve assemblies  120 . The gaseous product then passes through Pipe assembly  123  to Gaseous product ports  126 . 
     Valve assemblies  120  are operated by the Process Control System shown in  FIG. 11 . Compressed air tanks  131  are configured in a cascade array  130  which allows for buoyancy control (as shown in  FIG. 9 ). Cleats  103  provide securing points for lines and the like. Watertight enclosures  140  house various equipment. 
       FIG. 1B  is a side view (including some perspective) of floating vessel  100 . In addition to the elements shown in  FIG. 1A ,  FIG. 1B  shows mooring points  101 , butterfly valves  121  and electrically controlled valve actuators (for example digitally controlled rotary actuators)  122  of valve assemblies  120 , walls  201  of rigid enclosure  200  and several elements extending below flotation vessels  102 . 
     Flotation vessel support blocks  105 , lower perimeter mating assembly  210  of rigid enclosure  200 , liquid product Bubble diverting assembly  240 , liquid product submerged conduit  235 , and liquid product bubble diverting assembly stays  245  are also visible. 
       FIG. 1C  is an isometric bottom view of floating platform  100 . This view best illustrates the interior of rigid enclosure  200 , as well as some structural aspects of flotation platform  100  (such as structural beam assemblies  108  and  208 ). 
     Floating Platform  100  and Rigid Enclosure  200  might alternatively be assembled with weldments replacing the majority of assemblages that are connected using conventional fasteners engaged into drilled and or tapped members. In this preferred embodiment the structure is illustrated with the majority of assemblages being assembled with fasteners, aiding in the ability to transport individual components taking into consideration logistics and available transportation modes. 
     Vertical Walls  201  are secured by Drilled and Tapped Mounting Block  106  welded to flotation Vessel  102  and also secured to Drilled and Tapped Solid Vertical and Horizontal Bars  107  along with Upper Deck  204  that comprise and form the structure of the Rigid Enclosure  200  located within the floating platform  100 . Vertical walls  201  are additionally secured using Exterior Structural beam assembly  108  connected to Drilled and Tapped Mounting Block  106 . Drilled and Tapped Mounting Blocks  106  are welded into place at various locations on the flotation Vessel  102 . 
     In a preferred embodiment, all mating vertical wall  201  and upper deck  204  surfaces connected to vertical and horizontal bars  107  have an appropriate gasket material like Buna-N, Viton, etc. to provide for a watertight seal including hinged door assembly  276  and manhole port  202  and other appropriate locations. 
     In a preferred embodiment, Watertight sensor enclosures  205  may be incorporated within Rigid Enclosure  200  and may contain various equipment (not shown) such as pulsed radar liquid level sensors, laser liquid level sensors, pressure sensors providing redundant sensing, a wide angle low light internally mounted video camera looking downward, and a downward projecting LED lighting source. Each Watertight sensor enclosure  205  is preferably provided with a clear Polycarbonate Lexan™ MR-10 bottom cover (not shown) for viewing, inspection and access. The aforementioned liquid level and pressure sensors might be mounted through the clear Polycarbonate Lexan™ MR-10 bottom cover. 
     Liquid product Bubble diverting assembly  240  prevents gaseous product from entering the recessed ingress flange (not shown) located in the lower section of the Bubble diverting assembly  240 . The gaseous product will rise vertically adjacent to Bubble diverting assembly  240  and continue its upward ascension above Bubble diverting assembly  240  into the interior of Rigid Enclosure  200  and into Gaseous product connection  206 . Bubble diverting assembly  240  enables liquid product within the Bubble diverting assembly  240  enclosure to travel upward via downward submerged conduit  235  via liquid product Internal tee  230  to liquid product Lateral conduit  225 . The liquid product then passes through Liquid product port bulkhead connections  220 , with the flow controlled by Valve assemblies  120 , and then passes through Pipe assembly  123  and on to Liquid product ports  124 . Bubble diverting assembly Stays  245  might be connected between the interior Rigid enclosure vertical walls  201  or other members within the Rigid Enclosure  200  and the Bubble diverting assembly  240  for the purpose of providing mechanical stability. The interior of Rigid Enclosure  200  might contain one or more Bubble diverting assemblies  240  and further might incorporate directional louvers for directing or channeling gaseous product  566  away from the ingress of the Bubble diverting assembly  240 . 
       FIG. 1D  illustrates an alternative to Bubble Diverting assembly  240  shown in  FIG. 1C . Rigid Enclosure Bubble Diverter  280  is a lower extension of Rigid enclosure  200  and containing within Bubble Diverter  280  attached to enclosure walls  201  and Drilled and tapped solid vertical and horizontal bars  107  provide a walled structure with an open bottom and top that may further comprise a lower horizontal framework using for example the Drilled and tapped solid vertical and horizontal bars  107 . 
     Bubble diverter  280  may have a frustum, trapezoidal or conical shaped vertical surface with a closed bottom with an open area at the top supported by members from the bottom or sides extending outward and connected to the surrounding structure and providing an opening around the lower perimeter as to allow the ascending liquid and gaseous product to rise adjacent to the exterior of Bubble diverting assembly  280  while conversely disallowing the gaseous product from descending within the interior of the bubble diverting assembly  280  where an open ended conduit is in proximity to the lower inside portion of the bubble diverting assembly  280 . Furthermore, Bubble diverting assembly  280  may have fins or slats  290  connected to standoffs  288  or may be further secured to an exterior wall  283  attached to the standoffs with exterior wall  283  comprising for example a plurality of elongated lateral open slots between the attached fins  290 . In the aforementioned assembly fins  290  are secured to an exterior wall  283  and attached to interior wall  282  of bubble diverting assembly  280  by standoffs  288 . This establishes a collective region between interior wall  282  and exterior wall  283  for liquid product flow and provides a minimal introduction of gas bubbles within said region. It further allows the liquid product to flow along the exterior of the interior wall and over upper opening  284  perimeter edge of bubble diverting assembly  280 .  FIG. 1D  shows a Bubble diverter fin  290  with a pair of dashed lines that represent a front or rear aspect of a fin as opposed to an edge or side view. 
     The Bubble diverting assembly  280  upper opening  284  is located substantially below the anticipated lower boundary of the variable gas liquid interface level within the rigid enclosure  200  and the uppermost portion of the SSFCE  500 . Furthermore, a port (not shown) that can be opened or closed remotely or manually might be introduced at the lower portion of the Bubble diverting assembly  280  interior wall  282  to initially allow a liquid to fill the volume or drain such volume within said assembly. 
       FIG. 2  comprises  FIGS. 2A ,  2 B,  2 C, and  2 D, and shows detailed views of portions of floating platform  100  of  FIG. 1 .  FIG. 2A  is an isometric side view of a solar panel elevated assembly comprising an elevated structure  250  supporting watertight solar panels  252  including adjustable angle assemblies attached to the  200  Rigid enclosure Rigid enclosure upper deck  204 . The Floating platform  100  may obtain its power for operation from the plurality of Watertight solar panels  252  that charge batteries (not shown) enclosed within one of the Watertight enclosures  140 . Structure  250  also supports navigation lighting aids  255 , antennas and support structure  260  and lightning arresters  265 . 
       FIG. 2B  is an isometric side view of a hinged manhole port  202  allowing entry into rigid enclosure  200  via wall  201 . A watertight equipment enclosure  140  (side view) is seen to the right of manhole cover  202  and compressed air tank enclosure  130  (showing one of a plurality of air tanks  131 ) is seen to the left. 
       FIG. 2C  is an isometric side view of the Outrigger pump discharge external bulkhead port  276  with hinged door bolted to the Outrigger pump discharge port interior bulkhead flange  278  formed in a side wall  201  of rigid enclosure  200 . The Outrigger pump discharge port internal bulkhead flange  278  can be seen in  FIG. 1C . Outrigger pump assembly  150  is connected as shown in  FIG. 2D . 
     One embodiment for the introduction of water into SSFCE  500  is by way of a temporarily installed outrigger pump assembly containing a hydraulically operated axial flow pump as shown in  FIG. 2D . 
     Outrigger pump assembly  150  is temporarily secured to the Floating platform  100  providing a connection with Flange  155  to Rigid enclosure  200  sidewall  201  formed port Outrigger pump discharge port internal bulkhead flange  278  shown in  FIG. 1C . Outrigger pump  152  pumps seawater into rigid enclosure  200 , to fill SSFCE  500  to partial capacity. 
       FIG. 2D  is an isometric side view of Outrigger pump assembly  150 , used to pump seawater into rigid enclosure  200 , to fill the SSFCE to partial capacity. Locator buoy support enclosure  110 , Locator buoy  112  and external bulkhead port attached hinged door  276  have been removed for clarity. Outrigger pump  152  connects to Outrigger pump discharge pipe assembly  154 , supported by Outrigger pump assembly frame  151 . Outrigger pump discharge pipe assembly  154  terminates at Outrigger Pump discharge port flange  155  and makes a bulkhead connection to Outrigger Pump discharge port internal bulkhead flange  278  via the Rigid enclosure  200  sidewall  201 . 
     Outrigger pump  152  in this embodiment is an Axial flow pump and may be operated by hydraulics using, for example, an external diesel power unit  159  (not shown) having a hydraulic pump  156  (not shown), and hydraulic lines  158  (not shown) connected to a hydraulic motor  157  (not shown) operating an impeller (not shown) within the outrigger pump  152  housing. An ultrasonic liquid flow sensor  753  (not shown) might be attached to Outrigger pump discharge pipe segment  154  for the measurement of flow and volume of the liquid introduced into the SSFCE  500 . 
     SSFCE  500  is generally assembled in segments  300 , attaching components such as Subsea buoys  520  and Tethered cable connection lanyards  518  and Mooring lines  510  as required. 
     SSFCE containment enclosure  500  creates an “Ocean within an ocean” system, capturing and containing all of the leaking hydrocarbons as well as containing a great deal of seawater. SSFCE  500  might be deployed horizontally and empty on the surface of the water  502 . The Subsea terminator interface assembly  600  end of SSFCE  500  is then drawn down or pulled toward the targeted area of hydrocarbon emissions  502  by a remote operated vehicle (ROV, not shown) or other means. During the descent, SSFCE  500  is partially filled with seawater via Outrigger pump assembly  150  being temporarily secured to Floating platform  100 . The water pumped into SSFCE  500  creates a transport medium for the oil and gas hydrocarbon emissions. 
     The SSFCE  500  contained water volume is based on the total volumetric capacity of SSFCE  500  minus the anticipated worst case mean flow rate and/or volume during transit of the liquid and gaseous hydrocarbons minus a percentage of the SSFCE  500  total volume to allow for dynamic changes and to provide a buffer for, e.g. compressive forces upon SSFCE  500 , changes in flow rates, additionally introduced reservoir water, etc. These factors and others not mentioned might provide guidance for the volume of water required as a liquid transport media. 
     Outrigger pump assembly  150  is removed and the Outrigger pump discharge external bulkhead port with hinged door  276  is secured to Outrigger pump discharge port internal bulkhead flange  278  after operations to partially fill the SSFCE  500  are completed. 
     In a preferred embodiment, SSFCE  500  comprises adjoined segments  300 , each comprising panels  302  formed of, for example, a non-elastic geomembrane fabric. Segments  300  are connected at their edges to form tubes. Buoys  520  comprise Positive Offset Neutral Buoyancy attachment Devices (PONBADs) and are used to fine tune the buoyancy requirements of segments  300  based upon their location and function by adjusting the buoyancy value required by the addition or subtraction internally or externally specific amounts of weight 
     The segments include structure along their edges which allows the segments to be attached to form SSFCE  500 . 
       FIG. 3  comprises  FIGS. 3A through 3L , and shows various views of SSFCE  500  segments  300 . An SSFCE segment  300  is a tube formed of panels  302  affixed together and supported by straps  308 . The segments are then connected, for example via hook-and-loop connections, to achieve the desired SSFCE  500  length. 
     Straps  308  connect together at their ends provide the main vertical mechanical support loading between segments  300  and the hook and loop connections  303  and  305  are primarily used as the interconnects providing a continuation of the SSFCE segment  300  function in the transport of material emanating from the hydrocarbon leak. 
       FIG. 3A  is side isometric view of a first embodiment of an SSFCE segment  300  including panels  302 , support straps  308  and strap termination points  312  for connecting adjacent segments  300 . As an example, panels  302  might comprise 500 foot by 100 inch pieces of high-performance reinforced geomembrane such as Seaman XR5 8130 EIA (Ethylene Interpolymer Alloy) Polyester. 
     Furthermore the panel material used in the SSFCE segments might also include additional layers or laminations of the same or different material to the interior or the exterior for purposes such as strength and or thermal considerations. 
     Those skilled in the art will appreciate that this is just one example, and many variations are possible. For example, the length or diameter of segments  300  may be different. 
     Segment  300  lengths of approximately 500 feet work very well due to fabrication, weight, counter-buoyancy requirements, logistics handling, etc. Longer or larger diameter segments  300  would require an increase in the number and/or the size of subsea buoyancy modules  520  to reduce the total topside loading. 
     Segments  300  can be made of other materials and may have frustums or other geometrical characteristics that may be symmetrical or asymmetrical in geometry. Segments  300  are not limited to four panels in construction, as they might comprise one or more panels with or without a plurality of straps. 
     Four panels  302  are welded together, creating seams along their long edges to form a 500-foot tube. There are many methods of welding panels together, e.g. Hot Air Wedge, Contact Hot Wedge, Radio-Frequency weldments, extrusion fillet weldments, chemical bonding adhesives. 
     Support straps  308  might comprise 4-inch-wide polyester strap material folded in half to cover the 2 inch wide hot wedge weldment and dual double stitched to the weldment using for example a Gore Industries Tenara thread. Additional stitching of the Support straps  308  may be of benefit including variations of stitch patterns, thread of other means of attachment. 
     Widths and lengths of the material for the seams, stitching, straps and panels may all be variable in size and material. 
     Eyelets or grommets  310  are inserted in support straps  308  to allow attachment of mooring lines, tethered loop handles, rings or carabiners and to further allow operators to easily handle, tow and manipulate segments. 
     At the top of segment  300 , along the short edges of panels  302 , is disposed, for example, a loop material  304  in Y-shaped flaps  303  (as shown in  FIG. 4B ) or some other configuration. In this case, hook material  306  formed on I-shaped flap  305  is disposed at the bottom of segment  300  along the short edges of panels  302  in a configuration selected to engage with loop material  304  at the top of the next segment  300 . This hook-and-loop connection is the main connection between segments, and provides a nearly waterproof seal. There is less chance of intrusion of the oil and gas into the connection, as those fluids are moving vertically upward and along the surface and the system typically is not under pressure. If the orientation was the other way, one could potentially have seepage of the compromised fluids into the inside portion of the connection. Straps  308  provide further the main structural support and connection between segments. 
       FIG. 3B  is a detailed view of connected strap termination points  312 , to provide the primary vertical load bearing connection between one segment  300  and another. For example, termination points  312  might be formed of 316 Stainless Steel and comprise a terminator strap connector with a bolt hole for connecting two strap segments  308  (the bolt and nut connection—or other fastener—is not shown). Termination point  312  might also consist of one or more bolt holes to connect with another termination point  312  and matching number of bolt holes for connecting the protruding attachment point  314 . 
       FIG. 3C  is a detailed view of connected strap termination points as in  FIG. 3A , further including a protruding attachment point  314  for connecting a buoy  520  (see  FIG. 5 ) and or engaging mooring or other lines, cables, etc. 
       FIG. 3D  is a detailed oblique wireframe view of SSFCE Segment  300 . 
       FIG. 3E  is an isometric view of a second embodiment of an SSFCE  300 A segment section comprising SSFCE  300  as in  FIG. 3D , further including drag coefficient reduction panels  302 A and tail flap panels  302 B. Construction of SSFCE  300 A segments might include the attachment and welding of  302 A panels to  302  panels during the construction of SSFCE segment  300 A with the subsequent attachment of straps  308  and eyelets  310  and or grommets  310 , etc. Panels  302 A are the main constituents of the drag coefficient reduction system and panels  302 B assist in reducing drag and turbidity, vortex turbulence, etc. 
       FIG. 3F  is a top view of the segment  300 A of  FIG. 3E .  FIG. 3G  is a variation on the segment  300 A of  FIG. 3E  where the drag coefficient reduction panels are connected using both opposing edges of the SSFCE segment (or in some cases opposing edges of two or more SSFCE segments). 
       FIG. 3H  is a side view of the segment of  FIG. 3E . 
       FIG. 3I  illustrates an embodiment of a SSFCE segment  300 , which includes an internal Relief port  370  attached to the inside of SSFCE segment  300 D with flanges  374 . Relief port  370  has an opening  371  at its top terminus and a closed bottom terminus  372 . Relief port  370  is installed below the maximum anticipated lower boundary depth of any accumulation of liquid and or emulsified hydrocarbon product. 
     The surface of SSFCE segment  300 D has a partitioned opening constructed to accommodate a One-way port  375  further comprising a slotted semi-flexible plate  376  shown in  FIG. 3K  and exterior attached membrane flaps  377  secured by battens  383 , attached to a flexible membrane material  382  both shown in  FIG. 3L  forming the completed assembly membrane flap  377 .  FIG. 3J  illustrates the placement of One-way port  375  with both an internal membrane  381  gasket panel and external membrane  380  gasket panel that is attached around the perimeter of One-way port  375  internally and externally and further secured to SSFCE segment  300 D. 
     Relief port  370  has at its lower terminus a closed bottom  372  with an access opening  378  that might further comprise an attached membrane flap  379  having an interior perimeter of a hook or loop closure material that creates a seal when secured to opposing hook or loop closure material  384  that is formed around outer exterior perimeter opening  378 . 
     Opening  378  of Relief port  370  is located below One-way port  375  and allows for the removal of precipitated material that might accumulate. This reduces the probability of obstructing the openings formed on slotted semi-flexible plate  376 . Variations in this design are possible. The terminus of Relief port  370  might have a different opening and access method. The geometry of Relief port  370  might vary. The embodiment might further include an exterior conduit or channel connected to One-way port  375  for other purposes. 
     Other variations on SSFCE segments  300 D might include an external port connection on the SSFCE segment side to connect an internal tube made partially buoyant ascending vertically to further reduce the probability of gaseous and liquid compromised emissions from entering downwardly into the tube and allowing for the relief to the exterior of excess water volume. A further variation might introduce to this side port a descending weighted tube to further disallow gaseous and liquid compromised emissions from descending into the external side port (as such materials are typically buoyant). This embodiment might further be revised to incorporate a channel constructed of panel material to replace the aforementioned internal and external tubes that interface with SSFCE segment  300 D side mounted port. This embodiment may further include a channel or tube connection continuing below the SSFCE segment  300 D side mounted port descending downward on the interior of the SSFCE segment  300 D for a distance to a separate port that might have a hook and flap arrangement for closure for the purpose of collecting any precipitated particulate having a density greater than the water media such that material is accumulated in the enclosed volume and is able to be removed at a later time, while primarily decreasing the probability that any descending material would interfere with the operation of the aforementioned glands membrane glands. 
     A further variation might incorporate a flexible membrane type gland comprising a number of slits operating like a valve attached to a frame of sufficient rigidity located at the SSFCE  300 D exterior side port and or further located along or at the end of the exterior channel or tube assemblage. A further variation might incorporate on the exterior side of the gland interface with said slits a number of strips of a lesser tension or more elastic yielding gland material of sufficient width to overlap and cover the slits further disallowing the ingress of fluid from exterior to the interior of the gland thereby creating a form of a check valve. 
     The embodiment might further include and is not limited to the number of ports, placement or orientation around or within the perimeter of SSFCE Segment  300 D. 
       FIG. 4  comprises  FIGS. 4A-4F , and shows detailed views of various hook-and-loop connections between segments.  FIG. 4A  is a side view of I-shaped hook flap  305  of a first embodiment of the connection, while  FIG. 4B  is a side view of V-shaped loop flaps  303 . Hook flap  305  has hook material  306  disposed on both sides. Loop flaps  303  have loop material  304  disposed on the inside surfaces. In use, hook flap  305  is inserted between loop flaps  303  and hook material  306  engages loop material  304 . Water must follow a circuitous path in order to leak though the connection thus formed. 
     In one preferred embodiment, loop material  304  is disposed at the top of segment  300  and hook material  306  is disposed at the bottom of segment  300 , as this configuration has been found to permit the least amount of leakage. With the oil and gas migrating upward there is only an upward shear, with downward travel essentially non-existent. 
       FIGS. 4C and 4D  show a second embodiment of a hook-and-loop connection similar to that shown in  FIGS. 4A and 4B , but wherein loop flaps  303 A and hook flap  305 A further comprise membrane materials  330  and  332  that provide a barrier that is compressed by the adjacent hook and loop material providing an enhanced liquid and gas seal. Interior membrane  330  might consist of a pliable elongated silicon bead/tubular member, while exterior membrane  332  might consist of a pliable rectangular silicone strip member. 
       FIGS. 4E and 4F  show a third embodiment of a hook-and-loop connection. Loop flaps  303 B form a V-shape having loop material disposed on all four sides. Hook flaps  305 B form a W-shape having hook material on all six surfaces. Engaging flaps  303 B and  305 B thus forces water to follow an even more circuitous path in order to leak through this connection. Those skilled in the art will appreciate various other configurations of hook flaps  305  and loop flaps  303  that could form similar connections between SSFCE  502  segments  300 . 
       FIG. 5  comprises  FIGS. 5A and 5B  which illustrate a deployment configuration of SSFCE  500 .  FIG. 5  shows how SSFCE  500  connects a hydrocarbon leak to floating platform  100  Rigid Enclosure  200 . SSCFE  500  is a self-supporting flexible containment enclosure providing the conveyance method between subsea terminator assembly  600  or canopy terminator  300 C and floating platform  100  at sea surface  502 . There may be other variations and numbers of SSFCE subsea terminators connected to the SSFCE  500 . 
       FIG. 5A  shows a side view of the deployment.  FIG. 5B  shows the connection between a PONBAD and a strap termination point. 
       FIG. 5A  shows an example of an SSFCE  500  having five SSFCE segments  300  connected in a manner such as those shown in  FIG. 4  in order to form a 2500 foot (in this example) tube to direct a hydrocarbon leak  550  from the sea floor  504  (or other leak source) to floating platform  100  rigid enclosure  200 , where gaseous and liquid products are separated and directed as required. In general, floating platform  100  is located at the waterline  500 , though it may be semi-submerged when necessary. SSFCE  500  may be connected at seafloor  504  via a compromised emissions terminator interface such as subsea terminator interface assembly  600  shown in  FIG. 6  or Canopy Terminator  300 C shown in  FIG. 7C . Subsea buoys  520  are attached (for example) at terminators  314  between segments  300 . Various mooring lines  510  stabilize SSFCE  502  and attach to anchorage point(s)  516 . 
     Other rode mooring or structural support points (not shown) may be attached as well. e.g. a Floating Platform Storage and Offloading (FPSO) vessel, Floating Storage and Offloading (FSO) Vessel, Drill Rig, or other structures like a Catenary Anchor Leg Mooring (CALM) buoy system. 
     Any entrapped air in SSFCE  500  during the deployment rises to the surface, leaving SSFCE  500  essentially collapsed and ready to engage the containment of the compromised emissions after it is partially filled with seawater. 
       FIG. 5B  shows an example of how subsea buoys  520  are attached to connection points  314  via tethered cable connection lanyards  518  attached at eyehooks  522 . The purpose of subsea buoys  520  is to create neutral or slightly positive buoyancy with respect to final anticipated loads being applied. 
     Subsea buoys  520  might comprise PONBADs—Positive Offset Neutral Buoyancy Attachment Devices, formed, for example, of Syntactic Foam. Different sizes and densities of material are chosen according to the desired outcome. PONBAD performance may also be fine tuned by the additional or subtractive application of the desired buoyancy equivalent offset weight using removable or attachable modules/members. 
       FIG. 6  comprises  FIGS. 6A ,  6 B,  6 C, and  6 D, illustrates subsea terminator interface assembly  600  which connects between SSFCE  500  and leak sources  550 . Interface assembly  600  comprises frustum panel enclosure section  605  and terminator section  625 , connected via connector plate  616 . Frustum panel enclosure section  605  comprises panels  302 , support straps  308  and eyelets  310  constructed in a frustum shape and is part of and transitions the terminator to SSFCE  500 . 
     One example of a preferred embodiment of a subsea terminator interface assembly  600  interfacing with a compromised well-head or Blow out preventer BOP (not shown) is illustrated in  FIG. 6A . The wellhead or BOP riser assembly is cut off, leaving a short riser stub. The operator  958  places the lower conduit section  607  over the stub using handles  608 , and secures lower conduit section  607  by tightening the tapered pointed set bolts  610  onto the riser stub section. 
       FIG. 6B  is a side view of terminator section  625 . Terminator plate  606 , lower conduit section  607 , handles  608 , eyebolts  609 , tapered pointed set bolts  610  and bolt strip  611  form terminator section  625 .  FIG. 6C  is a top view of connector plate  616 , comprising split plates  614  and compression straps  615 , forming mounting positions  612 . A variation on terminator section  625  might include a tapered annulus within the ingress end of lower conduit section  607 . A further variation on terminator section  625  might include a lower flange at the lower conduit section  607  ingress to accommodate the attachment of other flanged connections for termination to various pipe diameters and geometry using reducers or other mechanically attached interfaces. 
     Subsea terminator interface assembly  600  is assembled by lowering terminator section  625  through frustum panel enclosure section  605  until panel terminator plate  606  is blocked by the narrower opening formed at the apex of lower Frustum panel enclosure section  605 , such that the attachment of split plates  614  and compression straps  615  secure Frustum panel enclosure section  605  to the lower portion of panel terminator plate  606 . 
     Compression straps  615  with Split plates  614  form a seal with panel terminator plate  606  against the lower surface Panel terminator plate of  606 . Fasteners  613  attach connector plate  616  to enclosure section  605  and terminator plate  606 . Terminator plate  606  is smooth with rounded edges to limit wear and chaffing. 
     Upper eyebolts  609  provide for the attachment of guy lines  620  between terminator interface assembly  600  and termination points  604  to SSFCE  502 , to reduce strain between lower conduit section  607  and panel enclosure section  605 . Lower section eye bolts  609  provide for the attachment of safety or backup guy lines  622  between the lower conduit section  607  and the object that the terminator is connected to, such as a BOP riser stub (not shown) or other structures, and may reinforce and reduce the vertical shear load on the tapered pointed set bolts  610 . In general, subsea interface terminator assembly  600  would be constructed topside and would be the first to be deployed in the succession of components comprising SSFCE  500 . 
       FIG. 6D  is a side view of a dual subsea terminator interface assembly  600 A, configured to connect to dual SSFCE segments  300 . It basically comprises two subsea terminator interfaces similar to interfaces  600  connected by horizontal manifold tee section  652  to a terminator section  625 . Valves  654  control the flow of leaking hydrocarbons to SSFCE  502  (via enclosure sections  605  and conduit sections  607 ) and to flanged ports  658 . This arrangement might be used to direct the compromised emissions to more than one Floating Platform  100 . The flanged ports  658  provide connections to jump line conduits or hose to introduce product into other nearby distribution systems or may be used in reverse to introduce materials into the SSFCE system. 
     A variation on subsea terminator  600  might have a number of multiple size flanged ports, valves and manifolds connected to a lower single section of conduit section  607 . 
     Optionally, the Process control system  950  may have full duplex communication capabilities and power extended to further monitor characteristics of the flow emanating from the source, such as temperature, flow rates, material content, etc. 
     A further variation on the Terminator section  625  and Frustum panel enclosure section  605  might include items such as attached instrumentation  780  or sensors  750  to measure internal and external temperature, emission flow rate and or operate valves by motorized actuators. 
       FIG. 7  comprises  FIGS. 7A ,  7 B and  7 C. 
       FIG. 7A  is an external side view of SSFCE tee assembly  300 B. 
       FIGS. 7A ,  7 B illustrate use of an SSFCE tee assembly  300 B.  FIG. 7A  is an external side view of assembly  300 B with Frustum panel segment  302 C that allow assembly  300 B to attach to dual SSFCE segments  300 . Frustum Panel Segment  302 C is shaped like a clipped pyramid or trapezoid. Guy Lines  622  are broken to illustrate that in a preferred embodiment these would be of a variable length, preferably being shorter than the mechanical length or height of the  300 B enclosure, thus reducing the strain or tension forces acting upon  300 B and inherently providing some slack or a ruffle/ripple/frill/gathering for tee assembly  300 B. The other broken lines for the fabric panels are to indicate variability in size as well. Tee assembly  300 B includes connection portions at the top and bottom (such as loop flap  303  and hook flap  305 ). 
       FIG. 7B  is a bottom isometric view of tee assembly  300 B with Guy lines  622  removed for clarity. It shows how liquid and gaseous material flows from more than one SSFCE Segment  300  and combine to form one flow within standard SSFCE segment  300  above. Tee assembly  300 B might be employed in an opposite configuration to divide into separate flows. 
     SSFCE Tee assembly  300 B might further include additional internal arrangements of panels such as louvers and or meshed panels for enhanced directional control of the individual or combined components comprising the hydrocarbon material flow. 
       FIG. 7C  shows an outer side view of a single Canopy terminator  300 C that might be used to cover, straddle, envelop or tent a subsea floor fissure, a horizontal pipe-transport leaking assemblage or other leak source  550 . A Canopy terminator  300 C might be fabricated to various sizes to cover areas that show evidence of leaks. It may have one or more panels or frustums that may be symmetrical or asymmetrical in geometry. 
     Canopy terminator  300 C might also have attached to its lower perimeter Hook flaps  305  skirt assembly  345  as shown in side view in  FIG. 7D . Skirt assembly  345  is attached with Loop flaps  303  and might contain within the formed lateral Sleeve  344  a suitable weighted material like sand, gravel or chain to ensure the Canopy terminator  300 C sufficiently interfaces with seafloor bottom  504 . 
     Switchable Magnet  352  or other connecting or clamping device attaches to weighted anchoring object  354  (such as a mass of Ferrous material) or other structures to provide anchorage upon seafloor surface  504 . Anchoring object  354  may be embedded into the seafloor surface with engagement protrusions. 
     If a number of deployed canopy terminators  300 C are combined, a collection method can be employed for gross widespread emissions of gaseous and liquid hydrocarbons in thermally unstable seafloors or with seafloor emissions emanating from unstable or underlying fractured strata below the seafloor. A blown out or compromised well casing or bore hole below the seabed might also cause subsea floor fissures. Combining multiple canopy terminators  300 C each connected to SSFCE  300  segments and connected using one or more SSFCE Tee Assemblies  300 B further directed to a single SSFCE  300  Segment forms a multi-segmented complete SSFCE  500  system. 
       FIG. 8  comprises  FIGS. 8A-8E  and illustrates an autonomously operated floating flare platform according to the present invention.  FIG. 8A  is an isometric view of floating flare platform  800 ,  FIG. 8B  is a side view of floating flare platform  800 ,  FIG. 8C  is a stern side isometric view of floating flare platform  800 ,  FIG. 8D  is a bottom isometric view of the floating flare assembly and  FIG. 8E  is a detailed hidden isometric view of thermal blocks  822  used to isolate the radiant heat conducted from the radiant panels  820  on floating flare platform  800 . Floating flare platform  800  is used to burn off gaseous hydrocarbons delivered to it from floating platform  100 . The embodiment shown here is located on a separate platform, and the gaseous hydrocarbons provided via a tethered Flexible marine hose  701  (not shown) or the like. 
     Floating flare platform  800  provides for an integrated apparatus to flare (burn off) gaseous emissions from floating platform  100  that are directed from gaseous product ports  126  (See  FIG. 1 ) via tethered Flexible marine hose  701  (not shown) to gaseous product port  126  on floating flare platform  800 . Flexible marine hose  701  might comprise a flexible marine hose suitable for transporting liquid and gaseous hydrocarbon products. Flexible marine hose  701  may also have attached to it “winker lights” (not shown) for collision avoidance and other transport lines (not shown) to convey liquid, air, gas, electricity, and/or means for electrically grounding the conduit to minimize static and to provide lightning protection. A preferred Flexible marine hose  701  would have a grounding conductor included as part of the construction from the manufacturer. 
     Floating flare platform  800  may be structured similarly to floating platform  100  in  FIG. 1 , including flotation vessels  102  for supporting the structure, mooring points  101 , support blocks  105 , cleats  103 , etc. Solar panels  252  may be provided to generate electricity. The vertically suspended Solar panel  252  in  FIG. 8A  has been removed in  FIG. 8C  for clarity. In this embodiment Floating flare platform  800  obtains its power for operation from a plurality of Deep discharge batteries  781  (not shown) charged by Watertight solar panels  252 . This powers condensate collection enclosure  804  chemical pump  805  (not shown) to remove accumulated condensate liquid for injection into the flare assembly gas stream, flashback enclosure  806  water pump  807  (not shown), and including such items (not shown) as sensors  750 , liquid level detectors  753  and  767  (not shown), solenoid operated valves  787  (not shown), process control system computer  850  (not shown), ground radio digital link transceivers  980  (not shown) for communications to and from Floating platform  100 , and a flare ignition controller system  852  (not shown) comprising a Flare ignition Controller  852 , Flare igniter  854 , Flare ignition fuel  856  and Flare ignition purge gas  858 . Condensate collection enclosure  804  is also known as a “knockout” box or drum used in the collection of any condensates from the gas stream. 
     Structurally speaking, Vertical corner support assemblies  810  are secured to an arrangement of Flotation vessels  102 . They form inside corners to secure Upper horizontal beam assembly  812 , which is constructed in a horizontal framework as seen in  FIGS. 8A ,  8 B,  8 C, and  8 D. Exterior horizontal single support assembly  814  and Exterior horizontal corner support assembly  816  are secured to Upper horizontal beam assembly  812 . Radiant panels  820  mount Thermal blocks  822  with fasteners and isolate them from assemblies  812 ,  814  and  816 .  FIG. 8C  illustrates two bolted split plates  821  attached to radiant panel  820  surrounding the lower portion of flare barrel  832 , providing access to flare barrel  832  flange connection (not shown) to Flashback enclosure  806 . 
     Flare assembly  830  comprises Barrel  832 , Arms  834  and Orifice  836  and is secured to the top of Flashback enclosure  806  with a flanged pipe connection (not shown). Also not shown in  FIG. 8A  are examples of orifice  836  tip outlets that may be used. Various other designs might be supplied by different manufacturers. Flashback enclosure  806  is secured by flanges at two locations at the bottom of Upper horizontal structural beam assembly  812 . Flashback enclosure  806  is also secured to Lower structural beam assembly  801  by flanges at four locations, as shown in  FIGS. 8C , and  8 D. 
     Lower horizontal structural beam assemblies  801  are also secured to the Flotation vessels  102  and secure Floating flare upper deck  802 , Condensate collection enclosure  804 , Flashback enclosure  806 , Watertight solar panels  252 , Watertight equipment enclosures  140 , fuel gas tanks (not shown) for the ignition of flare assembly  830 , and Purge gas tanks (not shown) for purging explosive gas from Flare assembly  830 . 
     Flare ignition system  852  is conventional and is not shown or described in detail. Briefly, a flare igniter  854  is typically secured to Flare assembly  830 , and is fueled by a flare ignition fuel  856  tank containing fuel such as propane or LNG and operated by a flare ignition controller  852 . The flare ignition purge gas  858  tank contains pressurized nitrogen or other like purge gas and is operated by the flare ignition controller  852 , which is controlled by the Process Control System  850  shown in  FIG. 12 . 
     Other conventional equipment  780  and sensors  750  might further include components such as chemical pumps, water pumps, liquid level sensors, Ground radio data link  980  providing communication for control options along with operational information such as pressure levels, flow rates, temperatures, etc. 
     Floating flare platform  800  supports Upper deck  802 , upright assembly  810 , Condensate collection enclosure  804 , and flashback enclosure  806 . Vertical corner support assembly  810 , supports Flare assembly  830  and Radiant panels  820  via exterior single support assemblies  814  and exterior corner support assemblies  816 . 
       FIG. 8B  shows suspended counterweight  840  attached to platform  800  via cables  842 . The purpose of the counterweight is to assist in the reduction of vessel heave, pitch and roll by damping platform  800  motion, thus improving the platform&#39;s overall stability. 
     Thermal blocks  822  isolate conductive heat from Radiant panels, preventing heat radiated from the Flare Assembly from affecting Floating flare platform  800 . These are better shown in  FIG. 8E . 
       FIG. 8E  shows a detailed view of thermal blocks  822 . Each thermal block  822  is preferably formed of a thermal block base material  824  bonded by High temperature and high strength bonding material  826  to Thermal block insulator material  828 . 
     Thermal blocks  822  form base material Countersunk fastener holes for insulating material  829  for attaching thermal blocks  822  to radiant panels  820 . Thermal blocks  822  also form Countersunk fastener holes for base material  825  for attaching Thermal blocks  822  to upper horizontal structural beam assembly  812 , exterior single support assemblies  814 , and exterior corner support assemblies  816 . Thermal block insulator material  828  might consist of high temperature ceramic composite material. 
     In this embodiment radiant panels  820  might be constructed of stainless steel panels with associated stainless steel fasteners to withstand the radiant energy and shield the vessel and structure below. Radiant panels  820  might further include an insulative material secured to the underside to further reduce downwardly emanating radiant energy. 
     Watertight equipment enclosures  140  are provided to enclose and safeguard various equipment (not shown). For example, Floating flare platform  800  preferably includes a flare ignition controller system  852  as described above located within a watertight equipment enclosure  140 . Other watertight equipment enclosures  140  might contain equipment  780  and sensors  750  such as deep discharge batteries  781 , a charge controller and regulator  782 , the Process Control System  850  shown in  FIG. 12 , Ground radio data link  980 , a condensate collection enclosure chemical pump  805 , a flashback seal enclosure water pump  807 , multiple liquid level sensors  750  and other sensors  750 , and various other process equipment  780 . 
     Floating Flare  800  Process Control System  850  (see  FIG. 11 ) provides for the autonomous operation and monitoring of activities such as the flare ignition controller system  852 , operation of solenoid valves  787  for flare ignition fuel  856  and purge gas  858 , and other process equipment described above. Floating Flare  800  obtains its power for operation from batteries  781  charged by the Watertight solar panels  252 . 
       FIG. 9  illustrates a portion of the buoyancy control logic for floating platform  100 .  FIG. 9  is primarily a logic drawing, but it does include a cutaway side view of one flotation vessel  102  to illustrate the submergence and surfacing processes. The components that comprise Buoyancy control system  935  is a part of operations performed by the Process Control System  950 . 
     Flotation vessel  102  in  FIG. 9  includes two ports: Water port  908  (along bottom interior surface  904 ) having a short interior vertical conduit orientated toward the bottom; and Air port  906  (along top interior surface  902 ) having a short interior vertical conduit orientated toward the top. Both ports  906 ,  908  are located on the exterior vertical surface of Flotation vessel  102  facing the interior perimeter of Flotation vessels  102 . Electronic liquid level sensor  920  might be located on the same surface as Air port  906  and Water port  908 . 
     In the preferred embodiment, there are four Water pumps  918 , acting in two pairs operating as two pumps in parallel. One pair of pumps provides operation for an opposing pair of Flotation vessels  102 , while the second pair provides operation for the adjacent opposing pair of Flotation vessels  102 . This arrangement provides for a uniform and symmetrical distribution of introduced liquid ballast and additionally provides redundancy and increased reliability. This preferred pairing arrangement is also used to provide and control air in a uniform and symmetrical distribution which again provides redundancy and increased reliability. All hose lengths are preferably of equal diameter and length, resulting in equivalent flow rates and pressure drops for the corresponding liquid and air media types. 
     This arrangement may be simplified to one pair of water pumps  918  in parallel providing control to Aft position  100 A and Bow position  100 B, while the other pair in parallel provides control to Port position  100 P and Starboard position  100 S as shown in  FIG. 1A . 
     Solenoid valves  922 ,  924 ,  926 , and  928  are normally closed with the logic condition being 0 or not enabled. 
     Buoyancy system  935  (in turn controlled by Process Control System  950 ) controls the process of surfacing (or decreasing the draft) by enabling logic function  921  (SI) by simultaneous activation of solenoid valves  922  and  924 , egressing ballast water and displacing it with pressurized air to achieve the level of buoyancy required. Solenoid valve  922  is activated, permitting compressed air from compressed air tank array  130  to flow into regulator  132  and into flotation vessel  102  Air port  906 . Solenoid valve  924  opens to allow water to “blow out” ballast through Ballast blow out port and inline check valve  912  from Water port  908 . When the desired depth is achieved, logic  921  deactivates and solenoid valves  922 ,  924  close. 
     The action and process of submergence (or increasing the draft) is performed by enabling logic function  925  (S 2 ) to cause simultaneous activation of solenoid valves  926 ,  928  to displace air within Flotation vessel  102  and to replace the air with the ballast water. Solenoid valve  926  opens air vent outlet  910  to allow the air to escape from Air port  906 . Solenoid valve  928  controls pump  918  which causes inflow through gross/fine filter water inlet  914  to Water port  908 . 
     Electronic liquid level sensor  920  provides a liquid level measurement inside each buoyancy vessel  102 . Other sensors (not shown) provide data representing the actual draft or depth of Floating platform  100 . When the desired depth (or draft) is achieved logic condition  925  is disabled and valves  926  and  928  are deactivated or closed. 
     In a preferred embodiment ports  906  and  908  are mounted within the interior perimeter of Flotation vessels  102  and adjacent to Rigid enclosure  200  (e.g. air port  906  on top interior vertical surface  902  and waterport  908  on bottom interior vertical surface  904 ). Another port placement method (not shown) mounts both ports to gasketed bolt on flanges located on flotation vessel  102 , enabling access to both sides of the two ports. 
     In a preferred embodiment, flotation vessel  102  may have a number of transverse baffles or surge plates installed (not shown) to minimize longitudinal surge and slosh of ballast water due to ocean wave action. Sacrificial anodes (not shown) may be provided for corrosion control. 
     The achieved draft or resultant depth of floating platform  100  is based on many factors such as: volume and mass of the ballast seawater  503  contained in flotation vessel  102 ; total mass of floating platform  100 ; volume of crude oil  564  content within the upper SSFCE segment  300  and its potentially variable density value; volume of gaseous product  566  within Rigid enclosure  200  and the upper SSFCE segment  300 ; the vertical load of the total SSFCE assembly  500  as measured by strain gauges (not shown); horizontal and vertical loading of SSFCE assembly  500  by undersea transverse current velocities; amount and degree of emulsified products  564  and  566  contained and affecting the overall buoyancy; weather characteristics; and Global Positioning Satellite GPS location deviation from the target. 
     These and other variables are one of the reasons for an advanced Process Control System  950  to monitor and adjust the dynamics of this invention. The complexity and number of variables under consideration is preferably addressed by an autonomous Process Control System  950  which also enables digital communication for remote monitoring and control by operators  958 . 
       FIG. 10  shows a flow chart illustrating the product flow system  954  for both the gaseous hydrocarbon and liquid hydrocarbon material from origination to destination. 
     In one embodiment, SSFCE  500  has one input and one output. Floating platform  100  has multiple outputs, enabling flexibility and or changeouts in the presentation of product output for final disposition. For example, offloading liquid product requires time to disconnect and reconnect to tankers when vessels are changed out. Multiple liquid product ports reduce this time. To further extend the time required for product presentation to offload vessels, a number of conventional temporary storage Towable bladder bag  700  might be incorporated in the product flow configuration. This embodiment also supports routing the gaseous product to multiple outputs, for example to support two Floating flare platforms  800 . 
       FIG. 11  is a block diagram showing a majority of the Process Control System  950  operations performed on the Floating Platform  100 . 
     The operations performed start by loading and initializing the default program with initial parameters, enabling data logging; system functions, actuators and sensors are checked and communication links are established prior to starting operation.  FIG. 11  illustrates a process flow of operations that are continuously monitored and adjusted as required. 
     To achieve control of Floating platform  100 , Process Control System  950  makes use of the inputs from various sensors  750 . Further the Process Control System  950  provides control functions to buoyancy control system  935 , product flow system  954 , and other equipment  780 . Product flow system  954  includes equipment such as Valve assemblies  120 , Other equipment  780  and sensors  750  might include various pumps, solenoid valves, solid state IGBT relays  783 , voltage and current sensors  773 , navigation aid lighting  255 , other electronic equipment, liquid to air heat exchanger system  785 , pulsed radar liquid level sensors  751 , laser liquid level sensors  752 , pressure sensors  768 , etc. A number of Sensors  750  might typically be located within watertight sensor enclosures which may additionally include an internal Video Camera  788  with LED lighting  789 . A number of sensors  750  preferably redundant are used, including pulsed radar liquid level sensor  751 , laser liquid level transmitters  752  and pressure sensors  768  providing information to control the flow rates and volumes preferably by digital control valve actuators  122  in conjunction with the autonomous draft functionality of the platform. 
     Other sensors  750  preferably are incorporated in the Floating Platform  100  such as ultrasonic liquid flow sensor  765 , an ultrasonic gas flow sensor  754 , multipoint liquid level sensor switch  767 , strain gauges  770 , moisture detection sensors  775 , temperature sensors  772 , pressure sensors  768 , pressure sensor switch  769 , and photoelectric cell sensor  774 . The Process Control System  950  additionally monitors, via sensors  750 , such events as external wave height, periods and impingements, internal liquid level heights and periods, internal and external hydrostatic pressures, flow rates, buoyancy forces and the overall mass loading of the SSFCE  500 , and GPS coordinates. Process Control Systems  950  autonomously performs specific functions based on continuously monitored sensor inputs and further communicates to a more specific and limited Process Control System  850  onboard the Floating flare platform  800  where additional parameters are monitored and functions performed. 
     Three related and important parameters are critical for sustained operation: (1) the need to establish, maintain and periodically adjust the Floating platforms  100  draft via buoyancy control system  935 ; (2) maintaining the gas flow and contained volume within the rigid enclosure via product flow system  954 ; and (3) maintaining the flow and contained volume of crude oil via product flow system  954 . 
     As an example, the process control system might use a pulsed radar liquid level sensor  751  and laser liquid level sensor  752  in combination, measurements may be obtained of the surface height and depth of the accumulated liquid hydrocarbon emissions  564  within the upper portion of the SSFCE  500  structure in conjunction to the location of the respective sensors. 
     A pulsed radar liquid level sensor  751  will provide a distance value by the time measured to make a round trip of a reflected signal from a material having a significantly different dielectric constant than the medium it is transmitting thru. Seawater having a higher dielectric constant in the area of 60 to 80 will reflect the signal with a strong contrast compared to hydrocarbon products having a relatively low dielectric constant in the area of 4.0 and below with methane gas having a dielectric constant less than 2.0. The laser liquid level sensor  752  measures the round trip time when the laser beam is reflected from a liquid or solid surface. The sensors  751  and  752  may each be duplicated for redundancy and used for backup purposes and to also allow for averaging of the data provided. 
     Process Control System  950 , along with power control equipment  780 ; is preferably located within Watertight Equipment Enclosures  140  and further includes items (not shown) such as a master process control system  950  computer, a redundant process computer, electronic modules  799  comprising for example, analog and digital input and output control modules, signal isolators, etc.; current sensors  773 , solid state IGBT relays  783 , a water to air heat exchanger  785 , a sensor arrangement providing for a tri-axial accelerometer, rate gyro and magnetometer  771  measuring x-y-z acceleration, pitch, roll, yaw rate and magnetometer data and communication links comprising ground radio data link  980  and satellite data link  988 . In a preferred embodiment of this invention, the Primary Process Control System  950  being the primary controller is located on board the Floating platform  100  while a secondary, smaller and more process specific Process Control System  850  illustrated in  FIG. 12  is located on the Floating flare platform  800 . Process Control System  950  may be operated autonomously and located on floating platform  100  in communication with floating flare platform  800 , or may be operated in a remote location, or may be distributed among two or more of these locations. 
     In the preferred embodiment the remote Human Machine Interface HMI monitoring and control capability afforded to the Floating Platform  100  and Floating Flare Platform  800  is provided by a meshed digital communications link using ground radio data link  980  transceivers onboard both Floating Platform  100  and Floating Flare  800  enabling secure communication to operators  958 , such as the local Deployment operations manager. Depending on the range, communication to these platforms may be from land, sea or air. Communication between the Floating Platform  100  and Floating Flare is of a minimal distance. Communication via the HMI interface is further enhanced by the use of Satellite data links  988  between the Floating Platform  100  and providing a redundant link to the Local Site Deployment operations manager while extending communication to Remote Spill Management Engineering and Regulators enabling information to be readily available for other concerned parties such as other government regulators, corporate office and engineering locations as illustrated in  FIG. 15 . 
     According to the present invention a Process Control System  950  provides autonomous monitoring and control performed in near real time better than the reaction times by a human operators reaction times is able to perform, while also enabling supervisory monitoring and control by a human operator  958  to remotely monitor and control the operation using a Human Machine Interface HMI via digital communication radio links that are accessible concurrently by ground radio and or satellite communication. 
       FIG. 12  is a block diagram showing a majority of the Process Control System  850  operations performed on the Floating Flare  800 . The operations performed start by loading and initializing the default program with initial parameters, enabling data logging and establishing the communication link. The system checks the operational functions, pumps, valves, actuators and sensors and the process starts. Process Control System  850 , along with other control equipment is preferably located within Watertight Equipment Enclosures  140 . The Process Control System  850  monitors by sensors such values as gas pressure, liquid levels and temperatures to operate specific functions and communicates the operation and status via a communication link. 
       FIG. 13  illustrates an example of the fluid flow control portion of the control system. 
     The Process Control System  950  uses Programmable Logic Controllers PLC and also Proportional Integral Derivative PID controllers to manage overall the Fluid flow out  977  rate based on the Fluid flow in  970  to the system. Desired liquid levels values are established with Set Points SP  971  with actual Liquid Level Process Variables PV  972  and Pressure Sensors Process Variables PV  976  are compared by the PID controllers  974  monitoring the values and establishing an offset  973  or change that is translated to a Manipulated Variable MV  975  to adjust the Fluid Flow Output  977 . The process is continuous with a preference in minimizing the need for constant adjustment by forecasting the rate of change in the processing algorithms. Multiple Process Variables PV, Set Points SP and Manipulated Variables MV are established for Process Control System  950  to monitor and control draft operations and product flow. Process Control System  950  uses a number of algorithms that interact with the PV&#39;s, SP&#39;s and MV&#39;s along with other parameters and heuristic based tables to control operation of Floating Platform  100 . 
     As an example, a forward looking cascade of Proportional Integral PI to Proportional Integral Derivative PID gain scheduling algorithms for non-linear flows might be used. It would be noted by those experienced in the art that the example illustrated is extensively interrelated and is concomitant in operation with the gaseous control and buoyancy control portion of the Process Control System  950 . 
       FIG. 14  illustrates a 4 phase solid, liquid and gas model of the Floating Platform  100  Rigid Enclosure  200 , Self-Supporting Flexible Containment Enclosure (SSFCE)  500  and Bubble Diverting Assembly  240 . The primary materials discussed are seawater, methane gas, methane hydrates and crude oil. Typically hydrocarbon emissions being both gaseous  566  and liquid  564  having a density less than Seawater  503  eventually rise to the surface and are constrained within the uppermost portion of the SSFCE  500  structure connected to Floating Platform  100  Rigid Enclosure  200 . An enclosed and controlled volume of Gaseous product  566  prevents Liquid product  564  from rising within the Floating Platform  100  Rigid Enclosure  200  above a predetermined level such as the Waterline  502  used as a reference in this example. As more Liquid Product  564  is accumulated an increasing buoyant upward pressure is created and forces the Liquid product  564  through the upwardly ascending conduit to the Liquid Product Port  124  by the adjustment of a flow control valve (not shown) to release the Liquid Product  564 . The gaseous product  566  bubbles ascend through the Seawater  503  and through the accumulated volume of Liquid product  564  contained within the uppermost portion of the SSFCE  500  structure and are deflected and diverted past the opening of the Liquid Product ascending conduit connected within the Bubble Diverting Assembly  240  lower portion. The Gaseous Product  566  bubbles continue their upward ascent and break through the upper surface of the accumulated Liquid Product  564  and continue to add to the maintained volume of Gas Product  566  that is released by the adjustment of flow control valve assembly  120  (not shown). When sufficient volumes have been established, the same inflow rate entering from the bottom of the SSFCE  500  will be removed from the SSFCE  500  enclosures uppermost section and Floating Platform  100  Rigid Enclosure  200  for both the Liquid product  564  and the Gaseous product  566  using adjustments of the flow control valve assemblies  120 . 
     The inherent function of the upper portion of the SSFCE  500  structure and the Floating Platform  100  Rigid enclosure provides for the accumulation of Liquid product  564  by creating a vertical Gun barrel separation method that is well known, and eventually aggregating like type materials by natural phase separation using the Seawater  503  as the transport medium. Hydrocarbon emissions may be found as heated deposits located by deep well drilling in the earths crust. The release of these heated deposits from a well bore or fissure can generate a large amount of thermal energy. Additionally these thermal emissions when released eventually create a thermosyphon effect and may be compared to a contemporary residential wall radiator heating system in this example and model. 
     Ascending material at an elevated temperature  570  and transitioning to a Lower temperature  572  from the compromised emission site will typically move upward within the center of the SSFCE while Cooler Seawater Descending  574  will flow downward along the interior perimeter. The thermal flows expected are also likened to that of a chimney and a convection cycle is initiated. The natural dynamics of convection flow loops known as thermosyphons circulate the liquid by the changes in the buoyant forces generated by the thermal gradients due to heat introduced into the system, thermal loss due to conduction and dilution. The exterior of the SSFCE  500  also provides a substantial heat sink for increasing thermal dissipation due to conduction. 
     Pressure points  576 ,  577  and  578  are noted to indicate the relative gauge pressure is equal on both the interior and exterior surface and this equality is maintained irrespective of the depth. 
     In addition to normal occurring gaseous hydrocarbon emissions or Methane Gas  566  underground, there may be large deposits of Methane clathrates, typically called Methane hydrates  567  being a solid form of a large amount of methane trapped within a crystal structure of water forming a solid, very much like ice that can be found in underground reservoirs and even occur on the seafloor and on land at the appropriate temperature and pressures. 
     Methane hydrates  567  are often cited as problematic due to disruptions of oil and gas exploration and production operations in the obstructing or clogging of production lines or by the “kick” produced by the rapid sublimation from a solid to the release of methane gas  566  and water in a closed system such as a riser pipe section or from a well bore. Control to minimize or prevent these “kicks” is often accomplished by operations such as adjusting flow rates, the removal of water and the introduction of material like ethylene glycol or methanol, etc. Gaseous Hydrocarbon Emissions or Methane Gas  566  released from reservoirs and introduced into well bores and distribution lines may encounter lower temperatures and with high pressures may create the methane hydrates  567 . Additionally Methane hydrate bearing layers are sometimes formed within geological formations pressurized by the weight of the formation pressure and seawater. 
     A depressurization inside the well enables the methane hydrates to dissociate into methane gas and water. When solid methane material  567  is introduced into the SSFCE  500  it finds a significant boundary barrier enclosed volume, a relaxed pressure and elevated temperature to undergo a natural gas phase transition while providing the room for the significant volumetric expansion to a gas without the need for hydrate inhibiting solvents to be used. 
     Containment and presentation operations are based on a “Ocean within an ocean” model providing an effective boundary barrier to the environment. 
       FIG. 15  illustrates communication pathway options. 
     Although the Floating Platform  100  and Floating Flare  800  structures Process Control Systems  950  and  850  respectively may be operated autonomously and even communicate between each other using a hard-wired communication path, a design capability embodiment is incorporated providing wireless communication between the Floating Platform  100  and the Floating Flare  800  to further ensure appropriate functions are performed. This is further enhanced by enabling remote monitoring and operations by the Local Site Deployment Operators  982  via a ground radio data link  980  while communication is conducted concurrently between Floating Platform  100  and Floating Flare  800  using the same ground radio data link  980 . 
     If Local Site Deployment Operators  982  are out of range using Ground Radio Data Link  980 , a communication link may also be established using the Satellite Data Link  988  to communicate to the Floating Platform  100  via Satellite Network  990 . Furthermore, teams of Remote Spill Management, Engineering and Regulators  984  may access the operations globally via Satellite Data Link  988  and or Internet Network  986  via Satellite Network  990  and subsequently monitor, control and communicate directly to the Floating Platform  100 , Floating Flare  800  and communicate to the Local Site Deployment Operators  982 . With secured digital communication radio links using redundant ground radio data links  980  along with Satellite data links  988  providing access to a system such as the Inmarsat Broadband Global Area Network BGAN satellite system  990 , a Human Machine Interface HMI enables senior management, engineers, government regulators, on-site personnel and others to have near real-time access to data and specific user access to operational control functions. Digital communications enable authorized secure local and global interaction to a combined supervisory autonomous control system with the present invention. 
     While the exemplary preferred embodiments of the present invention are described herein with particularity, those skilled in the art will appreciate various changes, additions, and applications other than those specifically mentioned, which are within the spirit of this invention. For example, certain components of SSFCE  500  may also be used to collect or transport other liquids or gases, such as pumped or sumped products from subway and tunnel flooding, or hydrocarbon emissions collected from marshes and estuaries or for the gross collection of hydrate saturated areas. SSFCE  500  components may also be used to divert water to fight fires.

Summary:
A rapidly deployable flexible enclosure system for the collection, containment and presentation of hydrocarbon emissions from compromised shallow or deepwater oil and gas well systems, pipelines, other structures, including subsea fissures. The flexible containment enclosure can accommodate various depths and collection terminator configurations. The flexible containment enclosure system is connected to a floating platform and supported by positive offset neutral buoyancy attachment devices. The floating platform with the flexible containment enclosure separates liquid and gaseous materials and directs them to separate ports for removal from a rigid enclosure cavity integrated within the floating platform. Gaseous emissions may optionally be directed to a tethered floating flare system. The system has the ability to partially or fully submerge for extended durations and resurface on demand manually or by transmitted signal. The system provides for operation by a combined tele-supervisory and autonomous control system.