WO2011147021A1

WO2011147021A1 - Expandable polymer bladder apparatus for underwater pipelines and wells

Info

Publication number: WO2011147021A1
Application number: PCT/CA2011/000607
Authority: WO
Inventors: Peter Karl Krahn
Original assignee: Peter Karl Krahn
Priority date: 2010-05-28
Filing date: 2011-05-30
Publication date: 2011-12-01

Abstract

Expandable polymer bladder apparatus embodiments with flow control mechanism for initially reducing and regaining control of the flow and subsequently in stopping or regulating and controlling the flow of fluids from a ruptured pipeline or well particularly in a deep (sea) underwater scenario. The apparatus has an expandable bladder made of a polymer resistant to rupture by internal or external pressure, piercing by physical abrasion or contact with sharp surfaces and chemical degradation by the fluid being brought under control, and is concentrically mounted around a fluid transport and control tube resistant to rupture by internal pressure, piercing by physical abrasion or contact with sharp surfaces and chemical degradation by the fluid being brought under control, and a fluid transport tube having an inlet port which does not have flow control and an exit port which has a flow control valve and a connective coupling.

Description

Expandable Polymer Bladder Apparatus for Underwater Pipelines and Wells FIELD OF INVENTION

[0001} The present invention relates to environmental control of ruptured pipelines and wells, and more specifically, to an expandable polymer bladder apparatus for stopping and controlling the flow of ruptured pipelines and wells in deep (sea) underwater conditions. The expandable polymer bladder apparatus can be used for initially reducing and regaining control of the flow and subsequently in stopping or regulating and controlling the flow of fluids from a ruptured pipeline or well particularly in a deep (sea) underwater scenario and perform other tasks as described herein.

BACKGROUND OF THE INVENTION

[0002] Fluids are transported in pipelines which must pass through both overland and under water areas crossing lakes, rivers, stream or ocean on either surface or subsurface situations. Fluids such as crude oil or natural gas are also extracted from the earth in deep ocean or lake wells (deep water) and transported by pipelines up to fixed or floating platforms at the surface.

[0003] The extraction of crude oil and natural gas from deep water scenarios is carried out in remote and hazardous locations which are subject to intense natural forces such as high subsurface hydrostatic pressures, strong water currents, heavy seas with large waves and strong winds. Other anthropogenic factors such as human error, collision, explosion, fire or structural defects can lead to the fracture and/or severance of the drilling well pipes or pipelines which results in uncontrolled release of the fluids such as crude oil or natural gas into the surrounding environment particularly in deep off shore ocean wells. (Figure 1 A)

[0004] When crude oil, petroleum products, natural gases, liquid chemicals or chlorinated water are released in an uncontrolled manner into the environment from underwater pipelines or wells they can cause serious destructive forces due to pollution, or risks of water contamination and explosion, fire or injury to human, animal and plant life and in certain cases long term financial losses mounting into the billions of dollars and loss or destruction of valuable habitat. l Explosion, fire and toxicity hazards can be very difficult and dangerous to contain especially in areas of significant water depth, or where there are multiple factors (such as water depth, fast currents and turbidity) that complicate control of the ruptured well or pipeline in deep water conditions.

[0005] In emergency rupture situations, for example an oil well blow out or explosion and fire in a deep ocean setting, it is necessary to quickly and safely restore control of fluid flow from the rupture to minimize the zone of impact, restore safe operating conditions and minimize long term environmental, economic and social costs and other impacts. Therefore, a portable, readily adaptive control device capable of sealing multiple diameters of pipes is required to assist in restoring flow control of the well or pipeline system with minimal risk to human, plant, or animal life or structural facilities.

[0006] Control of the pipeline or deep ocean well may require the injection of sealant materials to facilitate plugging or capping of the leaking well. A device that is capable of both regaining flow control and facilitating short term or permanent plugging of a ruptured well or pipeline in deep water conditions is required.

[0007] Devices are available for controlling fluid flow include a top cap which due to hydraulic pressure above the cap and the entrainment of water cannot collect a high percentage of the escaping oil. At great depths, the low water temperature can result in the formation of ice which clogs the extraction system. To combat this, the top cap system must allow oil to escape to ensure (sea) water does not enter the collection system. Other devices include partial flow- extraction tubes which only capture a small percentage of the actual flow being discharged.

[0008] Devices called inline packers are designed to be inserted down a conventional operating well, not a damaged well or pipeline. The packers anchor by an expansion of a rubber bladder or shear mechanism and have the ability to have a central flow. Some packers are retrievable from the well bore, others are not. [0009] Other systems are not designed to be delivered and inserted into the damaged well or pipeline at deep (sea) water depths (5000 feet below surface) and both collect the oil and seal the pipe from intrusion of sea water.

[0010 Other systems do not have the ability to inject antifreeze chemicals to prevent freezing of the entrained water while isolating the flow of oil from exterior water.

[001 1] Other systems do not have the ability to inject dispersants, before, during or after flow control has been achieved.

[0012] Other systems do not have three alternate ways of anchoring the plug and collection system and provide increased protection against blow out.

[0013 ] Therefore, there continues to be a need for a flow control device that can rapidly be deployed by a variety of transport mechanisms including tethered submersibles and submarine systems and that is capable of both regaining flow control and facilitating short term or permanent plugging of a ruptured well

SUMMARY OF THE INVENTION

[0014] It is an object of the invention to provide an improved apparatus useful for reestablishing flow control from a ruptured deep water (ocean) well or pipeline to the point of stopping flow completely and subsequently allowing the temporary re-connection of fluid transport systems until an alternate method of control or equipment replacement can be installed. The device can also be used for the injection of sealing compounds into the ruptured pipeline or well once flow control has been established for the purpose of plugging or sealing in the damaged well or pipeline.

[0015] The present invention accordingly relates to an expandable polymer bladder apparatus with a flow control mechanism. The expandable polymer bladder apparatus consists generally of an expandable bladder made of a polymer resistant to rupture by internal or external pressure, piercing by physical abrasion or contact with sharp surfaces and chemical degradation by the fluid being brought under control. The expandable bladder apparatus is concentrically mounted around a fluid transport and control tube made of a metal or other substance resistant to rupture by internal pressure, piercing by physical abrasion or contact with sharp surfaces and chemical degradation by the fluid being brought under control. At the center of the device there is a fluid transport tube having an inlet port (A) which does not have flow control and an exit port (G) which has a flow control valve and a connective coupling.

BRIEF DESCRIPTION OF THE DRAWINGS

[0016] These and other features of the invention will become more apparent from the following description in which reference is made to the appended drawings wherein:

FIGURE 1A shows a side perspective view of an example of the expandable polymer bladder apparatus approaching a damaged underwater well which has an uncontrolled release of oil and natural gas, in accordance with an embodiment of the present invention;

FIGURE ID shows a side perspective view of an example of the expandable polymer bladder apparatus inserted into a damaged underwater well which has an uncontrolled release of oil and natural gas. The expandable polymer bladder has been inflated so that the internal diameter surface of the expandable polymer bladder has sealed itself against the outer surface of the flow tube. The expandable polymer bladder has been inflated so that the external diameter surface of the expandable polymer bladder has sealed itself against the inner surface of the damaged well tube. The expandable polymer bladder(5) may have an abrasive outer surface which allows the surface of the expandable polymer bladder (5) to scratch or score the scale deposits or the metal on the interior surface of the ruptured pipe and increase it's frictional grip to counteract pressure forces from the escaping oil/gas. The anchor rams have been deployed in the extended position and provide additional securing and centering of the expandable polymer bladder apparatus in the damaged well. An external compression collar blowout retention ring (99.3) w^rhich inhibits the expulsion of the expandable polymer bladder apparatus (5) has been attached at the (C ) to (D) position. The external compression collar blowout retention ring (99.3) counteracts pressure forces pushing on the expandable polymer bladder apparatus (5) by engaging the D3 contour if the hydraulic anchor ram(s) and the expandable polymer bladder device (5) experience high pressure and slide or lose grip on the inside of the damaged pipe or well. An external flow line has been attached to the exit (G) end of the flow tube. A valve at the (G) end of the flow tube has been opened and the mixture of oil and gas is flowing from the damaged well through the expandable polymer bladder apparatus flow tube into the external flow line. The external flow line is directing the flow of oil and gas in a controlled manner to a containment facility aboard a surface platform or ship, in accordance with an embodiment of the present invention.

FIGURE 1C shows a side perspective view of an example of the expandable polymer bladder apparatus (5) inserted into a damaged underwater well which has an uncontrolled release of oil and natural gas. The expandable polymer bladder (5) has been inflated so that the internal diameter surface of the expandable polymer bladder (5) has sealed itself against the outer surface of the flow tube (1). The expandable polymer bladder (5) has been inflated so that the external diameter surface of the expandable polymer bladder (5) has sealed itself against the inner surface of the damaged well tube. The anchor rams with ram (29) and ram contour with swivel hinge and grip points (38) have been deployed in the extended position and provide additional securing and centering of the expandable polymer bladder apparatus in the damaged well. An external compression collar blowout retention ring (99.3) which inhibits the expulsion of the expandable polymer bladder apparatus (5) has been attached at the (C ) to (D) position. The external compression collar blowout retention ring (99.3) counteracts pressure forces pushing on the expandable polymer bladder apparatus (5) by engaging the D3 contour if the hydraulic anchor ram(s) and the expandable polymer bladder device (5) experience high pressure and slide or lose grip on the inside of the damaged pipe or well. An external flow line has been attached to the exit (G) end of the flow tube. An external tank containing a drilling mud, cement or other sealing compound has been attached the filling line at the (G) end. A valve at the (G) end of the flow tube has been opened and the mixture drilling mud, cement or other sealing compound is flowing from the tank to the damaged well through the expandable polymer bladder apparatus flow tube into the external flow line. The external flow line is directing the flow of drilling mud, cement or other sealing compound in a controlled manner from a containment facility aboard a surface platform or ship into the flow tube (1) of the expandable polymer bladder (5) and subsequently into the damaged pipeline or well. The sealing compound sets up a permanent plug to stop the flow of oil/gas from the damaged well or pipeline in accordance with an embodiment of the present invention.

FIGURE ID shows a side perspective view of an example of the expandable polymer bladder apparatus (5) with a primary and a secondary bladder and with articulating joint(s) (40) around the hollow flow tube to allow minor bends, inserted into a damaged underwater well which had an uncontrolled release of oil and natural gas. The primary and secondary expandable polymer bladders (5) have been inflated so that the internal diameter surface(s) of the expandable polymer bladder(s) (5) have sealed themselves against the outer surface of the flow tube. The expandable polymer bladder(s) (5) have been inflated so that the external diameter surface(s) of the expandable polymer bladder(s) (5) have sealed themselves against the inner surface of the damaged well tube. The anchor rams with ram (29) and ram contour with swivel hinge and grip points (38) have been deployed in the extended position and provide additional securing and centering of the expandable polymer bladder apparatus in the damaged well. An external flow line has been attached to the exit (G) end of the flow tube. The flow of oil and/or gas is being directed to tanks on a platform or ship in accordance with an embodiment of the present invention.

FIGURE IE shows a side perspective view of an example of the expandable polymer bladder apparatus (5) with articulating joint(s) around the hollow flow tube to allow minor bends, inserted into a damaged underwater well which had an uncontrolled release of oil and natural gas. The primary and secondary expandable polymer bladders (5) have been inflated so that the internal diameter surface(s) of the expandable polymer bladder(s) (5) have sealed themselves against the outer surface of the flow tube. The expandable polymer bladder(s) (5) have been inflated so that the external diameter surface(s) of the expandable polymer bladder(s) (5) have sealed themselves against the inner surface of the damaged well tube. The anchor rams with ram (29) and ram contour with swivel hinge and grip points (38) have been deployed in the extended position and provide additional securing and centering of the expandable polymer bladder apparatus in the damaged well. An external tank containing a drilling mud, cement or other sealing compound has been attached the filling line at the (G) end. A valve at the (G) end of the flow tube has been opened and the mixture drilling mud, cement or other sealing compound is flowing from the tank to the damaged well through the expandable polymer bladder apparatus flow tube into the external flow line. . The external flow line is directing the flow of drilling mud, cement or other sealing compound in a controlled manner from a containment facility aboard a surface platform or ship into the flow tube (1) of the expandable polymer bladder (5) and subsequently into the damaged pipeline or well. The sealing compound sets up a permanent plug to stop the flow of oil/gas from the damaged well or pipeline in accordance with an embodiment of the present invention.

FIGURE 2 shows a cross-sectional side view of the expandable polymer bladder device (5) inserted into the damaged oil and gas well shown in Figure 1. The expandable polymer bladder device has not been inflated by either pressurized gas (nitrogen) or (sea) water. This figure also shows a side view and front view of the expandable polymer bladder mounting plate with a concentric hole for the flow tube and the circumferential holes for connecting bolts. In this non- limiting view there is only a compressed gas (nitrogen) tank for inflation of the expandable polymer bladder and power assist to the flow tube exit valve at (G) in accordance with an embodiment of the present invention.;

FIGURE 3 shows a cross-sectional side view of the expandable polymer bladder device (5) inserted into the damaged oil and gas well shown in Figure 1 with forward looking or panning cameras (33F, 33FP) mounted on servo motors, (33SM) which allow remote viewing of the positioning and operation of the expandable polymer bladder device. (5) The forward looking or panning cameras mounted on servo motors (33SM) mounted at the top of the compressed gas (nitrogen) tank allow remote viewing of the positioning and operation of the expandable polymer bladder device (5) and a general view of the entrance to the damaged oil and gas well shown in Figure 1. The forward looking or panning cameras (33F, 33FP) mounted on servo motors (33SM) mounted at the (A) end of the flow tube allow remote viewing of the positioning and operation of the expandable polymer bladder device (5) and a detailed view of the entrance to the damaged oil and gas well shown in Figure 1 in accordance with an embodiment of the present invention.;

FIGURE 4 shows a side cross sectional view of the expandable polymer bladder (5) which has a smooth exterior surface that upon inflation, contacts the inner surface of the damaged oil and gas well shown in Figure 1. The figure also shows the two compressed gas or pressurized (sea) water ports (17) that allow rapid pressurization and inflation of the expandable polymer bladder (5) after it is inserted into the damaged oil and gas well shown in Figure 1. The figure also shows the compressed gas or pressurized water pressure transducer (PT1) which monitors the internal pressure of the expandable polymer bladder (5). This allows the operator on a surface platform, ship or submersible to monitor the safe pressure operating limits of the expandable polymer bladder. The figure also shows the expandable polymer bladder pressure release valve (18.5). This valve is set to open at a specified internal bladder pressure and release pressure to prevent over pressurization and possible damage of the expandable polymer bladder (5) in accordance with an embodiment of the present invention.;;

FIGURE 5 shows a side cross sectional view of the expandable polymer bladder (5) which has a rough exterior surface that upon inflation, contacts the inner surface of the damaged oil and gas well shown in Figure 1. The rough exterior surface which can consist of a fine grained sharp abrasive or similar material embedded in an outer coating that provides additional friction force to counteract the hydrostatic pressure induced on the (A) end of the inflated bladder by the escaping oil and gas. The figure also shows the other components shown in Figure 4 in accordance with another embodiment of the present invention;

FIGURE 5A shows a side cross sectional view of the expandable polymer bladder (5) which has a rough exterior surface that upon inflation, contacts the inner surface of the damaged oil and gas well or pipeline shown in Figure . The rough exterior surface which can consist of material such chain mail (21.1) or wire mesh (21.2) or braided wire fibers (21.3) or other synthetic structural fiber surface such as carbon fiber. (21.4) which provides additional friction force to counteract the hydrostatic pressure induced on the (A) end of the inflated bladder by the escaping oil and gas. The chain mail (21.1) or wire mesh (21.2) or braided wire fibers (21.3) or other synthetic structural fiber surface such as carbon fiber (21.4) also provide additional structural integrity by limiting the pore size of the expandable polymer bladder (5) which is exposed to these pressures. The figure also shows the other components shown in Figure 4 in accordance with another embodiment of the present invention FIGURE 6 shows a side cross sectional view of the expandable polymer bladder (5) which has a rough exterior surface that contains raised ribs (21) which have a smooth surface that upon inflation, contacts the inner surface of the damaged oil and gas well shown in Figure 1. The raised ribs of the exterior surface which can consist of a polymer or similar material that provides additional friction force to counteract the hydrostatic pressure induced on the (A) end of the inflated bladder by the escaping oil and gas. The figure also shows the other components shown in Figure 4 in accordance with another embodiment of the present invention;

FIGURE 6 also shows a side cross sectional view of the expandable polymer bladder (5) which has a rough exterior surface that contains raised ribs (21) which have a rough surface (21.5) that upon inflation, contacts the inner surface of the damaged oil and gas well shown in Figure 1. The rough exterior surface of the raised ribs (21.5) which can consist of a fine grained sharp abrasive or similar material provides additional friction force. The raised ribs of the exterior surface can consist of a polymer or similar material to the expanded polymer bladder (5) that provides additional friction force to counteract the hydrostatic pressure induced on the (A) end of the inflated polymer bladder (5) by the escaping oil and gas. The figure also shows the other components shown in Figure 4 in accordance with another embodiment of the present invention;

FIGURE 7 shows a side and cross sectional view of the expandable polymer bladder which has been expanded upon inflation and contacts the inner surface of the damaged oil and gas well shown in Figure 1. Figure 7 also shows an end and side view of an additional securing device consisting of an hydraulic anchor piston and a ram and a ram contour with grip points. (27, 28, 29, 38) Upon pressurization the hydraulic anchor piston (27) drives the hydraulic anchor ram (28) out. The hydraulic anchor ram (28) is connected to a ram contour with grip points (29) and swivel hinge 38). The swivel hinge (38) allows the ram contour (29) to adjust to the inner wall of the ruptured oil and gas well upon contact. The grip points on the ram contour (29) are made of sharp metal points or abrasive material the increase the frictional force of the device to counteract that pressure force of the escaping oil and gas and aid in centering the position of the expandable polymer bladder in accordance with another embodiment of the present invention; FIGURE 8 shows a side perspective view of the suspension bracket (22) and a single ballast tank (Ml) mounted to the underside of the suspension bracket (22) for the purposes of providing a stabilizing mass and center of balance for the device shown in Figure 1 in accordance with another embodiment of the present invention;

FIGURE 9 shows a side and front view perspective view of the flow deflection cone (42) between points (A) and (B) of the flow tube. The flow deflection cone provides stream lining to the (A) end of the device to reduce turbulence of the oil and gas which is escaping the damaged well in Figure 1 in accordance with another embodiment of the present invention;

FIGURE 9 also shows a side and front view perspective view of the spring loaded centering guides (42) between points (A) and (B) of the flow tube. The spring loaded centering guides (42) provide directional guidance during the insertion and extraction of the device. Maintaining the flow tube and the expandable polymer bladder in the center of the damaged well will assist in reducing disruptional directional forces which would act on the flow tube and the expandable polymer bladder should they enter the damaged well at an angle. This will reduce the turbulence of oil and gas which is escaping the damaged well in Figure 1 in accordance with another embodiment of the present invention;

FIGURE 10 shows a side view of the attachment of a Remotely Operated Vehicle (ROV) (60) with a pow er supply, computer, sensory and data logging unit (65), forward and panning cameras and lighting (66) attached to a mounting bracket attached to the device shown in Figure 1. The ROV (60) provides propulsion and manipulation for insertion of the device into the damaged oil and gas well shown in Figure 1. The computer, sensory and data logging unit (65), forward and panning cameras and lighting (66) attached to a mounting bracket provide visual information and sensory data of the conditions en route and at the damaged oil and gas well shown in Figure 1 in accordance with another embodiment of the present invention.

FIGURE 11 shows a side view of the attachment of a Remotely Operated Robotic Arm (RORA) (71 , 72) with the absence of the power supply (64), computer, sensory and data logging unit (65) and forward and panning cameras and lighting. The RORA (71, 72) is attached to a remotely operated robotic bracket (70). The RORA (71, 72) provides manipulation for insertion and extraction of the expandable polymer bladder (5) into the damaged oil and gas well shown in Figure 1 in accordance with another embodiment of the present invention;

FIGURE 12 shows a cross-sectional top view of expanded polymer bladder in compressed and expanded state, the hydraulic anchor rams in the expanded state, the actuator and valve header and the mounting bracket in accordance with another embodiment of the present invention;

FIGURE 12 also shows a top and side view of an additional securing device consisting of an hydraulic anchor piston shown in Figures 7, 8, 9. Upon pressurization the hydraulic anchor piston (27) drives the hydraulic anchor ram (28) out. In Figure 12, the hydraulic anchor ram (28) is connected to a ram contour with grip points (29) without a swivel hinge (38). The ram contour in this view does not adjust to the inner wall of the ruptured oil and gas well upon contact. The grip points on the ram contour (29) are made of sharp metal points or abrasive material the increase the frictional force of the device to counteract that pressure force of the escaping oil and gas in accordance with another embodiment of the present invention;

FIGURE 12 also shows a top view of the suspension bracket and suspension anchors and the ballast which may be a tank or solid metal unit;

FIGURE 12 also shows an end view looking in the (C ) to (D) direction of the hydraulic anchor rams (28) with ram contour(s) (29) with grip point(s) (30) in the fully extended position engaged to the inner circumference of the damaged well or pipe. The grip points on the ram contour (29) are made of sharp metal points or abrasive material the increase the frictional force of the device to counteract that pressure force of the escaping oil and gas in accordance with another embodiment of the present invention.

FIGURE 13 shows a top and side view of an additional securing device consisting of an hydraulic anchor piston shown in Figures 7 and 12. Upon pressurization the hydraulic anchor piston drives the hydraulic anchor ram out. The hydraulic anchor ram is connected to a ram pin. The ram pin in this view does not adjust to the inner wail of the ruptured oil and gas well upon contact. The grip is made of a sharp metal point which may penetrate the wall of the ruptured oil and gas well

Π to increase the frictional force of the device to counteract the pressure force of the escaping oil and gas in accordance with another embodiment of the present invention;

FIGURE 13 also shows a control consol positioned on a command vessel connected via an umbilical chord to the device in accordance with another embodiment of the present invention;

FIGURE. 14 shows a side perspective view of the positioning of a high pressure water pump;

FIGURE 14 also shows a side perspective view the location of multiple ballast tanks secured underneath the suspension bracket in accordance with another embodiment of the present invention;

FIGURE 14 also shows a side perspective view the location of at least one metal ballast plate secured underneath the suspension bracket and the ballast tanks and secured to the suspension bracket by suspension bolts and nuts in accordance with another embodiment of the present invention;

FIGURE 15 shows a top perspective view of the positioning of a high pressure water pump located between two compressed air tanks in accordance with another embodiment of the present invention;

FIGURE 15 also shows a top perspective view of the batteries and computer controls and sensory data logger located between two compressed air tanks in accordance with another embodiment of the present invention;

FIGURE 16 shows a schematic view of the ballast tank (M 1 ) operating system which includes, a compressed gas (nitrogen) tank connected via a header to a ballast tank, a (sea) water pump (80) powered by a battery (81 ) connected via a header (25) to a ballast tank (Ml) and a compressed gas/pressurized water release valve (82) connected to the ballast tank (Ml). The ballast tank (Ml) can be alternately filled with expanded gas or pressurized water to increase or decrease the buoyancy of the device in accordance with another embodiment of the present invention; FIGURE 17 shows a view of the battery mounting plate (33BP) located on top of the compressed gas (nitrogen) tank (8). It also shows the battery unit (33B) which powers the servo motors (33SM) and forward looking or panning camera (33F, 33FP) in accordance with another embodiment of the present invention;

FIGURE 18 shows a side view of the articulating joint(s) (40) which are located in the flow tube ( 1 ) between (B) and (C). The articulating j oint(s) (40) al lows minor flexing in the flow tube ( 1 ) to accommodate bending of the flow tube (1) and the expandable polymer bladder (5). Bending of the flow tube ( 1 ) and the expandable polymer bladder ( 5) may be required to accommodate bends in the damaged well or pipeline caused by rupture, explosion, and impact or by original construction design in accordance with another embodiment of the present invention;

FIGURE 19 shows a top view of the articulating joint(s) (40) which are located in the flow tube (1) between (B) and (C). The articulating joint allows minor flexing in the flow tube (1) to accommodate bending of the flow tube ( 1 ) and the expandable polymer bladder (5). Bending of the flow tube ( 1 ) and the expandable polymer bladder may be required to accommodate bends in the damaged wel 1 or pipeline caused by rupture, explosion, and impact or by original construction design in accordance with another embodiment of the present invention;

FIGURE 20 shows a side view of the dual or multiple bladder line (91) which is centered on the articulating joint(s) (40) which are located in the flow tube (1) between (B) and (C). The articulating joint allows minor flexing in the flow tube (1) to accommodate bending of the flow tube and the expandable polymer bladder (5). Bending of the flow tube (1 ) and the expandable polymer bladder (5) may be required to accommodate bends in the damaged well or pipeline caused by rupture, explosion, and impact or by original construction design. The dual or multiple bladder line (91 ) is the line formed when two or more expandable polymer bladders are mounted on an articulating flow tube ( 1 ) in accordance with another embodiment of the present invention.

FIGURE 21 shows a top view of the dual or multiple bladder line (91) which is centered on the articulating joint(s) (40) which are located in the flow tube (1) between (B) and (C). The articulating joint allows minor flexing in the flow tube ( 1 ) to accommodate bending of the flow tube (I) and the expandable polymer bladder (5). Bending of the flow tube (1) and the expandable polymer bladder may be required to accommodate bends in the damaged well or pipeline caused by rupture, explosion, and impact or by original construction design. The dual or multiple bladder line (91) is the line formed when two or more expandable polymer bladders are mounted on an articulating flow tube (1 ) in accordance with another embodiment of the present invention.

FIGURE 21 also shows the flow tube pressure sensor (210) which senses pressure within the flow tube, conductivity sensor (21 3), temperature sensor (212) and other sensors (213) and may transmit it to the umbilical cable (13) to the control console (100)

FIGURE 22 shows a top view of the dual or multiple bladder line (91) which is centered on the articulating joint(s) (40) which are located in the flow tube (1) between (B) and (C). The articulating joint allows minor flexing in the flow tube (1) to accommodate bending of the flow tube (1) and the expandable polymer bladder (5). Bending of the flow tube (1) and the expandable polymer bladder may be required to accommodate bends in the damaged well or pipeline caused by rupture, explosion, and impact or by original construction design. The dual or multiple bladder line (91 ) is the line formed when two or more expandable polymer bladders are mounted on an articulating flow tube (1 ). Figure 22 also shows the primary expandable polymer bladder (5) and the secondary "plus" expandable polymer bladder. (5S) The primary expandable polymer bladder (5) and the secondary "plus" expandable polymer bladder (5S) are in contact with each other at the dual or multiple bladder line (91). Figure 22 also shows the secondary compressed gas/(sea) water inlet port(s) (17S) for secondary "plus" expandable polymer bladders. (5S) Figure 22 also shows the secondary compressed gas/(sea) water exhaust port(s) (18S) for secondary "plus" expandable polymer bladders. (5S) Figure 22 also shows the bladder tube (17ST) which conveys the secondaiy compressed gas/(sea) water inlet port(s) (17S) from the distribution header (25) to the secondary "Plus" expandable bladder.(5S) Figure 22 also shows the bladder tube ( 17ST) which conveys the secondary compressed gas/(sea) water exhaust port(s) ( 18S) from the secondaiy "Plus" expandable bladder to the distribution header (25) in accordance with another embodiment of the present invention. FIGURE 22 also shows the location of a flow meter (200) with magnetic propeller (201), differential pressure (202), conductive injection (203), pitot tube (204), manometer 205 or other flow sensing mechanism (206) may be installed at the (E) position of the flow tube. At this position the maximum length of flow to reduce turbulence can be achieved prior to encountering turbulence from the flow control valve (14). The flow meter can be connected to the computer controls and sensory data logger (81) to provide estimates of flow rate in the flow tube.

Figure 23 shows a side view of the external compression collar without the blowout retention ring (95). The collar is connected at the bottom by the external compression collar hinge (97). The collar is connected at the top by the external compression collar securing lock. (99) The red rectangles represent the external compression pads of metal with abrasive or pins located on the inner curvature (96). In another non-limiting embodiment, the red rectangles represent the external compression pads of rubber or other synthetic material with abrasive or pins on the inner curvature. (96.1) The ring is of external diameter D4 and internal diameter D3+ in accordance with another embodiment of the present invention.

Figure 24 shows a side view of the external compression collar with the external compression collar blowout retention ring. (99.3) The collar is connected at the bottom by the external compression collar hinge (97). The collar is connected at the top by the external compression collar securing lock. The red rectangles represent the external compression pads of metal with abrasive or pins on the inner curvature (96). In one non-limiting embodiment the external compression pads may be of hard rubber or other synthetic material with abrasive or pins on inner curvature. (96.3) The collar is of external diameter D4 and internal diameter D3+. The external compression collar with blowout retention ring inhibits the expulsion of the expandable polymer device (5) by engaging the D3 contour if the hydraulic anchor ram and the expandable polymer bladder device (5) experience high pressure and lose grip on the inside of the damaged pipe or well and slides out of the pipe in the (A) to (G) direction in accordance with another embodiment of the present invention.

Figure 25 shows an end view of the external compression collar without the blowout retention ring looking from the (A) to (G) direction. The collar is connected at the bottom by the external compression collar hinge (97). The collar is connected at the top by the external compression collar securing lock. The red rectangles represent the external compression pads of metal with abrasive or pins located on the inner curvature (96). In another non-limiting embodiment, the red rectangles represent the external compression pads of rubber or other synthetic material with abrasive or pins on the inner curvature. The ring is of external diameter D4 and internal diameter D3+ direction in accordance with another embodiment of the present invention.

Figure 26 shows an end view of the external compression collar (95) with the external compression collar blowout retention ring (99.3) looking from the (A) to (G) direction. The collar is connected at the bottom by the external compression collar hinge (97). The collar is connected at the top by the external compression collar securing lock. The red rectangles represent the external compression pads of metal with abrasi ve or pins on the inner curvature (96). In one non- limiting embodiment the external compression pads may be of hard rubber or other synthetic material with abrasive or pins (96.1) on inner curvature. The collar is of external diameter D4 and internal diameter D3+. The external compression collar with blowout retention ring inhibits the expulsion of the expandable polymer device (5) by engaging the D3 contour if the hydraulic anchor ram and the expandable polymer bladder device (5) experience high pressure and lose grip on the inside of the damaged pipe or well slide in the (A) to (G) direction in accordance with another embodiment of the present invention.

Figure 26 also shows the vertical hydraulic anchor rams and the horizontal hydraulic anchor rams with D3 contours (28, 29). These hydraulic anchor rams with contours (D3) provide anchoring stability and centering of the expandable polymer bladder (5) in accordance with another embodiment of the present invention.

FIGURE 27 shows an antifreeze (methanol) injection system. The antifreeze injection system can be mounted on the top or bottom of the device. Antifreeze (methanol) can be loaded from a surface storage tank, via hoses down to the antifreeze (methanol) injection system by a connective delivery hose. The delivery hose connects to the antifreeze (methanol) supply line connector (1 0). The antifreeze (methanol) supply line connector (130) is regulated by an antifreeze (methanol) supply actuator (131 A) which controls an antifreeze (methanol) supply valve (131). The antifreeze (methanol) supply valve (131) regulates the flow of antifreeze (methanol) to the antifreeze (methanol) supply tank ( 133). The antifreeze (methanol) supply tank (133) provides a reservoir supply of antifreeze (methanol) to the antifreeze (methanol) injection line (135). The flow of antifreeze (methanol) in the antifreeze (methanol) injection line (135) is regulated by the antifreeze (methanol) injection valve actuator (134A) which controls the antifreeze (methanol) injection valve (134). The antifreeze (methanol) is injected into the flow tube (1) as and when required to prevent freezing of the oil and gas mixture in the flow tube in accordance with another embodiment of the present invention.

FIGURE 27 shows a freeze gas (nitrogen) injection system. The freeze gas (nitrogen) injection system can be mounted on the top or bottom of the device. Freeze gas (nitrogen) can be loaded from a surface storage tank, via hoses down to the freeze gas (nitrogen) injection system by a connective delivery hose. The delivery hose connects to the freeze gas (nitrogen) supply line connector (140). The freeze gas (nitrogen) supply line connector (140) is regulated by a freeze gas (nitrogen) supply actuator (141 A) which controls a freeze gas (nitrogen) supply valve (141). The freeze gas (nitrogen) supply valve (141) regulates the flow of freeze gas (nitrogen) to the freeze gas (nitrogen) supply tank (143). The freeze gas (nitrogen) supply tank (143) provides a reservoir supply of freeze gas (nitrogen) to the freeze gas (nitrogen) injection line (145). The flow of freeze gas (nitrogen) in the freeze gas (nitrogen) injection line (145) is regulated by the freeze gas (nitrogen) injection valve actuator (144 A) which controls the freeze gas (nitrogen) injection valve (144). The freeze gas (nitrogen) is injected into the freeze gas (nitrogen) tracer coils which refrigerates the flow tube ( 1 ) as and when required to induce freezing of the oil and gas mixture in the flow tube. This is a backup mechanism to controlling flow from the flow tube (1) should the actuated valve at the (G) end of the flow tube fail to control the flow of oil and gas from the flow tube (1) in accordance with another embodiment of the present invention.

FIGURE 28 shows a dispersant injection system. The dispersant injection system can be mounted on the top or bottom of the device. Dispersant can be loaded from a surface storage tank, via hoses down to the dispersant injection system by a connective delivery hose. The deliver}' hose connects to the dispersant supply line connector (160). The dispersant supply line connector ( 160) is regulated by a dispersant supply actuator ( 161 A) which controls a dispersant supply valve (161 ). The dispersant supply valve (161) regulates the flow of dispersant to the dispersant supply tank (163). The dispersant supply tank (163) provides a reservoir supply of dispersant to the dispersant injection line (165). The flow of dispersant in the dispersant injection line (165) is regulated by the dispersant injection valve actuator (164 A) which controls the dispersant injection valve (1 4). The dispersant is injected into the flow tube (1) as and when required to improve dispersion of the oil and gas mixture in the water column and reduce fouling of fish and wildlife, flora and fauna, beaches and anthropogenic structures in accordance with another embodiment of the present invention.

FIGURE 29 shows an end (G) view of the four quadrants of the device. The location of each of the following systems could be rotated to exist in any of the other three quadrants in accordance with another embodiment of the present invention.

FIGURE 29 also shows the antifreeze (methanol) system is located in the lower right quadrant. This view shows the antifreeze (methanol) supply line connector (130), the antifreeze (methanol) supply valve actuator (131 A), the antifreeze (methanol) supply valve (131), the antifreeze (methanol) supply tank (133), and the antifreeze (methanol) injection line (135) in accordance with another embodiment of the present invention.

FIGURE 29 also shows the freeze gas (nitrogen) system is located in the lower left quadrant. This view shows the freeze gas (nitrogen) supply line connector (140), the freeze gas (nitrogen) supply valve actuator (141 A), the freeze gas (nitrogen) supply valve (141), the freeze gas (nitrogen) supply tank ( 143), and the freeze gas (nitrogen) injection line ( 145). It also shows the freeze gas (nitrogen) tracer coils ( 146), the freeze gas (nitrogen) tracer coils protection tube (147) and the freeze gas (nitrogen) exhaust line (148) in accordance with another embodiment of the present invention.

FIGURE 29 also shows the dispersant system is located in the upper left quadrant. This view shows the dispersant supply line connector (160), the dispersant supply valve actuator (161 A), the dispersant supply valve ( 161 ), the dispersant supply tank (163), and the dispersant injection line (165) in accordance with another embodiment of the present invention. FIGURE 29 also shows the compressed gas system is located in the upper right quadrant. This view shows the compressed gas supply line connector (170), the compressed gas valve actuator (171 A), the compressed gas supply valve (1 1), and the compressed gas supply tank (132) in accordance with another embodiment of the present invention.

FIGURE 30 shows an antifreeze (methanol) injection system. The antifreeze injection system can be mounted on the top or bottom of the device. Antifreeze (methanol) can be loaded from a surface storage tank, via hoses down to the antifreeze (methanol) injection system by a connective delivery hose. The delivery hose connects to the antifreeze (methanol) supply line connector (130). The antifreeze (methanol) supply line connector (130) is regulated by an antifreeze (methanol) supply actuator (131 A) which controls an antifreeze (methanol) supply valve (131). The antifreeze (methanol) supply valve (131) regulates the flow of antifreeze (methanol) to the antifreeze (methanol) supply line ( 133L). The antifreeze (methanol) supply line (133L) provides direct connection to the antifreeze (methanol) injection line (135). The flow of antifreeze (methanol) in the antifreeze (methanol) injection line (135) is regulated by the antifreeze (methanol) injection valve actuator (134A) which controls the antifreeze (methanol) injection valve (134). The antifreeze (methanol) is injected into the flow tube (I) as and when required to prevent freezing of the oil and gas mixture in the flow tube in accordance with another embodiment of the present invention.

FIGURE 30 also shows a freeze gas (nitrogen) injection system. The freeze gas (nitrogen) injection system can be mounted on the top or bottom of the device. Freeze gas (nitrogen) can be loaded from a surface storage tank, via hoses down to the freeze gas (nitrogen) injection system by a connective delivery hose. The delivery hose connects to the freeze gas (nitrogen) supply line connector (1 0). The freeze gas (nitrogen) supply line connector (140) is regulated by a freeze gas (nitrogen) supply actuator (141 A) which controls a freeze gas (nitrogen) supply valve (141).

The freeze gas (nitrogen) supply valve (141) regulates the flow of freeze gas (nitrogen) to the freeze gas (nitrogen) supply line (143L). The freeze gas (nitrogen) supply tank (143) provides a direct supply of freeze gas (nitrogen) to the freeze gas (nitrogen) injection line (145). The flow of freeze gas (nitrogen) in the freeze gas (nitrogen) injection line ( 145) is regulated by the freeze gas

(nitrogen) injection valve actuator (144A) which controls the freeze gas (nitrogen) injection valve (144). The freeze gas (nitrogen) is injected into the freeze gas (nitrogen) tracer coils (146) which refrigerates the flow tube ( 1 ) as and when required to induce freezing of the oil and gas mixture in the flow tube. This is a backup mechanism to controlling flow from the flow tube (1 ) should the actuated valve at the (G) end of the flow tube fail to control the flow of oil and gas from the flow tube (1) in accordance with another embodiment of the present invention.

FIGURE 31 shows a dispersant injection system. The dispersant injection system can be mounted on the top or bottom of the device. Dispersant can be loaded from a surface storage tank, via hoses down to the dispersant injection system by a connective delivery hose. The delivery hose connects to the dispersant supply line connector (160). The dispersant supply line connector

( 160) is regulated by a dispersant supply actuator (161 A) which controls a dispersant supply valve

( 161) . The dispersant supply valve (161) regulates the flow of dispersant to the dispersant supply line (163L). The dispersant supply line (163L) provides a direct supply of dispersant to the dispersant injection line (165). The flow of dispersant in the dispersant injection line (165) is regulated by the dispersant injection valve actuator (1 4A) which controls the dispersant injection valve (164). The dispersant is injected into the flow tube (1) as and when required to improve dispersion of the oil and gas mixture in the water column and reduce fouling of fish and wildlife, flora and fauna, beaches and anthropogenic structures in accordance with another embodiment of the present invention.

FIGURE 31 also shows the compressed gas system can be mounted on the top or bottom of the device. Compressed gas can be loaded from a surface storage tank, via hoses down to the compressed gas injection system by a connective delivery hose. This view shows the compressed gas supply line connector (170), the compressed gas valve actuator (171 A), the compressed gas supply valve (171), the compressed gas supply line ( 172) connected to the compressed gas supply line (173L) connected to the compressed gas injection line (175). The compressed gas injection line (175) is regulated by the compressed gas injection valve actuator (174A) which controls the compressed gas injection valve to distribute the compressed gas in accordance with another embodiment of the present invention. FIGURE 32 shows a heated water injection system. The heated water injection system can be mounted on the top or bottom of the device. Heated water can be loaded from a surface storage tank, via hoses down to the heated water injection system by a connective delivery hose. The delivery hose connects to the heated water supply line connector (180). The flow of heated water from the heated water supply line connector (180) is regulated by a heated water supply valve actuator (181 A) which controls a heated water supply valve (181). The heated water supply valve (1 1 ) regulates the flow of heated water to the heated water supply line ( 182). The heated water supply line (182) provides a supply of heated water to the heated water supply tank (183). The heated water supply tank (183) provides heated water to the heated water injection line (185). The flow of heated water in the heated water injection line (185) is regulated by the heated water injection valve actuator (184A) which controls the heated water injection valve (184). The heated water is injected into the heated water tracer coils (186) which heats the flow tube (1) as and when required to induce heating of the internal surface of the flow tube (1) and heating of the oil and gas mixture in the flow tube (1). This is a backup mechanism to controlling flow from the flow tube (1 ) should the flow tube begin to freeze or should the actuated valve at the (G) end of the flow tube begin to freeze and fail to control the flow of oil and gas from the flow tube (1) in accordance with another embodiment of the present invention.

FIGURE 33 shows another embodiment of the heated water injection system. The heated water injection system can be mounted on the top or bottom of the device. Heated water can be loaded from a surface storage tank, via hoses down to the heated water injection system by a connective delivery hose. The delivery hose connects to the heated water supply line connector (180). The flow of heated water from the heated water supply line connector (180) is regulated by a heated water supply val ve actuator ( 181 A) which controls a heated water supply valve (181). The heated water supply valve (181 ) regulates the flow of heated water to the heated water supply line (182). The flow of heated water flows directly to the heated water supply line (143L) which provides a direct supply of heated water to the heated water injection line ( 185). The flow of heated water in the heated water injection line (185) is regulated by the heated water injection valve actuator (184A) which controls the heated water injection valve (184). The heated water is injected into the heated water tracer coils (186) which heats the flow tube (1) as and when required to induce heating of the internal surface of the flow tube (1) and heating of the oil and gas mixture in the flow tube (1). This is a backup mechanism to controlling flow from the flow tube (1) should the flow tube begin to freeze or should the actuated valve at the (G) end of the flow tube begin to freeze and fail to control the flow of oil and gas from the flow tube ( 1 ) in accordance with another embodiment of the present invention.

FIGURE 34 shows the heated water system is located in the lower left quadrant. In other embodiments, the heated water system may be located in any of the other three quadrants of the device. This view shows the heated water supply line connector (180), the heated water supply valve actuator (181 A), the heated water supply valve (181), the heated water supply tank (183), and the heated water injection line (185). It also shows the heated w^rater tracer coils (186), the heated water tracer coils protection tube (187) and the heated water exhaust line (188) in accordance with another embodiment of the present invention.

One or more currently preferred embodiments have been described by way of example. It will be apparent to persons skilled in the art that a number of variations and modifications can be made without departing from the scope of the invention as defined in the claims.

FIGURE 35 shows the multiple expandable polymer bladder system which would consist of a series of expandable polymer bladders (5) mounted on a multiple bladder concentric header tube (218). The multiple bladder concentric header tube (218) provides an annular space between the exterior of the flo tube ( I ) and the interior of the multiple bladder concentric header tube (21 ). The annular space provides space for mounting the multiple bladder header(s) (215). The multiple bladder header(s) (215) conduct the compressed gas/sea water pressure fluid to the individual or sets of bladder fluid injectors/valves (217) which pass via a connecting hole and attach to the individual bladders. The bladder fluid injectors/valves (217) allow injection of the compressed gas/sea water pressure fluid to the single bladder or sets of bladders at the same time to expand the bladders. Where articulating joints are included in the flow tube there must be the equivalently spaced multiple bladder header tube flex joint(s) (216) in the multiple bladder header tube (s) (215) and in the multiple bladder header concentric header tube (218) to allow flexing of the multiple bladder system. FIGURE 36 shows a bleed header system ( 220 ) with bleed header couplings ( 221) and bleed header valves (222) which can be connected to the coupling at the (G) end of the flow tube (1) to allow one or more streams of fluid to be bled from the flow tube (5) This allows the diversion of flow to two or more containment systems.

FIGURE 37 shows a conceptual plan view of a single or multiple compressed solid polymer system. The concentric fixed plate(s) (230) are mounted on the outside of the flow tube (1) and provide a base of support for the compression of the compressible polymer seal rings (233) and the movable concentric compression plates.(234) When the reversible electric or hydraulic drives turn or pull the threaded or sliding hydraulic shafts the movable concentric compression plates (234) compress the compressible polymer seal rings (233) which expand in a radial direction and seal against the outer surface of the flow tube(l ) and the inner surface of the (indented) damaged pipe. (245)

FIGURE 38 shows a conceptual plan view of the movable blade sealing system. The concentric fixed plate(s) (230) are mounted on the outside of the flow tube ( 1 ) and provide a base of support for the rotating hydraulic or electrically driven shaft(s) (242) which are connected to the reversible electric or hydraulic drives at the (C ) position. Movable compression blades (240) with compressible polymer seals (241) are mounted on spring (243) loaded bearings (244) and are positioned against the concentric fixed plate(s) (230) by key lock or threaded compression nuts. The movable compression blades (240) with compressible polymer seals (241) are in the outer annulus open position when they are in contact with the exterior of the flow tube. When the reversible electric or hydraulic drives (232) are rotated in the clock wise direction when viewed from the (A) end, they close the outer annulus (229) and form a seal against the inside of the (indented) damaged pipe. (245) Where the indentations contact the movable compression blade(s) (240) the spring (343) loaded bearings (244) will allow the impacted movable compression blade to stop while the other movable compression blade(s) (240) to continue to rotate until they contact the undamaged portion of the pipe.

FIGURE 38 also shows a plan view of the movable compression blade(s) (240) and their general overlapping configuration in the open annulus and closed annulus position. FIGURE 39 shows the shows a conceptual plan view of the movable blade (240) sealing system plus the expandable polymer bladder (5) configuration. In this view a concentric bladder pressurization line cylinder (251) may or may not be added to the outside of the flow tube. (1) The expandable polymer bladder(s) are inserted between consecutive fixed concentric plates (230) and moveable compression blades (240). After the moveable compression blades (240) have been moved to the outer annulus (229) closed position the expandable polymer bladder(s) are pressurized and inflated so that they form a seal against outer wall of the flow tube(5) or outer wall of the concentric pressurization line cylinder and the inner wall of the (indented) damaged pipe. (245)

FIGURE 40 shows a plan view of the moveable compression blades (240) in the outer annulus (229) open and outer annulus (229) closed position and how they overlap to provide a seal of the outer annulus (229).

FIGURE 40 also shows that the moveable compression blade(s) (240) configuration at the (H) end has a wide end where the blade connects to the spring loaded (244) blade shaft bearing (243) which may slightly exceed the height of the fixed concentric plate(s) (230). It also shows that the (J) end of the moveable compression blade(s) (240) configuration has a narrow and notched end to allow the annulus (229) open position to be achieved.

FIGURE 41 shows a cross sectional view of the configuration of the moveable compression blade(s) (240) where the rotating hydraulic or electrically driven shaft (242) passes through the fixed concentric plate(s) (230) and attaches to the moveable compression blades (240). This figure also shows the relative internal positions of the fixed concentric plate bearing (230B), the blade shaft bearing ( 243) and the blade shaft bearing spring (244). This figure also shows the "S" shape of the moveable compression blade(s) (240) that allows overlapping of the moveable compression blade(s) (240) and allows one or more of the moveable compression blade(s) (240) to remain partially open against an indentation while the remaining moveable compression blade(s) (240) fully open to the closed outer annulus (229) position. FIGURE 42 shows a cross sectional view of the flow tube (1) the concentric bladder pressurization line cylinder (251 ), fixed concentric plates (230), the outer annulus (229) open, and a mounted movable compression blade plate (240). It also shows the inner and outer boundaries of the inner annulus (252). It also shows the bladder pressurization line (250) is connected from inner annulus (252) to outer annulus (229) by a bladder inflation connector (254) and connects to expandable polymer bladder. (5) It also shows a moveable compression blade(s) (240) in the outer annulus (229) closed position.

Figure 43 shows a cross sectional view of the flow tube (1 ) with an external sliding sleeve sealing system that consists of a polymer sealing sleeve (262, bladed polymer compression sheath (262B), external tapered pressure sleeve pipe (261 ), external pressure sleeve pistons (265), external piston collar (266), external grip pads (263) with rotatable elbow connectors (263(A) and external grip pistons. It shows that when the external pressure sleeve pipe (261) is forced in the upstream direction by the external pressure sleeve pistons (265) that the optional bladed polymer compression sheath (262B) is expanded against the polymer sealing sleeve (262) forcing the polymer sealing sleeve (262 against the interior surface of the external damaged pipe (259) closing off the annulus between the flow tube ( 1 ) and the external damaged pipe (259) and forcing all liquid through the open annulus of the flow tube(l). The figure also shows that external grip pads (263) can be used to provide additional stabilization force againsi the interior surface of the external damaged pipe (259) to prevent expulsion of the device due to rising pressures resulting from partial or total closing of the annulus of the flow tube (1).

Figure 43 also shows that the external tapered pressure sleeve pipe may have multiple configurations of the taper including slopes, plateaus and ridges.

Figure 44 shows a broader cross sectional view of the flow tube (1) with an external sliding sleeve sealing system that consists of an external pressure header (267), external hydraulic pump, and external pipeline connector. The external hydraulic pump is used to provide pressure through the header to the external pressure sleeve pistons which drive the external tapered pressure sleeve pipe in an upstream direction and the external grip pistons which drive the grip pads in an outward/radial direction. Figure 44 also shows that an external pipeline connector can be mounted at the downstream end of the device for connection to other pipelines, skids or equipment.

Figure 45 shows that a remotely operated vehicle (ROV) (270) can be connected to the External Sliding Sleeve Sealing System to transport it to the damaged pipe. Figure 45 also shows that an ROV external clamping system (271) may be required to provide stability and insertion force to the External Sliding Sleeve Sealing System

DETAILED DESCRIPTION OF THE INVENTION

[0017] General Operation of the invention - insertion of the Device

[0018] With reference to Figure 1 A, for example, a ruptured oil well in deep water is leaking oil and/or natural gas into the ocean and polluting the water in an uncontrolled manner. The "Expandable Polymer Bladder Apparatus" is deployed by cable or by submersible, submarine or guided ROV towards the ruptured well. With reference to Figure IB, the "Expandable Polymer Bladder Apparatus" is inserted into the ruptured well and the bladder is inflated with gas (nitrogen) or sea water. The angle of insertion may be any angle from zero to ninety degrees depending on the condition and physical situation of the rupture pipe or well. Partial flow control is established by directing the oil and/or natural gas into the open ended flow control tube at the "A" end. Flow exiting the flow control tube is gradually stopped by closing an actuated valve at the "G'^" end of the flow control tube. A new pipeline is attached to the coupling at the "G" end and the control valve is opened up and the oil and/or natural gas is pumped to the surface onto a containment vessel. Once control of the oil/natural gas flow is re-established alternative measures can then be taken to control or permanently close the well.

[0019] General Operation of the Invention - Insertion of the Device on the top of the Blow Out Preventor.

[0020] With reference to Figure 1 F, in the circumstance where the riser has been cut from the blow out preventor due to damage to the riser, the device can be applied in the vertical position. In this instance a caisson (190) must be inserted over the cut end of the blow out preventor and secured to the blow out preventor. Securing the caisson (190) may require a clamp system or welding of the caisson (190) to the blow out preventor. Once the caisson (190) has been secured, the device can be inserted and secured using the hydraulic anchor rams (28) with ram contours (29) with grip points (30). The external compression collar blowout retention ring (99.3) (which inhibits the expulsion by engaging the D3 contour if the hydraulic anchor ram (28) and the expandable polymer bladder device (5) experience high pressure and slide or lose grip on the inside of the damaged pipe or well) can be attached to the exterior and top end of the caisson (190) and secured. Once stability has been established the following general steps can be initiated in the optimal order. The dispersant injection system can be initiated and dispersant added to the escaping oil and gas mixture. The methanol injection (130) can be initiated and added to the oil/gas mixture to prevent formation of hydrates. The heated water flow can be initiated (180) to reduce risk of freezing inside the flow tube (1). A collection hose can be attached to the connective coupling (15) to initiate extraction of the oil/gas flow to the surface. If stability continues, water can be injected into the expandable polymer bladder (5) which will begin to close off the annulus between the flow tube (1) and the caisson (190). Should stability be maintained, the expandable polymer bladder can be fully inflated, completely closing the annulus and directing all oil/gas flow through the flow tube. Λ decision to discontinue addition of dispersant can be made depending on the percentage of capture of the oil and gas.

[0021 J General Operation of the Invention - Insertion of Sealing fluids or compounds

[0022] With reference to Figure 1 A and Figure 1 C, for example, a ruptured oil well in deep water is leaking oil and/or natural gas into the ocean and polluting the water in an uncontrolled manner. The "Expandable Polymer Bladder Apparatus" is deployed by cable or by submersible, submarine or guided RO V towards the ruptured well. With reference to Figure IB a fill or sealant material is injected under pressure via the expanded polymer bladder device into the damaged oil and gas well and sets up a sealing barrier to permanently shut in the well.

[0023 j General Operation of the Invention - Extraction of the Device [00241 With reference to Figure 1 B the device can be extracted from the damaged well by deflating the expanded polymer bladder and retracting the anchor rams. The internal pressure of the well pushing on the expanded polymer bladder will force the device from the well. In another non-limiting design, a remote operated vehicle, or cable may be used to assist in towing the device out of the damaged well.

[0025] As will be appreciated from the detailed description of the invention below, the Expandable Polymer Bladder Apparatus can be useful for controlling the flow from a ruptured pipeline or well in shallow and deep (ocean or lake) water conditions. The device can be constructed in various diameters and lengths so that it is adaptable to a range of pipeline or well pipe diameters which makes it adaptable to multiple scenarios and physical/mechanical constraints. The multiple design diameters allows for economical manufacture to reduce the number of devices which must be maintained in inventory to service a field situation. For this reason, lengths and diameters are described as variables which are adapted during the manufacture of the device to best suit the potential or actual operating conditions.

[0026] Description of the Flow Control Tubing

[0027] With reference to Figure 2, in one non-limiting embodiment, flow control tube (1) is a tube of diameter Dl with an open end adapted at (A) to allow fluid to be conveyed into the tube. Without limiting the choices the flow tube can be constructed of metal, fiberglass, carbon fiber or other material which is structurally capable of withstanding the stresses imposed and resistant to degradation by the fluid being controlled and resistant to impact and abrasion damage. Without limiting the choices the diameter Dl is chosen to be of a proportion of the pipeline or well tube diameter D3 which is sufficient to deliver the desired flow once control of the flo has been established. The flow control tube may be a length (LI) depending on the circumstances but sufficient to allow complete insertion of the bladder at least a distance of L2. In such an embodiment, the tube at (A) does not have any internal pipe threads but does have external pipe threads for the connection of any other fixtures. Without limiting the choices the flow tube at (C) to (D) can have a length of (L3) depending on the circumstances but sufficient to allow complete construction of the required control valves for flow control of compressed gas or high pressure (sea) water into and out of the expandable polymer bladder (5) The flow tube at (D) to (E) has a suspension bracket (22) attached to it to allow the mounting of other apparatus described below. The flow tube at (E) has an external pipe thread to which an actuated exit flow valve (14) of diameter D 1 is connected. The flow tube at (E) has a threaded nipple (15.1) which is connected to the actuated valve at (F) and to a connective coupling ( 15) at (G). The connective coupling (15) of diameter Dl with an internal thread at the (F) end capable of attaching to the connective threaded nipple ( 15.1 ) and a connective threaded or snap lock mechanism at the (G) end which is capable of a quick connect to fluid transport tubing or hose or other flow containment device. Once flow control has been re-established, the connective coupling (15) allows the connection of hoses or other pipes to allow the transport of fluid to containment facilities on the bottom or at the surface of the water body.

[0028] Description of the External Bladder Mounting Plates.

[0029] With reference to Figure 2, in one non-limiting embodiment a concentric external bladder mounting plate (2) consists of a circular plate made out of metal or other material resistant to the fluid. The internal diameter of the external circular mounting plate has a pipe thread which matches the external pipe threads of the flow tube ( 1 ). The external mounting plate has a diameter of D2 which is chosen to be of a proportion of the pipeline or well tube diameter D3 which is sufficient to provide support to the expandable polymer bladder(5). The external bladder mounting plate (2) has equally spaced bolt holes (3) around the circumference of the plate. In such an embodiment there may or may not be a concentric internal bladder mounting plate (4) which consists of a circular plate made out of metal or other material resistant to the fluid.

[0030] Description of the Internal Bladder Mounting Plates.

[0031] With reference to Figure 2, in one non-limiting embodiment where the internal bladder mounting plate (4) is used it has equally spaced bolt holes (3) around the circumference of the plate which match the holes in the external bladder mounting plate. In the embodiment where there are external and internal expandable polymer bladder mounting plates at (B) and (C) the plates are joined by bolts secured by nuts.

[0032] Description of the Securing of the External Bladder Mounting Plates.

[0033] With reference to Figure 2, in one non-limiting embodiment the external mounting plate sleeve (16) has an internal diameter of Dl and has an internal pipe thread which is threaded on to the flow rube to secure the external bladder mounting plate (2) at (B) and (C) against the expandable polymer bladder (5).

[0034] Operation of the Expandable Polymer Bladder without an Internal Mounting Plate.

[0035] With reference to Figures 2, 3, 4, 5, and 6, in one non-limiting embodiment, the expandable polymer bladder (5) may be formed as a cylindrical unit designed with an internal tube of diameter D1+ which fits over the external surface of the flow tube of diameter D 1. In one non-limiting embodiment the expandable polymer bladder does not have an internal bladder mounting plate but does have two compressed gas inlet ports (17) and at least one compressed gas/water exhaust port (18) and at least one pressure release valve. (18.5) The expandable polymer bladder (5) runs the length L3 between the external bladder mounting plates at (B) and (C).

[0036] Operation of the Expandable Polymer Bladder with Internal and External Mounting Plates

[0037] With reference to Figure 2, in one non limiting embodiment, the expandable polymer bladder and the internal and external bladder mounting plates at the (B) end of the bladder are held in place by bolts (6) which are connected through the internal bladder mounting plate, the expandable polymer bladder and the external bladder mounting plate and secured by metal ring washers and nuts (7). In Figure 2, the expandable polymer bladder arid the internal and external bladder mounting plates at the (C) end of the bladder are held in place by bolts (6) which are connected through the internal bladder mounting plate, the expandable polymer bladder and the external bladder mounting plate and secured by a metal ring washers and nuts. (7) [0038] Operation of the Expandable Polymer Bladder with a Smooth Surface

[0039] With reference to Figure 4, in one non-limiting embodiment the exterior surface of the expandable polymer bladder may be a smooth surface (19).

[0040] Operation of the Expandable Polymer Bladder with a Rough Surface

[0041] With reference to Figure 5, in one non-limiting embodiment the exterior surface of the expandable polymer bladder may be a rough surface (20).

[0042] Operation of the Expandable Polymer Bladder with a chain mail or wire mesh or braided wire fibers or other synthetic structural fiber surface such as carbon fiber.

[0043] With reference to Figure 5A, in one non-limiting embodiment the exterior surface of the expandable polymer bladder (5) may be a combination of the expandable polymer bladder (5) material as an inner layer and an exterior chain mail (21.1) or wire mesh or braided wire fibers (21.2) or other synthetic structural fiber surface such as carbon fiber. (21.3) Where the exterior surface is chain mail (21.1), the outer surface of the chain mail (21.1) may be a rough scored surface to increase the frictional co-efficient of the device and increase the abrasive adherence to the inner surface of the ruptured pipeline or well. The inner surface of the chain mail (21.1) may be a smooth surface so as not to abrade the outer surface of the expandable polymer bladder (5). The chain mail (21.1) provides an expandable protective sheath as the expandable polymer bladder (5) is inflated. The pore spacing of the chain mail (21.1) provides increased structural integrity to the expandable polymer bladder (5) by decreasing the pore space upon which the internal and external pressures can act on the expandable polymer bladder (5). Where the exterior surface is wire mesh (21.2), the outer surface of the wire mesh (21.2) may be a rough scored surface to increase the frictional co-efficient of the device and increase the abrasive adherence to the inner surface of the ruptured pipeline or well. The inner surface of the wire mesh or braided wire fibers (21.2) may be a smooth surface so as not to abrade the outer surface of the expandable polymer bladder (5). The wire mesh or braided wire fibers (21.2) provides an expandable protective sheath as the expandable polymer bladder (5) is inflated. The pore spacing of the wire mesh or braided wire fibers provides increased structural integrity to the expandable polymer bladder (5) by decreasing the pore space upon which the internal and external pressures can act on the expandable polymer bladder (5). Where the exterior surface is another fiber material such as carbon or other synthetic fiber (21.3), the outer surface of the carbon or other synthetic fiber (21.3) may be a rough scored surface to increase the frictional co-efficient of the device and increase the abrasive adherence to the inner surface of the ruptured pipeline or well. The inner surface of the carbon or other synthetic fiber (21.3) may be a smooth surface so as not to abrade the outer surface of the expandable polymer bladder (5). The carbon or other synthetic fiber (21.3) provides an expandable protective sheath as the expandable polymer bladder is inflated. The pore spacing of the carbon or other synthetic fiber (21.3) provides structural integrity to the expandable polymer bladder (5) by decreasing the pore space upon which the internal and external pressures can act on the expandable polymer bladder (5)

[0044] Operation of the Expandable Polymer Bladder with a Ribbed Surface

[0045] With reference to Figure 6 in one non-limiting embodiment the exterior surface of the expandable polymer bladder may be a ribbed surface with a smooth surface on the ribs (21). In one non-limiting embodiment the exterior surface of the expandable polymer bladder may be a ribbed surface with a rough surface on the ribs. (21.5)

[0046] Operation of the Suspension Bracket

[0047] With reference to Figures 2 and 12, in one non-limiting embodiment the suspension bracket (22) may consist of side brackets extending laterally from the central tube. In one non- limiting embodiment the suspension bracket (22) may consist of a concentric circular central tube (22C) of D1+ inside diameter that fits over the flow tube with side brackets extending laterally from the central tube. The central tube (22C) may be attached to the flow tube by direct weld, glue or other mechanism that prevents rotation of the central tube (22C) around the flow tube. In one non-limiting embodiment the suspension bracket (22) may consist of a concentric rectangular central tube (22CR) of D1+ inside diameter that fits over the flow tube with side brackets extending laterally from the central tube. The concentric rectangular central tube (22CR) may be attached to the flow tube by direct weld, glue or other mechanism that prevents rotation of the central tube (22C) around the flow tube. In one non-limiting embodiment the suspension bracket

(22) may consist of side brackets extending laterally from the central tube with cross braces (23) to support a mounting platform (24) for the compressed air tank (8) of volume VI . In one non- limiting embodiment, compressed air tank securing straps (26) are attached to the cross braces

(23) to secure the compressed air tank. (8)

[0048] Operation of the Compressed Gas (Nitrogen) Tank.

[0049] With reference to Figure 2, in one non-limiting embodiment a compressed gas (nitrogen) tank (8) is mounted on top of the fluid transport and control tube (1) and secured to the mounting platform (24) between the (D) end of the expandable polymer bladder (5) and the (E) end of the flow transport tube. (1) The compressed air tank (8) is secured to the mounting platform by the compressed gas (nitrogen) tank securing straps. (26)

[0050] Operation of the Bladder Inflator System using a Control Valve and Compressed Gas (Nitrogen).

[0051] With reference to Figures 2 and 12, in one non-limiting embodiment, the bladder inflator valve actuator (35 A) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to the bladder inflator valve actuator (35 A) which opens the bladder inflator valve (35) The compressed gas (nitrogen) tank (8) supplies expansion force to the expandable polymer bladder (5) by transmitting compressed gas (nitrogen) through a transmission tube (9) to a distribution header (25). The distribution header delivers compressed gas (nitrogen) to a bladder inflator valve (35). Compressed gas (nitrogen) enters the expandable polymer bladder (5) by passing from the bladder inflator valve (3 ), through the bladder compressed gas/water filling ports ( 17) into and expands the bladder against the flow control tube ( 1 ) and the ruptured pipeline or well (200). When the appropriate pressure is reached inside the expandable polymer bladder (5) a signal is sent from the bladder pressure transducer sensor (PT1) to the control consol (100) A signal is sent from the control consol (100) to the bladder inflator valve actuator (35A) which closes the bladder inflator valve (35) [0052] Operation of the Bladder Inflator System using a Control Valve and Pumped (Sea) Water

[0053] With reference to Figures 2, 12, 14, and 15 in one non-limiting embodiment, the bladder inflator valve actuator (35A) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to the bladder inflator valve actuator (35A) which opens the bladder inflator valve. (35) A signal is sent from the control consol (100) to the high pressure (sea) water pump (80). The high pressure (sea) water pump (80) uses electrical power from the onboard high pressure (sea) water pump batteries (81) and supplies expansion force to the expandable polymer bladder (5) by transmitting high pressure (sea) water through a transmission tube (9) to a distribution header (25). The distribution header (25) delivers high pressure water to a bladder inflator valve (35). High pressure water enters the expandable polymer bladder (5) by passing from the bladder inflator valve (35) through the bladder compressed gas/water filling ports (17) into and expands the bladder against the flow control tube (1 ) and the ruptured pipeline or well (200). When the appropriate pressure is reached inside the expandable polymer bladder (5) a signal is sent from the bladder pressure transducer sensor (PT1) to the control consol. (100) When proper internal bladder pressure is reached a signal is sent from the control consol (100) to the bladder inflator valve actuator (35 A) which closes the bladder inflator valve (35) and shuts down the high pressure (sea) water pump (80)

[0054] Operation of the Bladder Deflator System using a control Valve.

[0055] With reference to Figures 2, 4, and 12 in one non-limiting embodiment, the bladder inflator valve actuator (35A) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to the deflator valve actuator (36A) which opens the deflator valve (36). Compressed gas (nitrogen) or (sea) water exits the expandable polymer bladder (5) by passing through the compressed gas/water exhaust port (18) and deflates the bladder from the surface of the flow control tube (1 ) and the surface of the ruptured pipeline or well (200). [0056] Operation of the Bladder Deflator System using a Pressure Relief Valve.

[0057] With reference to Figures 4. 5, and 6 in one non-limiting embodiment a bladder pressure transducer sensor (PT1) is connected to the control consol (100) in a command vessel for the purposes of registering the internal pressure of the expandable polymer bladder (5). The expandable polymer bladder (5) may experience an excessive pressure build up within the expandable polymer bladder (5) which opens the bladder pressure release valve (18.5). Compressed gas (nitrogen) or (sea) water exits the expandable polymer bladder (5) by passing through the bladder pressure release valve (18.5) and deflates the bladder from the exterior surface of the flow control tube (1) and from the surface of the ruptured pipeline or well (200) until the proper operating pressure within the expandable polymer bladder (5) is reached. The bladder pressure release valve ( 18.5) then closes automatically to maintain the proper operating pressure with the expandable polymer bladder (5). The bladder pressure release valve (18.5) is not connected to the control consol ( 100) in a command vessel (150) for the purposes of control.

[0058] Structure of the Circular Hydraulic Anchor Ram Header.

[0059] With reference to Figure 12, in one non- limiting embodiment, the anchor ram header is a circular tube (27.1 ) that is concentrically mounted around the flowtube between (C ) and (D) position. In one non-limiting embodiment the anchor ram header with a circular tube (27.1 ) has an even number of hydraulic pistons positioned diametrically opposite of each other. In one non- limiting embodiment there are two hydraulic pistons positioned diametrically opposite of each other. In one non-limiting embodiment there are four hydraulic pistons positioned diametrically opposite of each other.

[0060] Structure of the Rectangular Hydraulic Anchor Ram Header.

[0061 ] With reference to Figure 12, in one non-limiting embodiment, the anchor ram header is a rectangular tube (27.2) that is concentrically mounted around the flow tube between (C ) and (D) position. In one non-limiting embodiment the anchor ram header with a rectangular tube (27.2) has an even number of hydraulic pistons positioned diametrically opposite of each other. In one non-limiting embodiment there are two hydraulic pistons positioned diametrically opposite of each other. In one non-limiting embodiment there are four hydraulic pistons positioned diametrically opposite of each other.

[0062] Operation of the Hydraulic Anchor Ram Contour with non-flexible Grip Points Mechanism

[0063] The anchor ram piston valve actuator (37A) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to the anchor ram piston valve actuator (37A) which opens the anchor ram piston valve (37). The compressed gas (nitrogen) or (sea) water distribution header (25) distributes compressed gas (nitrogen) or (sea) water to the

[0064] The hydraulic anchor piston (27) drives hydraulic anchor rams (28) outward when the piston is pressurized. The hydraulic anchor rams (28) drive the ram contour (29) with grip points (30) into the inside D3 contour of the ruptured pipe providing centralization of position and additional grip of the device to the ruptured pipe. The ram contour (29) does not have a flexible swivel hinge.

[0065] Operation of the Hydraulic Anchor Ram with flexible Ram Contour Mechanism

[0066] With reference to Figure 7, in one non-limiting embodiment, the anchor ram piston valve actuator (37A) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to anchor ram piston valve actuator (37A) which opens the anchor ram piston valve (37). The compressed gas (nitrogen) or (sea) water distribution header (25) distributes compressed gas (nitrogen) or (sea) water to the hydraulic anchor piston (27). In this embodiment, the hydraulic anchor ram (28) has a swivel hinge (38) connecting the ram contour with grip points (29) to the hydraulic anchor ram(s) (28). The swivel hinge (38) allows the anchor ram contour with grip points (29) to adjust to the D3 contour of the ruptured pipe to facilitate gripping of the anchor ram contour with grip points (29) to the D3 contour of the ruptured pipe. The hydraulic anchor piston (27) drives hydraulic anchor rams (28) outward when the hydraulic anchor piston (27) is pressurized. The hydraulic anchor ram(s) (28) drive the anchor ram contours) (29) with grip points (30) into the inside D3 contour and adjust to the contour of the ruptured pipe providing centralization of position and additional grip of the device to the ruptured pipe.

[0067] Operation of the Hydraulic Anchor Ram with Pin Mechanism.

[0068] With reference to figures 13 and 15, in one non-limiting embodiment, the anchor ram piston valve actuator (37A) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to anchor ram piston valve actuator (37A) which opens the anchor ram piston valve (37). The compressed gas (nitrogen) or (sea) water distribution header (25) distributes compressed gas (nitrogen) to the hydraulic anchor piston (27). In this embodiment the hydraulic anchor ram has an anchor pin (31.5) connected to the end of the hydraulic anchor ram. (28) The anchor ram piston valve actuator (37A) pressurizes the hydraulic anchor piston (s) (27). The hydraulic anchor piston (27) drives the hydraulic anchor rams (28) outward when the piston(s) (27) is pressurized. The hydraulic anchor rams (28) drive the anchor pins (31.5) into the inside D3 contour and possibly puncture the side of the ruptured pipe providing centralization of position and additional grip of the device to the ruptured pipe.

[0069] Operation of the Hydraulic Anchor Ram Release Mechanism.

[0070] With reference to figures 12, 13 and 15 in one non-limiting embodiment, the anchor ram release valve actuator (39A) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol ( 100) in a command vessel (150). A signal is sent from the control consol ( 100) to anchor ram release valve actuator (39 A) which opens the anchor ram piston release valve. (39) The pressure inside the hydraulic anchor piston (27) drives hydraulic anchor rams (28) inward when the piston (27) is depressurized. The hydraulic anchor rams (28) retract from the inside D3 contour and release the grip of the device from the ruptured pipe.

[0071] Structure of the Ballast System

[0072] With reference to figures 14, 15 and 1 in one non-limiting embodiment the ballast system without wishing to be limiting can consist of at least one, two or four ballast tanks (Ml) attached to the underside of the suspension bracket (22). Each ballast tank will be connected to the ballast tank distribution line (83). Each ballast tank will have a protective, adjustable metal ballast plate (84) on its underside which is connected to the ballast tank(s) (Ml) via a series of at least 4 ballast plate suspension bolts (85) and ballast plate nuts (86). The ballast plate suspension bolts (85) are connected to the suspension bracket. (22) The metal ballast plates are adjustable in that more or less plates can be suspended on the underside bolts to increase or decrease the mass of the device. Each ballast tank will have a ballast tank pressure relief valve Ml.5 for emergency release of pressure. Each ballast tank will have a pressure transducer (PT2) which is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150).

[0073] Operation of the Ballast Tanks using a Pressure Relief Valve.

[0074] With reference to Figure 14, in one non-limiting embodiment a ballast tank pressure sensor (PT2) is connected to the control consol (100) in a command vessel for the purposes of registering the internal pressure of the ballast tank (Ml). The ballast tank(s) (Ml) may experience an excessive pressure build up within the ballast tank(s) (Ml) which opens the ballast tank pressure release valve (Ml .5). Compressed gas (nitrogen) or (sea) water exits the ballast tank (Ml) by passing through the ballast tank pressure release valve (Ml.5) and deflates the ballast tank until the proper operating pressure within the ballast tank (Ml ) is reached. The ballast tank pressure release valve (Ml .5) then closes automatically to maintain the proper operating pressure with the ballast tank (Ml)). The ballast tank pressure release valve (Ml .5) is not connected to the control consol (100) in a command vessel (150) for the purposes of control.

[0075] Operation of the Ballast System

[0076] With reference to figures 14, 15 and 16 in one non-limiting embodiment additional stabilizing ballast (M 1 ) is attached to the suspension bracket (22) on each side of the underside of the suspension bracket (22). The stabilizing ballast may be a combination of a single solid metal (steel/lead) ballast plate(s), and/or tank(s) which can alternately be filled and emptied with compressed gas (nitrogen) or (sea) water. The stabilizing ballast (Ml) has sufficient mass to provide a balanced center of gravity when the entire system is suspended by hoisting cables (31) or carried by or under a Remote Operated Vehicle (ROV). (60)

[0077] Operation of the Ballast System - Inflation and Deflation with Compressed Gas

[0078] With reference to Figures 8, 9, 10, 11, 12, 13, 14, 15, 16 in one non-limiting embodiment, the ballast tank deflator valve actuator (82AD) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to the ballast tank deflator valve actuator (82AD) which opens the ballast tank deflator valve (82D). A signal is sent from the control consol (100) to the compressed gas (nitrogen) valve actuator (82AGI) which opens the ballast tank gas inflator valve (82GI). Compressed gas (nitrogen) flows from the compressed gas (nitrogen) tank (8) through the compressed gas inflator valve (82GI) through the ballast tank distribution line (83) to the ballast tank(s) (Ml). The compressed gas (nitrogen) displaces the water contents of the ballast tank(s) (Ml). The inflation of the ballast tanks (Ml ) by compressed gas (nitrogen) decreases the mass of the ballast tanks (Ml) which increases the buoyancy of the device and causes the device to rise in the water column.

[0079] Operation of the Ballast System - Inflation and Deflation with (sea) Water.

[0080] With reference to Figures 8, 9, 10, 11, 12, 13, 14, 15, 16 in one non-limiting embodiment, the ballast tank deflator valve actuator (82AD) is connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). A signal is sent from the control consol (100) to the ballast tank deflator valve actuator (82AD) which opens the ballast tank deflator valve (82D). A signal is sent from the control consol (100) to the (sea) water valve actuator (82AWI) which opens the ballast tank (sea) water inflator valve (82 WI). A signal is sent from the control consol (100) to turn on tine high pressure (sea) water pump (80). Electrical power from the onboard high pressure (sea) water pump batteries (81 ) activates the high pressure (sea) water pump (80) and pressurized (sea) water flows from the high pressure (sea) water pump (80) through the ballast tank distribution line (83) to the ballast tank(s) (Ml). The pressurized (sea) water displaces the compressed gas (nitrogen) contents of the ballast tank(s) (Ml) which exits the ballast tank(s) (Ml) via the ballast tank deflator valve (82D). The inflation of the ballast tanks (M 1 ) by (sea) water increases the mass of the ballast tanks (M I ) which decreases the buoyancy of the device and causes the device to sink in the water column.

[0081] Suspension Cables

[0082] With reference to Figure 2, in one non-limiting embodiment, the hoisting cables (31) are attached to the suspension anchors (32) in at least 2 to 4 positions. The suspension anchors (32) are connected to the suspension bracket (22). The hoisting cables (31 ) permit the attachment of the device to an umbilical winch system (120), guided submersible Remote Operated Vehicle (60) system or submarine vessel for carrying, positioning, deployment and control.

[0083] Forward Looking or Panning Cameras on the Top of the Compressed Gas Tank

[0084] With reference to figures 2, 3 and 7 in one non-limiting embodiment, the forward looking or panning camera(s) (33) is/are connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). The forward looking or panning cameras (33F) (33FP) can be installed on the top surface of the compressed air tank (8) or high pressure water pump (80) to allow a view of the approach and the final positioning and performance of the device. A signal is sent from the control consol (100) to the forward looking (33F) or panning cameras (33FP) to control the view. If a panning camera is used a 360 degree view can be obtained. If the forward looking or panning camera is mounted on a servo motor (33SM) an angular and 360 degree view can be obtained.

[0085] Forward Looking or Panning Camera Battery and lighting unit mounted on the Compressed Gas Tank.

[0086] With reference to figure 18 in one non-limiting embodiment a battery and camera mounting plate (33BP) is attached to the top of the compressed gas mounting bracket. The battery unit (33B) is mounted on top of the battery and camera mounting plate (33BP). The forward or panning camera and lighting system is mounted on the battery and camera mounting plate (33BP) or alternatively on the battery unit (33B).

[0087] Forward Looking or Panning Cameras on the Top of the Flow Tube Entrance.

[0088] With reference to figures 3, 7 and 8 in one non-limiting embodiment, the forward looking(33F) or panning camera(s) (33FP) is/are connected by a control cable (12) to an umbilical chord (13) which is connected to a control consol (100) in a command vessel (150). The forward looking or panning camera(s) (3 F, 33FP) can be installed on the top surface of the flow tube camera mount coupling (33CMC). The flow tube camera mount coupling (33 CMC) is a threaded coupling of diameter D 1 + which threads onto the (A) end of the flow tube. The control cable (12) runs from the forward looking or panning camera(s) (33F, 33FP) along the top surface of the flow tube (1 ) between the flow tube ( 1 ) and the inner circumference of the expandable polymer bladder (5) mat encircles the flow tube. (1) The forward looking or panning camera(s) (33F, 33FP) at the flow tube entrance allow a view of the approach and the final positioning and performance of the device. A signal is sent from the control consol (100) to the forward looking (33F) or panning cameras (33FP) servo motors (33 SM) to control the view and if a panning camera is used a 360 degree view can be obtained. If the forward looking or panning camera is mounted on a servo motor (33SM) an angular and 360 degree view can be obtained.

[0089] Contents of the Umbilical Chord

[0090] In one non-limiting embodiment, the control system connecting lines for the bladder inflation actuators (35 A), bladder deflation actuator (36A), bladder pressure transducer sensor (PT1), anchor ram piston valve actuator (37A), hydraulic ram deflation actuator (39A), ballast tank inflation actuators (82AGI, 82AWI), the ballast tank deflator valve actuator (82AD), ballast tank pressure sensor (PT2), flow tube fluid exit actuator (14A) and the panning cameras (33F) and (33FP) and 33SM) can be combined into an umbilical chord (13) which is connected to the control consol (100) in a command vessel (150) located in a submersible, submarine, or surface platform or ship.

[0091] Contents of the Supply Tube(s) [0092] The supply tube(s) may contain tubes which contain compressed gas, compressed nitrogen, freeze gas(es), methanol, (antifreeze liquids), dispersants.

[0093] Contents of the Hoisting Cables.

[0094] In one non-limiting embodiment the hoisting cables (31) are connected from the suspension anchors (32) to a Remotely Operated Vehicle ( OV) , Submarine, Platform or ship and are of sufficient length, flexibility and tensile strength to support the deployment, positioning and retrieval of the device in deep (sea) water conditions.

[0095] Fluid Deflection Cone

With reference to Figures 9 and 10 in one non-limiting embodiment, a fluid flow deflection cone (42) which has a threaded center coupling of diameter D 1 + can be threaded onto the (A) end of the flow control tube (1) until it butts up against the external mounting plate. (2). The largest diameter of the fluid flow deflection cone (42) would be D2 and would cover the bolts and the (A) side face of the external mounting plate (2). The fluid deflection cone serves to increase streamlines and reduce turbulence and drag of the fluid exiting the ruptured pipeline or well.

[0096] Spring Loaded Centering Guides

[0097] With reference to Figure 9 in one non-limiting embodiment, spring loaded centering guides (43) may be affixed to the (A) side of the fluid flow deflection cone (42). Without wishing to be limiting the spring loaded centering guides (43) may be added as even numbered pairs with a minimum of 1 or two pairs. The spring loaded centering guides (43) have a curve in the direction from (A) towards (B) with a closed loop curl at the (B) end. The centering guides can be attached to the fluid flow deflection cone (42) or mounted on a separate threaded spring loaded centering guide coupling (44) of diameter D1+. The centering guides in the un-compressed state will subtend a diameter of D3+. As the device approaches the open end of the ruptured pipeline or well, the spring loaded centering guides (43) will contact the outer walls of the ruptured pipe or well at the D3 diameter. The centering guides will push on the outer wall of the ruptured pipe or well and direct the flow tube ( 1 ) towards the center of the ruptured pipe or well. When the device has penetrated the ruptured pipe or well to a depth of (A) to (B) the flow tube will be essentially centered in the ruptured pipe or well. The spring loaded nature of the spring loaded centering guides (43) will cause the guides to bend and follow the inner contour of the ruptured pipe or well during the insertion of the device to the final depth at (A) to (C). If the device is to be extracted from the ruptured pipe or well the closed loop curl ends of the centering guides will follow the inner contours of the ruptured pipe or well during the extraction and limit entanglement with any obstruction or edges in the inner contour of the ruptured pipe or well.

[0098] Remotely Operated Vehicle (ROV) - Submersible Mounting Bracket

[0099] With reference to Figure 10 in one non-limiting embodiment an ROV-Submersible Mounting Bracket (61 ) can be attached to the suspension bracket (22) for the purposes of securing an ROV- Submersible propulsion unit. (60) The ROV-Submersible Mounting Bracket (61) may consist of a framework which supports the ROV- Submersible propulsion unit (60).

[00100] Remotely Operated Vehicle (ROV) - Submersible Propulsion Unit.

[00101] With reference to Figures 10, 14 and 15 in a further non-limiting embodiment an ROV-Submersible propulsion unit (60) including forward and reverse propulsion thrusters (62), rotating lateral propulsion thrusters (63), an ROV power supply/battery unit (64), an onboard computer, ROV sensory and data logging unit (65), an ROV forward and panning camera and lights system (66) and umbilical chord (13) can be attached to the ROV-Submersible Mounting Bracket (61). The ROV-Submersible propulsion unit (60) can be used to transport, manipulate and insert the expandable polymer bladder (5) into the ruptured pipeline or well for inflation of the expandable polymer bladder (5) and securing of the anchor ram contours (29) or anchor pins (31.5).

[00102] Remotely Operated Robotic Bracket

[00103] With reference to Figure 11 in one non-limiting embodiment a remotely operated robotic bracket (70) can be attached to the suspension bracket (22) for the purposes of securing remotely operated robotic articulator(s) (71) and remotely operated robotic arm(s) (72) to the bracket

[00104] Operation of Remotely Operated Robotic Articulators and Remotely Operated Robotic Arms

[00105] With reference to Figure 1 1 in one non-limiting embodiment the remotely operated robotic articulator(s) (71) allow for angular rotation of the device to facilitate positioning, insertion and extraction of the device into and from the ruptured pipeline or well. The remotely operated Robotic Arms (72) allow for forward, reverse, extension and retraction of the device to facilitate positioning, insertion and extraction of the device into and from the ruptured pipeline or well

[00106] Articulating Joint in the Flow Tube to Permit Minor Bends of the Flow Tube and Expandable Polymer Bladder.

[00107] With reference to Figures 18 and 19 in one non-limiting embodiment at least one or more articulating joints (40) are located in the flow tube between (B) and (C). The articulating joint (40) allows minor flexing in the flow tube to accommodate bending of the flow tube and the expandable polymer bladder (5). Bending of the flow tube (1) and the expandable polymer bladder may be required to accommodate bends in the damaged well or pipeline caused by rupture, explosion, impact, mechanical failure or by original construction design of the pipeline or well.

[00108] Dual Expandable Polymer Bladder System

[00109} With reference to Figures 20, 21 and 22 in one non-limiting embodiment the dual expandable polymer bladder line (91) is a line, at which at least one partition of the expandable polymer bladder (5) may be made. The center of the dual expandable polymer bladder line (91) would be through the center of the articulating joint(s). (40) Multiple expandable polymer bladders (5) would have the same configuration of additional dual bladder lines ( 1) through the center of each articulating joint(s) (40) to accommodate bends in the pipe. The purpose of dual or multiple expandable polymer bladders (5) is to permit articulation of the flow tube around bends or kinks in the damaged well or pipeline. With the expandable polymer bladders (5) in the deflated mode, the articulating joint(s) (40) would allow moderate bending of the flow tube (1) in order to allow maximum depth insertion of the flow tube (1) prior to inflation of the expandable polymer bladder(s) (5).

[00110] Inflation and Deflation of the Dual Expandable Polymer Bladder System

[00111} With reference to Figures 20, 21 and 22 in one non-limiting embodiment the dual expandable polymer bladder system would consist of the primary expandable polymer bladder (5) and at least one secondary expandable polymer bladder. (5S) The primary expandable polymer bladder would be inflated via compressed gas/(sea) water inlet ports (17). The secondary expandable polymer bladder (5S) would be filled via me secondary compressed gas/(sea) water inlet port(s) (17S). In one non-limiting embodiment, the secondary compressed gas/(sea) water inlet port ( 17S) would pass along the center annulus of the primer expandable polymer bladder (5) and connect to the secondary expandable polymer bladder (5S). In this embodiment the secondary gas inlet port (17S) would have to be a non-compressible tube so as not to collapse due to pressurization of the primary expandable bladder. (5) In another non-limiting embodiment the secondary compressed gas/(sea) water inlet port ( 17S) would pass through a bladder tube ( 17ST) in the body of the primary expandable polymer bladder (5) and connect to the secondary expandable polymer bladder (5S). In this embodiment the secondary compressed gas (sea) water inlet port ( 17S) and the bladder tube ( 17ST) and the would have to be non-compressible tubes so as not to collapse due to pressurization of the primary expandable bladder (5)

[00112] Multiple Bladder Concentric Header Tube and Single Header System

[00113] With reference to Figure 35 in one non-limiting embodiment the multiple expandable polymer bladder system would consist of a series of expandable polymer bladders (5) mounted on a multiple bladder concentric header tube (218). The multiple bladder concentric header tube (218) provides an annular space between the exterior of the flow tube (1) and the interior of the multiple bladder concentric header tube (218). The annular space provides space for mounting the multiple bladder header tube(s) (215). The multiple bladder header tube(s) (215) conducts the compressed gas/sea water pressure fluid to the bladder fluid injectors/valves (217) which pass via a connecting hole through the multiple bladder concentric header tube (218) and attach to the individual bladders. The bladder fluid injectors/valves (217) allow injection of the compressed gas/sea water pressure fluid to the bladders at the same time to expand the bladders in unison.

[00114] Multiple Bladder Concentric Header Tube and Multiple Header System

[00115] With reference to Figure 35 in one non-limiting embodiment the multiple expandable polymer bladder system would consist of a series of expandable polymer bladders (5) mounted on a multiple bladder concentric header tube (218). The multiple bladder concentric header tube (218) provides an annular space between the exterior of the flow tube (1) and the interior of the multiple bladder concentric header tube (218). The annular space provides space for mounting the multiple bladder header tubes (215). The multiple bladder header tubes (215) conduct the compressed gas/sea water pressure fluid to the individual or sets of bladder fluid injectors/valves

(217) which pass via a connecting hole through the multiple bladder concentric header tube (218) and attach to the individual bladders. The bladder fluid injectors/valves (217) allow injection of the compressed gas/sea water pressure fluid to the single or sets of bladders at the same time to expand the bladders.

[00116] Multiple Bladder Concentric Header Tube and Multiple Header System and Articulating Joints

[ 00117] With reference to Figure 35 in one non-limiting embodiment the multiple expandable polymer bladder system would consist of a series of expandable polymer bladders (5) mounted on a multiple bladder concentric header tube (218). The multiple bladder concentric header tube

(218) provides an annular space between the exterior of the flow tube (1) and the interior of the multiple bladder concentric header tube (218). The annular space provides space for mounting the multiple bladder header tubes (215). The multiple bladder header tubes (215) conduct the compressed gas/sea water pressure fluid to the individual or sets of bladder fluid injectors/valves (217) which pass via a connecting hole through the multiple bladder concentric header tube (218) and attach to the individual bladders. The bladder fluid injectors/valves (217) allow injection of the compressed gas/sea water pressure fluid to the single or sets of bladders at the same time to expand the bladders. Where articulating joints are included in the flow tube there must be the equivalently spaced multiple bladder concentric header tube flex joint(s) (216) in the multiple bladder header tube(s) (215) and in the multiple bladder concentric header tube (21) to allow flexing of the multiple bladder system.

[00118] External Compression Collar without Blowout Retention Ring

[00119] With reference to Figures 23, 24, 25 and 26 in one non-limiting embodiment the external compression collar without blowout retention ring (95) may be attached to the exterior of the damaged well or pipeline at the (C ) to (D) position of the fully inserted expandable polymer bladder (5). The external compression collar without blowout retention ring (95) consists of a metal or other suitable material ring of diameter D4 that forms a circular channel (99.4) around the outside of the damaged pipe. The circular channel (99.4) has a depth from D4 to D3+ where

D3+ is the outside diameter of the damaged well or pipe. The circular channel (99.4) has external compression pads (96) of metal with abrasive or pins welded or glued or otherwise attached on

D4- inner curvature. In another non-limiting embodiment the circular channel (99.4) has external compression pads of hard rubber or other synthetic material (96.1) with abrasive or pins (96) bolted or glued or otherwise attached on D4- inner curvature of the external compression collar without blowout retention ring. (95) The circular channel is cut into two equal sections. The gap between the two lower sections is joined by an external compression collar hinge.(97) This hinge allows the external compression collar without blowout retention ring (95) to be fully opened prior to attachment to the exterior of the damaged well or pipeline. The gap between the two upper sections is joined by an external compression collar securing lock. (99) The external compression collar securing lock (99) allows the external compression collar without blowout retention ring (95) to be closed around the exterior D3 - diameter of the damaged well or pipeline.

The external compression collar securing lock (99) is attached to the external compression collar without blowout retention ring (95) by external compression collar anchoring bolts (99.2) or by welding, gluing or other secure manner. The external compression collar without blowout retention ring (95) is secured to the exterior of the damaged well or pipe by insertion and rotation of the external compression collar securing bolt(s) (99.1 ) or some other securing mechanism. The external compression collar without blowout retention ring (95) attached in such a manner provides stability to the circumference of the damaged well or pipe and improved anchoring of the expandable polymer bladder (5) by providing external compressive forces which counteract the internal expansive forces applied by the escaping fluid, the expandable polymer bladder (5) and the horizontal and vertical D3 anchor contours.

[00120] External Compression Collar with Blowout Retention Ring

[001211 With reference to Figures 23, 24, 25 and 26 in one non-limiting embodiment the external compression collar with blowout retention ring (95.1) may be attached to the exterior of the damaged well or pipeline at the (C ) to (D) position of the fully inserted expandable polymer bladder (5). The external compression collar with blowout retention ring (95.1) consists of a metal or other suitable material ring of diameter D4 that forms a circular channel (99.4) around the outside of the damaged pipe. The circular channel (99.4) has a depth from D4 to D3+ where

D3+ is the outside diameter of the damaged well or pipe. The circular channel (99.4) has external compression pads of metal with abrasive or pins (96) welded or glued or otherwise attached on

D4- inner curvature. In another non-limiting embodiment the circular channel (99.4) has external compression pads of hard rubber or other synthetic material (96.1) with abrasive or pins (96) bolted or glued or otherwise attached on D4- inner curvature. The circular channel is cut into two equal sections. The gap between the two lower sections is joined by an external compression collar hinge. This hinge allows the external compression collar with blowout retention ring (95.1 ) to be fully opened prior to attachment to the exterior of the damaged well or pipeline. The gap between the two upper sections is joined by an external compression collar securing lock. (99)

The external compression collar securing lock (99) allows the external compression collar with blowout retention ring (95.1 ) to be closed around the exterior D3+ diameter of the damaged well or pipeline. The external compression collar securing lock (99) is attached to the external compression collar with blowout retention ring (95.1) by external compression collar anchoring bolts (99.2) or by welding, gluing or other secure manner. The external compression collar with blowout retention ring (95.1 ) is secured to the exterior of the damaged well or pipe by insertion and rotation of the external compression collar securing bolt(s) (99.1) or some other securing mechanism. The external compression collar with blowout retention ring (95.1) attached in such a manner provides stability to the circumference of the damaged well or pipe and improved anchoring of the expandable polymer bladder (5) by providing external compressive forces which counteract the internal expansive forces applied by the escaping fluid, the expandable polymer bladder (5) and the horizontal and vertical D3 anchor contours. The external compression collar blowout retention ring (99.3) consists of a deeper channel on the (D) side of the External Compression Collar with Blowout Retention Ring (95.1) The external compression collar blowout retention ring (99.3) has an internal diameter of (D5) which provides an internal anchoring plate by extending the ring to the inside of the damaged well or pipeline. The external compression collar with blowout retention ring (95.1) provides additional protection against blowout of the expandable polymer bladder (5) by creating an inner lip against which the horizontal and vertical anchor ram(s) D3 contour will catch should internal pressures cause the expandable polymer bladder (5) and the vertical anchor ram(s) D3 contour to begin to lose grip and be pushed out of the pipe or well.

[00122] Antifreeze (Methanol) Injection system with Storage Tank

[00123] With reference to Figures 27, 28, and 29 in one non-limiting embodiment an antifreeze injection system can be attached to the top side or underside of the device. Figures 27 and 29 provide an underside view and an end (G) view of the device and the antifreeze injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. The purpose of the antifreeze injection system is to maintain fluid flow by preventing freeze up of the entrained water in the escaping mixture of liquid and gaseous hydrocarbons. When the fluid escapes the well, the ambient pressure is reduced allowing gases to flash and increase in volume. This expansion causes an endothermic reaction reducing temperature which may result in freezing and formation of ice crystals in the entrained water. The ice crystals can conglomerate and clog the flow tube ( I ) and fluid extraction system. Introduction of an antifreeze such as methanol can reduce or eliminate the formation of ice crystals. The antifreeze injection system has an antifreeze (methanol) supply line connector (130) to allow connection to an antifreeze supply line (132). The antifreeze (methanol) supply valve actuator

(131 A) controls the antifreeze (methanol) supply valve (131) to increase or decrease the supply of antifreeze (methanol) via the antifreeze supply line (132) to the antifreeze (methanol) supply tank

(133) which is located on the underside/topside of the device. The antifreeze (methanol) supply tank (133) provides on board storage for the antifreeze (methanol). The antifreeze (methanol) supply tank (133) discharges to the antifreeze (methanol) injection line (135). The antifreeze (methanol) injection valve actuator (134A) controls the antifreeze (methanol) injection valve

(134) which allows regulated flow of antifreeze (methanol) into the flow tube (1)

[00124] Antifreeze (Methanol) Injection system without Storage Tank

[00125] With reference to Figures 21, 28, 29, 30, and 31 in one non-limiting embodiment an antifreeze injection system can be attached to the top side or underside of the device. Figures 27, 29 and 30 provide an underside view and an end (G) view of the device and the antifreeze injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. The purpose of the antifreeze injection system is to maintain fluid flow by preventing freeze up of the entrained water in the escaping mixture of liquid and gaseous hydrocarbons. When the fluid escapes the well, the ambient pressure is reduced allowing gases to flash and increase in volume. This expansion causes an endothermic reaction reducing temperature which may result in freezing and formation of ice crystals in the entrained water. The ice crystals can conglomerate and clog the flow tube (1) and fluid extraction system. Introduction of an antifreeze such as methanol can reduce or eliminate the formation of ice crystals. The antifreeze injection system has an antifreeze (methanol) supply line connector (130) to allow connection to an antifreeze supply line (132). The antifreeze (methanol) supply valve actuator ( 131 A) control s the antifreeze (methanol) supply valve ( 131 ) to increase or decrease the supply of antifreeze (methanol) via the antifreeze supply line (132) to the antifreeze (methanol) supply line (133L) which is located on the underside/topside of the device. The antifreeze (methanol) supply line (133L) provides direct connection to the antifreeze (methanol) injection line (135). The antifreeze (methanol) injection valve actuator ( 134A) controls the antifreeze (methanol) injection valve (134) which allows regulated flow of antifreeze (methanol) into the flow tube. (1)

[0 126] Freeze Gas (Nitrogen) Injection System with Storage Tank [00127] With reference to Figures 27, 28 and 29 in one non-limiting embodiment a freeze gas (nitrogen) injection system can be attached to the top side or underside of the device. Figures 27 and 29 provide an underside view and end (G) view of the device and the freeze gas injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. The purpose of the freeze injection system is to constrict or shut down fluid flow in the flow tube ( 1 ) by initiating freeze up of the entrained water in the escaping mixture of liquid and gaseous hydrocarbons. Should the valve to control oil and gas exit flow (14) partially or completely fail to control fluid flow from the flow tube (1) the freeze gas (nitrogen) system can be used to control the flow. The freeze gas (nitrogen) is injected into the freeze gas (nitrogen) injection system which discharges into the freeze gas (nitrogen) tracer coils (145). The expansion of the freeze gas (nitrogen) within the freeze gas (nitrogen) tracer coils (145) causes an endothermic reaction reducing temperature and resulting in freezing and formation of ice crystals along the internal surface of the flow tube. (1) Ice will continue to build up within the flow tube, constricting the flow diameter which increases up gradient hydraulic pressure but reduces flow from the flow tube. The ice crystals can conglomerate and clog the flow tube (1) and fluid extraction system thereby completely constricting flow of the fluid escaping the flow tube. The freeze gas (nitrogen) injection system has a freeze gas (nitrogen) supply line connector ( 140) to allow connection to a freeze gas (nitrogen) supply line. (142) The freeze gas (nitrogen) supply valve actuator ( 141 A) controls the freeze gas (nitrogen) supply valve (141) to increase or decrease supply of freeze gas (nitrogen) via the freeze gas (nitrogen) supply line (142) to the freeze gas (nitrogen) supply tank (143) which is located on the underside of the device. The freeze gas (nitrogen) supply tank (143) provides on board storage for the freeze gas (nitrogen). The freeze gas (nitrogen) supply tank (143) discharges to the freeze gas (nitrogen) injection line (145). The freeze gas (nitrogen) injection valve actuator (144A) controls the freeze gas (nitrogen) injection valve (144) which allows regulated flow of freeze gas (nitrogen) into the freeze gas (nitrogen) tracer coils (146). The freeze gas (nitrogen) tracer coils encircle the exterior wall of the flow tube. ( 1 ) Expansion of the freeze gas (nitrogen) in the freeze gas (nitrogen) tracer coils is endothermic thereby inducing freezing to the exterior walls of the flow tube. The freeze gas (nitrogen) tracer coils protection tube (147) is a concentric tube that provides exterior protection to the freeze gas (nitrogen) tracer coils (146). The freeze gas (nitrogen) tracer coils (146) terminate at the (E) position of the flow tube and exit to the freeze gas (nitrogen) exhaust line. (148) The freeze gas (nitrogen) exhaust line allows the expanding nitrogen to escape into the water column.

[00128] Freeze Gas (Nitrogen) Injection System without Storage Tank

With reference to Figures 27, 28, 29, 30 and 31 in one non-limiting embodiment a freeze gas

(nitrogen) injection system can be attached to the top side or underside of the device. Figures 27,

29 and 30 provide an underside view and end (G) view of the device and the freeze gas injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. The purpose of the freeze injection system is to constrict or shut down fluid flow in the flow tube (1) by initiating freeze up of the entrained water in the escaping mixture of liquid and gaseous hydrocarbons. Should the valve to control oil and gas exit flow

(14) partially or completely fail to control fluid flow from the flow tube (1) the freeze gas

(nitrogen) system can be used to control the flow. The freeze gas (nitrogen) is injected into the freeze gas (nitrogen) injection system which discharges into the freeze gas (nitrogen) tracer coils

(145). The expansion of the freeze gas (nitrogen) within the freeze gas (nitrogen) tracer coils

(145) causes an endothermic reaction reducing temperature and resulting in freezing and formation of ice crystals along the internal surface of the flow tube. ( 1 ) Ice will continue to build up within the flow tube, constricting the flow diameter which increases up gradient hydraulic pressure but reduces flow from the flow tube. The ice crystals can conglomerate and clog the flow tube (1) and fluid extraction system thereby completely constricting flow of the fluid escaping the flow tube. The freeze gas (nitrogen) injection system has a freeze gas (nitrogen) supply line connector (140) to allow connection to a freeze gas (nitrogen) supply line. (142) The freeze gas (nitrogen) supply valve actuator ( 141 A) controls the freeze gas (nitrogen) supply valve

(141 ) to increase or decrease supply of freeze gas (nitrogen) via the freeze gas (nitrogen) supply line (142) to the freeze gas (nitrogen) supply line ( 143L) which is located on the underside of the device. The freeze gas (nitrogen) supply line (143L) provides direct discharge to the freeze gas

(nitrogen) injection line (145). The freeze gas (nitrogen) injection valve actuator (144A) controls the freeze gas (nitrogen) injection valve (144) which allows regulated flow of freeze gas

(nitrogen) into the freeze gas (nitrogen) tracer coils (146). The freeze gas (nitrogen) tracer coils encircle the exterior wall of the flow tube. (1 ) Expansion of the freeze gas (nitrogen) in the freeze gas (nitrogen) tracer coils is endothermic thereby inducing freezing to the exterior walls of the flow tube. The freeze gas (nitrogen) tracer coils protection tube (147) is a concentric tube that provides exterior protection to the freeze gas (nitrogen) tracer coils (146). The freeze gas (nitrogen) tracer coils (146) terminate at the (E) position of the flow tube and exit to the freeze gas (nitrogen) exhaust line. (148) The freeze gas (nitrogen) exhaust line allows the expanding nitrogen to escape into the water column.

[00129] Dispersant Injection System with Storage Tank.

[001301 With reference to Figures 27, 28, 29 in one non-limiting embodiment a dispersant injection system can be attached to the top side or underside of the device. Figures 28 and 29 provide a top side view and end (G) view of the device and the dispersant injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. Oil and gas mixtures can exit, the damaged well or pipeline and due to lower densities, float to the surface where they can cause extensive environmental and physical and chemical damage by coating surfaces including the bodies of fish and wildlife, flora and fauna, beaches and anthropogenic structures. During the period when the device is initially inserted into the damaged well or pipeline the mixture of liquid and gaseous hydrocarbons will flow on the outside past the contracted expanded polymer bladder (5) and through the open flow tube (1 ) exit valve (14). The escape of the mixture of liquid and gaseous hydrocarbons will also occur if the expandable polymer bladder contracts due to induced or accidental loss of internal pressure. The escape of the mixture of liquid and gaseous hydrocarbons will also occur if the actuator (14A) on the valve to control the exit flow (14) from the flow tube (1) is accidentally or purposely induced into the open position. The purpose of the dispersant injection system is to facilitate the injection of chemical dispersant into the escaping mixture of liquid and gaseous hydrocarbons. The turbulence of the escaping mixture of liquid and gaseous hydrocarbons will mix the escaping mixture of liquid and gaseous hydrocarbons with the dispersant, causing the liquid and gaseous hydrocarbons to dissolve into the water column. This will allow broader dispersion of the liquid and gaseous hydrocarbons, facilitate weathering and bio-degradation and significantly reduce the risk of extensive environmental and physical and chemical damage from coating surfaces including the bodies of fish and wildlife, flora and fauna, beaches and anthropogenic structures. The dispersant injection system has a dispersant supply line connector (160) to allow connection to the dispersant supply line (162). The dispersant supply valve actuator ( 161 A) controls the dispersant supply val ve ( 161 ) to increase or decrease the supply of dispersant via the dispersant supply line ( 162) to the dispersant supply tank (1 3) which is located on the top side/underside of the device. The dispersant supply tank ( 163) provides on board storage for the dispersant. The dispersant supply tank (163) discharges to the dispersant injection line (165) to the flow tube ( 1 ). The dispersant injection valve actuator ( 164 A) controls the dispersant injection valve (164) which allows regulated flow of dispersant into the flow tube. (1) The dispersant injection valve actuator (166 A) controls the dispersant injection valve (166) which allows regulated flow of dispersant into the annulus injection line ( 167) which discharges dispersant into the annulus flow as long as the bladder is not inflated. (1)

[00131 ] Dispersant Injection System without Storage Tank.

[00132] With reference to Figures 27, 28, 29, 30 and 31 in one non-limiting embodiment a dispersant injection system can be attached to the top side or underside of the device. Figures 28,

29 and 31 provide a top side view and end (G) view of the device and the dispersant injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. Oil and gas mixtures can exit the damaged well or pipeline and due to lower densities, float to the surface where they can cause extensive environmental and physical and chemical damage by coating surfaces including the bodies of fish and wildlife, flora and fauna, beaches and anthropogenic structures. During the period when the device is initially inserted into the damaged well or pipeline the mixture of liquid and gaseous hydrocarbons will flow past the outside of the contracted expanded polymer bladder (5) and through the open flow tube (1) exit valve (14). The escape of the mixture of liquid and gaseous hydrocarbons will also occur if the expandable polymer bladder contracts due to induced or accidental loss of internal pressure. The escape of the mixture of liquid and gaseous hydrocarbons will also occur if the actuator (14A) on the valve to control the exit flow (14) from the flowtube (1) is accidentally or purposely induced into the open position. The purpose of the dispersant injection system is to facilitate the injection of chemical dispersant into the escaping mixture of liquid and gaseous hydrocarbons. The turbulence of the escaping mixture of liquid and gaseous hydrocarbons will mix the escaping mixture of liquid and gaseous hydrocarbons with the dispersant, causing the liquid and gaseous hydrocarbons to dissolve into the water column. This will allow broader dispersion of the liquid and gaseous hydrocarbons, facilitate weathering and bio-degradation and significantly reduce the risk of extensive environmental and physical and chemical damage by- coating surfaces including the bodies of fish and wildlife, flora and fauna, beaches and anthropogenic structures. The dispersant injection system has a dispersant supply line connector (160) to allow connection to the dispersant supply line (162). The dispersant supply valve actuator (161 A) controls the dispersant supply valve ( 161 ) to increase or decrease the supply of dispersant via the dispersant supply line (162) to the dispersant supply line (163L) which is located on the top side/underside of the device. The dispersant supply line ( 163L) provides direct discharge to the dispersant injection line (165). The dispersant injection valve actuator (164A) controls the dispersant injection valve ( 164) which allows regulated flow of dispersant into the flow tube. ( 1 )

[00133] Compressed Gas System with Storage Tank

[00134] With reference to Figures 27, 28, 29 in one non-limiting embodiment a compressed gas system can be attached to the top side or underside of the device. Figures 28 and 29 provide a top side view and end (G) view of the device and the compressed gas system. The compressed gas system can be used to inflate the expanded polymer bladder (5), drive the hydraulic anchor ram cylinder (27) and anchors rams (28), and drive any actuated valves that require additional power to open and close. The compressed gas system consists of a compressed gas supply line connector (170), compressed gas supply valve actuator (171 A), compressed gas supply valve (171), compressed gas supply line (172), compressed gas supply tank (173), compressed gas injection valve actuator (174A), compressed gas injection valve (174A), compressed gas injection line. (175)

[00135] Compressed Gas System without Storage Tank

100136] With reference to Figures 27, 28, 29 and 31 in one non-limiting embodiment a compressed gas system can be attached to the top side or underside of the device. Figures 28, 29 and 31 provide a top side view and end (G) view of the device and the compressed gas system. The compressed gas system can be used to inflate the expanded polymer bladder (5), drive the hydraulic anchor ram cylinder (27) and anchors rams (28), and drive any actuated valves that require additional power to open and close. The compressed gas system consists of a compressed gas supply line connector (170), compressed gas supply valve actuator (171 A), compressed gas supply valve (171), compressed gas supply line (172), compressed gas supply line (173L), compressed gas injection valve actuator (174A), compressed gas injection valve (174A), compressed gas injection line. (175).

[00137] Heated Water Injection System with Storage Tank

[00138] With reference to Figures 32, 33 and 34 in one non-limiting embodiment a heated water injection system can be attached to the top side or underside of the device. Figures 32 and

33 provide atop side or underside view and Figure 24 provides an end (G) view of the device and the heated water injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. The purpose of the heated water injection system is to maintain fluid flow in the flow tube (1) by initiating warming of the entrained water in the escaping mixture of liquid and gaseous hydrocarbons. Should the flow tube(l ) or valve to control oil and gas exit flow (1 ) partially or completely fail to control fluid flow from the flow tube (1) due to freezing of entrained water the heated water system can be used to control the flow. The heated water is injected into the heated water injection system which discharges into the heated water tracer coils (185). The heating of the heated water tracer coils (185) causes an exothermic heat transfer increasing the temperature of the flow tube (1) preventing the freezing and formation of ice crystals along the internal surface of the flow tube. (1) This prevents the ice crystals from conglomerating and prevents clogging of the flow tube (1) and fluid extraction system thereby maintaining flow of the fluid escaping the flow tube. The heated water injection system has a heated water supply line connector (180) to allow connection to a heated water supply line. (182) The heated water supply valve actuator (181A) controls the heated water supply valve ( 181 ) to increase or decrease supply of heated water via the heated water supply line

(182) to the heated water supply tank (183) which is located on the underside/topside of the device. The heated water supply tank (183) provides on board storage for the heated water. The heated water supply tank (183) discharges to the heated water injection line (185). The heated water injection valve actuator (184A) controls the heated water injection valve (184) which allows regulated flow of heated water into the heated water tracer coils (186). The heated water tracer coils encircle the exterior wall of the flow tube. ( 1 ) Heat transfer in the heated water tracer coils is exothermic thereby inducing heating to the exterior walls of the flow tube. The heated water tracer coils protection tube ( 187) is a concentric tube that provides exterior protection to the heated water tracer coils (186). The heated water tracer coils ( 186) terminate at the (E) position of the flow tube and exit to the heated water exhaust line. (188) The heated water exhaust line allows the expanding nitrogen to escape into the water column.

[00139] Heated Water Injection System without Storage Tank

With reference to Figures 32, 33 and 34 in one non-limiting embodiment a heated water injection system can be attached to the top side or underside of the device. Figures 32 and 33 provide an underside/topside view and Figure 34 provides an end (G) view of the device and the heated water injection system. The fluid escaping from a ruptured pipeline or well is usually a mixture of liquid and gaseous hydrocarbons and water. The purpose of the heated water injection system is to maintain fluid flow in the flow tube (1) by initiating warming of the entrained water in the escaping mixture of liquid and gaseous hydrocarbons. Should the valve to control oil and gas exit flow ( 14) partially or completely fail to control fluid flow from the flow tube ( 1 ) due to freezing, the heated water system can be used to control the flow. The heated water is injected into the heated water injection system which discharges into the heated water tracer coils (185). The heating of the heated water tracer coils (185) causes an exothermic heat transfer increasing the temperature of the flow tube (1) preventing the freezing and formation of ice crystals along the internal surface of the flow tube. (1) This prevents the ice crystals from conglomerating and prevents clogging of the flow tube ( 1 ) and fluid extraction system thereby maintaining flow of the fluid escaping the flow tube. The heated water injection system has a heated water supply line connector (180) to allow connection to a heated water supply line. (182) The heated water supply valve actuator ( 181 A) controls the heated water supply valve ( 181 ) to increase or decrease supply of heated water via the heated water supply line (182) to the heated water supply line (183L) which is located on the underside/topside of the device. The heated water supply line (183L) provides direct discharge to the heated water injection line (185). The heated water injection valve actuator (184 A) controls the heated water injection valve (184) which allows regulated flow of heated water into the heated water coils (186). The heated water tracer coils encircle the exterior wall of the flow tube. (1) Injection of the heated water in the heated water tracer coils is exothermic thereby inducing heating to the exterior walls of the flow tube. The heated water tracer coils protection tube (187) is a concentric tube that provides exterior protection to the heated water tracer coils (186). The heated water tracer coils (186) terminate at the (E) position of the flow tube and exit to the heated water exhaust line. (188) The heated water exhaust line allows the heated water to escape into the water column.

[00140] Flow Meter with Magnetic Propeller, Differential Pressure, Conductive Injection or other flow sensing mechanism

[00141] With reference to Figure 22 in one non-limiting embodiment a flow meter (200) with magnetic propeller (201), differential pressure (202), conductive mjection (203) pitot tube (204), manometer (205) or other flow sensing mechanism (206) may be installed at the (E) position of the flow tube. At this position the maximum length of flow to reduce turbulence and induce laminar flow can be achieved prior to encountering turbulence from the flow control valve (14). The flow meter can be connected to the computer controls and sensory data logger (81 ) to provide estimates of flow rate in the flow rube.

[00142] Flow Tube Pressure Sensor (210) which senses pressure within the Flow Tube

[00143] With reference to Figure 22 in one non-limiting embodiment a flow tube Pressure Sensor (210) which senses pressure within the Flow Tube (1) and transmits the information regarding pressure via the umbilical chord (13) to the control consol (100)

[00144] Conductivity sensor (211), which senses conductivity within the Flow Tube

[00145] With reference to Figure 22 in one non-limiting embodiment a conductivity sensor (211), which senses conductivity within the Flow Tube and transmits the information regarding pressure via the umbilical chord (13) to the control consol (100) [00146] Temperature sensor (212) which senses Temperature within the Flow Tube

[00147] With reference to Figure 22 in one non-limiting embodiment a temperature sensor (212) which senses temperature within the Flow Tube and transmits the information regarding pressure via the umbilical chord (13) to the control consol (100)

[00148] Other sensors (213) which sense parameters in the flow tube,

[00149] With reference to Figure 22 in one non-limiting embodiment other sensors (213) which senses conductivity within the Flow Tube and transmits the information regarding pressure via the umbilical chord (13) to the control consol (100)

[00150] Bleed Header System

[00151 ] With reference to Figure 36 in one non-limiting embodiment a bleed header system ( 220 ) with bleed header couplings ( 221) and bleed header valves (222) can be connected to the coupling at the (G) end of the flow tube ( 1 ) to allow one or more streams of fluid to be bled from the flow tube (5) This allows the diversion of flow to two or more containment systems.

[00152] Single or Multiple Compressed Solid Polymer Sealing System

[00153] With reference to Figure 37 in one non-limiting embodiment a single or a series of fixed concentric plate(s) (230) is/are attached to the exterior of the flow tube (1). These fixed concentric plate(s) (230) form an annulus (229) between the outer diameter of the fixed concentric plates(s) (230) and the inner wall of the damaged pipe. A series of rotating threaded or sliding hydraulic shafts (231 ) are attached in equidistant spacing around the circumference of the fixed concentric plate(s) (230) by passing through holes in the fixed concentric plate(s) (230). Reversible direction electric rotational or sliding hydraulic drives (232)are attached at the (C ) end to turn the (C ) end of the rotating threaded or pull the sliding hydraulic shafts. (231) Compressible polymer seal rings (233) are slid into position against the fixed concentric plates. (230) Movable concentric compression plates (234) with holes to accept the series of rotating threaded or sliding hydraulic shafts (23 ) are positioned against the compressible polymer seal rings (233). Threaded compression nuts (235) are threaded against the movable concentric compression plates. (234) In one non-limiting embodiment, where a reversible electric drive

(232) is used the drive turns the rotating threaded shaft (231) in a counter clockwise direction when viewed from the (A) end which causes the threaded compression nuts (235) to compress against the movable concentric compression plates. (234) The movable compression plates (234) compress against the compressible polymer seal rings (233). The compressible polymer seal rings

(233) compress laterally and expand concentrically outward until they engage the internal circumference of the flow tube (1 ) and the interior wall of the (indented) damaged pipe (245) and seal the external annulus. (229) In one non-limiting embodiment, where a reversible hydraulic drive (232) is used the hydraulic shaft (231) is drawn in the direction from (C ) to (D) which causes the threaded compression nuts (235) to compress against the movable concentric compression plates. (234) The movable compression plates (234) compress against the compressible polymer seal rings (233). The compressible polymer seal rings (233) compress laterally in the (C ) to (D) direction and expand concentrically outward until they engage the internal circumference of the flow rube (1) and seal the external annulus (229) . Upon sealing the external annulus, the pressure in the (indented) damaged pipe (245) will increase and the flow in the flow tube (1) will increase proportionately.

[00154] Movable Blade Sealing System

[00155] With reference to Figures 38, 40, 41 and 42 in one non-limiting embodiment one or more fixed concentric plates (230) are attached to the outer wall of the flow tube. (1) An even numbered ( 4 to 8) series of rotating threaded or hydraulic shafts (242) are attached in equidistant spacing to the fixed concentric plate(s) (230) by passing through holes in the fixed concentric plate(s) (230). Reversible direction rotating electric or hydraulic drives (232) are attached to the

(C ) end of the rotating threaded or sliding hydraulic shafts. (242) One or more series of moveable compression blades (240) are attached to each rotating threaded or hydraulic shafts

(232) on the (A) side of each of the fixed concentric plate(s) (230). Each movable compression blade (240) has a blade shaft bearing (243) and a blade shaft bearing spring (244) and a compressed polymer seal (241). The blade shaft bearing spring (244) fits around the blade shaft bearing (243) The blade shaft bearing (243) is seated in a hole in the (H) end of the movable compression blade (240). The blade shaft bearing (243) is attached to the rotating threaded or hydraulic shafts (242) The compressed polymer seal (241 ) is secured into a channel that runs on the outer circumference of the compression blade (240). Each moveable compression blade (240) is shaped on the (H) end so as to be rounded with a diameter that is slightly larger than the external circumference of the fixed concentric plate(s) (230). Each moveable compression blade

(240) is shaped on the outer circumference from (H) to (J) end with a curvature equal to the internal radius of the damaged pipe. Each moveable compression blade (240) is shaped with a narrow point on the (J) end which gradually broadens on the inner circumference until it reaches the (H) end where it rapidly broadens to accommodate the rotating threaded or hydraulic shaft(s) (242), the compression blade shaft bearing (243) and blade shaft bearing spring. (244) The compression blade (240) is or may be secured in position by a threaded compression nut(s) (235). When the compression blades (240) are positioned against the outer circumference of the flow tube (1) the blades are said to be in the outer annulus (229) open position. When the annulus (229) between the outer surface of the flow tube and the inner surface of the damaged tube is open, escaping oil/gas mixture can flow through the outer annulus (229) and through the flow tube (1). When the reversible direction electric or hydraulic drives (232) are actuated and rotate the threaded or sliding hydraulic shaft (242) in the clock wise direction when viewed from the (A) end, the moveable compression blade(s) (240) rotate outward till the compressed polymer seal

(241 ) contacts the inner circumference of the damaged pipe and forms a seal against it called the annulus (229) closed position. When the annulus (229) between the outer surface of the flowtube and the inner surface of the damaged tube is in the outer annulus (229) closed position, escaping oil/gas mixture can flow only through the flow tube (1). Hydraulic pressure of escaping fluids create a force against the moveable compression blades (240) which is counterbalanced by the fixed concentric plate(s). (230) Depending on the configuration of the connections to the reversible electric or hydraulic drives (232), one or more moveable compression blade(s) (240) can rotate outward (clock wise looking from the (A) to (G) direction) to the closed annulus (229) position. In the example where there are eight blades, numbered 1, 2, 3.. 4, 5, 6, 7, and 8 in step one, four of the moveable compression blade(s) (240) numbered 1, 3, 5, 7 can be moved to the outer annulus (229) closed position at one time which will partially restrict fluid flow through the outer annulus (229) and increase pressure against the moveable compression blade(s) (240). This will decrease flow through the outer annulus (229) and increase flow through the flow tube (1) When pressure and flow at the (A) end of the flow tube (1) stabilizes and additional pressure can be tolerated, in step two, four of the moveable compression blade(s) (240) numbered 2, 4, 6, 8 can be moved to the outer annulus (229) closed position. This will increase pressure against the moveable compression blade(s) (240) and decrease flow through the outer annulus (229) and increase flow through the flow tube. (1) Flow through the outer annulus (229) after combined steps one and step two may be near zero depending on the seal of the compression blade(s) (240) against the inner circumference of the damaged pipe. (245) In the situation where there is an indentation in the damaged pipe (245) the moveable compression blade(s) may not fully extend into the outer annulus(229) closed position. In this case the blade shaft bearing spring (244) will allow the impacted moveable compression blade(s) (240) to stop as soon as they contact the indentation in the damaged pipe (245). This will allow the reversible direction electric or hydraulic drives (232) which are actuated to continue to rotate the threaded or hydraulic shaft (242) in the clock wise direction (viewed from the (A) end) and the remaining moveable compression blade(s) (240) will rotate outward till the compressed polymer seal (241) contacts the inner circumference of the damaged pipe and forms a seal against it called the outer annulus (229) closed position

[00156] Movable Blade Sealing System with single or multiple Expandable Polymer Bladders.

[00157] With reference to Figures 39, 40, 41 and 42 in one non-limiting embodiment the

Movable Blade Sealing System with single or multiple Expandable Polymer Bladders is the same configuration and operation as the Movable Blade Sealing System with the following additional features. A concentric bladder pressurization line cylinder (251) may or may not be mounted on the external surface of the flow tube. In one non-limiting embodiment, a concentric bladder pressurization line cylinder (251) of a large enough diameter is mounted on the outside of the flow tube (1) and has sufficient internal diameter to create an inner annulus (252) of sufficient size to allow the passage of bladder inflation lines (253). At least one or more expandable polymer bladder(s) (5) is mounted between each series of fixed concentric plates (230) and moveable compression blades. (240) The expandable polymer bladders) (5) are connected to the bladder pressurization line (250) by the bladder pressurization connector (254) which passes through the wall of the concentric bladder pressurization line cylinder (251). Depending on the configuration of the connections to the reversible electric or hydraulic drives (232), one or more moveable compression blade(s) (240) can rotate outward (clock wise looking from the (A) to (G) direction) to the closed outer annulus (229) position. In the example where there are eight blades, numbered 1, 2, 3, 4, 5, 6, 7, and 8 in step one, four of the moveable compression blade(s) (240) numbered 1, 3, 5, 7 can be moved to the outer annulus (229) closed position at one time which will partially restrict fluid flow through the outer annulus(229) and increase pressure against the moveable compression blade(s) (240). This will decrease flow through the outer annulus (229) and increase flow through the flow tube (1 ) When pressure and flow at the (A) end of the flow tube (1) stabilizes and additional pressure can be tolerated, in step two, four of the moveable compression blade(s) (240) numbered 2.4, 6, 8 can be moved to the outer annulus (229) closed position. This will increase pressure against the moveable compression blade(s) (240) and decrease flow through the outer annulus (229) and increase flow through the flow tube. ( 1 ) Flow through the outer annulus (229) after combined steps one and step two may be near zero depending on the seal of the compression blade(s) (240) against the inner circumference of the damaged pipe. (245) In the situation where there is an indentation in the damaged pipe (245) the moveable compression blade(s) may not fully extend into the annulus(229) closed position. In this case the blade shaft bearing spring (244) will allow the impacted moveable compression blade(s) (240) to stop as soon as they contact the indentation in the damaged pipe (245). This will allow the reversible direction electric or hydraulic drives (232) which are actuated to continue to rotate the threaded or sliding hydraulic shaft (242) in the clock wise direction (viewed from the (A) end) and the remaining moveable compression blade(s) (240) will rotate outward till the compressed polymer seal (241) contacts the inner circumference of the (dented) damaged pipe (245) and forms a seal against it called the outer annulus (229) closed position. When the pressure is stabilized, one or more of the expandable polymer bladders) may be pressurized which causes the bladder to expand outward till it contacts the wall of the (dented) damage pipe (245) As the bladder expands it creates a seal against the outer circumference of the concentric bladder pressurization line cylinder (251) and the inner wall of the (dented) damaged pipe (245). In one non-limiting embodiment, where a concentric bladder pressurization line cylinder (251) is not used, as the bladder expands it creates a seal against the outer circumference of the flow tube (1), the bladder pressurization lines (250) and the inner wall of the damaged pipe (245)

[00158] External Sliding Sleeve Sealing System with single piston collar.

[00159] With reference to Figures 43, 44 and 46 in one non-limiting embodiment the external sliding sleeve sealing system consists of a flow tube (1) that provides an unobstructed internal orifice to maintain flow through the pipe. At the up stream end of the flow tube (1) a polymer sealing sleeve (262) is attached to the external surface. The upstream end of the polymer sealing sleeve (262) is tapered so as to allow it to be secured to the flow tube (1) by the polymer sealing sleeve anchor (262A). The polymer sealing sleeve anchor (262A) attaches the polymer sealing sleeve (262) and the polymer compression sheath (262B) to the exterior of the upstream end of the flow tube (1). The polymer compression sheath (262B) is a bladed metallic or other suitable material sheath that lies between the external polymer sealing sleeve (262) and the external tapered pressure sleeve pipe.(261) The external tapered pressure sleeve pipe (261) is mounted with the tapered end fitting underneath the bladed polymer compression sheath (262B). The external tapered pressure sleeve pipe (261 A) may have variable configurations in the taper including but not limited to single or multiple slopes and plateau and ridge or hollow areas. The polymer sealing sleeve (262) has an equal but opposite taper to the tapered pressure sleeve pipe (261). As the external tapered pressure sleeve pipe (261) moves from the downstream to the upstream position, the taper is forced against the bladed polymer compression sheath (262B) which in turn is forced against the polymer sealing sleeve (262). This causes the bladed polymer compression sheath (262B) to expand its blades and forces the polymer sealing sleeve (262) to rise up the slope of the external tapered pressure sleeve pipe (261) and contact the internal surface of the external damaged pipe (259). As the external tapered pressure sleeve pipe (261 ) continues to move in the upstream direction it compresses the polymer sealing sleeve (262) so as to close the annulus between the flow tube (1) and the external damaged pipe (259) and directs all subsequent flow through the internal annulus of the flow tube (1 ). The external tapered pressure sleeve pipe (261) is connected to an external pressure sleeve piston(s) (265) which in turn are anchored in the external piston collar (266) at their down stream ends. The external pressure sleeve pistons (265) are connected to the external pressure header (267) which is connected to the external hydraulic pump. (268) Upon activation, the external hydraulic pump (268) pressurizes the external pressure header (267) which in turn pressurizes the external pressure sleeve pistons (265) which push the external tapered pressure sleeve pipe (261) in the upstream direction. To provide additional grip to the internal surface of the external damaged pipe (259) there are (or may be) external grip pads (263) between the external tapered pressure sleeve pipe (261) and the external piston collar. (266) The external grip pad (263) is connected to down stream end of the external tapered pressure sleeve pipe (261 ) and the upstream end of the external grip pistons (264) by rotatable elbow connector(s) (263A) The rotatable elbow connectors (263A) are connected near the top of the external grip pads (263) so as to be slightly off centered. The external grip piston (264) is anchored into the external piston collar (266). The external grip pistons (264) are connected to the external pressure header (267) which is connected to the external hydraulic pump. (268) Upon activation, the external hydraulic pump (268) pressurizes the external pressure header (267) which in turn pressurizes the external grip pistons (264) which push upstream onto the off centered rotatable elbow connectors (263 A). This causes the external grip pads (263) to rise and contact the internal surface of the external damaged pipe (259). The external grip pads (263) may have polymer coated, abrasive coated, serrated or otherwise roughened surfaces that provide extra grip to prevent expulsion of the device. The external pipeline connector (269) is at the down stream end of the device and can facilitate connection of the device to a new pipeline or to a valve system or to a specific skid system so as to regain flow control of the fluid and if necessary inject additives such as dispersants to the fluid. The moveable sleeve sealing system may be transported to the damaged external pipe (259) by a remotely operated vehicle or ROV Transport unit (270). The ROV transport unit may have an ROV external clamping system (271). The ROV external clamping system (271) may be required to attach to the external surface of the damaged external pipe (259) using the ROV external clamping system (271) in order to stabilize the moveable sleeve sealing system and supply sufficient force to insert the moveable sleeve sealing system into the external damaged pipe (259). Once the moveable sleeve sealing system is inserted, the external hydraulic pump (268) can be activated to pressurize the external pressure header (267) and subsequently pressurize the external pressure sleeve pistons (265) to force the external tapered pressure sleeve pipe upstream to lock the polymer sealing sleeve (262) and the external grip pads (263) against the internal surface of the extemal damaged pipe (259). Frictional force in a radial direction is supplied by the polymer sealing sleeve (262) compressing against the internal surface of the external damaged pipe (259). Frictional force increases with the increase in length of the polymer sealing sleeve (262) which is compressed against the internal surface of the extemal damaged pipe (259). The length of compressed sealing sleeve which is compressed can be increased by increasing the length and form of the taper on the upstream end of the external tapered pressure sleeve pipe (261). The polymer sealing sleeve (262) may also have an internal bladder layer or cells which extend to the surface of the polymer sealing sleeve (262) which contain adhesives such as catalyzed epoxy resins cells (272). The catalyzed epoxy resin cells (272) will burst upon compression and allow the epoxy resin to flow to the external surface of the polymer sealing sleeve (262) and mix and react to form an adhesive bond to the internal surface of the external damaged pipe (259). If after insertion, the internal annulus of the flow tube is restricted or closed with a valve the internal pressure will rise. This internal pressure will increase the force against the annulus formed by the flow tube (1), the polymer sealing sleeve and the external tapered pressure sleeve.(261) This force will seek to thrust the device out of the external damaged pipe (259) This force will also increase the pressure against the polymer sealing sleeve(262) forcing it further into any space between the external tapered pressure sleeve (261) and the internal surface of the external damaged pipe (259). This will increase the frictional pressure caused by the polymer sealing sleeve (272) to countering force against the thrust force. Depending on the yield strength of the flow tube (1) and the extemal tapered pressure sleeve (261) there may be radial deformation of these pipes which causes them to expand against the internal surface of the extemal damaged pipe (25 ) thereby increasing frictional force which will counter act thrust force.

[00160] Extemal Sliding Sleeve Sealing System with Double piston collar.

[00161 ] With reference to Figures 45, 46 and 47 in one non-limiting embodiment the external sliding sleeve sealing system consists of a flow tube (1) that provides an unobstructed internal orifice to maintain flow through the pipe. At the up stream end of the flow tube (1) a polymer sealing sleeve (262) is attached to the extemal surface. The upstream end of the polymer sealing sleeve (262) is tapered so as to allow it to be secured to the flow tube (1) by the polymer sealing sleeve anchor (262A). The polymer sealing sleeve anchor (262A) attaches the polymer sealing sleeve (262) and the polymer compression sheath (262B) to the exterior of the upstream end of the flow tube (1). The polymer compression sheath (262B) is a bladed metallic or other suitable material sheath that lies between the external polymer sealing sleeve (262) and the external tapered pressure sleeve pipe.(261) The external tapered pressure sleeve pipe (261) is mounted with the tapered end fitting underneath the bladed polymer compression sheath (262B). The external tapered pressure sleeve pipe (261 A) may have variable configurations in the taper including but not limited to single or multiple slopes and plateau and ridge or hollow areas. The polymer sealing sleeve (262) has an equal but opposite taper to the tapered pressure sleeve pipe (261). As the external tapered pressure sleeve pipe (261) moves from the downstream to the upstream position, the taper is forced against the bladed polymer compression sheath (262B) which in turn is forced against the polymer sealing sleeve (262). This causes the bladed polymer compression sheath (262B) to expand its blades and forces the polymer sealing sleeve (262) to rise up the slope of the external tapered pressure sleeve pipe (261) and contact the internal surface of the external damaged pipe (259). As the external tapered pressure sleeve pipe (261 ) continues to move in the upstream direction it compresses the polymer sealing sleeve (262) so as to close the annulus between the flow tube (1) and the external damaged pipe (259) and directs all subsequent flow through the internal annulus of the flow tube (1 ). The external tapered pressure sleeve pipe (261) is connected to external pressure sleeve piston(s) (265). In this non limiting embodiment, the pressure sleeve pistons (255) are secured between two external piston collars. (266) The distance between the two external piston collars (266) can be variable and accommodate a variable length of piston. . The external pressure sleeve pistons (265) are connected to the external pressure header (267) which is connected to the external hydraulic pump. (268) Upon activation, the external hydraulic pump (268) pressurizes the external pressure header (267) which in turn pressurizes the external pressure sleeve pistons (265) which push the external tapered pressure sleeve pipe (261) in the upstream direction. To provide additional grip to the internal surface of the external damaged pipe (259) there are (or may be) external grip pads (263) between the external tapered pressure sleeve pipe (261) and the external piston collar. (266) The external grip pad (263) is connected to down stream end of the external tapered pressure sleeve pipe (261) and the upstream end of the external grip pistons (264) by rotatable elbow connector(s) (263 A) The rotatable elbow connectors (263 A) are connected near the top of the external grip pads (263) so as to be slightly off centered. The external grip piston (264) is anchored into the external piston collar (266). The external grip pistons (264) are connected to the external pressure header (267) which is connected to the external hydraulic pump. (268) Upon activation, the external hydraulic pump (268) pressurizes the external pressure header (267) which in turn pressurizes the external grip pistons (264) which push upstream onto the off centered rotatable elbow connectors (263A). This causes the external grip pads (263) to rise and contact the internal surface of the external damaged pipe (259). The external grip pads (263) may have polymer coated, abrasive coated, serrated or otherwise roughened surfaces that provide extra grip to prevent expulsion of the device. The external pipeline connector (269) is at the down stream end of the device and can facilitate connection of the device to a new pipeline or to a valve system or to a specific skid system so as to regain flow control of the fluid and if necessary inject additives such as dispersants to the fluid. The moveable sleeve sealing system may be transported to the damaged external pipe (259) by a remotely operated vehicle or ROV Transport unit (270). The ROV transport unit may have an ROV external clamping system (271). The ROV external clamping system (271 ) may be required to attach to the external surface of the damaged external pipe (259) using the ROV external clamping system (271) in order to stabilize the moveable sleeve sealing system and supply sufficient force to insert the moveable sleeve sealing system into the external damaged pipe (259). Once the moveable sleeve sealing system is inserted, the external hydraulic pump (268) can be activated to pressurize the external pressure header (267) and subsequently pressurize the external pressure sleeve pistons (265) to force the external tapered pressure sleeve pipe upstream to lock the polymer sealing sleeve (262) and the external grip pads (263) against the internal surface of the external damaged pipe (259). Frictional force in a radial direction is supplied by the polymer sealing sleeve (262) compressing against the internal surface of the external damaged pipe (259). Frictional force increases with the increase in length of the polymer sealing sleeve (262) which is compressed against the internal surface of the external damaged pipe (259). The length of compressed sealing sleeve which is compressed can be increased by increasing the length and form of the taper on the upstream end of the external tapered pressure sleeve pipe (261). The polymer sealing sleeve (262) may also have an internal bladder layer or cells which extend to the surface of the polymer sealing sleeve (262) which contain adhesives such as catalyzed epoxy resins cells (272). The catalyzed epoxy resin cells (272) will burst upon compression and allow the epoxy resin to flow to the external surface of the polymer sealing sleeve (262) and mix and react to form an adhesive bond to the internal surface of the external damaged pipe (259). If after insertion, the internal annulus of the flow tube is restricted or closed with a valve the internal pressure will rise. This internal pressure will increase the force against the annulus formed by the flow tube (1), the polymer sealing sleeve and the external tapered pressure sleeve.(261) This force will seek to thrust the device out of the external damaged pipe (259) This force will also increase the pressure against the polymer sealing sleeve(262) forcing it further into any space between the external tapered pressure sleeve (261) and the internal surface of the external damaged pipe (259). This will increase the frictional pressure caused by the polymer sealing sleeve (272) to countering force against the thrust force. Depending on the yield strength of the flow tube (1) and the external tapered pressure sleeve (261) there may be radial deformation of these pipes which causes them to expand against the internal surface of the external damaged pipe (259) thereby increasing frictional force which will counter act thrust force.

Listing of Parts

.1 threaded nipple (15.1) external mounting plate sleeve (16)

One or two compressed gas inlet ports (17) S secondary compressed gas inlet port(s) for secondary "plus" expandable polymer bladders (17S) ST bladder tube (17ST)

One or two compressed gas/water exhaust port (18) S secondary compressed gas/water exhaust port(s) for secondary "plus" expandable polymer bladders (18S) .5 one pressure release valve. (18.5) polymer bladder may be a smooth surface (1 ). polymer bladder may be a rough surface (20). smooth surface on the ribs (21). .1 chain mail (21.1) .2 Wire mesh (21.2) .2 braided wire fibers (21.3) .3 Other synthetic fiber such as carbon fiber (21.4) .5 rough surface on the ribs (21.5). a suspension bracket with a concentric circular central tube (22) CR a suspension bracket with a concentric rectangular central tube cross braces (23)

mounting platform (24) for the compressed air tank (8) distribution header (25).

compressed gas (nitrogen) tank securing straps. (26) hydraulic anchor piston (27)

.1 the anchor ram header is a circular tube (27.1)

.2 the anchor ram header is a rectangular tube (27.2)

hydraulic anchor rams (28)

ram contour(s) (29)

ram contour (29) with grip points (30)

suspended by hoisting cables (31)

.5 anchor pin (31.5)

suspension anchors (32)

forward looking or panning camera(s) (33)

F forward looking or panning cameras (33F) (33FP)

SM servo motor (33SM)

BP a battery and camera mounting plate (33BP) B battery unit (33B)

CMC flow tube camera mount coupling (33CMC).

A bladder inflator valve actuator (35 A)

bladder inflator valve (35)

A deflator valve actuator (36A)

deflator valve (36)

A anchor ram piston valve actuator (37 A)

anchor ram piston valve (37)

anchor ram has a swivel hinge (38)

A the anchor ram release valve actuator (39A)

anchor ram piston release valve (39). articulating joint(s) (40)

fluid flow deflection cone (42)

spring loaded centering guides (43) threaded spring loaded centering guide coupling (44)

Remote Operated Vehicle (ROV). (60)

ROV-Submersible Mounting Bracket (61) forward and reverse propulsion thrusters (62) rotating lateral propulsion thrusters (63),

ROV power supply/battery unit (64)

ROV sensory and data logging unit (65)

ROV forward and panning camera and lights system (66) remotely operated robotic bracket (70) remotely operated robotic articulator(s) (71) remotely operated robotic arm(s) (72) high pressure (sea) water pump (80). onboard high pressure (sea) water pump batteries (81) AD the ballast tank deflator valve actuator (82AD) D the ballast tank deflator valve (82D). AGI the ballast tank compressed gas (nitrogen) valve actuator (82AGI) AWI (sea) water valve actuator (82A WI) which opens the ballast tank (sea) water mflator valve (82WI). WI ballast tank (sea) water mflator valve (82 WI). AE actuators 82AE piston valve empty actuator E piston empty valve AF 82AF piston valve fill actuator F piston fill valve 83 ballast tank distribution line (83).

84 a protective, adjustable metal ballast plate (84)

85 ballast plate suspension bolts (85)

86 ballast plate nuts (86)

90 90 degree vertical tilt

91 Dual Bladder Line (91 ) is a line at which at least one partition of the bladder may be made. Multiple bladders would have the same configuration to accommodate bends in the pipe.

95 External Compression Collar without Blowout Retention Ring (95)

95.1 External Compression Collar with Blowout Retention Ring (95.1)

96 (96) External Compression pads of metal with abrasive or pins on inner curvature

96.1 (96.1) External Compression pads of high density rubber pads with abrasive or pins on inner curvature

97 (97) External Compression Collar Hinge

98 (98) Spacing between compression pads to allow closure of the

Compression Rings.

99 (99) External Compression collar Securing Lock

99.1 (99.1) External Compression Collar Securing Bolt(s)

99.2 (99.2) External Compression Collar Anchoring Bolt(s) 99.3 (99.3) External Compression Collar Blowout Retention Ring

99.4 circular channel 99.4

100 a control consol (100)

120 umbilical winch system (120),

130 antifreeze (methanol) supply line connector (130)

131A antifreeze (methanol) supply valve actuator (131 A)

131 antifreeze (methanol) supply valve (131)

132 antifreeze (methanol) supply line (132)

133 antifreeze (methanol) supply tank (133)

133L antifreeze (methanol) supply line (133L)

134A antifreeze (methanol) injection valve actuator (134A)

134 antifreeze (methanol) injection valve (134)

135 antifreeze (methanol) injection line (135)

140 freeze gas (nitrogen) supply line connector (140)

141A freeze gas (nitrogen) supply valve actuator (141 A)

141 freeze gas (nitrogen) supply valve (141)

142 freeze gas (nitrogen) supply line (142)

143 freeze gas (nitrogen) supply tank (143) 143L freeze gas (nitrogen) supply line (143L)

144A freeze gas (nitrogen) injection valve actuator (144A)

144 freeze gas (nitrogen) injection valve (144)

145 freeze gas (nitrogen) injection line (145)

146 freeze gas (nitrogen) tracer coils (146)

147 freeze gas (nitrogen) tracer coils protection tube (147)

148 freeze gas (nitrogen) exhaust line 148

150 a command vessel (150).

160 dispersant supply line connector.

161A dispersant supply valve actuator (161 A)

161 dispersant supply valve (161)

162 dispersant supply line (162)

163 dispersant supply tank (163)

163L dispersant supply line (163L)

164 A dispersant injection valve actuator to flow tube (164 A)

164 dispersant injection valve to flow tube (164A)

165 dispersant injection line to flow tube (165)

166A dispersant injection valve actuator to annulus (166 A) 166 dispersant injection valve to annulus (164 A)

167 dispersant injection line to annulus (165)

170 compressed gas supply line connector (170)

171A compressed gas supply valve actuator (171 A)

171 compressed gas supply valve (171)

172 compressed gas supply line (172)

173 compressed gas supply tank (173)

173L compressed gas supply line (173L)

174A compressed gas injection valve actuator (174A)

174 compressed gas injection valve (174 A)

175 compressed gas injection line (175)

180 heated water supply line connector (180)

181A heated water supply valve actuator (181 A)

181 heated water supply valve (181)

182 heated water supply line ( 2)

183 heated water supply tank (183)

183L heated water supply line (183L)

184A heated water injection valve actuator (184 A) 184 heated water injection valve (184)

185 heated water injection line (185)

186 heated water tracer coils (186)

187 heated water tracer coils protection tube (187)

188 heated water exhaust line (188)

190 caisson (190)

191 Clamp system to grasp the top of the Blow Out Preventor

200 Flow meter (200)

201 Flow meter with magnetic propeller (201)

202 Flow meter with differential pressure sensor (202)

203 Flow meter with conductive injection (203)

204 Flow meter w h pitot tube other flow sensing mechanism

205 Flow meter with manometer (205)

206 Flow meter with other flow sensing mechanism (206)

210 Flow tube pressure sensor (210)

211 Conductivity sensor within the flow tube (211)

212 Temperature sensor within the flow tube (212)

213 other sensors within the flow tube (213) 215 multiple bladder header(s)(215)

216 Multiple bladder header(s) flex joint(s) (216)

217 Bladder fluid injection connectors/valves (217)

218 multiple bladder concentric header tube (218)

219 multiple bladder concentric header tube flex joint(s) (219)

220 Bleeder header (220)

221 Bleeder header couplings (221)

222 Bleeder header control valves (222)

229 Annulus (229)

230 Fixed compression plates (230)

230B Fixed compression plate bearing (230B)

231 Rotating threaded or sliding hydraulic shaft (231)

232 Reversible electric or hydraulic drives to turn or pull the threaded or sliding hydraulic shafts (232)

233 Compressible polymer seal rings (233)

234 Movable concentric compression plates (234)

235 Threaded compression nuts (235)

240 Moveable compression blades (240)

241 Compressed polymer seals (241) 242 Rotating hydraulic or electrically driven shaft (242)

243 Blade Shaft Bearing (243)

(244) Blade Shaft Bearing Spring (244)

245 Indented damaged pipe (245)

246 Wide Rear diameter may slightly protrude circumference

247 Narrow front diameter is smaller to allow closure of the blade

248 Arc matches inner circumference of the damaged pipe (248)

250 Bladder pressurization line (250)

251 Concentric bladder pressurization line cylinder (251)

252 Inner annulus (252)

253 Bladder inflation line (253)

254 Bladder inflation connector (254)

259 External damaged pipe

260 Internal conveyance pipe

261 External Tapered Pressure Sleeve pipe

261A External tapered pressure sleeve pipe with variable tapers and plateaus

262 Polymer Sealing Sleeve

262A Polymer Sealing Sleeve anchor 262B Polymer compression sheath

263 (263) External Grip Pad

264 (264) External Grip Piston

265 (265) External Pressure Sleeve pipe piston

265R (265R) External Pressure Sleeve pipe piston rods

266 External Piston Collar

267 External Pressure Header

268 External hydraulic pump

269 External Pipeline Coupling

270 ROV Transport Unit

271 ROV External Clamping System

272 catalyzed epoxy resins cells

(A) (A) Entrance to the Flow Tube

(B) (B) Intersection of the Flow Tube and the upstream External Mounting Plate and upstream end of the Expandable Polymer Bladder.

(C ) (C ) Intersection of the Flow Tube and the downstream end of the

Expandable Polymer Bladder and the downstream External Mounting Plate

(C ) to (D) Section where the flow distribution header is mounted and the piston ram is mounted on the flow tube. (D) to (E) Section where the suspension bracket (22) and the mounting bracket is attached to the flow tube.

(E) to (F) Section where the exit flow control valve is located on the Flow Tube.

(F) to (G) Section where the threaded nipple and the hose connector coupling is located on the flow tube.

Dl control tube (1) is a tube of diameter Dl

D2 The external mounting plate has a diameter of D2

D3 pipeline or well tube inside diameter D3

D3+ Pipeline or well tube outside diameter D3+

D4 D4 -External compression Collar Diameter.

D5 D5 - External Compression collar Blowout Retention Ring diameter.

Claims

An expandable polymer bladder apparatus comprising: a flow tube having a longitudinal bore of a first dimension Dl and a pipe thread at either end capable of receiving threaded couplings having a bore size greater than Dl; a fluid flow deflection cone having a threaded center coupling of dimension greater than Dl with a concentric cone flaring to a second dimension; a spring loaded centering guide having a threaded center coupling of a dimension greater than Dl and one or more pairs of curved springs attached thereto; a concentric external bladder mounting plate having a diameter of D2, an internal diameter pipe thread corresponding to the external pipe threads of the flow tube, and a first plurality of evenly spaced bolt holes around the circumference of the plate; a concentric internal bladder mounting plate having a diameter less than D2 and a second plurality of evenly spaced bolt holes around the circumference of the plate corresponding to the bolt holes in the external bladder mounting plate; an expandable cylindrical polymer bladder having a concentric internal tube of diameter greater than Dl which fits over the external surface of the flow tube, one or more fluid filling ports, one or more gas exhaust ports, and one or more pressure release valves; an hydraulic anchor ram, an anchor ram piston valve and a fluid distribution anchor ram header, wherein the header distributes fluid to a hydraulic anchor piston; an actuated valve distribution header having a plurality of actuators and actuated valves to distribute fluid to the expanded polymer bladder, hydraulic anchor piston or release fluid from the expanded polymer bladder and hydraulic anchor piston;

2. The apparatus of claim 1, wherein the external bladder mounting plate and internal bladder mounting plate may be manufactured of metal, fiber glass, carbon fiber or other chemical, pressure and abrasion resistant material.

3. The apparatus of claim 1, wherein the pipe thread of the internal diameter of the external circular mounting plate corresponds to the external pipe threads of the flow tube.

4. The apparatus of claim 1 , wherein the expandable polymer bladder extends between a first external bladder mounting plates and a second external bladder mounting plate.

5. The apparatus of claim 1, wherein the exterior surface of the expandable polymer bladder is smooth.

6. The apparatus of claim 1, wherein the exterior surface of the expandable polymer bladder is rough.

7. The apparatus of claim 1, wherein the exterior surface of the expandable polymer bladder is ribbed and the surface of each rib is smooth.

8. The apparatus of claim 1, wherein the exterior surface of the expandable polymer bladder is ribbed and the surface of each rib is rough.

9. The apparatus of claim 1, further comprising an expandable metal chain mail outer surface layer exterior to the expandable polymer bladder, the chain mail layer smooth on its inner surface and rough on its outer surface.

10. The apparatus of claim 1, further comprising an expandable metal wire mesh outer surface layer exterior to the expandable polymer bladder, the chain mail layer smooth on its inner surface and rough on its outer surface.

11. The apparatus of claim 1, further comprising an expandable metal braided wire fiber outer surface layer exterior to the expandable polymer bladder, the chain mail layer smooth on its inner surface and rough on its outer surface.

12. The apparatus of claim 1, further comprising an expandable synthetic braided wire fiber outer surface layer exterior to the expandable polymer bladder, the chain mail layer smooth on its inner surface and rough on its outer surface.

13. The apparatus of claim 12, wherein the anchor ram further comprises a ram contour connected to the anchor ram.

14. The apparatus of claim 13, wherein the ram contour is pivotally connected to the anchor ram by a swivel hinge.

15. The apparatus of claim 14, wherein the anchor ram further comprises one or more grip points on its outer surface.

16. The apparatus of claim 1, wherein the anchor ram further comprises one or more hydraulic anchor pins on its outer surface.

17. The apparatus of claim 1 , wherein the anchor ram header is circular.

18. The apparatus of claim 1 , wherein the anchor ram header is rectangular.

19. The apparatus of claim 1, further comprising a suspension bracket comprising side brackets extending laterally from a central tube.

20. The apparatus of claim 1, further comprising one or more pairs of suspension anchors attached to the suspension bracket.

21. The apparatus of claim 1, further comprising an actuator and an actuated valve of diameter Dl to control the exit of oil, gas or other fluid from one end of the flow tube.

22. The apparatus of claim 1, further comprising a connective threaded nipple of diameter Dl capable of entering the actuated valve and the connective coupling.

23. The apparatus of claim 1 , further comprising a connective coupling of diameter D 1 with an internal thread at one end attachable to the connective treaded nipple and a connective mechanism at another end connectable to a flow containment device.

24. The apparatus of claim 1, further comprising a compressed gas tank of volume VI of sufficient strength and of sufficient volume to contain an internal pressure of compressed gas with sufficient expansion volume to fill and maintain the expanded polymer bladder in the expanded state for an indefinite period of time.

25. The apparatus of claim 1, further comprising a servo motor platform which is capable of 360 degree rotation and 90 degree vertical tilt which supports and directs the directional view of a forward looking camera mounted on the compressed air tank or the threaded coupling platform at one end of the flow tube.

26. The apparatus of claim 1 , further comprising one or more ballast tanks.

27. The apparatus of claim 1, further comprising a remotely operated vehicle (ROV) with forward and reverse propulsion thrusters and rotating lateral propulsion thrusters which attaches to the ROV submersible mounting bracket and has sufficient directional power and control to manipulate the device in deep (sea) water conditions.

28. The apparatus of claim 1, further comprising a remotely operated vehicle (ROV) submersible mounting bracket (61) attached to the suspension bracket of sufficient strength to support the weight of the device, an ROV, an ROV power supply battery unit, an ROV Computer Sensory and Data Logging unit and an ROV camera and lighting system.

29. The apparatus of claim 1, further comprising a power supply battery unit which is capable of being mounted on ROV submersible mounting bracket which has sufficient electrical storage capacity to power the ROV and the ROV Computer Sensory and Data Logging unit and an ROV forward or panning camera and lighting systems in deep (sea) water conditions.

30. The apparatus of claim 1, further comprising an ROV Computer Sensory and Data Logging unit which is capable of maintaining control and recording and transmitting sensory data and control data necessary for the operation of the device and connected by a control cable to an umbilical chord which is connected to a control consol in a command vessel in deep (sea) water conditions.

31. The apparatus of claim 1, further comprising an ROV forward or panning camera and lighting systems located on the ROV submersible mounting bracket or on the ROV power supply battery unit, which is capable of providing lighting and forward or panning still or video camera views in deep (sea) water conditions.

32. The apparatus of claim 1, further comprising a remotely operated robotic bracket that can be attached to the suspension bracket for the purposes of securing remotely operated robotic articulator(s) and remotely operated robotic arm(s) to the bracket.

33. The apparatus of claim 1, further comprising remotely operated robotic articulator(s) and remotely operated robotic arm(s). The remotely operated robotic articulators) allow for angular rotation of the device to facilitate positioning, insertion and extraction of the device into and from the ruptured pipeline or well. The remotely operated Robotic Arms allow for forward, reverse, extension and retraction of the device to facilitate positioning, insertion into and extraction of the device from the ruptured pipeline or well.

34. The apparatus of claim 1, further comprising a control consol which performs the following functions: sensing and recording and displaying all sensory data sent to the Expandable Polymer Bladder Apparatus; sensing and recording and displaying all sensory data sent from the Expandable Polymer Bladder Apparatus; sending and recording and displaying all control command functions to the Expandable Polymer Bladder Apparatus; receiving and recording and displaying all control command function responses sent from the Expandable Polymer Bladder Apparatus; containing all control manipulators necessary to control all functions on the Expandable Polymer Bladder Apparatus; containing all control manipulators necessary to control the robotic arms; containing all control manipulators necessary to control all functions on the remotely operated vehicle; containing all the control devices necessary to receive and display video transmissions from the Expandable Polymer Bladder Apparatus; containing all the control devices necessary to store and transmit video transmissions from the Expandable Polymer Bladder Apparatus to video, satellite, internet or other mass communications systems and networks; mtaining all the control devices necessary to receive and display video transmissions from the remotely operated vehicle (ROV); and containing all the control devices necessary to store and transmit video transmissions from the remotely operated vehicle (ROV) (60) to video, satellite, internet or other mass communications systems and networks.

35. The apparatus of claim 1 , further comprising an umbilical cable containing: all the transmission and receiving cables necessary to control all the functions on the Expandable Polymer Bladder Apparatus, all the transmission and receiving cables necessary to control all the functions on the remotely operated vehicle (ROV); all the transmission and receiving cables necessary to control all the functions on the remotely operated robotic articulator(s) and remotely operated robotic arm(s); all the transmission and receiving cables necessary to control all the functions on the forward looking or panning cameras and lighting systems on the Expandable Polymer Bladder Apparatus; and all the transmission and receiving cables necessary to control all the functions on the forward looking or panning cameras and lighting systems on the remotely operated vehicle unit.

36. The apparatus of claim 1 , further comprising a one or more articulating joint(s) that allows minor flexing in the flow tube to accommodate bending of the flow tube and the expandable polymer bladder.

37. The apparatus of claim 1. further comprising onboard high pressure (sea) water pump batteries.

38. The apparatus of claim 1, further comprising one or more secondary expandable polymer bladder in contact with the primary expandable polymer bladder at a dual or multiple bladder line, secondary compressed gas inlet port(s) for secondary expandable polymer bladders, secondary compressed gas exhaust port(s) for secondary expandable polymer bladders, and a bladder tube which conveys the secondary compressed gas inlet port(s) from the distribution header to the secondary expandable bladder and which conveys the secondary compressed gas exhaust port(s) from the secondary expandable bladder to the distribution header.

39. The apparatus of claim 1, further comprising an external compression collar.

40. The apparatus of claim 40, further comprising a blow out retention ring.

41. The apparatus of claim 1, further comprising external compression pads with abrasive or pins on the inner curvature.

42. The apparatus of claim 42, wherein the external compression pads are metal.

43. The apparatus of claim 42, wherein the external compression pads are synthetic.

44. The apparatus of claim 1, further comprising an external compression collar hinge.

45. The apparatus of claim 1, further comprising an external compression collar securing lock.

46. The apparatus of claim 1, further comprising an external compression collar securing bolts.

47. The apparatus of claim 1, further comprising an external compression collar anchoring bolts.

48. The apparatus of claim 1, further comprising an external compression collar blowout retention ring.

49. The apparatus of claim 1 , further comprising an external compression collar circular channel.

50. The apparatus of claim 1, further comprising An antifreeze (methanol) supply system comprising: a supply line connector; a supply line valve actuator; a supply line valve; a first supply line; a second supply line; a supply line tank; a first injection line valve actuator; a second injection line valve actuator; and an injection line.

The apparatus of claim 1, further comprising A freeze gas (nitrogen) supply system comprising: a freeze gas (nitrogen) supply line connector; a freeze gas (nitrogen) supply line valve actuator; a freeze gas (nitrogen) supply line valve; a first freeze gas (nitrogen) supply line; a freeze gas (nitrogen) supply line tank; a second freeze gas (nitrogen) supply line; a first freeze gas (nitrogen) injection line valve actuator; a freeze gas (nitrogen) injection line valve actuator; a freeze gas (nitrogen) injection line; one or more freeze gas (nitrogen) tracer coils; a freeze gas (nitrogen) tracer coils protection tube; and a freeze gas (nitrogen) exhaust line. an injection line.

The apparatus of claim 1, further comprising A dispersant supply system comprising: a dispersant supply line connector; a dispersant supply line valve actuator; a dispersant supply line valve; a dispersant supply line; a dispersant supply line tank; a second dispersant supply line; a first dispersant injection line valve actuator, a dispersant injection line valve actuator; a dispersant injection line; a first dispersant injection line valve actuator to the annulus; a second dispersant injection line valve actuator to the annulus; and a dispersant injection line to the annulus.

53. The apparatus of claim 1, further comprising A compressed gas supply system comprising: a compressed gas supply line connector; a compressed gas supply line valve actuator; a compressed gas supply line valve; a first compressed gas supply line; a compressed gas supply line tank; a second compressed gas supply line; a first compressed gas injection line valve actuator; a second compressed gas injection line valve actuator; and a compressed gas injection line.

54. The apparatus of claim 1, further comprising A heated water supply system comprising: a heated water supply line connector; a heated water supply line valve actuator; a heated water supply line valve; a first heated water supply line; a heated water supply line tank; a second heated water supply line; a first heated water injection line valve actuator; a second heated water injection line valve actuator; a heated water injection line; one or more a heated water tracer coils; a heated water tracer coils protection tube; and a heated water exhaust line.

55. The apparatus of claim 1, further comprising an expandable polymer bladder device structural frame comprising an adjustable Metal Ballast Plates, a Suspension Bracket, and one or more suspension anchors.

56. The apparatus of claim 1, further comprising a Caisson with a clamp system to attach to the blow out preventor.

57. The apparatus of claim 1, further comprising a flow meter with magnetic propeller, differential pressure, pitot tube, a monometer, or other flow sensing mechanism.

58. The apparatus of claim 1, further comprising a flow tube pressure sensor, a flow tube conductivity sensor, a flow tube temperature sensor, and other flow tube sensors.

59. The apparatus of claim 1, further comprising a multiple bladder header, multiple bladder header flex joint(s). bladder fluid injectors/valves, multiple bladder concentric header tube, and multiple bladder concentric header tube flex joint(s).

60. The apparatus of claim 1, further comprising a bleeder header system, bleeder header couplings, and bleeder header control valves.

61. The apparatus of claim 1 , further comprising compressed solid polymer system.

62. The apparatus of claim 1 , further comprising fixed concentric plates.

63. The apparatus of claim 1, further comprising rotating threaded or hydraulic sliding shafts.

64. The apparatus of claim 1 , further comprising reversible electric or hydraulic drives.

65. The apparatus of claim 1 , further comprising compressible polymer seal rings.

66. The apparatus of claim 1, further comprising moveable concentric compression plates.

67. The apparatus of claim 1, further comprising threaded compression nuts.

68. The apparatus of claim 1 , further comprising a movable blade sealing system.

69. The apparatus of claim 1 , further comprising movable compression blades.

70. The apparatus of claim 1, further comprising compressed polymer seals on compression blades.

71. The apparatus of claim 1, further comprising rotating hydraulic or electrically driven shaft.

72. The apparatus of claim 1, further comprising blade shaft bearings, and blade shaft bearing springs.

73. The apparatus of claim 1, further comprising a bladder pressurization line, and bladder inflation line connector.

74. The apparatus of claim 1, further comprising an external Sliding Sleeve Sealing System which consists of:

Internal flow tube;

External tapered pressure sleeve pipe; Polymer Sealing Sleeve; Bladed polymer compression sheath; Polymer Sealing sleeve anchor; External Grip Pad; Rotatable Elbow connector; External Grip Piston; External Pressure sleeve piston; External Pressure Header; External Hydraulic Pump; External Pipeline Connector; ROV Transport Unit; and ROV External Clamping System.