OUT OCEANIC OIL WELL

BACKGROUND OF THE INVENTION

The embodiment of invention is directed to plurality of mechanical devices and their utility methods for the emergency salvage of a blown out oceanic petroleum oil well, incorporating means of not only sealing oil leak from the well bore in an effective and immediate manner, but

also resorting to emergency reparative processes at the distorted well head and beyond, that an optimal structural and functional state of the well is restored, stopping the 'vicious cycle' of mere leak from the disrupted well turning to a spewing geyser into the ocean.

There are innumerable petroleum oil wells bored into the oceanic floor by highly evolved modern technological devices to tap the petroleum ( gas / crude oil ) reservoirs. Many oil wells are clustered in the Gulf of Mexico, Arabian sea and such oceanic grounds, often of significant distance from the coast line, such wells bored through the ocean floor to as far deep as a mile from the surface waters, to find their way into the underground oil containments spread many miles in area. Oil is collected from the wells into surface tanks in moderate containers, or into receptacles as large as ships.

The boreholes or shafts laboriously made into the oceanic floor to tap the geological oil reservoirs are modern wonder which improved in technology over decades. The drilling of boreholes that form the tunnels of the wells in the ocean ground are accomplished by innumerable varieties of 'Drilling Rigs', a drilling rig being defined as - 'an unit of equipment built to penetrate the superficial and the deeper aspects of the earth's crust'. The rigs can be built as small and portable to be moved by a single person, or they can be enormous in size and complexity of functioning so as to house equipment used to : drill oil wells; sample mineral deposits that can impede functional units; identify geological reservoirs; install underground utilities. Large units ( rigs ) generally configured as more permanent land or marine based structures in remote locations are also facilitated with living quarters for laboring crews involved in well construction, at times hundreds in number.

Hydraulic rotatory drilling originally devised by Anthony Francis Lucas, is utilized in oil well drilling. All bore wells incorporate inner 'casing annulus' during construction of the bore tunnel of the well leading to the underground reservoir. The 'casing annulus' is a hollow sheath which protects the bore hole against collapsing during drilling, and is made up of metal ( steel ) or polyvinyl chloride ( PVC ). The bore well has a nested configuration, that is, it narrows down as it courses down into the deeper layers of the earth's crust, and hence the deeper metal / PVC annuli of casings are built to be progressively smaller. The standard casings are usually 40 feet (13 meters ) in average length, and available in 14 casing diameter sizes, spanning 7-30 inches in outer diameter.

The drilling and production of oil and gas from the earth's mantle in the ocean floor is shrouded with risk and great hazard to the natural environment that includes both the marine life forms and the terrestrial ecosystem adjacent. The greatest hazard is the ignition of the entrained highly inflammable gases like Methane, causing dangerous fires, coupled with the risk of oil spewing and polluting the sea water. Such two man-made calamities at the same time can be

uncontrollable with available resources, and utterly devastating to the healthy existence of the earth's planetary life forms. For these reasons, error-proof safety systems in under water bore well digging, and highly trained personnel are required by law in all countries engaged in significant oil production. Despite such stringent laws, system failures and catastrophic results did occur historically though derived remedial measures through each 'adverse-event experience' uniquely different from the other in some form or other, are still nascent and less than perfect.

Recent event in the gulf shores of Mexico ( involving BP oil company's oil well under

construction, the Deep Water Horizon ), wherein the ignition of the entrained Methane gas and it's fire that continued unstopped for 36 hours, culminated in collapse of the surface structure of the oil well, resulting in an ever increasing gusher from the source. Several different attempts from BP oil company's technical team to contain the spewing geyser from finding its way into the body of water, and into the gulf shores had failed, mostly due to the inherently limited robotic attempts involved in a moderately deep aquatic habitat.

In the prevailing oceanic climate of the oil wells, after a bore well structure is disrupted, the sea water continuously gets into the oil well, whereas the oil rises to the surface, because of the relative densities of each, that could be contributing to the spewing of oil gush at a later time, while it would be only a spill to start with. There would be churning forces set forth at the land mark area of the disrupted bore well surface, the sea water trying to get in, while the lighter petroleum / crude oil is trying to get out. As the ocean water forcefully fills the underground oil containment space ( the hydrostatic pressure at any point in the ocean being proportional to the true vertical depth ), the pressure will rise more and more in a very short time, forcing the lesser dense oil to progressively rise into the ocean like an eruption.

Accordingly, it is imperative that immediate action be taken to contain the leak, and stop the sea water pouring into the containment of underground reservoir that will effectively dampen the rising pressure within its confined space, further reducing the spewing force of the oil gusher - thus breaking the vicious cycle. The calamity in gulf shores happened before the 'Production Tubing' and the 'Production Packer' were installed, and the wide 'A' annular space acted as the tunnel for the oil gusher. As a result the sea water very quickly found its way through the expansive oil well bore, and the oil in turn rose to the surface with a greater force. It was worse due to the absence of down hole safety valve ( DHSV ) which is usually placed in the 'Production Tubing' ( the valve being the last resort to contain the leak from the disrupted well ) as far below the surface as deemed safe, to be unaffected by any events leading to wipe out of the surface well head platform.

As any unforeseen adversity can happen at any time before the completion of the well to its last functional detail, safety measures to weather off such events at any step of the construction have to be in place, before beginning to undertake such operation.

The following embodiments are primarily structured to counteract the events when a 'fire-blow out' of the well head platform destroys any of the security devices before the well completion, wherein the timing of the adverse events to be countervailed are similar to that of the BP's Deep Water Horizon Oil Well blow-out i.e. before the production tubing and the production packer' are installed, OR in high production wells not destined to incorporate a production tubing and production packer when the whole annulus space ( the 'A' annulus ) is used as the oil production conduit. Other devices and methods are also included to counter adverse events in other contexts, and additionally, to prevent and alleviate the problems inherent to the prevailing oil production endeavors of the industry, whether or not so far recognized, nonetheless not so far addressed. The dictum 'prevention is better than cure' prevails more than any under any circumstance, especially when such endeavors are impressively simple, and impressively effective.

The inventions herein disclosed are directed to prevent and alleviate many of the problems discussed above though it is neither intended nor implied that the originally planned well structure is restored, but a functional order is definitely emphasized and resulted, however, as stated, manifestly different from the established norm. Such differences are being practiced on a regular basis even in the oil industry ( example - some high production wells are structured to operate without any 'Conduction Tubing' and 'Conduction Packer' usually incorporated within the casing 'A' annulus ). But the undeniable incentive to accommodate some differences from the practicing standards in an industry where such standards are justifiably warranted is: their ability to weather through a calamity with catastrophic consequences even in situations where norms and standards were followed throughout the well construction, and later during its maintenance - a classic example that the 'forces of nature' are not always necessarily contained by practicing rigorous standards, and what seems like a 'difference', and what seems as simplistic beyond belief, may indeed work, to contain what proved to be an uncontainable calamity.

Every effort was made to devise and describe the following invention with the best rationale, and with the available information at the time of this writing. However, the Author Inventor is neither legally liable nor personally responsible for any inadvertent errors or omissions, or for any 'adverse events' difficult to differentiate either as a mere association or as a consequence of application of the structural and procedural information enumerated. Additionally, many inadvertent and unforeseen consequences were / are inherent to such ventures as the deep sea explorations and the like, shrouded in dangers and never ceasing mystery, and were / are left to be counting on the tides of nature yet to be conquered by technological sophistication.

Accordingly, application of this disclosure in different situations, innumerable and unique, is a personal choice. Furthermore, understanding, analyzing, and adapting swiftly as needed, to diverse situations, still remain as the professional discretion, expertise, and the deemed responsibility of the involved company and its associates participating in the day to day practice of the implementation of this invention, in part or as a whole. BRIEF DESCRIPTION OF THE INVENTION

The embodiments of invention herein disclosed are directed to the emergency devices and their functions, to not only effectively seal the oil gusher from a blown out oceanic petroleum oil well, but also to establish an immediate and effective oil out-let system, set forth to optimize the mounting pressure within the bore well and its source of oil containment ( the bore-well either complete or yet to be complete in its structural mandates ), such an ordinate function effectuated by devices working in synchrony to achieve ultimate results deemed optimal and lasting. The disclosure is inclusive also of reparative devices and their methods at the well head and its vicinity, when such structures are disrupted.

The original US Patent Application 13 / 134370 ( by the same Inventor Applicant ) ( filed June 2011, to be Patented November 2015 ) also the related two CJP applications ( US ) ( filed Nov. 2015 ) enumerate measures following a catastrophic event, to effectuate an emergency rig-salvage that envisions an 'EMERGENCY DETACHABLE ISLAND RIG' ( DIR ) and also methods and means to be incorporated, for a 'SUBSEA LEVEL GAS SEPARATOR FROM THE CRUDE PETROLEUM OIL' for preventing a giant gas bubble formation so as to keep the rig from being a venue of danger. The subject matter is relevant to any oil company seriously contemplating in practicing pro-active safety measures for preventing catastrophic events at the outset, and also for the reason that the disclosures herein are best implemented in conjunction. Of great interest also is the fact that they are simple and easy to be incorporated and implemented. Mention of the inventions is also relevant as references to them will be contextually encountered thereto, in the enumeration of this disclosure.

THE FOLLOWING ARE THE EMBODIMENTS OF THE INVENTION -

THE EMERGENCY SEALING, STABILIZING, AND REPARATIVE DEVICES OF A DISRUPTED OCEANIC OIL WELL: ( 1 ) (a) 'Emergency Pneumatic Sealing Ensemble' unit ( EPSEU ): it is devised both as a 'more evolved design', the Emergency 'Evolved Pneumatic Sealing Ensemble' ( the EPSE ), and a simple design, as in an Emergency 'Simple Sealing Ensemble' ( the SSE );

(b) 'Emergency Oil Connecting and Stabilizing Unit' ( EOCS unit ) - it connects the EPSE / SSE device and the 'Emergency Stabilizing Unit with a Well Head-like Device' ( ESUWH ) at the well head.

( 2 ) 'Emergency Stabilizing Unit with a Well Head-like Device' ( ESUWH ) - it is effectuated on the well surface, and is made of heavy weight metal ( steel ), to stabilize the buoyant effects of any sealing device.

( 3 ) 'Emergency Plugging Oil Conduit' ( EPOC ) - it is devised to plug the fractured leaking oil- conduit, the 'production tubing'.

( 4 ) 'Emergency Isolation Platform' ( EH*) - it is a cement construction about the well surface, with devices to be incorporating the well head structures.

( 5 ) Threaded instant joint structures and caps - to instantly connect or close tubular systems.

( The above are best implemented in conjunction with the following ( disclosed in original US

Application 13/134370, and its CIP applications ) - (l ) 'Emergency Detachable Island Rig ' (DIR); (2) A model of 'SUBSEA LEVEL GAS SEPARATOR FROM THE CRUDE PETROLEUM OIL ' near the well head - an unit structured on the ocean floor, particularly designed to separate the gas from the liquid and semisolid crude of petroleum oil, to mitigate 'Blow-Out Preventer '

( BOP ) failure, due to entrainment of inflammable gases under uncontainable high pressure. )

THE EMERGENCY SEALING, STABILIZING AND REPARATIVE DEVICES OF A

DISRUPTED OCEANIC OIL WELL :

( 1 ) THE EMERGENC PNEUMATIC SEALING ENSEMBLE UNIT ( EPSEU ) - The prototype embodiment for an emergency sealing of a disrupted oceanic petroleum oil well is an Emergency Pneumatic Sealing Ensemble Unit ( EPSEU ) functioning as an emergency seal in the well bore of the leaking oil well, deployed within hours with no wait time, along with incorporated oil conduit and buoyancy stabilizing components. It is the most important and cost effective device, as an immediate measure. The sealing ensemble unit EPSEU is structured in two designs - (1) an Emergency 'Evolved Pneumatic Sealing Ensemble' ( the EPSE ), and (2) an Emergency Pneumatic 'Simple Sealing Ensemble' ( the SSE ) : these devices to be used in the settings of either a disrupted or a non-disrupted innermost casing of the bore well respectively, as identified by the video and sonar devices. The EOCS unit that traverses the bore well connects the EPSE / SSE device with the ESUWH at the well surface.

The foregoing are preferable devices for a well under construction, that is, when the casing is completed, but the 'production tubing' and the 'production packer' are not yet installed, wherein its innermost casing ( the 'A' annulus ) is the annulus of concern aimed for an effective sealing ( example - the BP's Deep Water Horizon Oil Well blow out ).

( 2 ) THE 'EMERGENCY STABILIZING UNIT WITH A WELL HEAD-LIKE DEVICE' ( ESUWH ) -

The 'Emergency Stabilizing Unit with a Well Head like Device' ( ESUWH ), an invariable accessory to the foregoing device ( the EPSE / SSE ), is a heavy weight table-like metal ( steel ) structure having outwardly spanning legs with gradually widening bottoms, to be drilled into the sea bed, and cemented. Being a simple structure with also a simple operation to accomplish, it can be drilled swiftly into the sea floor, even by robotic instruments. The thickened and elaborated center of the circular table-top accommodates well head-like structures with also a central oil- conduit that is connected through the EOCS, to the EPSE / SSE device, stationed within the well bore. By its sheer weight and cementing to the sea floor, it overcomes the buoyancy effects of the EPSE / SSE device. When the 'EMERGENCY ISOLATION PLATFORM' ( ΕΠ ^> ) at the well surface, described in the subsequent section (4) below, is constructed, the well head-like structures of the ESUWH are incorporated into the platform.

( 3 ) THE EMERGENCY PLUGGING OIL CONDUIT ( EPOC ) - The 'Emergency Plugging Oil Conduit' ( EPOC ) is yet another embodiment that effectively plugs the 'production tubing' of a fully constructed oceanic oil well, if the production tubing is fractured ( with linear or circular cracking ), or partially or completely severed by surface blow out of the well. Such damage to the 'production tubing' is usually located near and adjacent to the well surface so as to be easily amenable for repair.

( 4 ) 'EMERGENCY ISOLATION PLATFORM' ( EIP ) OF THE WELL SURFACE WITH DEVICES TO BE INCORPORATING THE WELL HEAD STRUCTURES -

Emergency Isolation Platform ( EBP ) is a model design for incorporating the well-head like device ( ESUWH ), and is a permanent reparative / restoration structure at the well surface surpassing the maximum Diameter Of Disruption ( DOD ), to be built on a footage of reliable ocean grounds.

( 5 ) THE THREADED INSTANT JOINT STRUCTURES -

The invention further provides novel model of tubing directed to all tubular systems, said tubing structured to be having a threaded configuration on the inside or the outside, traversing the whole length, facilitating instant joining or closing of a broken or intact system, aided by means of 'instant joint structures' shaped as I, T, J, L, C, U etc. having straight or nested configuration, or closing caps with also complimentary threading.

THE TERMINOLOGY EMPHASIZED -

The device and the description when denote the terms 'upward', 'up', 'rear', and 'above' - they refer to the opening side of the bore well to the ocean side, whereas the terms 'lower', 'low' and 'below' refer to the oil containment side underneath the ocean floor. Furthermore, the leading / diving end or the head end of any instrument or device is the lower end of that device or instrument in the bore well, both terms being referred in upright position. DRAWINGS

( 1 ) Figure - 1 A: A schematic cut section-in-part of an Emergency 'Evolved Pneumatic Sealing Ensemble' ( the EPSE ), in its vertical disposition, showing a more involved / evolved design of the EPSE.

( 2 ) Figure - 1 B : A schematic cut section-in-part of an Emergency Pneumatic 'Simple Sealing Ensemble' ( the SSE ), in its vertical disposition, showing a simpler design of the SSE.

( 3 ) Figure - 2 A : A schematic diagram of a horizontal cross-section of an Emergency 'Evolved Pneumatic Sealing Ensemble' ( the EPSE ), showing structures at all strategic levels.

( 4 ) Figure - 2 B : A schematic diagram of a horizontal cross-section of an Emergency

Pneumatic 'Simple Sealing Ensemble' ( the SSE ).

( 5 ) Figure - 3 : A perspective view of a joint articulation of air tube connections with a sliding screw arrangement.

( 6 ) Figure - 4 : A schematic diagram of an 'Emergency Plugging Oil Conduit' ( EPOC ).

( 7 ) Figure - 5 : A schematic diagram of the plan of an 'Emergency Isolation Platform' ( EIP ) about the well surface, with devices to be also incorporating the well head.

DETAILED DESCRIPTION OF THE INVENTION

The embodiments of invention herein disclosed are directed to the emergency devices and their functions, to not only effectively seal the oil gusher from a blown out oceanic petroleum oil well, but also to establish an immediate and effective oil out-let system, set forth to optimize the mounting pressure within the bore well and its source of oil containment ( the bore well being complete or yet to be complete in its structural mandates ), such an ordinate function effectuated by devices working in synchrony to achieve ultimate results deemed optimal and lasting. The disclosure is inclusive of reparative devices and their methods at the well head and it's vicinity, when such structures are disrupted.

As mentioned in the 'Brief Description of the Invention' the disclosure is best operative in conjunction with an 'EMERGENCY DETACHABLE ISLAND RIG', and further with devices and their methods of 'SUBSEA LEVEL GAS SEPARATOR OF CRUDE PETROLEUM OIL' preventing a giant gas bubble formation in the oil-collection system, by diverting the inflammable gases from the petroleum / crude oil, at the site most proximate to the source, thereby mitigating the failure of the measured operations of the 'Blow Out Preventer' ( BOP ) due to entrained gas under immeasurable pressure. Such measures are described in different PCT disclosures titled as 'EMERGENCY DETACHABLE ISLAND RIG' and 'SUBSEA LEVEL GAS SEPARATOR FROM CRUDE PETROLEUM OIL'. The original US Patent Application 13 / 134370 ( by the same Inventor Applicant ) ( filed June 2011, to be Patented November 2015 ) and also the related two CIP applications ( US ) ( filed Nov. 2015 ) detail the above subject matters. Mention is also made at places in this writing.

The devises listed and their functions briefly outlined in the foregoing sections are herein further detailed in sections 1-5.

( 1 ) THE EMERGENCY PNEUMATIC SEALING ENSEMBLE UNIT ( THE EPSEU )

THE EMERGENCY 'EVOLVED PNEUMATIC SEALING ENSEMBLE' ( THE EPSE ) WITH AN INVOLVED / EVOLVED DESIGN -

The Emergency 'Evolved Pneumatic Sealing Ensemble' ( the EPSE ) of the EPSE Unit ( the EPSEU ) is an embodiment of an exemplary design to be used with no wait time and within minutes of a catastrophic event, resulting in disruption / collapse of an oceanic oil well head, and its vicinity. The disclosure contemplates a prototype model of a strong inflatable vulcanized rubber device resistant to solvents of concern, like petroleum analogs / sea water. It is inflated to desired size and seal the whole circumference at a suitable site within the leaking bore well, to fully or partially stop the flow of the oil gusher resulting from a damage to the original bore well structure by whatever means, but mostly due to highly inflammable gas-fire destruction / explosion.

Through an oil conduit within it, the EPSE device is connected to the 'EMERGENCY OIL

CONNECTING AND STABILIZING' unit ( EOCS unit ) that not only counteracts the buoyant effects of the EPSE device at its stationed position in the bore well, but also serves as an oil conduit by its ultimate connection to the cemented heavy weight ESUWH device encompassing an oil-outlet tubing, at the well surface.

It is also implied that soon after the catastrophic event, a submarine robotic unit is stationed at the well head that controls and monitors the functional and safety devices, such unit further improvised with air chambers to supply air to the EPSE unit ( EPSEU ). The EPSEU is devised for situations when a blow-out happens while the construction is about to complete, as it occurred in BP's Deep Water Horizon Oil Well, in which the 'production tubing' and the 'production packer' were not yet installed, after the well casing was completed. Accordingly, the diameter of the leaking annulus or the 'A' annulus ( with the innermost casing forming its outer boundary ), usually encountered in a diameter of 9 and 5/8 inches - is the diameter of concern, that needs to be effectively sealed. The corresponding EPSEU built with an average diameter of 8" for effective passage, at times can be diagonally compressed to maneuver through projecting obstacles if any, until it reaches the destined area of totally preserved casement interior of the oil well, to be inflated for its wedging. The device is also available in higher / lower diameters to be used in bore wells with higher / lower diameter 'A' annulus, when higher / lower standard sizes are used as the inner most casing.

As afore stated, the EPSE device is made of vulcanized rubber ( a polysulfide elastomer ). Vulcanization gives rubber unique physical, dynamic, and chemical properties. The main polymers subjected to vulcanization are polyisoprene ( the natural rubber ), and styrene-butadiene rubber ( SBR ). During vulcanization some C-H bonds of the rubber are replaced by chains of sulfur atoms. It gives properties of better heat resistance, flexibility without cracking, elasticity, and expandability like a car tire. Vulcanized rubber is also abrasion resistant. Vulcanized rubber is insoluble in petroleum, and is used to make gasoline hoses routinely used in gas stations.

Ordinary rubber is also very hard to be dissolved in any solvent / medium. Naphtha, a petroleum distillate is the only petroleum substance that can dissolve rubber when rubber is fragmented into small pieces and immersed in the solvent. The crude oil contains 15-30% naphtha by weight, and generally contains lower than that amount when it is admixed with sea water in a destroyed bore well. It needs to be noted that all the bolt joints and assembly washers of rubber for all the devices and structures herein described, shall also use vulcanized rubber to specifically resist the degrading attack of petroleum analogs, the solvents of concern in this setting.

The depth where the EPSE device has to be stationed is variable depending on the severity of destruction. Prior estimates by video and sonic devices are necessary to map the general configuration of the well structure for a substantial distance in its depth, to mark out the level from where the cross sectional integrity of the well bore deeper is still preserved all through, in its entire circumference. It is the ideal level to station the pneumatic sealer ensemble. Because of the inherent adaptability of the pneumatic device, a substantially complete and tight seal is expected, especially with the involved height of the device. It has to be further noted that any irregularities / breaches in the circumferential counter of the bore well above its stationed position will not generally impede the function of the devised assembly as an effective gas / liquid sealer, thereby ultimately preventing the leak at the well head and its circumferential vicinity.

The Emergency Pneumatic Sealing Ensemble ( EPSE ) is built with the projected total diameter of the inflated pneumatic sealer to far exceed the bore well diameter it is stationed at, for tight and secure wedging, but the pressure needed for such wedging is calculated to be below the 'burst pressure' with sufficient safety margin. It is possible to be still functional when it is less than maximally inflated, but it is not possible to wedge even at maximal inflation if it is of the same diameter or of lesser diameter than that of the well bore. In other words, it is workable erring in over sizing ( however, in a size that would not impede its passage ) instead of under sizing. If there are significant metal projections in the entry area, but not beyond ( though sharp edged cracks and breaches may be present ), the device can be made leaner with strong compressive rubber bands that can be cut immediately after the obstacle is passed, as doing this nearer to the surface is better. Cutting at the site of stationing can be an option if the robotic arms can accomplish such purpose.

Figure-1 A shows a schematic cut-in-part sectional diagram of the EPSE device in its vertical disposition. Figure-2 A further depicts a horizontal cross sectional view of the EPSE device showing its important structures at all strategic levels. Both views are described simultaneously for better understanding of the structure as a whole, and the corresponding functions to relate with the structures are also simultaneously described.

Figure -1 A depicts EPSE device 2 having a generally cylindrical body 4 except for a spindling upper ( or rear ) end 6, and a spindling lower ( leading ) end 8 that are dome shaped in their upper and lower surfaces. The upper Dome ( UD ) 10 and the lower Dome ( LD ) 12 are comprised of structures heavily reinforced in their thickness for a natural thrust needed during the navigation of the EPSE device in the well bore. Figure-1 A depicts the upper dome 10 showing the exterior face of a flange 14 of a metal ( preferably steel ) spool 16, with the central hollow 18 of the spool 16 traversing the center of the whole thickness of the dome 10.

Both figure-1 A and figure-2 A show the central structure of the EPSE device 2 that houses a wide bore steel tube 22 that functions as the EPSE body oil conduit ( of 5-10 cm diameter, similar to the diameter of the standard 'production tubing' ). The oil conduit tube 22 is connected to the hollowed structure 18 of the spool 16 of the dome 10 above, and the hollowed spool structure 24 of dome 12 below, thereby forming a continuous tube which functions as the petroleum oil conduit of the EPSE device that is also continued as lower oil inlet tube 26 below the LD 12, and as the oil outlet tube 28 above the UD 10. The oil outlet tube 28 has exterior threading that compliments the threading of the 'Oil Connecting and Stabilizing Unit' ( EOCS ) that is to be attached in segments to the EPSE ensemble during its progressive descent and measured navigation into the bore well. Both the metal spools housed in the domes 10 and 12 have plurality of joint bolts that pass through the whole thickness of the rubber domes, and are secured to the exterior and the interior flanges by metal screws in corresponding locations. Such arrangement reinforces the metal and rubber joint ( i.e. the spool and the dome joint ) apart from the conventional joining by rubber glue, contact cement etc. Obviously, the domes 10 and 12, and the corresponding upper and lower ends of the EPSE ensemble are lesser in their diameters compared to the rest of the body 4 of the device, as it is intended that the leading end maneuvers through the well bore by the thrust imparted by its thickness coupled with the spindled fore structure.

The additional structures of the lower dome 12 are pendulum-like structures 34, 3-4 in number, that are attached in equidistance to the perimeter of the exterior flange 36 of the dome 12. The heavy metal pendulum-like structures 34 add to some of the required weight needed for the thrust to navigate the device initially in the bore well, and further to counteract the buoyant effect of the EPSE device 2, in its stationed position in the bore well. When fully inflated to wedge tightly, such wedging of the EPSE device within the bore well also counteracts the buoyancy of the pneumatic device, before the ESUWH is incorporated. However, the EOCS unit with the robotic hold during and after its segmental attachments also serves such purpose, as will be described in the following.

After introduced into the bore well, the navigation of the EPSE device is a carefully measured and monitored process to effectuate its smooth descent, and to further successfully negotiate any sharp obstacles before its designated stationing in the well bore marked by wholly preserved integrity of the innermost casing at and below, as mapped out by video and / or sonar devices.

In accordance with the cut section of the vertical or the axial structural scheme of the pneumatic sealer ensemble EPSE of figure-1 A, the EPSE device embodies a sturdy but expansive rubber coat 38 which is the bodily continuum of the upper and lower domes 10 and 12 that together form the surface structure of the EPSE ensemble. The EPSE device as a whole is expansive like a car tire, within the maximum thickness allowable for the needed expansion, depending also upon the size needed for its expedition. Few hours or days after a catastrophic event, the deposition of the semisolid crude onto the uneven / sharp surfaces if any, makes the cave well of sojourn not particularly forbidding for the sealer ensemble, as it could be otherwise.

The embodiment further envisions that the rubber coat 38 that forms the protective capsule houses smaller air capsules 40, ranging about 6-8, in each of the two sets positioned as one above the other, and arranged in a circular manner like a whorl ( in its cross sectional design ) around a central oil conduit 22, as shown in figure-lA and figure-2A. The air capsules 40 are at least 2 feet in average length, giving an average total height of 5 feet to the EPSE device. Smaller or larger sizes can also be made as per the need. Each air capsule 40 seems cylindrical or spindle shaped in configuration, as viewed in the vertical cut section of the device. In a horizontal cross- section however, each air capsule 40 is not circular, but is spatulate, with its outer contour being expansive abutting the surface coat 38, and its sides tightly approximating its adjacent members ( see figure-2 A ) - creating a smooth circular outer contour to the device as a whole, with no indentations between the member air capsules that can otherwise allow oil leak ( vs. circular cross-sectional configuration of the air capsules that may create deep surface indentations ). The air capsules 40 are made of very expansive vulcanized rubber. Of the two similar sets of circularly arranged air capsules 40, the members of the upper set 44 are adjacent to the upper dome 10, and are attached at their upper ends, to the lower free surface of the upper dome 10. The lower set of air capsules 46 is adjacent to the lower dome 12, and the lower ends of the capsule members are attached to the upper free surface of the lower dome 12. Accordingly, when any one or more of the air capsules 40 deflate by sustaining a puncture, it / they will collapse towards the

attachment(s), above or below. The upper and lower sets 44 and 46 are separated by a

membranous partition 42, extending horizontally throughout, into the center of the interior, from the surface coat 38.

Each air capsule 40 has its own tubular connection 48, said tubing connecting the air capsule 40 to the air source. From the lower set 46, all the tubing is devised to emerge from the upper ends of the air capsules. From the upper set 44, they emerge from the bottom. Both the sets converge over the membrane 42 to ultimately travel as a single bundle to be enclosed in a sheath of non- compressible vulcanized rubber hose 20 that travels in close proximity with the EPSE body oil conduit 22, and further above with the oil conduit outlet tube 28. It may temporarily dissociate where the oil conduit tube has to be incorporated into the well head structure of the ESUWH, to approximate again with the oil conduit tube in its further course, to finally dissociate to reach the destination of air pumping and air pressure monitoring unit.

A second or third set of tubing can start where ever is needed, the individual tubes connected to the corresponding tubes by a secure articulation, both tubing being similarly color coded. The tubes originating from the upper set 44 can have colors with intercepting black-banding, whereas the lower set 46 can have similar color without bands for the correspondingly positioned capsule members. The sets travel together ( to the destination of the air pressure monitoring unit ) in a weather resistant metal ( helically wound ) covered vulcanized rubber hose ( with scattered eyelets for needed anchorage ) colored outwardly as RED. The corresponding vertical pair of air capsules in sets 44 and 46 are similarly numbered, except that the capsule members of the upper set 44 are marked with U next to the number, whereas the capsule members of the lower set 46 are marked with L next to the number. Said pattern of color-coding is also observed for the additional sets of extension tubes to the point of their termination in the pressure monitoring unit. For the internal orientation of the numbered and tubule-matched individual capsule members within the EPSE device, at least one member's position has to be indexed with an emblem of an asymmetrical rubber / metal design ( to identify clockwise or anticlockwise directions ) situated on the upper dome 10, to be identified by sonar devices, so that all the air capsule members can be properly oriented within the EPSE device. The oriented positions of the emerging rubber hoses 20 and 32 ( the details of the latter encountered in the following paragraphs ) with respect to the metal emblem and oil conduit tube 22 / 28, and further with the adjacent air capsules comprising the sets 44 and 46 with their assigned numbers and the corresponding color coding of their tubules, as shall be diagrammatically mapped out by the manufacturer in vertical and cross sectional views, can also act as such markers of positional orientation of the individual capsule members.

If necessary, articulation of the first and second sets of the air tubules of the travelling air hose 20 in the open and turbulent ocean waters has to be carefully planned, and must be done with due regard for correct articulation as well as air tight sealing required of each. At any articulation site, the vulcanized rubber hose housing the tubular members enlarges to be housed in a hemispherical metal structure, or any such suitable structure that articulates with similar structure of the second set. The tubular members are fitted with metal terminals that also enlarge in size, and have the color matched numbers engraved on them for proper articulation with the corresponding members of the second set similarly sized, and have color matched numbers also engraved. Such enlargement facilitates optimally configured larger size suitable even for robotic articulation. Figure-3 shows a joint articulation of the travelling air tubules with a sliding screw arrangement typically suitable in this setting. The articulating tubing of the first and second sets 50 and 52 of the joint articulation has similar threading externally, for substantial lengths of the joint terminal / origin. A sliding screw 54 having complimentary threading internally, and an internal diameter of a size that accommodates the external diameter of the first and second set terminal / origin 50 and 52, is a suitable type of joint in this setting. To start with, the sliding joint-screw 54 is situated completely on any one of the articulating members leaving its end exposed, as shown in the figure-3. The ends 50 and 52 of the articulating members are snapped into approximation by needed design 56. In that position, the sliding screw 54 is slid over the corresponding articulating member by rotating movement through its inner complimentary threading, so that it covers equal lengths of the members 50 and 52 of the joint. The rubber tubing 55 of the second set starts within the metal enclosure. After proper articulation of the terminals similar to 50 and 52 of the travelling air hose 20, the hemispherical enclosures are snapped close, securing the joint terminals inside. The enclosures are further secured by eyelets locked with sufficient caliber metal wire, its two ends making a number of secure twists over each other - a closure that can resist undoing by turbulent tides of the ocean in adverse weather. Similar articulation with a new tubing just outside the EPSE unit should be possible, in case the original rubber hose of the EPSE unit at any level is broken, though an enclosure is not needed at this level. It is very important that the manufacturer certifies the patency and functionality of the tubing and of the sealing device by actual prior testing of each unit ( with a statement to that effect, instead of the company's 'warranty of assumption', usually done as a routine ), a mandate needed of an emergency device to be preferably stocked in an off-shore work-unit. All the air capsules 40 are guarded by automatic mechanical one way check valves 58 in the place where the tubes 48 enter the capsules. The valve allows air flow in only one direction, that is, towards the air capsule from its tubular connection 48, and closes shut in the other direction. It is a safety device that precludes the entry of liquid / gas petroleum into the rest of the air circuit system if any one of the air capsules sustains a puncture.

It is necessary to deflate the air capsules 40 when the EPSE device has to be taken out of the bore well. It can be done by a simple plan. The ends of the air capsules 40 adjacent to the upper and lower domes 10 and 12, are devised to be connected to a set of tubing 60, and each in the set of the said capsular tubing 60 is similarly color coded as the corresponding capsular tubule 48 of the inflating set described earlier, and the set of tubing 60 also travel with the air tubing hose 20 to the air monitoring unit in a different vulcanized metal covered rubber hose 32, colored GREEN ( with eye lets scattered at places for needed anchorage ). The deflating set 60 can also arise from the air capsules 40 on the same side of the origin of the inflating set 48. The deflating air tubing set 60 is not provided with any type of mechanical valves. At the monitoring terminal, the air tubes 60 emerging from the GREEN hose 32, to start with are sealed or clamped, and are kept as such until the EPSE device needs to be deflated. During deflation, the seals or the clamps are opened, when air gets out of all the air capsules. It is imperative that the clamp of any punctured capsule is not opened ( as oil can find its way into the system ) until the EPSE unit is taken out of the oil well. The air escapes with some pressure from the intact capsules. The articulation of the first and second sets of the travelling air hose 32 of the deflating tubular unit is similar to that of the inflating tubular unit of the air hose 20, earlier described.

The two rubber hoses 20 and 32 of the air tubing of the EPSE device can be anchored to the oil conduit EOCS unit tubing ( described in the following section ), as it is elongated in the well bore. The metal eyelets that are incorporated to the outside of the air tubing system travelling in the form of rubber hoses 20 and 32 can be tied to the EOCS unit at the places where its snapping locks are placed, making a twisting knot with the metal wires through the U latch of the lock. Such close approximation stabilizes and strengthens the air tubing system in its sojourn through the well bore. The air tubing system being incorporated into a rubber hose which itself has a thick metal helix as its wall, is a safeguard to be kept diagonally uncompressible, and further to resist inadvertent attacks by the marine life forms, beyond the well.

Pressure monitoring for each air capsule 40 is separately done, and when the sealer EPSE ensemble is stationed in a suitable place in the bore well, all the air capsules 40 are filled equally to optimum pressure ( that was previously calibrated by the manufacturers ), and ascertained that the assembly as a unit is definitely enlarged to dimensions that far exceed the dimensions of the bore well, however below the safely attainable maximum pressure, which is separated by 'burst pressure' by a reasonable safety margin. Such built-in dimensions and prior calibrations allow the air capsule(s) to be further expanded and take over the space and volume of a lost member, by accidental puncture, thereby making no significant loss in the surface contour of approximation to the bore well interior. When a single member is lost by a gradual leak or by a leak due to explosive burst, it will be reflected in its pressure record, as either a gradual loss or as a precipitous fall respectively. When pressure fall is observed in one monitor, the adjacent monitors are to be immediately observed to note if two other are showing gradual falling in their pressures, but stabilized after a lapse of time. These are reflective of the two adjacent members that are losing the pressure due to loss of surface tension, but not air volume. They can be differentiated by their ability to build back their pressures by pumping more air, whereas it is not possible with the member that was punctured. When such situation is encountered, the two adjacent capsules are to be expanded to their maximum allowable pressures, so that they can fully or partially replace the loss of air volume, and correct the gaps in the contour created in the upper or in the lower unit. If there is a gradual or a precipitous fall simultaneously in more than one air capsule not correctable by pumping of more air, it denotes that the damage is not localized, and that a wider area with puncture to multiple air capsules 40 is involved.

Devising the EPSE with upper and lower sets 44 and 46 of air capsules is to maintain the inflated surface contour of the device as a whole, as at least one among the two of the air capsules in a corresponding vertical position may escape puncture in a rough sojourn through the bore well, though the devised structure in this regard demands more involved design, also necessitating intensive monitoring. However, the detrimental consequences of the related calamities call forth such requisites, and a simpler design, also herein specified, can be chosen if a smooth descent of the EPSE unit in an intact bore well is reasonably expected.

The disclosed EPSE device may not be limited to the described structure, and any other creative additions can also be added to the basic assembly. An additional set of un-inflated members of air capsules 62 can also be incorporated within the device in reserve, to take over the place of a corresponding lost capsule. This can be done by devising each inflating tube 48 to be having two separate lumens to bifurcate at the level of the air capsule to establish connections with the inflated and the un-inflated reserve capsules separately. Both the sets are similarly structured with the provisions of the valves 58, and the deflating tubes 60. The lumens of the tubes 48 similarly bifurcate at the air pressure monitoring unit, and the lumens of the un-inflated reserve set are temporarily clamped, and any one opened only when its inflated counterpart is punctured. It may be noted that through puncturing of its counterpart, the un-inflated member will not establish connections with its luminal system for the simple reason that the two luminal systems are practically separate throughout, though structured as conjoined tubes, except at the bifurcations of both the terminals, and this structurally separate unit is simply not used, meaning it is not air- inflated until subsequently, when needed. The members of the reserve set 62 are attached to the upper and lower surfaces of the central partition 42 of the EPSE device, and are structured to be packed-in to stay in close proximity with the central oil conduit tube 22 ( see figure-2 A ). This arrangement is to not to distort the contour of the inflated capsules peripherally. When any inflated member of the upper set collapses towards the upper dome 10, the corresponding member of the upper reserve set 62 expands above towards the upper dome 10, whereas the member of the lower set 62 similarly expands below towards the lower dome 12, to take over the position of any corresponding lost members of the lower set. The air tubules 48 of the first inflated capsules are coiled like a telephone cord at their entry into the air capsules, to allow their movements towards the domes 10 and 12, as their corresponding new members are expanded by inflation, to take their position. The bifurcated tubes corresponding to the first inflated air capsules of the sets 44 and 46 ( attached to the domes ) at the air monitoring terminal are strikingly thickened, to differentiate as the first set to be inflated, as their conjoined counterparts are similarly color coded. The reserve unit is an accessory option, and not a structural mandate of the basic EPSE device. The whole EPSE device can be replaced also if there is a puncture with significant oil leak through loss of contour, in a design without a reserve set. However, such punctures may be sustained again during the passage of the EPSE device through a damaged well casing, and the situation may not be any better despite duplication of efforts. The incentive for the inclusion of a reserve set of air capsules demanding involved design of the EPSE is that it removes uncertainty with anxious anticipation primarily due to the assurance of safe inflation of the well-guarded reserve set in the stationed position of the device, after the obstacles are passed.

The company manufacturing the device pre-calibrates the optimal maximum pressure and the burst pressure for the individual air capsules 40 of the EPSE device. Said optimal maximum pressure also represents the pressure allowable with safety margin for the individual air capsule 40 when 1-2 of the adjacent members are lost, whereas it is less when each capsule is inflated as a member of its set wherein all are intact and inflated. Such submaximal pressures are calibrated for a particular size EPSE device to be securely wedging in a particular diameter casing annulus. These distinct numbers should be always readily available.

Integration of sonar equipment and monitoring can be done by outside equipment attached below and above the ensemble by any suitable means ( the equipment can be securely anchored to the first articulating segment of the EOCS Unit ). They can hover around clockwise or anti-clockwise by remote control, to monitor any area precisely as needed.

THE EMERGENCY PNEUMATIC 'SIMPLE SEALING ENSEMBLE' ( THE SSE )

The EPSEU is also built encompassing a simple design, called as an Emergency pneumatic 'Simple Sealing Ensemble' ( SSE ), shown in Figure-1 B and Figure-2 B. The device of 'Simple Sealing Ensemble' 7 comprises a single air capsule 41 enclosed in a rubber coat 38 and is more easily expandable by virtue of its single air capsule compartment. Its accessory provisions are similar to a typical air capsule described in the previous EPSE design. It has one reserve capsule 15, and is fitted with a one way valve 58, a single inflating tube 48, and a single deflating tube 60. The device as a whole is structured like a car tire in its cross section, but many times its height ( and with upper and lower domes 10 and 12 ), to cover sufficient vertical height in the well bore. It has a less involved design, and accordingly, is an easy maintenance.

The air capsule 41 to be inflated first in the SSE is attached to the center 13 of the outer coat 38 of the device, and expands in all dimensions, especially inwards, as it is inflated. The reserve member 15 has its attachment in the center 17 of a rubber sheath 31 that surrounds the oil conduit 22, and expands mostly outwards when inflated. By virtue of its well-guarded position, the reserve member 15 is protected against any surface trauma. Because of the limited number of the connecting air tubing involved, they are easily color coded, and travel in a single hose 19 to the air pressure monitoring station. The detailed functionally oriented structure of the single air capsule 41 and the extension tubular system of the SSE device 7 is comparable to the involved design of the EPSE device described in the foregoing paragraphs including the sliding screw articulation model of the second / third sets of travelling air tubes of the inflating / deflating tubular systems. Similarly, its outer physical structure encompassing the inlet and outlet oil- conduit tubes ( 26 and 28 ) in continuum with the spool cylinders 18 and 24, the means of sonar monitoring, and its articulation with the EOCS unit are comparable to the EPSE device. Some similar strategic features are shown in the figure-l B and figure-2 B, also along with features that are dissimilar. The device's different pressure calibrations are also supplied by the manufacturers. For oil wells with no injury sustained to the interior of the innermost casing, the SSE can be a suitable model, and should be a chosen design for its less time taking installment, and simple monitoring techniques. The central oil conduit is identically structured, and the air inflating pressure-monitoring, and further, the deflating are similarly done, as in the previously detailed EPSE device.

THE EMERGENCY OIL CONNECTING AND STABILIZING UNIT ( EOCS UNIT ) OF THE EPSE / SSE DEVICE

The 'Emergency Oil Connecting and Stabilizing Unit' ( EOCS unit ) is an embodiment that stabilizes the EPSE / SSE device against its inherent buoyant effects, and that further connects it to the surface structures, thereby acting also as a connecting oil conduit. The EOCS unit is made of segmental, or of a straight-tube configuration. Mechanical counter-force from above is the best way of stabilizing the pneumatic device anywhere in the bore well. The EOCS unit achieves that purpose, being also secured by surface anchorage. The EPSE / SSE device within itself has few feet of oil conduit pipe 22. The EOCS unit is its connecting oil conduit added as 2.5 feet segments to a required length, to be terminally connected to the ESUWH at the well surface. Straight tubing similar to the 'production tubing' in its structure can also be elected in the case of an EOCS unit of a straight tube configuration, conforming to its partial or whole axial length, in suitable setting as when the bore well to be navigated is straight with no significant obstacles to maneuver through.

Each said segment that is successively attached to the EPSE / SSE device is configured to be of metal tubing with threading on both ends that articulates with adjacent EOCS segments with complimentary threading. The articulations are tightened with rubber washers, and locked through eye-let holes of both segments that approximate when the segmental articulation is completely threaded and tightened. The eye-let joint is secured by a snapping lock similar to the one encountered in daily use for locking suit-cases, shelves etc. Said snapped locking can be very quickly accomplished even by robotic devices. By successive additions, one at a time, the tubing shall be progressively lengthened to the distance where the EPSE / SSE is required to be stationed in the bore- well. The individual segment members can be chosen as long as possible, for easy and rapid elongation, the average range being 2.5 - 5 feet, though other sizes are not precluded, including a very long single tube, in suitable bore holes. After the EPSE / SSE device is stationed at the destined depth in the bore well, the last segment is added which is configured differently, that after its emergence from the bore well on the surface, the tubing shall have structural configuration similar to the standard 'production tubing', to be connected at the well surface to the devised well head-like structure of the ESUWH.

The place and depth where the EPSE / SSE unit has to be stationed are mapped with sonar and video devices, and the depth accordingly maintained, by addition of the needed tubing that are also measurable. With each segment as big as 5 feet, and their secure articulations made in a snapping few seconds, the navigation of the EPSE / SSE device within the bore well tends to progress in a swift manner required of a catastrophic setting.

The rubber hose / air tubing of the EPSE / SSE device can be anchored to the EOCS unit as it is elongated. The metal eye-lets that are devised outside the air tubing system can be tied to the EOCS unit at places where the snapping locks are placed, making a twisting knot with metal wires through the U of the lock. Such close approximation stabilizes and strengthens the air tubing system in its further course from the EPSE / SSE device.

( 2 ) THE EMERGENCY STABILIZING UNIT WITH A WELL-HEAD LIKE DEVICE ( ESUWH ) -

The prototype embodiment of an 'Emergency Stabilizing Unit with a Well Head-like Device' ( ESUWH ) stabilizes and sustains the EPSE / SSE device with the EOCS unit incorporated. It is instrumental in overcoming the buoyancy effects of the pneumatic sealers, such buoyancy further compounded by the well pressure from below that the EPSE / SSE unit cannot resist, though its inbuilt oil conduit to let out the oil is deemed to optimize the well pressure to certain extent. The said prototype embodiment of the ESUWH unit is a heavy weight device, made of steel, many tons in weight, structured like a round topped table incorporating 3-4 outwardly spanning legs with widening bottoms, to be drilled into and firmly cemented to the sea floor, a task deemed to be secure, yet can be easily and urgently accomplished. Its top of exceeding diameter has a central hole ( to resemble a bore hole with the diameter of the first casing cemented earlier but obviously / unobviously damaged, the diameter of the latter in one of its different marketed sizes being the 'corresponding diameter ' for the ESUWH to be chosen ) to accommodate a well head like structure - with casing hanger and other similar structures below, and with provisions on the top to incorporate a BOP that connects to the drilling riser. It is implied that the pre-explosion well head and its structures are totally damaged / wiped out ( as in BP' s Horizon oil well blowout ), or else taken out of the way being proven dysfunctional. The circumference on the ocean grounds about the outwardly spanning legs of the ESUWH unit is chosen to surpass the circumference encompassing the maximum 'Diameter Of Disruption' ( DOD ) at the well head, and the ESUWH is configured to be incorporated into the soon to be constructed permanent 'Emergency Isolation Platform' ( EIP ) about the well head, described in the following section-4. The ESUWH unit can have a higher circumferential measure by means of additionally having articulating extra-pieces projecting outwardly in equidistance, and incorporating the top's detachable legs. A sufficient overlap of the said radially adjustable pieces makes a firm and stronger articulation.

It is not labor intensive to cement the ESUWH device, and for such operation, the base-piece of the drilling conductor at the well head is dismantled, in case it is in-situ. The three / four legs of the ESUWH spread out from the well area avoid and surpass the ground area of the 'Diameter Of Disruption' ( DOD ), as is the aim during its installment. The center of the devised table top of the ESUWH with a central circular passage-hole within, is thickened or elaborated to house and stabilize the components needed for the well head-like structures. It is installed by robotic devices at the well head, as the needed manipulations are less complex. The ESUWH unit can be structured as: (1) 3-4 peripheral pieces of similar size and configuration articulating with the central circular piece with sufficiently firm overlap that is radially adjustable, with legs to be further incorporated, and (2) a separate circular central piece to embody the unit of table-top like structure described in the fore going, with legs to be further incorporated, with also provisions to be articulating if needed, with the peripheral structures as in (1) in the foregoing - both to be assembled on the ocean-bed over the well surface by any method feasible and secure, such on-site operation aiming to surpass the variable DOD. It implies, the structure (1) is optional and an accessory.

The structure of the base-piece of the drilling conductor soon to be deployed is devised to be bigger than the ESUWH. The base piece in-situ of the drilling conductor must be dismantled in all situations, to be fitted with a new base-piece devised to be structured as a funneled-sleeve required of the operation, however with the rest of the core structure of the functional unit and its articulating ends unchanged. The later structural incorporation of the ESUWH, substantively suited as a permanent metal frame / scaffold of the cemented Emergency Isolation Platform ( EIP ) soon to be constructed at the well surface, is described in section-4. ( 3 ) THE EMERGENCY PLUGGING OIL CONDUIT ( EPOC ) -

The 'Emergency Plugging Oil Conduit' ( EPOC ) is a prototype embodiment that effectively plugs the 'production tubing' of a fully constructed well, if the said tubing is damaged for whatever cause. Such damage can be cracks with oil leak, fractures involving substantial circumference, or it can be a total disconnect. Such damage to 'production tubing' is usually located near the surface. Most packer hardware of the 'production tubing' is permanent and requires milling in order to remove them from the production casing. If it is a retrievable packer, it can be easily removed.

Future models of 'production tubing' with threaded configuration can be easily closed with sturdy- structured closing caps, or conjoined by threaded segments ( both with complimentary threading ) establishing a new connection of oil conduit. But for old models with plain tubing and permanent packers, the situation can be riddled with problems, for an emergency repair or replacement. However, it is easy to electively reinstall a threaded 'production tubing' if so planned.

Accordingly, if a plain-tubing is in-situ, as an emergency measure, the leaking oil-conduit production tubing must be plugged, to occlude the leaks, and a new oil-conduit created within the plugged tubing lumen. The new oil-conduit must further communicate with the well-head like structure of the ESUWH, at the well surface. The EPOC is doable at a very early stage when pressure within the oil-containment is not built-up to a significant degree by the sea water finding its way into the underground oil-containment reservoir.

As schematically illustrated in figure-4, the embodiment of an 'Emergency Plugging Oil Conduit' ( EPOC ) comprises a metal ( steel ) tube with its diameter designed to be 1-2 cm smaller than the in-situ 'production tubing' ( of 5-10 cm standard diameter ), and further incorporating a rubber sheath outside, on most of its length. It is necessary that the upper component of the distorted or fractured in-situ 'production tubing' is completely severed, and taken out of the way. The EPOC 300 is configured in variable standard lengths of many feet, to be passed into sufficient depth, through the open upper part 304 of the remaining lower component 302 of the 'production tubing', for a reliable occlusion through a substantial length. The EPOC 300 has metal component 314 that is made of steel. The lower terminal end 306 of the metal component 314 is slightly narrowed, and has a conical rim, for easy maneuvering in its passage. The metal component 314 of the EPOC 300 is capsulated over most of its length with a strong and expandable vulcanized rubber sheath 308 that is connected at its upper end to an air source 310, through a tubing of vulcanized rubber 312. The air tubing 312 is covered with a strong helical metal wire, and travels with the emerging oil-conduit metal tube 316, to dissociate only to reach the destination of air source, also having one or two joint connections on its way, if needed - a scheme similar to the travelling air tubes of the EPSE unit described earlier.

After the EPOC 300 is passed to a required depth into the remaining lower component of the production tubing 302, the outer capsular rubber sheath 308 is inflated through the inflating air tube 312 to completely plug the tube 302 across its entire circumference, and throughout the length that the EPOC device 300 is passed into. After the full and required inflation of the rubber sheath 308, the tubing 312 is clamped at the monitoring terminal all the time, except to optimize the pressure within the pneumatic capsule / rubber sheath 308 by pumping more air, if the pressure is found below the calibrated optimum. Oil can pass up through the lumen of the metal tube 314 / 316. At its lower terminal 306, the tubing 314 is devoid of the rubber sheath 308 so as to ensure the tip of the tubing 314 to stay patent, and not to be occluded by the ballooning of the tip of the air-filled capsule 308. The upper end 316 of the metal tubing 314 that is connected to the well-head like structure 318 of the ESUWH device is configured in a compatible manner resembling a 'production tubing', to be hung to the tubing hanger about the well-head like device of the ESUWH.

Very early plugging of the oil-conduit accomplishes the most important goal of preventing the sea water finding its way into the oil containment. Any delay can otherwise cause dangerous pressure to build up, making every sealing maneuver at this time difficult or virtually impossible. If the inciting calamity is a well blow-out at the surface, sealing the production tubing in the manner described prevents sea water finding its way into the oil containment, despite the prevailing breaches in the innermost casing, as usually the damaged production tubing near the surface is the source of dangerous compromise in this situation, as the integrity of the lower completion is usually preserved.

With the plugging of the oil-conduit accomplished, it is easy to concentrate on the reparative measures, that is, the construction of the Emergency Isolation Platform ( EBP ) incorporating the ESUWH, as the well surface is deemed to be clean at this time, without the petroleum / crude oil / gas contaminating the sea water.

( 4 ) THE EMERGENCY ISOLATION PLATFORM ( EIP ) AT THE WELL HEAD -

Emergency installment of conduction platform and drilling conductor is essential as soon as the rig and its connections to the oil-well are destroyed, or found dysfunctional. The structure of the base piece of the drilling conductor is devised to be far bigger ( as an average of 50-60", whereas the higher dimensions are to be ordered urgently, a few days of wait time being acceptable, after the suitable emergency sealing device is installed into the bore well ) than the presently manufactured and available maximum size, and the said base piece is configured as inverted funnel shaped to encircle the destroyed leaking bore well and isolate it from the rest of the oceanic bed.

If the rig is damaged, stationing a basic portable rig with its functional conduction platform is a measure that saves precious and precarious time ( incorporating and stationing of an Emergency Detachable Island Rig, the DIR., is a measure highly desirable for the oil companies ). A high reliability drilling riser that also functionally controls the BOP is paramount, and also cementing the NEW REPARATIVE CASING, smaller than and overlying the breached first string of the INNERMOST CASING by the conventional process of circulating cement slurry into the casing shoe and the annulus and pumping through a plug and displacement fluid is central to the permanent and salvaging theme of the invention.

The footage of the detachable funnel base piece ( sleeve ) 142 of the drilling conductor is chosen to be about 30-40" wider than the largest diameter that defines the 'Diameter Of Disruption' ( DOD ) of the ocean floor about the well head, and should surpass the outer diameter of the conductor casing ( the first casing ). Such circumferential intact ocean floor is essential to drill a hole into the sea bed and then running the funnel base into the hole and cementing ( 143 ). There needs to be further stable ground within the funnel base piece, to construct a new cemented wellhead platform for incorporating the table-top well head like structure of the ESUWH, wherein the cementing of a new 'reparative casing' of 1 or 2 strings depth is actuated, to seal all the fractures and breaches of the well bore.

The said funneled base piece 142 is of varying dimensions with the rest of the structure unchanged, including its joint with the piece immediately above. Imprecision being immaterial, the in situ cemented base piece of the drilling conductor can be severed from the sea floor by whatever means feasible ( as any of its sea-ground remains are being cemented over, when the EIP is constructed ). There must be reliable means to mechanically support the tubular of the drilling conductor above in the midst of ocean tides, as the supporting base piece is dismantled, in case dismantling the whole drilling conductor that is fully functional otherwise is not a choice, while the ESUWH is installed. Suspending each joint of the drilling conductor to a stable surface structure separately by metal chains on either side can be a choice, in case a secure surface suspension is doubtful.

Figure-5 shows the schematic model of the reparative construction at the well head involving a proposed model device of a detachable / attachable base structure of the drilling conductor 140. The said base structure typically has an inverted funnel-shaped base piece 142. If the damage at the well head is significant, the intact solid ground 144 around which the new conductor 140 rests should be sufficiently wide for a secure footage. As the funnel base piece is cemented, an overhanging / embedding sea floor 143 is created for more secure base structure, with a slab of cement, by means of using QUIKRETTE, Hydraulic Water Stop Cement ( number 1126 ), a high strength material with quick consolidating properties even while wet, and available as above or below grade strengths, suitable for quick setting in 3-5 minutes. Manipulations by robotic arms are needed to aid the proposed overall construction. Within the tent like space on the top of the well head, created by the inverted funnel base, flexible steel metal sheets are wrapped around the metal legs of the ESUWH structure that was already installed. Cement slurry is poured around the metal sheets to tightly pack the space around it, as far as the boundary formed by the funnel base 142. It creates the elevated area 160 shown in the figure-5, forming a circumferential boundary of the circular room like area about the damaged well surface 154, said boundary surpassing the Diameter Of Disruption ( DOD ). The circular heightened cemented platform 146 conforming to the area 160 is built to be in flush with a centrally situated roof like design 148 formed by the well head like table top 152 of the ESUWH incorporating the structure 147, the latter with a diameter similar to the well's FIRST CASING. Such structuring is a means of bypassing the real or presumptively damaged ground 154, comprising the tops of the old casings 157. The damaged ground 154 can be covered with a metal sheet of similar dimensions with perforations to let out oil / gas emissions to the surface, but not the ground sludge, though in few days the ground settles and consolidates.

A new REPARATIVE CASING 150 ( smaller in diameter than the innermost casing that was previously installed in the casing set of 157 ), and an oil conduit 'production tubing' 156 pass through the center of the cemented roof, being suspended from the well head like structure 152, and hung to the incorporated tubing hanger, the latter having additional provision for the new smaller casing to be hung, a structural limitation of the devised well head. The cement structuring 141 covers more of the circumferential dimension over the rim of the funnel 142, to further strengthen the cemented area 143, where the funnel base was originally cemented. The above sequence of construction has to be carefully planned. In wells where there was a blow out with the well leaking at the top, and there are ocean craters spilling oil, but no obvious ground damage identified at the well head by a reasonable search, a new REPARATIVE CASING ( involving one casing string, and more if the video / sonar imaging so indicates ) smaller than the well's innermost casing can be cemented in the usual manner without the need of constructing a cemented platform, an easier operation that can be quickly done, obviously with the prior placement of the EPSE sealing the well bore below, to be removed soon after. However, a provision for the smaller tubing to be hung should be additionally incorporated into the existing tubing hanger of the in-situ well head, if necessary. The new casing can seal any possible leaks into the ocean in the vicinity of the well. This is a very important preventive measure to be undertaken very early on, a better time to intervene, and must be integrated in the protocol of environmental control, whenever oil leak is observed at the well head after an adverse event. Reparative casing 150, smaller in diameter than the smallest available casing at present, should be manufactured, and available to those who used the smallest available casing as the innermost. Smaller sizes are readily available for the rest.

If it is a concern to the oil company that the redundant space under the funnel base may cause the straight component of the drilling conductor above to cave in, such space can be completely filled-in with cement ( up to the junction of the straight and the funneling components of the base piece ). If such a design is contemplated, the inverted J tube 166 and the straight tube 168

( detailed in the subsequent paragraphs ) are structured in the roof of the EBP to be nearer to the reparative casing 150. As the base component 140 is detachable as it is attachable, the rest of the drilling conductor above it can be completely taken out when it is so decided at a later date.

If there is any surface explosion, usually the second string of the innermost casing ( that is well bore deeper than 40 feet or 12 meters from the surface ) is spared from any damage to the inside of the casement, and for this reason, installment of the first string alone can be sufficient. Video and / or sonar devices can be used to specifically examine the junction of the first and second string, and few feet below. To cement the NEW REPARATIVE CASING, overlying the first string of the innermost casing, the conventional process can be employed by circulating cement slurry into the casing shoe and the annulus, pumping through a plug and displacement fluid. At this time, the EPSE / SSE device can be lowered into the well bore beyond the depth of the first string, and its oil outlet tube 28 capped with metal cap having complimentary threading, as also it can be assumed that pressure in the oil containment is optimized by this time. The EOCS unit is disconnected for this purpose. Pressure recordings beyond the EPSE unit can also be documented for any concerns. Optimum pressure within the EPSE / SSE device, and tight wedging are paramount at this time to overcome the buoyant effects.

If it is a EPOC device plugging the 'conduction tube' that was in place as an emergency sealing device of the leaking well, it needs to be completely taken out along with the whole of the conduction tubing at this time, to station the EPSE device below the level of the first string, its oil conduit capped, for cementing the reparative casing. If second string of the casing is found to be damaged by video or sonar devices, the EPSE device needs to be stationed below the junction of the second and third casing string, to cement a second string also.

With the foregoing structuring of the well head platform, it may not be assumed that the problem of oil leak from the well bore and the oil containment is thoroughly solved. It is not prudent to assume that the cementing of the REPARATIVE CASING can be accomplished in a perfect manner as it can be done for a new construction. A second blow-out, and an anxious anticipation must be ruled out by all means in this labor intensive restoration, while also hoping for a successful well salvage. To that effect, some simple remedial measures can be easily implemented during the construction of the well head platform. Oil let-out pipes as exemplified below, can be embedded within the roof of the cemented platform, so that any oil spill is let out. These oil let- out pipes are further fitted with one way check valves to only let out the oil / gas possibly emanating from the damaged well grounds 154.

1. A moderately sized tube 168 can be embedded in the roof of the cement platform with its inlet opening into the space 158, said tube fitted with one way check valves at strategic places, and the tube 168 courses up to be joining the main pipe, at any suitable level. The valves allow only the outlet pipe 168 to empty any collection of oil / gas into the main oil pipe. The one way valves can be multiple ( at the level of the cement platform and at the level of main oil pipe ), to improve efficiency. The tube 168 is inverted L shaped, its horizontal limb entering the main oil pipe at 90° . Mechanical forces set up for the oil to flow upwards also help the entry tube to empty into the main oil pipe, and not the other way. The tube 168 is operative most of the times except when the main oil pipe or its connection is disrupted, though the Emergency Isolation Platform ( EIP ) is otherwise structurally and functionally intact, in which case the tube 168 is capped, and the J tube ( 166 ) ( described below ) is left open, to mitigate pressure build-up due to oil / gas collection within the enclosure of the EIP about the well head. 2. A moderately sized tube 166, inverted J shape in configuration, is set forth in the roof of the emergency isolation platform ( EIP ), fitted with one way valves to let-out only oil / gas, but not to let the sea water in. Through a threaded configuration its outlet can be capped or uncapped. Its inlet is dipping into the space 158 of the EEP, whereas its outlet is outside the cemented platform ( EIP ), thus traversing the thickness of the involved sloping cemented platform 146 of the newly constructed structure. The inverted J tube 166 is configured to let the oil / gas out from within the enclosure of the cemented platform in situations when the straight tube 168 is not operative, and the intact EIP is in open sea. In such circumstances the usually capped J tube 166 is uncapped to let out any built-in oil / gas from within the cemented platform.

Because of the inverted J shape with its outlet terminal facing downwards towards the ocean floor, any hydrostatic pressure due to true vertical height ( TVH ) of sea water at this level and is exerted on the one way valves of the tube 166 is minimized ( see the paragraph below ) though positioned within an open sea ( see also the below specified Pascal's law, not operative in this situation of unconfined body of sea water ). Contamination of ocean waters with oil / gas due to emissions from J tube 166 is minimal, as it is capped after the restoration of the inverted L tube and the collecting tube, that is sooner than it would be otherwise, due to the devised threaded configuration all through the length, of the entire tubular system of the oil well / rig. The J tubes can be more than one in moderate sizes to ensure their intended function.

In the body of sea water, the pressure at the surface ( the sea level ) is equal to the atmospheric pressure, that is 760 mm / Hg, but the pressure rises 1 mm / Hg for each 13.6 mm distance below the surface. Though this 'hydrostatic pressure' at any point results from the weight of the vertical column of water above it, the hydrostatic pressure of the deep sea exerted on the valves of the inverted J tubes 166 in this situation is immaterial for the reason that only the height of the column of fluid vertically above ( 'true vertical height ', the TVH ) any point of concern is what contributes to such hydrostatic pressure as in a situation where a tube has its opening facing upwards, and thus subjected to the direct effects of TVH. Furthermore, the Pascal's law ( the pressure exerted at any point in a closed body of fluid is equally exerted at all points with in that closed space ) is also not applicable in this situation, and hence the hydrostatic pressure at the tip of the inverted J tube 166 is not subject to the effects of hydrostatic pressure from any other point in an open body of the adjacent sea water.

If the destroyed rig is not functional, any small portable rig with needed basic requirements for the planned structuring can be employed, and the subsequent oil collection can be done in any manner feasible, as many avenues are available for this purpose. The DIR is favored mostly for the safety of the crew and for the safety of the ecosystem adjacent, with the sense of security that comes along with it. Threat to the oil company falling into disrepute, diminished morale, and disparaging legal implications of massive and widespread pollution, are also undeniable factors to consider. As the costly equipment, or the rig as a whole is invariably insured, the economics of the situation may not be the greatest concern for the oil companies. It is a good idea that the well salvaging devices described in this invention are stored elsewhere by the oil company to be readily assessable soon after a catastrophic event, as most of the emergency devices described herein, are structured in easily portable sizes. In rigs with DIR, they can be stored in the underwater basement, as it is a structure deemed to be preserved even after a fire, and shall continue to serve as the all-time power house off shore.

MULTIPLE LEAKING CRATERS IN THE OCEAN FLOOR -

If oil leak at different areas of the ocean floor is located by hovering airplanes, minimally filled-in appropriately sized balloons can be used to seal the ocean craters, and then permanently plug on the solid scaffold formed by the pneumatic sealer, by a structural combination of metal mesh and hydraulic water stop cement 1 126 ( QUIKRETTE ). With reparative permanent casing and cement sealing of the bore well, such craters are certain to lose their connections to the oil well bore. The ocean body has to be carefully surveyed to spot the areas of identified past spillage, if they were of significant size and number, and at this later date, they are not expected to be seen.

( 5 ) THREADED INSTANT JOINT CONFIGURATIONS

The invention further envisions a model of tubing directed to all tubular systems, and their methods of instant system joining or closing, for all future oil exploration units, or as a replacement-tubing for existing units. The model of tubular systems are structured to be having a deep threaded configuration on the inside or the outside, traversing the whole length, facilitating instant joining or closing of a broken or intact system, aided by means of - (1) 'instant joint structures' shaped as I, T, J, L, C, U, Y etc. with complimentary threading, and having a straight or nested configuration, or (2) closing caps, also with complimentary threading. The structure can have a stem of tubing with complimentary threading to connect, wherefrom it enlarges to a tubing double the size and articulating with a very sturdy and massive closing cap to resist enormous pressure possibly exerted by the tubular system, at the terminal.

The tubing involved can be production tubing, oil collection tubing, tubular system involving the rig, and any tubing wherein said configuration is deemed effective. Such structural mandate is as important as all the incorporated safety devices in case 'fire and well surface blow-out' happen, resulting in a 'disconnect' in the system - when instant joining anywhere necessary is

accomplished, or else instant closing of the system is similarly accomplished. The configured joint structures shaped as specified above, are used as one or multiple joints. I and / or T joints are usually needed to aid incorporating other joint structures, to restore a conduit line, or complex interconnections. It does not imply that the threaded tubing is novel, but implementing such system in the context of oil wells, especially involving all tubular systems and traversing their entire length is novel, as only such model can instantly join or close the system anywhere at any time mitigating catastrophic consequences.