WIRING SYSTEM COMPATIBLE WITH WIRELESS OPERATION FOR UNDERGROUND WELL USE AND ABANDONMENT

专利摘要:
probeless operable cable compatible system, attachable to annular spaces for underground pit use and abandonment. method and system of supplying or enabling the restoration of at least a portion of an underground zone by placing and rock covering of producible hair of a well supporting at least one equivalent well barrier cement element within a usable operable space, formed by at least one space-coupled element annular cable-operated and probe-less column-operable annular column, comprising cable transportable and probeless column components that are transported through a more internal and downward passage of a wellhead and by the use of energy , driven through the moving fluid of a recirculating fluid column, to operate or access at least one annular space of said innermost passage and to displace at least a portion of a wall of at least one tube around the said innermost passage, to provide at least one equivalent cement well barrier.
公开号:BR112014001623B1
申请号:R112014001623-2
申请日:2012-07-05
公开日:2021-07-13
发明作者:Bruce A. Tunget
申请人:Bruce A. Tunget；
IPC主号:

专利说明:

CROSS REFERENCES TO RELATED PATENT APPLICATIONS
The present patent application is an application under the Patent Cooperation Treaty (PCT): which claims priority to the UK patent application with patent application number GB1111482.4 entitled "Cable Compatible Rig-Less Operable Annuli Engagable System For Using and Abandoning a Subterranean Well" filed July 5, 2011 and published under GB248416SA and April 4, 2012, the entirety of which is incorporated by reference. DOMAIN OF THE INVENTION
The present invention generally relates to cable transportable and non-probe operable systems and methods which may be useful for installing insulating element in well barrier to delay or perform underground well abandonment operations in at least a portion of a well essentially water or essentially hydrocarbon. BACKGROUND OF THE INVENTION
The construction of an underground well to produce substantially water, for example, from wells mined by solving or cutting water in hydrocarbon wells, or to produce substantially hydrocarbons capital investment with an expectation of return on capital repaid over the life of the well, followed by the definitive abandonment of all or part of the well to delay additional costs, once the storage or production zones have reached the end of their economic life or the structural integrity of the well becomes an issue. For the hydrocarbon extraction industry, the productive life of a well is generally 10 designed for 5 to 20 years of production.
However, the conventional practice is mainly to prolong the life of the well for as long as possible, even after exceeding its original projected life, and, despite all the marginal economic losses incurred, to push the cost of final abandonment into the future. . For the underground storage industry, wells can be designed for a lifespan of 50 years, but storage wells over time can also encounter integrity issues that require intervention, maintenance or abandonment.
Embodiments of the present invention can be used to delay abandonment by placing barrier elements in the well to intervene or maintain the structural integrity of the well and allow production operations or marginal additional storage to continue until the definitive stop of those operations production or storage. Embodiments can also be used to permanently abandon all or part of underground storage or produced wells.
As the cost of putting up acceptable abandonment barriers to permanently isolate 5 underground pressurized liquids and gases comprises an investment with no return on capital, financially minded people are continually seeking to reduce the present net cost of abandonment by postponing it, by improving marginal production, or by minimizing the expenses associated with the abandonment of the lower part of a well, sometimes referred to as suspension until the definitive abandonment of the well. Embodiments of the present invention may be used with rig-less intervention operations to minimize the cost of improving marginal production and the abandoning a portion of the well to suspend the well until a definitive abandonment campaign is used to further minimize costs, potentially using non-scnda realizations.
The present invention generally relates to probeless systems and methods that can be used to install insulating elements in well barrier 25 to delay or perform underground well abandonment operations in at least a portion of a essentially water or essentially hydrocarbon well. This allows and/or prepares for production or storage in a different part of the well until the well reaches the end of its life and is ready for final abandonment without rig, using installed tubes that are coupled to the wellhead , to place apparatus or mixtures of solidifiable fluids at selected depths to isolate at least a portion of the well using probeless operable elements attachable to the annular space and methods of the present invention.
Various embodiments of the present invention may include the use of, or be used with, other inventions of the present inventor, including the inventions disclosed in UK Patent GB2471760B entitled "Apparatus And Methods For Sealing Subterranean Borehole And Performing Other Cable Downhole Rotary Operations" , published February 1, 2012; US patent application serial number 12/803,775 entitled "Through Tubing Cable Rotary System" filed July 6, 2010 and published as US2011/0000668 A1 on January 6, 2011; PCT patent application serial number GB2010/051108 entitled "Apparatus And Methods For Sealing Subterranean Borehole And Performing Other Cable Downhole Rotary Operations" filed July 5, 2010 and published as WO2011 ZOO 4183 A2 January 31, 2011, and PCT Patent Application Serial Number PCT/US2011/000377 entitled "Manifold String For Selectively Controlling Flowing Fluid Streams Of Varying Velocities In Wells From A Single Main Bore" filed March 1, 2011 and published as WO2011/119198 Al on September 2.9, 2011, all of which are incorporated herein in their entirety by reference.
The present invention significantly improves upon the prior art with embodiments of methods and apparatus for forming and using a fourth (4th) geological time dimension in well barrier elements necessary for the practice of rock cap restoration, in which the provision of a space 10 operational for the chronological record of the three-dimensional cement adhesion before placing and in support of at least one equivalent cement barrier element within said operable space, using at least one attachable element of the annular space to access at least one annular space of an innermost passage, by displacing at least a portion of a wall of at least one tube around the innermost passage to provide said operable space 20, bridge across said operable space , and placing said at least one cement equivalent of well barrier element through said operable space to the outside. at least one geological time interval space, which can be used to fluidly isolate at least a portion of an underground well, without removing the debris and associated installed pipes below one or more underground depths, to provide or enable restoration of rock cover above a producible zone. For example, the present inventor's Patent GB2471760B can be used to form a four (4) dimensional space when elements of a geological time interval space are present, for example when a static production shutter does not block a passage cancel. The present invention provides significant improvements by providing the elements of a geological time interval in cases where said elements may be otherwise unattainable without the use of a drilling rig. The methods of the present invention and apparatus can be used to, for example, place and/or tamp the cement equivalent of sealing material around the annular space block, such as a production plug, to increase the likelihood of forming with A four-dimensional geological space succeeds at the specific depth defined by the rock cover, which previously contained a productive zone before being penetrated by the well. Consequently, the spectrum of wells available for probeless abandonment is significantly increased by enabling or providing resealing of said rock cover at said specific depth in accordance with conventional industry practices for sealing a well in the fourth dimension of geological time.
Likewise, the present invention provides significant improvements to the prior art, for example WO2004/016901 Al entitled "Well
Abandonment Apparatus", which does not mention the industry practice in rock cap replacement and the lower cost drillless cable transportable practices, and teaches the use of more costly drill pipe methods and transport and circulation by flexitube using electrical and hydraulic umbilical lines for electrical supply and control. In contrast, the present invention can use the column of circulating fluid, within the plurality of passageways formed by tubes and casing in the original position, to operate a mateable element of the annular space and form and/or utilize a four (4) dimensional operable space, which may be consistent with the practice of restoring the rock cover to the imposed geological depth necessary to provide or enable said rock cover restoration over a geological period.
The present invention provides a system 20 of probeless methods and elements of accessing and exiting annular well spaces usable to solve the complex set of problems that have forced the industry to use expensive, over-specified drilling rigs and/or pipe. circulation 25 implemented to meet the minimum of best practices and published standards for well suspension, diversion and abandonment. Conventional probeless technology often uses, for example, drill weapons, abrasive cutters and cutting explosives to coarsely couple annular spaces, or complex and relatively large yet expensive and unsuitable flexitube or probeless tube handling arrangements constrained by minimum space and infrastructure, such as minimum marine facilities and onshore wells, 5 remote and normally unmanned.
The present invention provides compatible cable embodiments usable with wire and stranded wire ropes to provide selectively controllable access to all annular spaces 10 of the well to; i) properly clean the annular spaces to provide a wettable surface for proper adhesion of cement and other suitable permanent well barrier elements, ii) provide access to a chronological record to confirm the presence of primary cement behind the well casings , iii) provide separators between the well tubes to ensure that the tubes are embedded in cement and/or have cement, inside and outside the metal tubes 20 to prevent corrosion, iv) remove potential leak paths such as control and cables of the annular spaces, and vi) placing well barrier elements through resistant impermeable formations to meet the 25 published industry best practices of definitive abandonment, where no comprehensive conventional probe-less abandonment system is available for minimal installations with limited space and resources, eg power and facilities 30 larger, where the cost of numerous and complex s mounting and dismounting systems for rigs along a plurality of wells is prohibitive.
The methods and systems of the present invention can be used in various combinations to provide, in total, a probeless system for suspension, lateral diversion and well abandonment that meets industry best practices described in various publications, including revision 3 of August 2004 of NORSOK D-010, which defines the requirements of conventional well barrier elements used to form a plurality of pressure resistant envelopes that withstand pressurized underground liquids and gases.
The methods and apparatus of the present invention differ from the practices and apparatus of the conventional hydrocarbon and storage industry, which are designed for a significant life cycle, as the present embodiments can be used with a more economical means of placing a permanent barrier element. of well. For example, where a conventional pipe patch is designed to repair broken pipes for a significant period of production, different embodiments of the present invention can be used to provide temporary and/or partial pressurized fluid circulation capability to place a permanent cement plug. , because the extraordinary expenses to repair the broken pipe are unnecessary, since the well is being abandoned. Furthermore, the present invention can be used to increase the number of wells, where as. Lower cost drillhole wire operations can be used to place permanent well barrier elements, such as cement, as opposed to the conventional practice of using extremely expensive and over-specified drilling rigs to do work on an asset. that has no more value.
Can the present invention be used in probed or conventional non-probe arrays such as those described in the U.S. Patent 921918B2, published April 12, 2011, incorporated herein in its entirety by reference to provide a reference source for a probeless tube handling system. However, the present invention can also be used to minimize the impact and necessary operational resources, as the systems and apparatus of the present invention can be used with, but do not require, 20 tube handling arrangements and are operable by traction arrangements. spooling cable or flexitube column and pumping or optionally as an electrical line, through the wellhead using the well's recirculatable fluid column, Various embodiments of methods and fluids of apparatus elements of the present invention for suspension without probe, lateral deviation and abandonment systems can be combined with conventional methods, operable without a probe, with 30 devices, by placing well barrier elements and forming passage branches, from the innermost gallery, to be used in the access to annular spaces and productive zones of a well and/or to form new well barrier elements, which can be positioned without probe with art tubes. tubes, flexitube column and/or the recirculating fluid column of the well.
Pumpable elements of the systems of the present invention represent significant improvement over the teachings of EP0933414A1, published August 4, 1999, and GB2429725A, published March 7, 2007 which describe expandable gravel packages; US 200 3/014 4 3 7 4A1, published July 31, 2003, and EP1614669A1, published June 29, 2005, which describe mixtures of organophilic clay and cement, all of which are included in their entirety by reference in the present application. of patent. Where conventional practice focuses on insulating water production with expandable and reservoir insulation with clay and cement, the present invention provides methods for mixing graded hard particles that can be combined with expandable particles and clay-based cement to form a derivation matrix of annular spaces or pseudo-obturator within the annular spaces of the wells, forming well barriers and/or supporting the placement of a permanent barrier, such as pure cement. The present invention improves on conventional or existing probeless abandonment practices by incorporating drilling industry reagent mixing methods, commonly referred to as goo, usable to temporarily seal intrabore leaks. The present invention's combination of graded and expandable hard particles mixed with organophilic clay, oils and cement provide a means to insulate, without rig, well annular spaces during drilling operations and provide permanent barriers in selected parts of a well.
Other existing methods and systems, for example EPO933414A1 and GB2429725A describe packages of expandable particles used in water blocking and gravel packages, while US 2D 03/014 4 374 Al and EP1614669A1 describe a mixture of cement and organophilic clay, usable for sealing producible hydrocarbon formations, historically comparable to the use of "goose" by drilling practitioners to close fractured formations during drilling operations. Conventional packaging methods are silent on the present embodiments comprising graded hard particles mixed with expandable particles grades and clay mixtures to form an implantable fluid matrix that withstands high pressure or pseudo-obturator within an annular space, as specified in the present invention. Thus, the present invention provides significant improvement and benefit to practitioners of non-probe intervention and abandonment , with the use of d elements. and controllable rheological fluids comprising, for example, hard particles of specific sizes mixed with package mixes of specific graded, expandable particles in which the pore spaces are filled with a clay-based or cement-based goo. clay, to form a pressure support matrix. The pressure-bearing capacity of controllable theological fluids of the present invention is further enhanced with hydraulic packaging methods and elements, which can be used with intermixable gelatinous gum or pumpable mixtures of graded expandable particles and cement to form matrices with the particles expandables that withstand tension and pressure, and harder intermediate grades of mixed particle sizes with the light weight solids and particle sizes of a clay or cement based goo to seal the pore spaces between the packed particles and a wall of the well, for example, a tube, permeable tube and/or wall of strata, such that a pseudo-obturator can be formed in the annular spaces of a well for the purpose of abandonment, suspension and lateral deviation of the well. This pseudo-obturator is compatible with the hardening nature of cement or oil-based goo to provide support for the sealing materials, forming a indefinite pressure support derivation of, for example, cement in the walls and circumference of the annular spaces of the well during the abandonment without probe and/or the temporary suspension of underground wells. In addition, the present invention represents a significant improvement over conventional cement and clay mixtures, with method embodiments for segregating the implantation of chemically reactive fluid mixture reagents to control mixing and gelling chemistry, at the point where an element of well barrier is required, where another chemical reaction of expandable material with, for example, hydrocarbons or water is also possible at that point.
The expandable tube drilling and placement of the present invention represents a significant improvement over teachings such as those described in US patent applications 20 0 570,252 688, published November 17, 2005, and 2004/0069487Al, published April 15 2004, which describes the chronological record drilling of microholes, and PCT application WÕ 2009/152532Al, published December 17, 2009, which describes drilling a hole in a pipe and placing a sealable material within a space. cancel. The present invention improves upon such conventional practice by providing a plurality of sizes and placement means through which well barrier elements and recording tools can be placed to confirm primary cementation behind the casing to meet published minimum industry requirements, while similar conventional wire coil column methods or compatible apparatus are not available for the economic abandonment of a well.
Embodiments of the present invention using screws and/or axial traction provide more robust tube destruction combinable with means of transport for crushing and grinding well tubes, which do not require computer control, as described in the teachings of the US patent. US 6,868,906B1, published March 22, 2005. With respect to complex computer systems, the production of hydrocarbons from Greenfield is of significant value, and the associated savings from using computer-controlled systems is significant during the construction of a well, however, abandoned wells have no future value as well pipe that is no longer in use after the well is deconstructed, generally referred to as abandonment. Thus, abandonment economies are significantly different and require different tools. The present invention provides significant improvements in low cost probeless intervention by providing a system of methods and apparatus that meet the low cost needs of probeless abandonment which can be useful for the suspension and lateral deflection of zones. You will produce marginal from a well that may not be guaranteed to be completed during initial construction and/or does not justify the use of an expensive drilling rig or computer-operated systems, but can be used to provide the marginal revenue that offsets the cost of delay the ultimate abandonment.
U.S. patent application 2005/0252688 describes methods for individual microholes through strata immediately adjacent to cementitious casings for placing expandable sand sieves for a producible formation. However, this reference is silent on, and is not intended for, simultaneous placement of a plurality of holes and/or selectively accessing said holes with subsequent tools, such as conventional registration tools. Furthermore, this conventional method does not teach the placement of passageways through integral annular spaces as described by the present invention. While US patent application 2004/Q069487Al describes methods for providing measurements of strata and trace fluids within a microhole, it does not teach providing sufficient diameter, angular displacement, or selective hole reentry. Furthermore, the teaching of the invention WO2009/152532 A1 can be used to drill holes or cuts into an innermost tube to access a single annular space and place a well barrier element of hardenable material in the annular space, however , this reference does not teach, nor can it be used to access a plurality of annular spaces and/or the placement of measurement devices necessary for rock cover restoration using well barrier elements, such as teaching the provision of a pipe for production or storage in a different part of the well to delay final abandonment with marginal production. On the other hand, the present invention teaches a set of expandable holes and tubes 5, which are not restricted to microwells and can be used for fluid communication, placement of conventional recording apparatus and other devices, before placing cement in accordance with the 10 industry published guidelines. Thus, the present invention provides significant improvements over conventional technology by allowing more and larger holes and pipe sizes through the innermost bore of the well. This then allows the operators of well 15 to selectively orient, for example, higher torque electric motors and coiled-rope hydraulic motors to selectively place larger drill bits and selectively access a plurality of larger loaded expandable tubes 20 per drill, usable with higher flow rates, to communicate fluidly through annular spaces, which are isolatable from the passage of loaded expandable tubes to, for example, access producible zones, place devices, well barrier elements and/or elements of controllable theological fluid.
The spin-deployed, centrifugally-deployed, low-torque, disposable cable column compatible milling embodiments of the present invention represent a significant improvement over existing technology, such as those of U.S. Patents 5101895A1, issued April 7, 1997, and W02009/152532A1, published December 17, 2009. The present invention provides a significant improvement to low-cost milling without probe with balanced ball joint milling machines implementable with centrifugal rotational forces arranged to reduce torque and be disposable in-hole if the mill gets stuck during use.
One of the main objectives of the probeless abandonment of any part of a well is its destruction at the lowest possible cost, so the present invention is composed of simple and robust methods and low cost elements, which can be more similar to. the use of a sledgehammer instead of using the conventional computer-controlled teachings of US patent 6,868,906 Bl, which exclusively involves computer-controlled complex traction displacement for the transportation of drill rigs for well services and wire implantable or umbilicals. You. The operational benefits of the present invention are numerous and significant, requiring only fluid circulation, an electrical power source and/or traction line for operation, compared to complex operations that require computer control, in which the simple operations of the present invention are generally easier to support and cheaper.
In addition, if a set becomes stuck intrabore, the recovery value of the apparatus and tractors system operated in a complex closed circuit are significant, given the cost of construction of complex apparatus, thus limiting its usefulness due to the risk of loss in operations , as abandonment, where the well is a responsibility, with no future value. The methods and elements of the present invention are operable without a probe, with a traction cable and the pressures of a circulated fluid column to drive a hydraulic motor or an electrical conductor to operate an electric motor and/or disposable tractor, using reactive torque from the low-cost disposable motor to drive the push-pull of various rotating or non-rotating disposable devices to penetrate the walls within a well that is unable to provide future return on investment. The dangers of the destruction of said well, for example, the use of the fractionated cutting wheel, impacts, grinding and violent crushing in the destruction of steel pipes, by crushing, cutting and rotating equipment suspended from a non-rotating cable, represent a significant risk of equipment gets stuck in the bottom of the well and/or the cable breaks. The present invention provides significant advantages over more complex systems, for example, US patent 6,868,906B1, US patent application 2005/0252688, US patent application 2004/906948 7Al and W02 0 0 9/152 532Al, as it requires a less complex system designed to operate under high voltage load of, for example, a capstan unit for pulling cable, where the elements can be discarded into the hole, if necessary, to avoid the more costly operation of more complex systems, with an intrinsic reusable value that justifies the aforementioned complex system recovery.
Furthermore, conventional devices such as those described in WO 2009/152532 A1 are generally unsuitable for use with cable operations, as irregular rotation of their unbalanced grinding arm will occur when the grinding tubes move, and thus impose unacceptable traction loads on a high torque in-hole motor, potentially causing damage or grip and slip problems in the grinding assembly, which are generally unsuitable for rope operations, where low torque and balanced rotation are necessary to avoid cable entanglement. Although U.S. Patent 5101895A1 20 provides balanced cutting and/or grinding blade arrangements, the grinding blades are driven by a supplied and restricted torque within a rigid deployment arrangement that does not automatically adjust to balance rotation, limit 25 torque and avoid vibrations, which are unacceptable for a cable implanted cutter. On the other hand, embodiments of rotary cable milling tools of the present invention comprise the implantation of balanced cutters, which intrinsically adjust to the eccentricity of the tube with ball joints and rotary cutting structures, which are suitable for lower torque motors in low torque applications. flexitube column to avoid irregular rotation with the centrifugal rotation forces adjusting the implantation of the cutters to the displacement of the tubes.
The present invention provides significant improvements over the teachings of U.S. Patent 5,957,195, issued September 28, 1999 which describes an expandable pipe patch usable for repairing leakage in production piping. The present invention provides a swellable, expandable mesh-mesh fluid tube that can be used to place cement and/or controllable theological fluid elements in any annular space and/or to block fluid communication between the innermost passage. and one or more of the annular spaces. Thus, the present invention provides a significant improvement over conventional expandable tube patching in the probeless abandonment field, due to the high probability that the condition of the tube that caused the first rupture is the result of age, corrosion and/or wear. which will lead to further breaks or collapse of the pipe, which cannot be repaired with a single patch. In contrast, the present invention may include preventability as well as an ability to repair the pipe, due to the permeability of the mesh, which can provide pressure relief to prevent pipe rupture or collapse during placement and hardening of the pipe. cement, and where the mesh can be free of the water associated with cement hardening, as opposed to a solid conventional pipe patch. In addition, an expanded mesh tube 5 can be placed through the annular spaces of a well, and can be used to force heavier viscous fluids, eg cement, through or around the mesh tube, in which spaces The pores of the mesh can provide a natural pressure relief system, which can allow limited leaks to prevent air from bursting or collapsing a fluid tube when fluids of different densities exist inside and outside the tube, unlike technology. 15 conventional expandable solid tube. In addition, the present invention represents a significant improvement over conventional expandable sand sieves that are designed to prevent the production of sand by introducing expandable sleeves 20 or compactable and expandable graded particles in an expandable mesh screen tube, which provides the pressure relief benefits to prevent tube collapse while forcing most fluids to transfer through the tube to a selected location.
Embodiments of various methods and apparatus of the system of elements of the present invention can be used to form an enlarged passage, including the milling and crushing of pipes and well equipment and/or compression or compaction of pipes and equipment installed in the well to, for example, additionally forming or enlarging the passages for placing a permanent barrier element in the well. Other different embodiments comprise small boreholes and 5 casing assemblies, which can be used to place small diameter boreholes and/or expandable casings or seals or expandable materials within holes and annular spaces of a well, to form pressure resistant passages that they can be used to place, for example, recording equipment to determine any necessary corrective action within a borehole or annular spaces of a well. The present invention is therefore useful for marginal production improvement or repairs to underground storage well integrity to provide even more revenue and reduce the total net present cost of well abandonment by delaying it, hence the present invention it can also be used for the final abandonment of the underground parts of a well.
The abandonment of a well represents actions taken to ensure the permanent isolation of underground fluids under surface pressure and/or other permeable zones exposed with lower pressure, for example, groundwater, by the various parts of a well where reentry is not required , and in which portions, which are selectively used and/or abandoned, require permanent fluid isolation, at specified depths by 30 pressures within the strata, and the ability to withstand the pressure of the overlying layers of the stratum to isolate fluid pressures from lower surface strata or other upper permeable zones. Underground pressurized permeable zones, comprising formations of strata 5 accessed by a well that have the possibility of moving fluid when there is a pressure differential, in general, should be isolated to avoid pollution of other underground horizons, such as groundwater, or environments surface 10 and the ocean.
Various embodiments of the present invention can be used within a pressure controlled working envelope, using flexitube columns, lubricators, grease heads or other conventional pressure control equipment, coupled to the upper end of a wellhead and valve tree to intervene within the passages and annular spaces of an underground well that extends from the well head downwards so as to permanently isolate underground pressurized fluids accessed by the passages, without the risk and cost of placing heavy damping fluid in the well and break through surface pressure barriers, thereby exposing personnel and the environment to greater potential for uncontrolled fluid flow if the column of dense underground pressure dampening fluid is lost.
Performing abandonment and well intervention operations within a controlled pressure environment 30 is required for probeless operations in a subsea environment where risers and lubricators are coupled to the upper end of a subsea valve tree to remove the access plugs to the drilling deeper into the well. However, access to the annular spaces within a subsea well is limited, with most wells freeing the innermost annular space for the production flow during the initial thermal expansion, after which the subsea annular spaces are closed. Many subsea configurations also provide fluid access to the innermost annular space through a manifold placed in the subsea valve shaft, which can also be coupled to pipeline support tubes, such as a methanol line. The present invention can be used from boat and lubricator arrangements, within a controlled pressure environment, for example, a subsea lubricator and BOP, for probeless access and abandonment of a well without the need to use an oil riser. mud line at sea level or above.
Definitive abandonment, in general, is considered to be the placement of a series of permanent barriers, often referred to as plugging and abandoning, in whole or in part of a well, with the intention of never using it again or re-entering the abandoned portion. Permanent well barriers are generally considered well barrier envelopes, which comprise a series of well barrier elements that individually or in combination create a comprehensive seal, which has the characteristic of being permanent or eternal insulating further underground pressures. and avoid polluting shallower formations, eg water-permeable terrestrial zones, and/or terrestrial or ocean environments. Several publications, including Oil and Gas UK, January 9, 2009 issue of the Guidelines for Suspension and Abandonment of Wells, define the best conventional practices of definitive abandonment of a well and the associated well 10 acceptable acceptable barrier elements used to form a well. plurality of pressure-resistant envelopes, which support pressurized underground liquid and gases over geological time.
There are currently no comprehensive well abandonment systems 15 other than the use of an over-specified and expensive drilling rig. The present invention provides an important and significant solution, by specifying the methods and apparatus for, without a probe, suspend, divert and abandon on land and at sea, on the surface and underwater, wells of substantially hydrocarbons and substantially water, which are also in accordance with published conventional best practices for the placement of 25 industrially acceptable pit barrier elements for final disposal.
The cost of permanent abandonment can be expressed as a function of the amount of time required and the amount and type of equipment required to place permanent barriers to contain the pressures of underground fluids for an indefinite period of time. The cost of abandonment is generally higher when using the specification of a drilling rig, capable of constructing a well, with large lifting capacity, pumping and pipe handling systems that require a significant amount of equipment and support personnel to your operation. On the other hand, the cost of abandonment is generally significantly lower when operating with what is commonly referred to as a "no-probe" system, with much less support equipment and operating personnel, lower lifting, pumping, and pipe handling systems.
Embodiments of the present invention are generally usable to meet published minimum requirements and industry best practices for the placement of permanent barriers using probeless intervention and abandonment methods.
Drilling rig specifications are generally used to dismantle a well by cutting and lifting large and/or long strings of pipe from a well and potentially milling casings to place unobstructed cement plagues into the holes from which the pipes were removed. There are conventional risks, especially when equipment within a well must be removed to provide acceptable eternal barriers, as the equipment may be coated with radioactive material in low specific activity scale (LSA) or normally occurring deposits (NORM ), and accumulated over the productive life of the well. The probeless abandonment embodiments of the present invention can be used to protect the environment and personnel from these hazards, which, if carried out with existing practices, would add additional costs and/or reduce the efficiency of the abandonment practices. The probeless abandonment embodiments of the present invention provide acceptable methods and systems that can be used to leave contaminated well equipment within the strata.
Embodiments of the present invention can be used with installed well apparatus to avoid the need to remove completion equipment and expose personnel and the environment to a variety of hazardous materials which may have accumulated in the equipment over time. .
In situations where there is insufficient cement behind the casing and production equipment has been removed, a drill rig may conventionally be required to mill the casing so as to place a cement plug through the unobstructed hole in the strata. The resources and associated costs required for casing milling operations can often be equivalent to the original conventional cost of well construction.
Several embodiments of the present invention can be used to access annular spaces in order to measure the presence, or lack of, of cement behind the casing, while other embodiments can be used to shred production pipes and mill the casing to provide a free space for placing cement through a hole.
Operating a drilling rig requires a significant amount of space around the wellhead of the well being built or deconstructed for the placement and operation of high-capacity pipe lifting, pumping and handling systems, regardless of the work occur on land or at sea. Drilling rigs are generally the most expensive controllable primary items to influence the return on capital and offshore drilling rig specifications are generally significantly more expensive than onshore drilling rigs as they comprise living habitats. capable of supporting a significant number of people, often over a hundred people, within a potentially dangerous environment. Although the requirements for flexitube well operations are significantly lower than for a drill rig, they are considerably higher than for a cable logging operation that comprises electrical line or wire intervention.
The present invention can be used to provide smaller operational footprint without a probe, similar to power line and wire operations, which can be used, for example, on small, normally unmanned platforms, with methods and apparatus that require a minimum of associated resources and space to perform the necessary suspension, lateral deviation and finally the abandon operations.
Large lifting capacity probes that can be used for the removal of intrabore equipment are generally not necessary as long as the annular spaces can be accessed and the permanent 1 insulations can be placed within the annular spaces. Generally, probeless abandonment operations use piping or through-pipe operations to minimize equipment and personnel requirements, using the installed completion and casing columns to circulate the cement, and ultimately leaving the equipment at the bottom of the pit.
Providing annular space control and permanent isolation barriers in probeless operations is a challenge without universally accepted conventional probeless means for both verification and placement of permanent barriers within annular spaces, as required by published industry best practices, by because of the potential for many leak paths that exist when completion equipment is left inside a well, where conventional exploration can only take place after removal of completion equipment. For example, leaving cables and control lines at the bottom of the well inside a cement barrier can represent a significant leak path, as capillary or frictional forces can prevent viscous cement from entering the small diameter of a line. control or sheathing of a cable. In addition, although there may be records of originally installed primary cementation, over time the adhesion of primary cementation may have failed due to pressures and thermal cycles of the coatings during production and a leak path may exist between the coatings and the strata making abandonment without a properly placed probe ineffective.
In addition, when completion tubes or well completion tubes and equipment are left in the well during conventional well abandonment through drillless piping, leak paths may form around the installed apparatus if they are not compensated by others equipment, to be incorporated in, for example, cement, including checking the position and placement of permanent barriers within the holes and annular spaces of a well to determine if further corrective measures are required.
Various embodiments of the present invention can be used to compress broken downhole equipment into a surrounding hole to remove obstacles and potential leak paths, while providing space for recording behind the casing, to determine if there is acceptable cement adhesion.
The main characteristics that a permanent barrier must have to prevent the flow of pressured fluids through the barrier are: i) the integrity of long-term insulation that ii) adheres to completion equipment and iii) does not deteriorate or iv) shrink with the time, thus allowing the flow around the barrier, which barrier must be of a v) ductile or non-brittle nature to support loads and mechanical changes in the pressure and temperature regime, in which the ductile or non-brittle material must also vi ) resist penetration of intrabore fluids and/or gases, such as hydrocarbon gas, CO2 and H2S into or through its mass. Although cement is currently the main material in the oil and gas industry used for permanent well barriers, other suitable materials can also be used, provided they meet these necessary conventional requirements,
Embodiments of the present invention can be used with cement and other suitable permanent abandonment materials implementable without a probe, with various embodiments that can be used to clean holes and annular spaces of hazardous or benign debris that could potentially interfere with the placement of permanent impermeable barriers, eg cement, to provide more wettable surfaces for cement bonding, on which parts of the well can be opened for disposal of hazardous material, such as LSA encrustation, during abandonment.
The most prevalent permanent barrier for the abandonment of wells is a cement column of sufficient depth to ensure good quality and adherence of the cement to the completion equipment. The surface of the completion equipment must be both wettable and accessible when placing the cement paste. If equipment, such as completion or coating equipment, is left inside the hole in the strata, the cement must also be placed on both sides to incorporate the equipment or coating into adhered cement, as over time the equipment will metal can corrode if the bond with the cement is poor or the lack of proper cement adhesion exposes corrosive equipment to underground fluids, subsequently providing a leak path. Cement lining is not considered to be a permanent barrier to lateral flow into or out of the hole unless the inner and outer diameters of the lining and accommodated tubes are sealed with good quality cement that is adhered to the lining. inner or outer surface of the coating through annular itticrospaces if poor adhesion exists, to eventually corrode the coating when a localized coating of incomplete cement is present in the inner hole or annular space.
Various other embodiments of the present invention can be used to provide both space and displacement of eccentric tubes to allow for cleaning of completion equipment and liners along the bore, both fluidly and mechanically, to provide cleaner spaces and wettable surfaces and provide good enough quality adhesion of the cement, thus preventing axial or lateral flow of fluid under pressure.
As the useful life of an installed permanent well barrier can be measured in geological time, that is, over millions of years, and as nature abhors a vacuum, well barriers must also be designed to resist the repressurization of a depleted reservoir as it seeks to return to its original state over time. In many underground reservoirs, this requires placing barriers at specific depths to replace the original rock cover and hold the underground fluids under pressure, as before it has been penetrated by a well. Lack of foresight in the original well design 30 is often the main reason for using drill rig specification to abandon wells, as completion equipment, eg production shutters, are incorrectly placed for conventional abandonment no probe and/or marginal production improvement 5 when these shutters fail to isolate or. prevent access to isolated marginal producible formations.
Other embodiments of the present invention can be used to access all adjacent annular spaces 10, and replace and/or prevent isolation of the production shutter from an annular space, while other embodiments can be used to access isolated producible marginal formations or access formations of injectable strata 15 for the elimination of hazardous material waste, during the suspension and/or lateral deviation of a well and placement of insulation in the annular spaces and access tubes to delay or perform the final abandonment of a well, to potentially reduce the net cost current dropout.
Prevent exposure of the environment and personnel to hazardous materials, eg hydrocarbons from marginal producible formations, brines, naturally occurring or as a result of water injection, and/or LSA or NORM fouling, with a reasonable probability of success both during well operations and for the indefinite period below, it requires redundancy, that is, a plurality of tested barriers that can be verified. The integrity of a well is generally measured both during its operations and when it is abandoned, by the existence of at least two verified barriers.
Various embodiments of the present invention can be used to provide annular space supported cement placement for a plurality of annular space barriers that are verifiable with conventional registration and marking methods, but are not available for conventional probeless applications. due to its inability to selectively access annular spaces or drive test pressure through access passages to annular spaces, in which the present invention can be used to access all annular spaces to exit all or part of an underground well.
Well operators face a number of challenges at each stage of the well's lifecycle as they seek to balance the need to maximize economic recovery with the need to reduce the net present value of an abandonment liability to meet their operations and abandonment obligations safe and environmentally sensitive. When wells lose structural integrity, which can be defined as the apparent or probable presence of a future loss of pressure or fluid carrying capacity and/or general inoperability, the entirety or portions of a well can be isolated, for maintenance or suspension until definitive abandonment or may require immediate plugging and abandonment, potentially leaving reserves within the strata that cannot justify the cost of the intervention or a new well.
Some of the most frequently reported structural integrity problems are lack of centralization which leads to pipe erosion by thermal cycle movement, corrosion in the well piping system, for example by biological organisms or formation of H2S leaks by the pipe or destruction of pipes or equipment and/or 10 valve failures associated with subsurface safety valves, gas lift valves, annular space valves and other similar equipment. Other common problems include unexplained pressure in the annular space, connector failures, deposits, wear of casings from drilling operations, wellhead growth or shrinkage, and Christmas tree or valve tree malfunction or leaks on the surface or underwater.
Such issues include zones where operators are able to, or have chosen to, test and there are others (such as the inside of a pipe): that they cannot, or do not test, and that can pose a serious risk to economic and the environment.
Problems in various parts of a well, in particular the annular spaces, may not be accessible in a conventional manner without significant intervention or breaking of barriers in the well, for example with a drilling rig, and therefore 30 represent a significant cost and safety risk for operators who are not prepared for conventional rigless mitigation operations.
The main advantage of using specification drill rigs for the intervention in well 5 is the removal of tubes and access to the annular spaces during the intervention and abandonment of the well, where the ability to access and determine the lining condition of the annular spaces and the primary cement behind the production tube or pipeline is used to make fundamental decisions about future production and/or abandonment. If the well casings are corroded or an external cement casing is missing, corrective measures, eg milling the casing, 15 can be taken to provide a permanent barrier. On the other hand, the problem can be exacerbated by conventional non-bore abandonment of the well when blind decisions are made without access to the cement register of the annular spaces 20 and attempts to place cement fail, thus posing yet another barrier across problems. potentially serious and degenerating well integrity, which can pose a significant future challenge, both technically and economically, even for a drilling rig.
Various embodiments of the present invention can be used to gather information that less conventional drilling operations cannot by providing access and/or space for both measuring devices and sealing materials. Once such information is collected, still other embodiments can be used to place, without probe, barriers, and/or mill or shred tubes and liners to expose and pass between impermeable solid strata or rock cap formations for placement of permanent barriers without built-in equipment to ensure structural integrity.
Age is generally believed to be the main cause of structural integrity problems in wells. The combination of erosion, corrosion and general fatigue failures, associated with prolonged time in the field, particularly within wells that have already exceeded their designed lives, together with poor design, poor installation and failure to implement warranty standards. Integrity Standards of maintenance, associated with senescent well inventory, are generally responsible for the increase in the frequency of problems over time. These problems can be aggravated by, for example, increasing water cut-off levels, production stimulation, and gas lift later in field life.
However, the prevailing conventional consensus is that while age is undoubtedly an important issue, if managed correctly, it should not be the cause of structural integrity problems that can cause premature production disruption. In addition, completely depleting production zones by increasing production, prior to abandonment, provides an environment of underground pressure depletion, which may be more suitable for placing permanent barriers, given the decrease in the propensity of penetration of lighter fluids into the cement. , for example, during its placement.
There is a need to postpone abandonment with low-cost probeless operations for the placement of barrier elements to increase the return on invested capital, both for substantially water wells and for substantially hydrocarbon wells, through lateral deviation without - rig, for the improvement of marginal production, suspension and/or abandonment of parts of a well, to re-establish or prolong the structural integrity of senescent well assets in production and storage, and thus prevent pollution of underground horizons, such as groundwater or surface environments and from ocean to no.
There is a need for operations to lay down well barrier elements and a small occupied operating area that can be used to control costs and/or perform operations in a limited space, for example, electrical cable or wire operations, in normally unmanned platforms, boat platforms over subsea wells or in an environmentally sensitive area, eg permanent freezing areas, where a hostile environment and environmental impact are concerns. There is also a related need to work within a closed pressure controlled envelope to avoid exposing both the operating personnel and the environment to the risk of loss of control of underground pressures, especially if a column of heavy intervention dampening fluid in the well has been lost to, for example, underground fractures,
There is a need to avoid the high cost of drilling rigs with a probeless system capable of suspending, laterally diverting and/or abandoning on land and at sea, surface and subsea wells, of substantially hydrocarbons and water that use and/or that comply with published conventional best practices for placement of industry-acceptable well barrier elements for definitive abandonment.
There is a. need for risk prevention and elimination of the cost of protecting personnel and the environment against well equipment contaminated with radioactive materials and deposits, in order to put up without probe abandonment barriers and leave the equipment at the bottom of the well. There is an additional need to laterally bypass or probe-free fracture portions of a well for the disposal of hazardous materials resulting from the circulation of the well fluid column during suspension, diversion and abandonment operations.
There is a need to access the annular spaces without a probe to measure if there is an acceptable cementitious seal behind the casing and mill, without a probe, the casing and place cement if acceptable cementation does not exist. There is a further need to verify the placement of well barrier elements during the drillless operation to ensure successful adhesion of the hardenable material and whether sealing of well passages has occurred or whether further repair work is required.
There is a need to access 10 annular spaces, currently inaccessible, in conventional operations by probeless wire of minimal affected area, including bypassing annular space blockages, created, for example, by production shutters, during placement of 15 permanent well barrier elements within selected parts: from the well and through rock cover and other impermeable formations necessary to isolate underground pressures over geological time.
There is a need for a plurality of permanent well barriers that are verifiable through passages in the annular spaces selectively accessed without probe that can be used in operations with conventional extraction tools to maintain the structural integrity of a well before final abandonment, and which also provide access for the placement of permanent barriers to ensure the structural integrity of the hole through the strata.
There is a need to increase usable marginal production to offset operating costs until the occurrence of final abandonment, including providing the well-hole integrity while waiting until the abandonment campaign involving a plurality of wells can be used to further reduce plus the costs.
There is a need to reduce the abandonment liability for operators, without neglecting their obligations for the structural integrity of the well for safe and environmentally sensitive operations in the well, by suspension and abandonment, in an economical manner that is consistent with the provision of more capital for the exploration of new reserves in response to our world's growing demand for hydrocarbons, by minimizing the cost of operation, suspension and abandonment through the lower cost of non-suspension probe, lateral deviation and abandonment technologies. , verifiable well abandonments are needed to facilitate a market in which reducing well abandonment liability allows companies with more expensive operations to sell marginal well assets to smaller companies with lower operating costs, that is, reducing the risk of a residual abandonment liability, to prevent recoverable marginal reserves from being left within the strata because the more expensive general operating requirements make such recoverable reserves economically unfeasible. Several aspects of the present respond to these needs. SUMMARY
The present invention generally relates to cable-carryable and probe-less operable systems and methods that may be useful for installing a well barrier insulating element to delay or perform underground well abandonment operations in at least a portion of an essentially water or essentially hydrocarbon well.
Embodiments of the present invention include elements and systems operable without a probe and attachable to the annular space, comprising fluids and apparatus, to selectively form new well passages and/or block existing ones, for the placement of measurement and recording devices and well barrier elements in use, accessing at least a portion of the workable zones of an underground well and annular spaces, before abandoning the entire plurality of well passages, without the use of a drill rig. Embodiments of probeless methods and systems eliminate the need to remove installed pipes, thus allowing installed well equipment, and any associated scale or natural radioactive materials, to be left in place and yet comply with published industry best practices for confirmation of the integrity of the primary barrier element 1 of the well by means of registration with centralized concentric tubes and removal of possible leak paths for the placement of cements, polymers, graduated size particles, or any other suitable material that can be used inside of supported annular spaces to form permanent well barrier elements and undefined integrity of the abandoned well.
The present invention provides annular access systems, which can be used with controllable rheological fluid elements, recording tool elements, expandable elements, expandable elements, depositable tube elements, motorized elements, drilling elements, tractor elements, elements pipe milling elements, grinding elements and/or probeless elements, which may include elements couplable to the annular space operable and transportable by cable and probeless column which can be used to form or place well barrier elements to insulate at least part of the well. The present invention can be used to access annular spaces and workable zones of a well to perform or delay final well abandonment, providing additional marginal well production and/or longevity extension by probeless placement of additional barrier elements underground well. In addition, the present invention can be used for final well drill-down abandonment in wells where the annular spaces are conventionally inaccessible, thus saving the cost of using rig with drilling specification.
The present invention provides for lower rig free access to annular spaces and selective placement of pressure resistant pipes and well barrier elements in the required underground depths between annular spaces when intervening, maintaining and/or abandoning parts of a well to insulate portions affected by erosion and corrosion, which, in turn, can extend the life of the well and thus completely deplete a reservoir and further reduce the risks associated with the placement of the well barrier element and pollution liability of an abandoned well improperly.
The level of operations required for maintenance, intervention and restoration for well maintenance is constrained by the substantial conventional costs involved. Limited levels of production of senescent goods often do not justify the conventional practice of using higher cost drilling rigs, and conventional rigless technology is generally unable to access the various passages or all annular spaces within the pit.
Therefore, well operators generally place emphasis on eliminating troubled assets from their portfolio and seek to prevent future problems with better projects, rather than trying to remedy a poorly designed well, which in turn hastens a greater focus on asset divestitures, well design, installation and/or integrity assurance. Passing on the problem to others by selling a well does not mean, however, solving the issue of abandoning existing and aging wells from the point of view of responsibility.
When intervention is needed, major risk-averse oil and gas companies generally prefer operations such as disposal and replacement of assets, rather than steering, and favor the sale of senescent well assets to smaller companies with lower and higher costs. risk tolerance. Smaller companies, which require a lower profit margin to cover the marginal cost, are generally eager to acquire such marginal assets, but in the future they may be unable to afford the expense of abandoning the well, and thus transfer, liability back to the original owner and prevent the sale or create a false economy for the seller. Probe-less placements of reliable and low-cost wellbore elements to delay or carry out abandonment is critical for companies large and small if aging assets are to be bought and sold and/or to avoid such false savings. Thus, the probeless methods and components of the present invention, which can be used to place and verify well barrier elements for reliable abandonment, are important to all companies operating, selling and/or buying senescent wells.
Therefore, the structural integrity of producing and abandoned wells is critical, as responsibility for well abandonment cannot be passed on if a well ultimately leaks pollutants to the surface, groundwater or marine environments, as most governments retain all previous owners of a well 5 as responsible for its abandonment and the environmental impacts associated with subsequent pollution. Therefore, selling the liability of a well does not necessarily eliminate the risk when the asset is sold or abandoned, unless the final abandonment ensures permanent structural integrity.
Embodiments of the present invention can be used in well drilling intervention and maintenance to extend the life of a well by placing well barrier elements to isolate or abandon one part of a well and then operate another until that there is no longer economic production or the integrity of the well prevents new extraction or storage operations, after which the well can be completely and permanently abandoned indefinitely with the resource of the present invention of, without a probe, selectively accessing annular spaces both for placement and for checking the well barriers.
Preferred embodiments of the present invention provide methods (1A-1BU) and systems comprising probeless column operable elements (2A-2BU and 3A-3BU), which further comprise an apparatus (2A-2BÜ) for accessing and placing elements 30 of well barrier (3A-3BU) to provide (220) or activate (211-219) the rock cover restoration of at least a portion (4A-4BÜ) of a producible zone of an underground well.
Embodiments of the present invention can be used for placing and supporting at least one equivalent of well barrier element cement (3A-3B', 20, 216) within an operable usable space, formed of at least , an annular space-coupled element (2A-2BU) cable-operated and probeless column operable, comprising components that can be carried by cables and probeless column through an inner passage (25, 25E, 25AE) , which can be surrounded by at least one annular space of a plurality of annular spaces formed by installed tubes (11, 12, 14, 15, 15A, 19) extending downwardly from a wellhead (7 ) inside the underground strata (17) for the formation of a plurality of passages (24, 24A, 24B, 24C, 25, 25E, 25AE) in fluid communication with said producible zones through the rock layer.
Manifestations of the present invention are operable using power conductors through the moving fluids of the flowable fluid column of a well (31C) or by deploying a column of electrical conductors and/or deploying rope traction to operate at least one element of attachable annular space for accessing at least one annular space of the innermost passage, for displacing at least a portion of a wall of at least one tube around said innermost passage, to provide an operable space, traversing said operable space , and placing said at least one equivalent cement well barrier element across said operable space, adjacent to said rock cap, to form at least one geological time interval space that can be used to fluidly insulate said at least a portion of said underground well, without removing said installed pipes and associated debris from under one or more depths. underground tenes (218) of the associated rock layer to provide or enable said restoration of the aforementioned rock layer 1 .
Various embodiments can be used to abandon without rig and/or suspend a portion of the well, and then divert to one or more new productive zones.
Various other embodiments can be used to provide permanent fluid isolation and rock cap restoration by using an operable space to measure or provide (214) cement-like (216) adhesion (216) over a sufficient axial length (219) of tubes, which can be embedded in (215), or filled from the inside and embedded in (217), cementation, with separator (211) between tubes and support (212) of said cementation in said underground depth (218), adjacent to the strata of the impermeable rock cover, prior to carrying out said placement of said at least one equivalent cement well barrier element through said geological time interval operable space to allow said rock cover restoration above said productive zone .
Still other embodiments can be used to provide an abrasive, explosive, or shear component to access at least one annular space from the innermost passage, or to displace at least a portion of a tube wall to provide an operable space.
Various embodiments can be used to provide a motorized element (2B1, 2AN, 2AM2, 2BN, 2BO, 2BP) comprising at least one in-hole motor that can be suspended by a cable and operable, with the energy of said column without probe or of said flowable column fluid to drive at least one rotary shear component, or a mechanical linkage component.
Several related embodiments can provide an axially operable tractor element (2AW3, 2BN, 2BP3-2BP4, 2BQ), comprising said mechanical linkage or at least one shear component, which can be attachable to the tube wall to pass axially through. of the innermost passage, to displace another well barrier element or said wall.
Various other related embodiments can provide a tube mill element (2E2, 2AW2, 2BP2, 2BR) which can comprise one or more peripheral cutter components. The one or more peripheral cutting components may include wheels, blades, or combinations thereof, and the tube mill element may be implantable axially and radially away from the innermost passage, with a solid flesh or Kelly passage for milling and move said wall ,
Still further related embodiments may provide an annular space grinding element (2E6, 2AV3, 2AW1, 2AY1, 2BP1, 2BT1-2BT3) comprising one or more peripheral cutting rotary components, wherein the one or more peripheral rotary cutting components can include discs, blades, or combinations thereof, which can be used to axially, rotationally, and circumferentially penetrate and cut the tube wall.
Various embodiments may also provide a guide element (2C1, 2D3, 2E4, 2N6, 2Y1, 2Y2,2Z1, 2AB3-2AB4, 2AC, 2AM2, 2A01, 2AP, 2AQ1, 2AQ2, 2AT1, 2BT2-2BI3, 2BJ, 2BI6, 2BK , 2BL, 2BM) comprising a selectively orientable derailleur guide (2Y2, 2AB1, 2AQ1, 2BI6, 2B, 2BL, 2BM, 47), a tube (2D2, 2AE3, 2AF, 2AK, 2AL, 2A03, 2AS2, 2AT3, 2AV2, 2AV5, 2BI3, 2AB3, 2AC1, 2BI5), an annular space bridge (2X3, 2AH, 2AJ1-2AJ3, 2AU1, 2AY2, 2AZ, 2BB, 2BC, 2BD, 2BM2), or their combinations, which can be attachable and orientable within said innermost passage, to force the passage of another well barrier element or said movable fluids through said wall with a bore selector alignable between said innermost passage and at least one penetration into said wall.
Other related embodiments may provide at least a portion of a selectively steerable diverter guide or a guide tube which may be rotatably steerable and selectable with said bore selector, between a plurality of perforations in the tube wall, from the interior of said innermost passage.
Various other related embodiments can provide a tube component for fluid communication which may be positionable within said operable space, through said innermost passage or through said guide element, with said moving fluid pressure against a wall of said tube component for fluid communication.
Still other related embodiments may involve a guide tube wall comprising rigid material, mechanically expandable material, chemically expandable material or rigid expandable material which is sealable against said wall of said installed tube.
Other related embodiments may further comprise providing a motorized element for accessing the annular space by perforation (2B3, 2C1, 2E4, 2L3, 2Y3, 221, 2Z2, 2AA1, 2AB1, 2AC, 2AD, 2AE1, 2AN, 2AM2, 2AQ2, 2AS1, 2AV4 and 2BI1) comprising at least one rotary cutting member having a flexible shaft and a drill bit for penetrating and displacing a portion of said wall where said tube is installed.
Several related embodiments may comprise providing a motorized mechanical connection member capable of piercing to displace at least a portion of the tube wall to provide a spacer displacement or to prevent further displacement of at least a portion of the tube wall installed from the other party.
Still other related embodiments may comprise said mechanical connection member capable of piercing tube to provide fluid communication within operable space 15 to bridge between, or through at least two passages of the plurality of passages to access the space. operable.
Still other various related embodiments, may further comprise providing a mesh wall tube fluid communication component with at least a portion of said wall of said fluid communication tube comprising porous spaces sized to package and unpack 25 particles or compositions which can be used to selectively prevent or provide fluid communication through said pore spaces using the flow orientation of said column of flowable fluid, said pore space size 30, or said particles or compositions.
Other related embodiments may provide a clevis element (2B4, 2C2,2D1, 2E1, 2E5, 21'2., 2M, 2N2, 2R2}, with said fluid communication tube component for bridging at least , two perforations in said wall of said tube for segregating flow between said at least two perforations and another passage of said plurality of passages for fluidly connecting an annular space 10 above and below a blockage in the annular space to fluidly communicate around of the ring block.
Various other related embodiments of the yoke element may comprise a piston 15 that is slideable to displace or impact moving fluids or other well barrier element within said plurality of passages, using the pressure of the flowable fluid column, wherein the piston can slide can form a valve opening and closing at least one penetration in the tube wall to selectively and fluidly divert a portion of the column of flowable fluid in a circulation orientation, through said at least one penetration, or to fluidly communicate through a major portion of the flowable fluid column in the opposite direction of circulation.
Various embodiments can provide a pressure resistant plug element that can be mechanically or fluidly placed (2F-2K, 2N5, 2S2, 2T1, 2B7, 2D4, 2E7, 2N4, 202, 2P, 2Q, 2R1, 2S1, 2T3, 2U , 2V1-2V2, 2W2, 2X2, 2AE2, 2AG, 2AI, 2AK, 2AL, 2BF1, 2BF3, 2BI4) which can be expanded within said operable space and can be fixed or axially movable within at least one of said plurality of passageways to provide: displacement of at least a portion of the tube wall to provide an operable space, bridge across the operable space, or placement of at least one equivalent well barrier element of cement through the operable space to fluidly insulate the at least one portion of the underground well.
Other related embodiments of a fluidly placed pressure resistant plug element may include a mechanical plug with cylindrical components, bag or umbrella.
Other embodiments of a fluid dispensing pressure resistant closure member of the present invention may comprise a gelatinous closure with particulate or rheological fluid components that can be fluidly placed and gelatinously secured within at least one of said plurality of passageways.
Still other related embodiments can comprise graded particles with intermediate pore spaces that can be filled by a mixture of chemical reagents to form the gelatinous plug.
Embodiments of the present invention may include a compressible graded particle slurry which may have a mixture of chemical reagents comprising: a first fluid mixture of 5% to 60% organophilic clay. by weight of the composition mixed with a hydratable gelling agent that is sufficient to suspend the clay with thickening material and alkaline source components placed within 15% to 60% water by weight of the composition, wherein the first fluid can be Chemically mixable and readable with at least one second fluid, which may comprise 15% to 60% water by weight of the composition, and may be mixed with at least one of: i) hydraulic cement, from 15% to 75% by weight of the composition, or ii) oil-based slurry comprising 15% to 60% oil by weight of the composition mixed with materials weighing 15% to 75% by weight. composition weight. Although the aforementioned embodiments include particular ranges of percentages by weight of the materials of the composition that make up the graded particulate compactable slurry (i.e., the mixture of chemical reagents, organophilic clay, water, hydraulic cement, oil-based slurry, and the like thickening materials), other combinations of composition weight percentage ranges are possible for such materials.
Various other related embodiments may comprise axially compressing adjacent well components, within adjacent axially operable spaces, with a fluidly placeable pressure resistant plug element to form or enlarge the operable space. In one embodiment, an axial piston component may be used to axially displace at least a portion of a tube wall, moving liquids, or combinations thereof, by axially compressing the axially adjacent components within the axially adjacent space to form or expand the operable space.
Still other embodiments may comprise laterally compressing well components within the radially adjacent operable spaces, with a fluid placement pressure resistant plug element, to form the operable space for placement of at least one barrier element. of equivalent cement well through the operable space to fluidly insulate at least a portion of the underground well. In one embodiment, a side piston component may be used to laterally compress well components within adjacent radially operable spaces, with a closure element, e.g., fluidly placeable pressure resistant closure element, to form the operable space for placement of the well barrier element to fluidly insulate at least a portion of the underground well without removing the plurality of installed pipes and associated debris from one or more underground depths (218) below and to provide or enable restoration of the rock cover above of the reproducible zone.
Other embodiments of the present invention may provide a percussion element (2E3, 5 2S3, 2T2, 2U2, 2V1, 2W1, 2X5, 2BF3, 2BG6, 23H1-2BH3), which may comprise a lockable piston and 1 lockable piston, sealable inside of said innermost passage and firing by the energy released from the compression of said column of circulable fluid, 10 to travel along a dance pole or relock rod and emit an explosive hydraulic pulse of percussion, a mechanical impact, or its combinations, against objects below said releasable piston.
Finally, various other embodiments of the present invention provide explosive particles or an abrasive particle cutting element (2B6, 2E8, 2AV7) to remove the wellhead and enveloped tubes above the point of separation to complete the well abandonment. BRIEF DESCRIPTION OF THE DRAWINGS
Preferred embodiments of the invention are described below as examples only, with reference to the accompanying drawings, in which:
Figures 1 to 3 illustrate prior art diagrams of operations of different types of drilling rigs and Figure 4 shows a normally unmanned prior art marine platform. Figures 5 to 7 illustrate different 30 types of prior art probeless drilling operations.
Figures 8-9 illustrate prior art equipment that can be used to perform probeless operations,
Figure 10 shows a typical prior art well abandonment drill rig 5 for comparison to the industry published non-rig abandonment issues and conventional minimum requirements shown in Figures 11-15.
Figures 16 to 19 illustrate various embodiments of the present invention for the use and/or abandonment of substantially water or substantially hydrocarbon wells. Figure 20 illustrates a prior art well 15 configuration prior to abandonment. Figure 21 shows the same well afterward. of abandonment using various embodiments of the present invention.
Figures 22 to 26 show various embodiments of fluid elements of controllable rheology and positionable in the annular spaces of the present invention. Figure 26A illustrates a blend of hard and expandable material implantable with the fluid elements of Figures 22 to 26.
Figures 27 to 34 illustrate various embodiments of axially sliding annular locking deflection elements which may be used in the systems and methods of the present invention.
Figures 31 to 34 illustrate several 30 embodiments of an annular piston element that can be used in the systems and methods of the present invention.
Figure 34 illustrates an embodiment of a tube pin element that can be used in the systems and methods of the present invention.
Figures 35 to 41 show various annular piston element embodiments while Figures 42 to 46 illustrate percussion element embodiments, which can be used in embodiments of the system and method of the present invention.
Figures 47 to 5 3 and Figures 62 to 6 6 illustrate various embodiments of motorized access to the annular space, while Figures 54-61 illustrate various embodiments of the annular space piston, which can be used in embodiments of the system and method of the present invention .
Figures 67, 68 and 6A to 68B illustrate an expandable mesh membrane swellable member embodiment of the present invention.
Figures 69 to 71 show various embodiments of annular perforation, annular registration and piston plug annular access which can be used in embodiments of the systems and method of the present invention.
Figures 72 to 74 illustrate various embodiments of the router, while Figures 75 to 79 illustrate apparatus that can be used in various embodiments of the present invention. Figures 80 to 84 show various embodiments of the annular space separation of the present invention.
Figures 85 to 92 illustrate an embodiment of an axially slidable annular locking contour element, and Figures 94 to 104 illustrate various embodiments of striking element, which can be used within the scope of embodiments of the present invention. Figures 105 to 116 show various annular motorized access embodiments of the present invention.
Figures 117 to 122 illustrate various annular access guide embodiments of the present invention. Figures 123 to 147 illustrate various motorized annular access embodiments of the present invention. Embodiments of the present invention are described below with reference to the indicated figures. DETAILED DESCRIPTION OF ACHIEVEMENTS
Before explaining selected embodiments of the present invention in detail, it should be understood that the present invention is not limited to the particular embodiments described herein and that the present invention may be practiced or carried out in various ways.
Figure 1 is an isometric view of a prior art mobile self-elevating platform of a maritime drilling unit (163) with crane (195), helipad (194) and large scale drilling tower (193A) on a normally unmanned platform ( 170), which can be used, for example, to support the day-to-day needs of a hundred people while drilling a well kilometers into the underground strata. The wellhead (7) sits on the normally unmanned platform (170) immediately below the tower (193A) which is cantilevered over the platform once the facility is raised. While building a well and conducting drilling operations 10 offshore or on land require a significant level of resources and associated costs, abandoning the same well may require significantly fewer resources if installed pipes are left within the strata, but as conventional drillless methods to meet the various published industry standards for most wells are not adequate, drilling equipment is often used to abandon wells despite their cost.
Figure 2 shows an isometric view of the prior art modular drill rig crane, platform floor and pipe yard arrangement (165) without support equipment such as mud wells, pumps, compressors and power generation, with a large lifting capacity mast (193B) with lifting capacity comparable to the tower (193A in Figure 1), which can be used at sea or on land. Figure 2 shows another example of a platform 30 capable of drilling, usually over-specified for well abandonment, as it is difficult to move, erect and operate, and therefore expensive, despite a significantly smaller footprint compared to complete drilling rigs (eg 163 of Figure 1 and 164 of Figure 3).
Figure 3 is a front view of a prior art semi-submersible floating offshore drilling unit (164) with a crane (195) and full-size drilling rig (193A) floating at sea level (122A) on 10 rigs control devices (168), comprising a subsea eruption preventer (9A) coupled to a subsea tree and wellhead (7) on the seabed (122). Subsea well operations, including abandonment, must take into account the hazards and hydrostatic pressure of the column of ocean fluid between the seabed (122) and sea level (122A). Subsea operations without rig are possible with pressure control equipment (168A) significantly smaller than 20 subsea rigs of a drilling rig (168), but similar to surface equipment (168C and 168L of Figures 7 and 9, respectively) that is adapted for subsea use and implementation, coupled to a subsea tree and wellhead (7), in which lubricators and logging cable are deployed from a boat (201 in Figure 6) and coupled to the subsea tree and the well head (7). For the abandonment operations without rig, well barrier elements would be placed without rig through the lubricator (8 of the
Figures 7 and 9) on the boat, then lowered and coupled with the underwater tree to perform abandonment operations. Thereafter, the wellhead (7) could be cut and retrieved for the boat, as the ocean floor (122) was isolated from the underground pressure sources using permanent well barrier elements, eg cement.
Figure 4 is a plan view of a prior art normally unmanned marine platform (170A), optionally with a helipad (194), represented by dashed lines, for personnel access and a crane (195) for lifting boat rig (201 in Figure 6), illustrates the relatively small dimensions of the underlying deck jacket of 8.5 meters by 12 meters. After several operational production apparatus (196) and production manifolds and piping (197) are placed on the platform, there will be little room for intervention in wells and abandonment equipment, therefore, drilling rigs, despite being over-specified for various necessary operations as described in Figure 1 are sometimes required to provide the necessary space for personnel and equipment. Limited space in such installations may also preclude the use of probeless arrangements as described in Figure 5, where only the minor space requirements of probeless operations described in Figures 6, 8 and 9 may be possible.
Figure 5 shows an isometric view of a prior art probeless arrangement (166A) published in U.S. patent 7921916B2 with a jib crane (195), pressure control 5 (168B), comprising, for example , a compaction element, and working column (199) or pipe handling equipment (198) . Figure 5 illustrates a probeless arrangement designed to operate below ground level (121) or below sea level (122A) and mud line (122). Although embodiments of the present invention can be used with drilling probes (163, 164 and 165 of Figures 1, 3 and 2, respectively) and this probeless arrangement (166A), the present invention can be used with non-probe arrangements. probe C166B and 166C of the
Figures 6 and 7, respectively), which can be placed and operated in environments with limited space, where that arrangement (166A) may not be feasible.
Figure 6, an isometric view of a prior art probeless arrangement (166B) and offshore access system (200) from a boat (201) floating on the surface of the ocean (122A), illustrates a platform not normally used. manned (. 170B) with a mast (169) to deploy the wellhead (7) coupled pressure control equipment (16 8 D of Figure 9) and cable tool operations, which can be used with the methods and apparatus of the present invention.
Figure 7 is a front view of a prior art probeless ground arrangement (166C) that can be used with the present invention to reduce the cost and space requirements of abandonment. It depicts a truck (202) with a shaping cable winch (203) performing the deployment of a flexitube column (187), composed of, for example, coiled wire or flexitube, passing through several pulleys and inserting a lubricator ( 8) coupled to blowout preventers (9), and further coupled to the valve shaft (10): and the wellhead (7). A work post (199) is deployed with rotatable (72) and/or snap-on (98) connections at its lower end, which can be used with methods and apparatus of the present invention.
Figures 8 and 9 are isometric and front views of a prior art movable profile cable mast (169) profile cable eruption preventers (BOPs) and lubricator arrangement (168D), respectively, illustrate telescopic sections of the mast (205 ) above a base with pulleys (204) at the upper end, for the cables, on which a winch can be used to lift the pressure control equipment (168D) for coupling with a wellhead (7) . The mast (169) has a similar function to a rig (193A of Figures 1 and 3, and 193B of Figure 2), although with a significantly reduced lifting capacity suitable mainly for lifting pressure control equipment and lifting the lubricator (8), disconnected and connected again to the safety shutter (9) and to the valve shaft (10), in order to couple devices to a flexitube column (187) threaded through the lubricator and operated by a windlass (203 ). Pressure in a well is controlled, during intervention or abandonment, by closing the valve tree (10) and the BOP (9) when the lubricator is turned off for the placement and removal of appliances from within, after which the lubricator is reconnected and the valve and BOP are opened for implantation in the flexitube column (187), sealed in a sealing box located at the upper end of the lubricator (8), whereby the device can be deployed through the controlled pressure envelope of a well, through the wellhead (7) and the plurality of installed tubes coupled to and extending below the wellhead.
Figure 10, a schematic cross-sectional front view through the well and underground strata of the prior art permanent abandonment well with drilling rig (172A), depicts the production piping removed from the conductor (14), intermediate (15), production (12) and the seal casing (19) well casings, which are shown cemented to various bore diameters by the strata (17), between the bottom casing shoes (16) and various underground depths, within which cement plugs (20) are placed throughout the well to isolate hydrocarbon (95B) and water (95A) from producible zones or formation layers within the strata, whereby a portion of the production casing (12) is cut and removed for placement. of two plugs. As the gauge or diameter of the initial hole through the layers (17) varies between and over casing sections, the upper part of the cement behind the casing and above the casing shoe (16) is often unknown, if during the construction the record of adhesion to the coating was not performed and circulating pressures were used to estimate the cement top. In addition, due to testing, thermal cycling, and stress and pressure overload within a well, during its operational life cycle, the cement adhesion behind the coating may have been lost, even if it was initially present, providing , thus, an escape route for pressurized underground fluids. Various milling, crushing, and squeezing methods of the present invention can be used to emulate the removal of the innermost tubes by slitting and squeezing for placement of well barrier elements above their compacted remains.
As described later in Figures 14 25 and 15, the pipes can be left inside a well, during abandonment, provided a permanent barrier element, such as cement, is placed along the entire layer hole (17 ). In many cases, the depths and/or existence of a cement connection behind the various underground linings are unknown, and a drilling rig must be used to first remove the production pipeline to access the annular production space in order to carry out the registration of cement adhesion. on the other hand, various methods and apparatus of the present invention can be used to access these annular spaces in probeless operations so that registration can be made to determine the extent of cement adhesion behind the installed pipes, thus eliminating the need for a drilling probe
Referring now to Figures 11 and 12, a schematic front view of subterranean strata cut before (171A) and after (172B) the conventional permanent abandonment without probe, respectively, wherein the left part of Figure 11 shows a half cut through the strata and underground well casings, with a quarter of the completion section removed, and the right side is a simplified schematic representation of the left side, illustrating the intermediate casing (15) cemented {20} to a casing shoe (16) ) with the production liner (12) cemented (20) and penetrated (129), by firearms perforation, to expose a producible zone (95C). The production duct or tube (11), with nipple profiles or containers (45) above and below a production shutter (40) coupled to the casing (12), has a profiling cable entry guide (130) at the 30 your bottom end. During conventional abandonment, the cement is forced through the perforations, as shown in Figure 12, until the injection forces are too high, and the cement blocked, the cement (20A1) is left inside the pipe (11), Conventional operations is of 5 abandonment without probe, using installed pipes (11) for placing cement (20A1-20A3) inside the innermost passage (25), annular production space (24) and intermediate lining of annular space (24A), suffer from the inability to effectively circulate or support the cement placed, so contamination of the cement (20C) may occur. As shown in Figure 12, a plug (25A) was then placed in the tube (11), below the plug (40), and openings (129a) were made to place cement (20A2) in the innermost hole (25) and in the annular space of production (24) .
A second plug (25B) was placed using the flexitube column implant, then the tube (11) and production tubes (12) were penetrated (129B) to allow the cement (20A3) to be placed in the innermost passage ( 25), production annular space (24) and the intermediate annular space (24A).
As recording cement adhesions behind liners (12, 15) is generally not conventionally possible without pipe removal, neither the integrity of the cement behind the liner nor the top of the cement (206) can be confirmed as required by various standards of published industry. Although the (cement budget for producible zone (95C) may have been successful, lighter hydrocarbons may subsequently be pushed upwards and create channels within the cement (20A1), which prevents the barrier from being considered. Cement below the plug (40) and above the plug (25A) is likely to have been contaminated (20C), but although these small volumes are unlikely to cause pressure resistance integrity problems, the placement of cement (20A2) above the top of the cement (206) and behind the production liner (12) is not an acceptable permanent barrier in the industry, as the annular spaces (24A) are not cemented at that point (206). (20A3) placed through perforations (129) may not have entered the annular space of the intermediate liner (24A) and/or the fluid volume below the unsupported cement (20A3) may be sufficient to cause contamination of the cement (20C ) measure that it falls through lighter fluid.
The inability to confirm the existence of cement in the places necessary to form a permanent barrier capable of isolating underground pressures from above-ground environments, the ocean, and/or groundwater tables for an indefinite period of time is a serious problem for which conventional probeless abandonment often has no answers. Even when conventional flexitube is used to form a passageway for better cement placement during prior art probeless abandonment operations, in conventional practice there is no way to place probeless recording tools to confirm the existence of probe adhesion. cement nor are there any compatible cable tube grinding solutions in the prior art which are capable of removing low quality tubes and cement to expose the subterranean layers in order to place the good quality cement. Embodiments of the present invention can be used to solve the problems of recording, cementing and grinding tubes in a pressure-controlled environment through flexitube column operations in a cost-effective manner currently unavailable to professionals.
Figure 13, a plan view of a prior art concept of fluid flow within an offset eccentric tube arrangement (167.C), illustrates, for example, a production pipeline tube (11) within a tube. lining (12) within an intermediate lining tube (15), with a control line (79) within the annular production space (24), in which the tube (11) and the production lining ( 12) are eccentric with respect to the center of the intermediate coating (15) . If the eccentric tubes are not separated when, for example, penetrating the tubes and circulating through the innermost production passage (25) and back through either the annular space of the production tube (24), or intermediate tube ring (24A), a tube (207) of higher flow velocity will occur in the lowest frictional areas of the fluids which will reduce the flow, at a flow rate close to zero, due to the areas of higher friction (208) where the tubes touch or are too close. As probeless abandonment generally uses pipes installed to circulate a permanent well barrier, eg cement, into the well, the effect of zero flow in areas of high friction (208) can prevent pipe cleaning to create a wettable surface and/or the placement and adhesion of a fluidly circulable and hardenable permanent well barrier element, eg, cement, which can result in a leak path over time, even if the arrangement maintains, 15 start. the Intent è, the pressure from above, as lighter fluids and/or subterranean pressures find their way to the surface, through erosion of contaminated or poorly adhered barriers. Other serious leak path problems for probeless abandonment 20 are control lines (79) and cables in conventionally inaccessible annular spaces that cannot be filled with cement due to, for example, resistance to capillary friction. As conventional rigless approaches are not able to deal with pipe runout or the presence of control lines, drill rigs are often used for well abandonment.
Figure 14, a schematic front view 30 of the prior art concept of degrading a well barrier (167B), illustrates poor adhesion resulting in an annular microspace (210A) between cement and a pipe or absence (209) of cement. (20), which provides a potential leak path for fluids (210) from a producible zone 1 (95D), which can corrode liner tube (12) over time. Alternatively, the fluids can make their way into the annular production space (24) or travel upwards in the unfilled inner hole, or between the casing (12) and the cement (20) if there is poor cement adhesion, by where fluids can escape to pollute a surface or ocean environment, potentially causing dangerous conditions for inhabitants. For this reason, tubes and other devices, eg mechanical balers and plugs, are not considered permanent barriers as they will corrode over time. In addition, the surfaces of pipes and equipment must be clean and wettable to provide good adhesion, thus preventing corrosion, and providing a permanent well barrier element that retains its ability to resist pressure indefinitely.
Figure 15 is a schematic front view of the industry's published conventional acceptable minimum requirements for probeless abandonment (167A), showing a paraphrased representation of Oil and Gas UK Issue 9, January 2009 Guidelines for Suspension and Abandonment of Wells, Figure 1 entitled "Permanent Barrier schematic" Restoring the Cap Rock" used within the publication to describe "minimal industry best practices."
The industry's published best practices for the placement of a probeless permanent barrier 5 specifies the minimum height of good cement (219) of at least 30 meters, which must be placed at a depth (218) determined by the impermeability of the formation and strength of primary cementation behind existing coating 10. Circumferential tube separator (211) is required to prevent channeling (207 of Figure 13) of high fluid friction zones (208 in Figure 13) that result in cleanliness, poor adhesions and/or lack of cement (209 in Figure 13) 14) .
Low axial support (212) of the cement is required to prevent cement movement, collapse and gas migration during hardening, and surfaces wetted with clean water to provide good adhesion (213), 20 thus preventing poor adhesion and annular microspaces ( 210A in Figure 14) and leak paths (210 in Figure 14). Once these minimum requirements are met, published references generally conclude that a probeless operation will provide 25 "well barrier elements", from a permanent seal abandon plug (216), with the innermost pipes sealed with cement over cement. (217) and the casing and piping embedded in the cement (215). Provided that both the existence and sealing adhesion of the primary cement (214), adjacent to an impermeable formation and of adequate strength, are present, the resulting cement will contain future pressures (220) , Although "cement" is specified, the Oil and Gas UK Guidelines have also provided permanent alternative well barrier elements, as long as they provide an equivalent function to cement.
Meeting the industry's best drill-free abandonment practices, therefore, requires recording the primary cementation of the well behind the casing to ensure its presence and adhesion, followed by cleaning the well tubes to ensure they have wettable surfaces for cement adhesion. and embedding the piping and casings within the cement, by providing displacement, if necessary, of a sufficient portion of the well opposite an impermeable and resistant formation that is capable of replacing the rock cover.
Unfortunately, while current practice emphasizes the need to design for future well abandonment, this has not always been the case and some existing wells have been designed with no-rig abandonment in mind. For example, production plugs may be placed where future abandonment plugs must be placed and primary cementation may never have been recorded. As a result, conventional drillless abandonment practices are often inadequate to meet industry best practices for well abandonment, resulting in the use of over-specified drilling rigs.
However, the present invention can be used to unrig all, or a portion, of an underground well annular spaces and workable zones while meeting published industry best practices, such as those described in the Oil and Gas UK Guidelines and referenced NORSÕK standards. Meeting industry best practices for abandonment of wells requires accessing the annular spaces of the well in a probeless manner to record primary cementation, then remediate any poor primary cementation and place good cement plugs and/or other suitable seals. definitive abandonment inside a well.
Referring now to Figures 16 to 19, 21 to 46 and 48 to 74 they show various schematic cross-sections through well components and underground layers, the Figures illustrate methods and system or element embodiments for operating in wells and access reproducible zones and annular spaces by means of a wellhead (7), which is shown coupled to a plurality of tubes, comprising: conductor coatings (14), intermediate coatings (15), secondary intermediate coating (ISA) and production casing (12), cemented (20) at its lower ends, for the formation of casing shoes (16) within holes of different diameter in the underground strata (17), with an innermost tube (11) or pipe. production (11) coupled to the wellhead, inside the production casing (12), and secured at its lower end with a production packer (40). A seal lining (19) and seal lining top plug (40A) may also be present in various well configurations, with the seal lining or linings penetrated (129) by perforation by firearm elements or embodiments to enable production (3 4 P ) from a producible zone with lined pipes (95F). Any embodiment can be used with a wellhead (7), which can be placed in the mud line (122) if below sea level (122A), or at ground level (121) with production (34P ) occurring through the production pipe (11) from an open well producible zone 15 (95E), Production (34P) can be controlled by a valve tree (10, 10A) using surface valves (64) and/or by a subsurface safety valve (74) and control line (79) coupled to the tube (11), with 20 clamps below the wellhead (7).
A column of recirculating fluid (31C) can be circulated axially downwards or upwards through the tube (11), returning or entering, respectively, for example through the annular space 25 between the production liner (12) and the pipe ( 11), using a side sliding door (123), and the lower end of the piping and/or piping penetrations (11), to take the circulated fluid returns or to pump a recirculatable fluid through the opening of the annular space ( 13), of the annular space opening valve (13A), and/or the valve shaft (10). Circulation of the circulating fluid column (31C) in any of the annular spaces can also occur through openings between the passages of the annular spaces entering and leaving the openings of the annular spaces of the wellhead (13). The circulating fluid column (31C) may be stagnant, circulated through passages or injected into a permeable reservoir (95E, 95F) or fractures (18) in the strata, if the pressure exerted by the fluid column is sufficient. The flowable fluid column (31C) can be used to lay down well barrier elements, for example cement or graded particle mixtures, or to clean well components to provide a wettable surface (213 of Figure 15) and/or placing fluid elements of controllable rheology and fluid elements capable of being placed in the annular spaces during probeless abandon operations.
Conventional registration usually takes place within the innermost passage (25) and is unable to determine the state of the primary cementation around the liners (12, 14, 15 and ISA) as the registration tools inside the production tube (11) they cannot come into contact with the coatings. Various embodiments of the present invention, e.g., annular piston and annular space access elements, can be used to access the annular spaces for placement of registration tool elements to confirm primary cementation adjacent to the tubes (214 of Figure 15). Signals can, for example, be transmitted from the recording tool with the reflected signals collected by a different part of the recording tool, or the signals can be transmitted between the wellhead, surface or subsea sites and the in-hole transmitter or receiver . By using the embodiments of the recording tool methods of the present invention, the measurement signals can be coupled with the circumference of the tube walls to provide measurements of sonic, acoustic or various other forms, for example, the response time of the signals. which pass through adhered (216 of Figure 15) and non-adhered (209 of Figure 13, 210A of Figure 14) pipe cementation to measure the degree of adhesion and/or cementation present. The process can be visualized as making a glass beep or tinkle and measuring the received noise or vibration to determine if the glass is standing loose, in a liquid, or firmly cemented in place.
Depending on the result of the log measurements, various other elements of the element system of the present invention can be used to place temporary or permanent well barrier elements into the well at the appropriate underground depths (218-219) to meet industry best practices ( 211-220 of Figure 15} and avoid potential future leak points (210 of Figure 14, 208 of Figure 13) and/or simulate the abandonment of the platform (172A of Figure 10) by placing cement plugs (20) of the Figure 10 through sheaths (12, 15 and 19 of Figure 10) Furthermore, all embodiments are cable column compatible and therefore can be used with the probeless arrangement of Figure 5 or with the minimalist pressure controlled arrangements of the
Figures 6 to 10, to meet the published best practices (211-220 of Figure 15) for the definitive abandonment in the rig-less implementation of an underground well, ,
Various methods and elements, for example, controllable rheology fluids and expandable and swellable mesh membrane elements capable of being placed in annular spaces, can be used to temporarily restore sufficient integrity to fluid pressure by plugging fluid leaks to use the circulatable fluid column (31C) to provide sufficient cement (219 of Figure 15), at depths suitable for permanent barriers (218 of Figure 15), to contain future pressures (220 of Figure 15}, with annular separating elements that can be used to provide circumferential clearance1 (211 of Figure 15) for water washable wettable surfaces that allow for good adhesion (213 of Figure 15) during column fluid circulation (31C) and embedding of pipes in cement (215 and 217 of Figure 15) in order to provide a permanent abandonment sealing plug (216 of Figure 15) in accordance with published industry guidelines.
Various methods and elements, for example, axially slideable annular locking deflection, annular space guide, annular space drilling access and drill bit plug-in tube elements can be used to embed the casing (12, 14, 15, 15A, 19) and the pipe (111, in cement (215 of Figure 15), with the pipe and liners filled and wrapped to provide cement pipes in cement (217 of Figure 15), using a bypass arrangement around of locks in an annular space, eg a production shutter, and 15 by drilling inside annular spaces to create a recording space and a fluid circulation path, which can be used with recording tool elements and the circulating fluid column through holes and annular spaces of the well, at a selected depth (218 of Figure 15), to provide sufficient cement (219 of
Figure 215) that is adjacent to a primary cement barrier, adhered between the outer skins (12, 14, 15 and 15A) and an impermeable formation of sufficient strength to contain future pressures (220 of Figure 20). Thus, a permanent well barrier seal element (216 of Figure 15) can be provided in accordance with published industry guidelines.
Various other methods and elements, for example, annular piston, percussion, crushing and circumferential grinding, and axial elements movable by screw or traction, can be used to simulate a platform abandonment (172A of Figure 10) by compression, grinding and/or crushing of tubes, inside linings (12, 15 and 19 of the
Figure 10), to remove the tubes within the height of a barrier (219 of Figure 15) to the required barrier depth (218 of Figure 15) and through a resistant waterproof formation (220 of Figure 15). Thus, this provides permanent abandonment cement plugs (216 of Figure 15) within casings (12, 15 and 19 of Figure 10) in accordance with published industry guidelines.
Still other methods and elements, for example, temperature controllable fluids that can be placed in the annular spaces, and the annular piston elements, can be used as or in support of well barrier elements, e.g. cement, to prevent adjustment movement of the barrier, collapse and/or gas migration during hardening (212 of Figure 15) to provide good adhesion and ensure sufficient cement (219 of Figure 15) at a depth (218 of Figure 15 ) adjacent to a tough waterproof formation (220 of Figure 15) to provide permanent abandonment cement plugs (216 of Figure 15) in accordance with published industry guidelines.
Furthermore, while Figures 16 to 19, 21 to 46 and 48 to 74 illustrate various operable elements, compatible traction column cables (187) and/or compatible electrical and fluid column cables (31C), said elements can also be used with flexitube and/or articulated tube column, in various other configurations of conventional probe and probeless operable arrangements, in which the circumferential cutting elements and rotating handle tools of the present inventor and described in the referenced applications may also be used. as elements.
Figure 75, an isometric perspective view of the rotary handle tube cutting tool (175) can be used, for example, as a cutting element of the present invention and illustrates a cutting arm assembly (175B) 15 extended by the combination. the rotation of the rotary connector (175A) and the frictional resistance of the drag block (175C), where the element can be deployed through the innermost tube and can be used to cut through multiple lines of casing, with the roller of low torque cutting. This is similar in nature to a plumber's pipe cutter which can be deployed from the inside out rather than the outside in. Various apparatuses of the present inventor as described in GB 25 1Õ11290.2, including the drill bit (174), and/or conventional cutting devices can be used with a conventional motor and/or by the cable-compatible motor assemblies of the present inventor, and can be used as elements within method 30 of embodiments. es of the present invention.
Referring now to Figure 123, an isometric view of a method (1B0) of embodying a motorized element (2BO) is shown compatible with cable operations and which may be used within various embodiments of the present invention. The Figure shows an upper rotary connector (7 2U) that can be attachable to a cable (187 of Figure 9) and deployed through pressure control equipment and the innermost passage tube to operate various conventional and invented devices (2B01) , which can be used to access annular spaces and producible zones, to place the partially shown well barrier elements (3BO), 15 to leave a portion (4BO) of a well. The motor element (2BO) is constituted by a lower rotary connector (72L), which can be coupled with the elements (2B01) of the present invention and rotated by a fluid motor assembly (2B02), which is secured from above. (2B04) and below (2B03) by anti-rotation devices. The fluid motor is operated by pumping the circulating fluid column (310, bypassed by seals (2B05), which couples the circumference of the inner tube plus 25, into holes (59) that can be used to operate the motor (2B02) and lower element (2BQ1) within method embodiments of the present invention, wherein the element is an example of a motor usable in the following embodiments of the method.
Figures 16., 17, 18, 19 and 20-21 describe the methods and elements that can be used to access and/or abandon an entire well, which are interchangeable with other associated methods and 5 elements described in the rest of the specification, and which demonstrate that the adaptive system of methods and sets of elements of the present invention can be used to address the variability of underground strata and design characteristics of 1.0 wells of substantially water and substantially hydrocarbons when accessing, using and/ or abandoning at least a portion of a producible zone and annular spaces of an underground well.
Figure 16 is a cross-sectional front view of a recording tool (IA) method element of embodiment which can be used with a set of elements (2A) comprising transmitter (2A1-2A3) and receiver (2A4-) elements. 2A6) of conventional recording tool within a plurality of passages below a wellhead (7), shows signals transmitted axially upwards (17 3A) or downwards (173B), e.g. by means of wires or acoustically through the pipe walls and/or by means of fluid pulses within the fluids in the annular spaces, to measure the installed well barrier elements (3A1-3A3) and to determine the need for new well barrier elements 30 ( 3A4-3A6) within portions (4A1-4A3) of the well axially below the wellhead (7). The signal transmitters (2A1-2A3 and 2A7) and/or receivers (2A4-2A6) are coupleable with tubes, or fluids from the annular space, through penetration embodiment (2A3, 2A4) or through wellhead openings in the space annular (13) . A signal can be sent from the wellhead (2) or from an external transmitter (2A7), which can function in a similar way to a VSP recording tool used to calibrate the seismic data, but it can also be used to verify the existence of primary cementation adjacent to the hole in the strata (17) . Various embodiments of the present invention can be used to place the transmitting or receiving elements of the recording tool into a well, for example, the annular space piston method (IS of Figure 41) can be used to expose the production liner (12 of Figure 41) to the primary cementation record (20 of Figure 41) behind it; or, for example, an annular space perforation access element can be used to place the registration tool elements within any annular spaces.
Figure 17 is a cross-sectional front view with broken lines representing removed portions of the underground shaft and strata, which describes embodiments of a method (1B) that can be used with a motorized access assembly (2B) to the annular space (2B1, by example, 2B02 of Figure 123), circumferential crushing and milling1 (2B2, 2B5, eg 2BP1-2BP4 of Figure 129), access to annular space perforation (2B3, eg 2BU of Figure 147), annular locking bypass axially slidable (2B4 eg 2M Figures 28-30], cut by abrasive particles (2B6 eg 2AV7 of Figure 72) and annular piston elements (2B7 eg 2T3 of Figure 42), which can be deployed inside a well environment with controlled pressure without probe (168E). The Figure shows the elements (2B1, 2B2) inside the lubricator (8) that is coupled to the BOPs (9) and to the valve shaft (10) coupled to the wellhead (7), which can be deployed axially downwards into the interior. The upper part of the well using a flexitube column (187) Conventionally, the cement can be forced into the production zone (95F) and open well reservoirs (95E) penetrated by a drill gun, by injecting fluid from the circulating fluid column (31C) for the penetrations (129) of the seal casing (19) and open well (95E), to abandon a part (4 B 1) of the well to avoid further production (34P). Alternatively, an axially slidable annular locking deflection element (2B3) can be used to force the cement with a significantly reduced risk of missing injection with the cement-filled tube, where registration through the innermost hole (25) can determine if. sufficient primary cement (3B1, 20) exists behind the sealing lining (19) to insulate the reservoirs, prior to said forcing, while the annular space piercing element (2B3) can be used to access the annular space (24A) and determine whether the well barrier element (3B2) is sufficient to provide permanent integrity of the well to the portion (4E2) of the well.
Method (1B) can be used to abandon without rig all or a portion of a well by means of a pressure-controlled (8, 9, 10) flexitube column arrangement (18), on land below ground level. (121) or at sea below the mud line (122) and below the ocean surface (122A) in, for example, a subsea wellhead (7 of Figure 3) or offshore platform (17 0A and 1 7 0 B of Figures 4 and 6), without resorting to conventional methods that require a drill probe (163-165 of Figures 1-3). A bypass element (2B4) of a sliding axial annular space production closure (40) (24) can be used to access the annular spaces (24, 24A) through the hole made by the anterior element (2B3) and potentially the sliding sleeve (123), to place cement over the well barrier element (3B2) inside the annular spaces, through the intermediate lining (15) shoe (16) cemented (20) and hole of the layers (17), to leave the part (4B2), using the column of recirculating fluid (31C), which circulated through the innermost hole (25), annular spaces (24, 24A) and wellhead (7) in the sockets (13A). The abandonment of the upper section can be carried out using a grinding and crushing element (2B2) which can be coupled with the motorized element (2B1) or other grinding and/or crushing elements (2B5) to remove the tubes (11, 1.2) to place a permanent well barrier element through the hole of the strata (17) for sealing a portion (4B3) of the well through the existing well barrier element (3B3) and casing (15), with the primary barrier record (3B3) that as soon as the milling is completed and the intermediate coating (15) exposed, before placing the barriers.
An upper portion of well HB4) may comprise components that may be much more difficult to mill, such as, for example, subsurface safety valve (74) with associated control line (79) and line clamps. control, within the annular production space (24), which can be used and/or abandoned by first cutting the production piping (2B 6) with, for example, a rotating flexitube column cutter (175 of Figure 75 ). Then a piston (eg 4U of Figure 43) can be used to compress (2B7) or crush the well components, for placing a well barrier element (3B4) through the cement conductor (14) primer (20) and casing shoe {16}, in the annular spaces (24A, 24B) and through penetrations by a piercing weapon or a tube attachable to a drill bit, eg 2BI2 and 2BI3 of Figures 112-116. After that, pressure control (7, 8, 9, 10) is no longer needed and the wellhead and upper end of the casing can be cut and removed from the well, by, for example, conventional abrasive cutting (2B6) of the remaining tubes (14, 15), thus completing the abandonment5 without a probe.
Figure 18 shows a cross-sectional front view showing embodiments of a method (1C) that can be used with a set of elements (2C) comprising drill bit insertable tube (2C1) and blocking deflection elements axially slideable annular (2C2), which can be even more useful for drillless operations in a conventional underground well mining solution. (2BI2-2BI3) of Figures 108-109, to pass over the annular space between the inner (11A) and outer (11B) leach column, thus leaving a portion (4C1) of the outer leaching column, and allowing that fresh water is applied to mining by solution from a salt deposit (4) below the top of the salt deposit of (5) to expand (34A, 34B) the producible brine cave (34) without the use of a rig. perforation 25 to first remove the internal leaching sequence (11A ). Then the outer leach chain (11B) can be adjusted and subsequently the inner leach chain can be replaced. After completing the solution mining to form the producible product storage cave (34C), the leach columns (HA, 11B) can be removed and a production liner (11) can be coupled to the cemented final production liner (12) with a plug (40), a valve shaft (10A) and surface valves (64, also shown in Figure 17) installed at the upper end of the well, which can be used for storage operations. , a portion (402) of the producible storage frame (34C) can be used and/or abandoned in a probeless operation by installing an axially slidable annular locking branch (2C2) to flow around the shutter (40) and circulate through the cavern filled with abandoned materials, eg solid debris, with the remaining portion (4C3) within the main barriers (30, abandoned without a probe by circulation in a well barrier element, such as cement, using the Detour (2C2), after which the wellhead (7) can be removed by abrasive cutting or other probeless operations.
Referring now to Figure 19, a sectional front view through an underground shaft and strata is described, and shows embodiments of method (ID) which can be used with an array (2D) of annular locking deflection elements axially slidable (2D1), circumferentially expandable mateable (2D2), tube attachable to drill bit (2D3) and annular piston (2D4, 2D5), which can be used for drillless operations in a well manifold column of the present inventor, with an arrangement of columns for double production (11C, 11D), which can be used for sub-balanced lateral deflection operations through a pressure control device (168D) with, for example, flexitube (187) , to, for example, to control pressures and prevent well extinguishing with heavy liquids and to reduce film damage within reproducible formation zones.
In Figure 19, lower end penetrations (129A) and side through penetrations (129B) were placed using a selector hole, after which circumferentially expandable plug-in elements (2D2 ) were placed by the side penetrations15, eg 2AR2 of Figure 67. In then an axially slidable annular locking deflection member (2D1), e.g. (IBEj of Figures 85-93, may be placeable to leave the lower portions (4D1) of the penetrated seal liner (19) (129) , bypassing the smaller production plug (40) to circulate cement and to displace cement with a cement plug (25W), through the internal hole (25) and annular spaces (24, 24A), to leave25 the previous bypass portions (4D2) of the primary well barrier (3D1), thus suspending the final abandonment for a further lateral deviation. A drill bit coupling tube (2D3) that uses, for example, a flexible shaft and drill bit (2Y3 Figure 48) can mating with a fluid tube (2BI2 and 2BI3 of Figures 108 and 109) which can then be used to access a different formation in the producible zone for production (34) above the cemented lower section and below the cement plug (25W ), through the existing production pipe (11C) subsurface safety valves (74), valve shaft (10A) and production valves (64) coupled to the wellhead ( 7 ) .
After cessation of production, inner tubes 10 (11C, 11D) can be cut and annular pistons (2D4, 2D5), eg 2N5 of Figure 33, 202 of Figure 37 and/or 2Q of Figure 39, can be used to leave the upper portions (4D3) on the other side of the primary barrier (3D2) on the shoe 15 (16) of the production liner (12) and the upper portion (4D4) on the other side of the primary barrier (3D3) of the production liner conductor (14) by compressing descending equipment separate from the well, and potentially aiding said compression with a percussion element, e.g. (2T2 of Figure 42), and a rheological controllable fluid element (2T1) of Figure 42, after which the upper portion of the wellhead (1), the associated tubes and the valve tree (10A) 25 can be removed with, for example, probeless abrasive cutting, to return to ground level (121 ) to its original condition.
Figure 20 is a schematic front view of a section through subterranean strata 30, with break lines representing portions removed, showing a prior art hydrocarbon well for later probeless abandonment (171B) associated with Figure 21 , and using embodiments of the present invention, which describe a valve tree (10) with production valves (64) coupled to a wellhead (7), which is coupled to conductor (14), intermediate casing (15), production liner (12), sealing liner (19) penetrated by cannon (129) and production piping (11), which can be controlled by a safety valve (74), through a control line (79), which extends axially downward through pressure and fluid permeable strata formations (95G-95K) and relatively impermeable strata formations (94A-94K). The main factor affecting any project to abandon any underground well (171B) is the underground stratum (94A-94K and 95G-95K), which can vary significantly from one well to another, even within the same producing region, potentially they cause changes in the abandonment design and the usable elements in the realizations. Various types of production packaging (40, 40B, 40C) can be used to separate the producible zones used, for example, to control water production, where a bottom plug (25F) was used to isolate a producible wet zone. of water (95G), found during the construction of the well.
Figure 21 is a schematic cross-sectional front view of the strata, with break lines representing removed portions. The Figure shows embodiments of the method (1E) that can be used with an axially slideable annular locking deflection assembly (2E), (2E1, 2E5), axial tube crushing (2E2), percussion (2E3), access to annular space drilling (2E4), peripheral grinding (2E6), annular piston (2E7) and abrasive particle cutting elements (2E8), which can be used for permanent abandonment without rig of the well shown in Figure 20, representing suspension and recovered marginal production before the final abandonment of the well.
An axially slidable annular locking deflection element (2E1), e.g. (4M) of Figures 28 to 30, can be used to bypass the lower shutter (40C of Figure 20) and place a cement well barrier element ( 3E1) to leave the lower portion (4E1), in front of a resistant waterproof formation (94C of Figure 20), after which an axial tube mill element (2E2), for example, (2BR of Figures 135 to 140, with the motorized element (2BN) of Figure 124127), it can remove the tubes around the sliding side door (123), which has been dropped into and on top of which a cement barrier (3E2); can be placed, by forcing the flowable fluid column into the permeable producible zone (95H of Figure 20) to leave the next pouring portion, a percussion element (2E3) can be used against a touchable surface such as a piston or controllable rheological element, to compress the equipment and place a well barrier element (3E3) to further isolate and permanently abandon the lower portion (4E2) of the well, before suspending the abandonment and deviating laterally with a drilling access element of the annular space (2E4), for example (2AM4) of Figure 62, to provide the marginal production of a formation (95J of Figure 20), which may not have been initially completed, for example, because it presented a risk to the more favorable producible zones (95H and 551 of Figure 20) . After producing the offset formation (95J of Figure 20) the offset portions (4E3) are abandoned by penetrating the tubes and placing an axially slidable annular locking deflection element (2E5) over the penetrations to place a further barrier element. well (3E4), using circulation to place cement inside the annular space and the inner hole.
During previous abandonment, suspension and lateral diversion operations, well hazardous substances, eg LSA fouling, may be injected and abandoned in a fracture (18), formed for disposal purposes, which now comprises a portion (4E4) of the well that must be abandoned to protect a pervious productionable groundwater zone (95K). A peripheral grinding element (2E6), for example (2AY1, 2AY2) of Figure 74 or (2BP1-2BP4) of Figures 128 and 129, can be used to remove the piping (11) and production liner (12) , so that a cement well barrier element (3E5) can be forced into the fractures (18), thus leaving the part of the well (4E5) adjacent to the producible groundwater zone. Subsequently, an annular piston element (2E7) and method, e.g. (1BF) of Figure 94 to 10 99, can be used to compress the tubes and safety valve (74) downwardly, so that a barrier of cement (3E6) can be placed to leave the upper part (4E6) of the well, after which a drilling pin element, eg (1Z). of Fig. 49 and a cut through abrasive particles (2E8) can be used to remove the wellhead as one piece with a crane so that the ground surface (121) can be returned to its original state.
Furthermore, although the rig abandonment method (1E) can comprise numerous steps and elements with an increase in implementation time, when compared to a drill rig abandonment, the overall cost of abandonment is, in practice, significantly smaller than that of a drilling rig (163, 164, 165 of Figures 1, 2 and 3, respectively), because the work involves a limited amount of equipment and personnel, eg, non-rig abandonments (166A, 30 16613 or 166C) of Figures 5, 6 and 7, respectively, which are generally available at a significantly lower cost per unit of time, and where they can be used with the present invention, to satisfy published industry guidelines as recommended minimum 5 (211-220 in figure 15).
Figures 22-26 and 26A show sectional front views through fluid-filled passages showing embodiments of the method (1F-1K) that can be used to block associated passages, permanently or temporarily, until another barrier element member from well can be placed, using controllable rheology elements and fluid placeable in the annular spaces (2F-2K) comprising both conventional fluid and rheologically controllable slurry fluid (32, 33) embodiments that can be used with a fluid column flowable (31C) and the flow regimes described in this patent application to, in use, seal and/or support other 20 conventional and invented elements. The figures illustrate various fluid element placement arrangements. A controllable rheology element and fluid placeable in the annular spaces (2F-2J) may comprise any conventional fluid or slurry that can be used for well abandonment, e.g., conventional graded particle mixing, or an embodiment of the present invention , which comprises a first fluid having a high concentration of a hydrated organophilic clay that can chemically react with hydratable cement and/or a second fluid, e.g., oil-based slurry, which forms a viscous "goo" (32). The gooey material (32) can be loaded with graded mixtures of hard, expandable and non-expandable particles (33) that chemically react with a reagent fluid, placed at the point of use or transported with the particles, to form a "fluid slurry expandable or expandable" which may be capable of providing a well barrier member member that is placeable, serviceable and/or removable, with the ease of removal dependent upon the formulation being non-hardening and accessible. Fluid members (2F-2K, 3F-3K) can be deployed using theological and/or 15 flow regimes with top (221B-221D) and bottom (221A-221C) separation of sealable movable axial plug elements, which can comprise, for example, conventional separation of viscous and non-reactive polymer fluids, mechanical separation of plugs, or alternatively a container, such as a bucket that can be deployed by wire coil column. The reactants can be separated by the movable and sealable plug elements and can be controllably mixed using theological flow regimes, as the plugs exit the segregation arrangement or the bottom of the tube (11); and the fluid circulates upwards within the various flow regimes, eg bubble flow (223), and as the lighter and denser fluids interact, followed by slug flow or buffer flow (224), for comparatively large volumes of the first fluid, or transition flow (225), stops relatively small volumes of the first liquid, relative to the second fluid, with little annular flow (226) and/or annular flow by splines (227) that occur in changes of direction or in fluid passages with greater friction in the walls of the tubes.
Swellable particles from expandable well annular space abandonment packages can be of any shape (2Kl to 2K4 of Figure 26A) and composed of reactive hydrocarbons, reactive water or other uniform swellable reactive fluids (2K of Figure 26A), coated ( 2K2 of Figure 26A) and/or in layers (2K3, 2K4 of Figure 26A), which can be fluidly implanted within the plurality of passages of a well, where coatings can be applied to expandable materials or a film can inhibit swelling during implantation, and that it dissolves when placed and/or exposed to chemical reagents in a selected location of passage of the well and that helps in the formation of a matrix when broken or dissolved, thus exposing the swellable materials, to a reagent to make packaging of a gradual mixing of particles.
Various laminar and turbulent flow patterns of multi-rheological and/or multi-phase flows are possible when placing a well barrier element member or annular space mateable element of the present invention, e.g. well, depending on the frictional characteristics of the flow passage and the rheological properties, densities and velocities of the fluids. Two or more fluids of 5 different rheologies and densities, comprising two or more liquids and/or liquids and gases passing through a well passage, can take any of an infinite number of possible shapes, however, these shapes can be classified into 10 types of interfacial distribution, commonly called flow regimes or flow patterns. Regimes found in vertical flows include: bubble flow (223), where a first fluid is continuous, and there is no dispersion of a second fluid of different rheological properties within it that causes a bubble effect within the first fluid; slug flow or plug (224), where the second fluid bubbles coalesce to make larger bubbles 20 approaching the diameter of the passageway; transition flow (225), where the slug flow bubbles have been disrupted to form an oscillating agitation regime; annular flow (226), wherein the first fluid circulates, as a film, on the tube wall 25 (with some of the first fluid entrained in the core of the second fluid flow in the center); and annular flux flow (227), in which as the fluid flow rate increases, the droplet concentration in the core of the second fluid increases, which leads to the formation of large blocks or wisps of the first fluid. .
Fluid members of controllable rheology and placeable in the annular spaces (2F-2J), which comprise embodiments, e.g., drop-off slime (32) with graded expandable and/or non-expandable packaged particles (33) have the desirable characteristics of being easily placed within tight spaces, such as annular spaces and permeable well zones, where degraded pipes, partially collapsed pipes, debris from milling or crushing pipes and/or there are fractures in the reservoir, to, in use, provide a seal resistant to pressure, using arrangements of its liquids and/or packed particles with a controllable rheology in placement and chemical reaction with the surrounding or shaped fluids. The chemical reaction of the goo (32) can be visualized as organophilic hydrated clays mixed with the oils and suspended heavy particles, such as barite, in the oil-based slurry to form a gelatinous substance or clays mixed with cement to form a hard solidifiable substance. The chemical reaction in a mixture of expanding graded particles (33) can be visualized as hard graded particles (191 of Figure 26A), such as porcelain spheres, graded sand and gravel, or any other rigid material to form a matrix of contacts. with pores filled by smaller, non-expandable and/or expandable graded elastomeric particles (192 of Figure 26A), which can fit into the pore spaces and swell when exposed to, for example, hydrocarbons, thus further packing the particle contacts to form a gradual swelling particle mixture (33) that may be able to withstand the pressure.
The graded particle mixture (33) can be transported through the column of flowable fluid in, for example, components of water or non-hydrocarbon goo (32) and then mixed or poured into a dehydrocarbon fluid to swell and form an obturator within, for example, well annular spaces. As the goo (32) can be a 15 hydrocarbon based formulation, with the graded expandable particles (33) added to the goo during mixing or when placed on top of the goo in a plurality of placing stages, with the lighter hydrocarbons rising through the 20 particles of the goo (32) and can be used to swell mixtures of graded particles (33), implanted separately or together, and dependent on the swelling time of the particles, once exposed to the reagent. Mixtures of the goo 25 (32) and the expandable graded particles (33) can be compressed with the flowable hydrostatic fluid column (31C) by applying downward pressure from the wellhead to further compact, and/or solidify the mixture. of 30 graduated particles. Selectively control the mixture of graded particles (33) and low gravity solids from the goo (32) placed within a well space, and force excess moving fluid or goo gels (32) out of the pores of the mixture of particles. graded expandables (33) 5 can leave a matrix filled with hardened particles with pores completely filled by any expandable particles or low gravity solids of the goo to form a bridge over the walls of the well tubes, which may be able to hold more pressure. to, for example, maintain a significant cement column or act as a temporary production shutter for further marginal production, prior to the definitive abandonment of a well.
The application of goo is generally not practiced within the industry as it involves a reaction similar to the rapid hardening of cement. As a result, their practice is generally limited to regional applications where lost circulation presents a greater risk than said rapid hardening. While the goo is practiced in drilling applications where fracture formation and lost circulation are prevalent, it is not practiced in abandonment of 25 wells. However, as demonstrated herein, the present invention provides a significant improvement in dropout by providing methods for controlled placement, mixing and application that provide improvement relative to the inclusion of graded expandable and non-expandable particles compressible with goo to form a pseudo - pressure resistant particle matrix obturator that can be placed by fluid into the annular spaces. Various goo formulations can be summarized, for example, by a first fluid clay mixture
Organophilic from 5% to 60% by weight of the composition mixed with a gelling and hydratable agent sufficient to suspend clay concentrations and with thickening material and alkaline source components placed within 15% to 60% of water by weight of the composition. The first fluid can therefore be mixed and chemically reacted with at least one second fluid, comprising 15% to 60% water by weight of the composition, and mixed with: i) 15 to 75% hydraulic cement by weight of the oil-based composition or slurry, which contains from 15% to 60% oil by weight of the composition, mixed with thickening materials from 15% to 75% by weight of the composition. Thus, various embodiments of 20 controllable rheological fluids of the present invention can provide a graded mixture of graded expandable and/or non-expandable particles compressible with goo to provide a packing or matrix with porous spaces 25 filled by pressure resistant goo that can be implanted by fluid.
As the goo element (32) is a cementation and/or gelatinous mixture with optional compressible graded expandable and/or non-expandable particles 30, it can form, for example, a pressure-resistant plug embodiment, which depends on friction between the reacted gelatinous theological fluids and/or particles, such that the elements of the goo can be selectively and easily placed, used and then removed with chemicals that disperse the bonds, causing gelatinous rheology, to reduce swelling of, for example, elastomers between hard particles and/or to dislodge the gels or particles with, for example, motors that can be deployed by shaping cable, tractors and drills of the present inventor and/or other means.
Figure 22, a schematic cross-sectional front view, illustrates the left half of a well tube for a method (1F) of embodiment, with an assembly (2F) of fluid elements and separation plug elements (221A, 221B) which can be used with, for example, Production pipes ill) inside another pipe. For example, the production liner (12) can be used when the method of (1F) involves the column of circulating fluid (31C) between the innermost hole (25) and the annular production space (24), and through , for example, the lower end of the pipe (11), a placed element of tube that can couple to the drill bit (eg 2BI2 of Figures 112-116) or penetration and thus displace a lighter and less fluid. dense, such as water, with a viscous and denser fluid, for example, a well barrier element (3F) such as cement (20) or a rheological element that can couple to the annular space (2F) as a goo ( 32), within the portion of the well (4F) to be used and/or abandoned. The formation of a goo (32) to, for example, support the subsequent placement of cement, can occur by using two displacements, the first step being the displacement of water with a saturated fluid of highly concentrated hydrated organophilic clay, and the second step the . of mixing reactant fluid comprising dense and viscous oil-based slurry, similar to that used in drilling operations, to, for example, provide a viscous goo (32) capable of sealing limited pressure and/or withstanding another dense fluid, for example, cement.
Referring now to Figure 23, it shows a schematic front cross-section of the left half of a well tube, showing the method embodiment (1G) and the fluid elements (2G), which can be used with, for example, production piping (11), inside another tube, such as production liner (12), where the aim may be to circulate column fluid (31C) between the ring (24) and the hole plus 25 internal (25) to place a controllable rheology element and fluid placeable in the annular spaces (2G), eg a mixture of expandable graded particles (33) to leave a portion of the well (4G), with the lower bridge across. 30 of the walls of the larger tube (12) comprising, for example, a grout element (32) or a piston element (for example, 2AG of Figure 56). The grading, expandable particle mixture (33) can be implanted by diffusing it into position and allowing the particles to fall onto a support element. A fluid goo element (32 of Figure 22) implanted in this way may involve pressure to inject the gelatinous mixture downward into, for example, any pouring portions of a crushing piston arrangement (for example, 2AG of Figure 56 or 2X2 of Figure 46).
Figure 24 is a schematic front cross-section of the right half of a well tube, depicting the embodiment of a method (.1H) that can be used with fluid elements (2H) within, for example, the intermediate casing (15 ) and with a smaller tube, for example the production liner (12), which has been outwardly expanded into the intermediate annular space lining (24A) by a piston element (2H1). Method (1H) involves forcing fluids from the flowable fluid column (31C) beyond partial closure, caused by deformation of the casing (12) into the piston element (2H1), using a well barrier element member ( 3H), for example, cement, or an element of controllable rheology and fluid capable of being placed in the annular space (2H3) , for example, goo (32) , oara
Fluid mixtures can enter through a tube element attachable to the drill bit (2H2), for example, from 2BI2 Figures 112-116, or through penetrations into the inner tube (12) with, for example, agitation (225 ) and the tufted flow (227) at the intersection, with denser fluid falling into the annular flow (226).
Referring now to Figure 25, a schematic cross-sectional front view of a method embodiment (II) and fluid element assembly (21), which can be used with a well tube, e.g., production piping ( 11), inside another pipe, such as production casing (12), wherein the portion of the well to be used and/or abandoned: (411, 412) comprises piping (.11) and casing walls (12) and a leak obstruction (411) through the casing walls. Conventionally, cement placement (20) involves mixing chemical components on the surface and transporting them intrabore with any misalignment of fluid levels (311), being equalized (312) by the U-tube effect of higher density cements. The method (11) for placing a controllable rheological fluid, e.g., goo (32) and the mixtures of goo particles (32, 33) comprises separate placement of well fluid barrier elements (311-312) or mateable elements of the fluid of the annular space (211-212), eg, cement (20), grout (32) or of expandable graded particle components (33) separated by plugs (221A-221C) that fall through the innermost passage (25), and allowing the mixing of fluids in the annular space (24) with, for example, the agitation flow (225), caused by the rocking of the interior (25) and upward and downward passages (211) of the space. annular (24), with alternating pressures applied between the passages in the wellhead openings and the annular spaces; followed by allowing the fluids to equalize (U-tube) (212) at similar density levels and/or to apply equal pressure from above to compact, for example, goo in portions (411, 412) of the well, to be used and/or abandoned to assist in packing the graded hard particles (191 of Figure 26A) into the mixture until swelling of the blended grade particles (192 of Figure 26A) supports, for example, cement above the goo.
Figure 26 is a schematic cross-sectional front view of embodiments of the method (1J) and set of elements (2J) that make up the drill bit attachable tube, which separates the plug placement, controllable rheological fluid goo and mixing elements of compressible graded particles, which can be used with well pipes comprising, for example, the intermediate casing (15), production casing (12) and piping (11), in which a plug (25A) is installed inside of the innermost passage (25), connected to the surrounding annular spaces (24, 24A) by penetration of a tube element attachable to the drill bit (2J 5 , 2J6 for example, similar to 2AQ1 of Figure 66), with a sleeve of explosive expandable seal (2J4 eg similar to 2AR2 of Figures 67 and 68) throughout upper piercing weapon or penetrations 5 per drill bit element (129). The tube element attachable to the lower drill bit or penetrations was then placed to the front and rear components, e.g. a goo pill (32), separated by the separating bottom plug placing elements 10 (221A, 221B) , were transported by the circulation of the circulatable fluid column (31C) to mix as the fluids are separated from the segregating plugs, as they enter the 15 penetrations and annular spaces, to form a controllable rheological fluid slime (32) space-engaging element annular (2J1) in an annular space (24) and optionally (2J2) in the surrounding annular space (2 4 A).
The upper penetrations and second series of plugs can be placed after placing the goo or the explosive expandable sleeve, which is exploded during the packing and/or mixing of the goo. The second series of plugs, with separating elements (221C, 221D) containing a graduated expandable particle element (2J3) (33), can be circulated downward using the fluid column (31C) by pumping through the innermost passage and capturing returns through the upper penetration 30 (2J6 or 129) to release (222), for example, the graded expandable particles (2J3) through the accesses from the upper annular space (2J6 or 129) to the annular production space (24) and optionally any surrounding annular spaces (e.g. 24A), wherein the particles (33) are supported by the goo until swollen by the hydrocarbons in the goo, support its mass, providing one or more sealed annular spaces, thus , closing and pressure sealing the lower portion (4J) of the annular spaces for placement and support of an element of a more permanent well barrier element member (3J). Element placement within the annular spaces does not remove access to the innermost hole (25), because mixing has occurred in the annular space, and the plug elements (25A, 221A-221D) may be of a retrievable or pierceable type. The plug elements, either axial movable separating plugs (221A-221D) or backing plugs (25A), may comprise any form of conventional pumpable segregation means during placement, such as foam pump balls, crosslinked polymer fluids, darts and/or conventional implantable flexitube column devices. For example, a first portion of a rheological element can be placed using the circulation column, with the remaining part of the second reagent element implanted with a conventional wire bucket, which can be transported in a coiled wire column through a flowable stagnant fluid column for pouring reagent from the bucket over the first portion. Thereafter, the bucket can be removed and the circulating column fluid flow guidance continue its cycle, if additional mixing is required.
In addition, injection of chemicals, using penetrations or embodiments of the present invention, can occur within or under the goos of annular spaces (32) and elements placed (2J1-2J3) by particles (33) to remove the non-hardening fluid seal when necessary. Thus, the attachable peripheral fluid elements (2J1-2J3), eg goo, are puttable, usable and removable when necessary.
Figure 26A represents a schematic view of the embodiment of a method (IK) that can be used with the embodiment of the controllable and fluid rheology element placeable in the annular spaces (2K), comprising a mixture of hard particles (2K1-2K4) non-expandable steps (191) to form a bridge matrix between the wall portions (between 4K1 and 4K2) of one or more pipes to leave a portion of a passage and/or potentially support a permanent well barrier element (3K) . Gradual expandable particles of hydrocarbons or water (192) within a passage may have pores between the harder particles (191) of the graded mixture (2K), which can be filled by the expandable particles (192) which, when exposed to hydrocarbons , or, for example, water, form a bridge seal, and/or other substances, for example, low gravity solids from an oil-based slurry used in a goo or other conventional lost circulation materials (LCM in the acronym in English), such as graphite or calcium carbonate, which can also be used within pore spaces (131) . Graded hard particles (191) may be completely consistent or partially composed of expandable materials (192), for example, hard round particle element (2K2) is coated with an expandable material, or vice versa, having any shape, for example , square particle element (2K3) and/or a pentagonal particle element :(2K4) can be constituted by layers and/or have corners, and/or any irregular shape of sand and/or gravel particles of any size with rounded edges or edges to form a hardenable/expandable matrix through a tube wall or passage after expanding the expandable materials and/or filling the pore spaces within the matrix. Depending on the implantation and reactive reagent of the expansion fluids, the particles can be, for example, swellable by water or hydrocarbon, and the particles can be coated with a film to inhibit exposure to the expanding reagent liquid during transport.
Figure 27 shows a front view of the left half of a cut through a well and 30 strata, which depicts embodiments of the method (1L) that can be used with a set of elements (2L) comprising recording tool (2L1), axially slideable annular locking deflection (2L2) and access elements by perforation to the annular space (2L3). The figure illustrates the abandonment of a wellhead on land or at sea (7), above ground level (121) or mud line (122) and being disposed of below the ocean surface (122A). An annular space drilling access element (2L3), eg 2AD of Figure 53, has been used to drill axially coupled tubes (11, 12) below the wellhead (7) to access annular spaces (24, 24A), within which a recording tool element (2L1) was used to measure the presence of barrier elements from 15 primary wells (3L3, 3L4) around the casing(12,15). Having determined the necessary underground depths, the placement of a well barrier element (3L2), to meet the industry's recommended minimum published guidelines (211-220 of Figure 15), is achievable with an axially slideable annular blocking deflection element ( 2L2), for example (2M) of Figures 28 to 30, installed to provide flow around a production plug (40), allows a well barrier element 25 (3L1) to be forced into the zone of producible permeable open well (95E), using the recirculating fluid column (31C1, 31C2), circulated down (31CI) through the internal passage and having returns through the annular spaces 30 (24, 24A) or down (31C2) through the annular spaces and up through the internal passage (25) to place the second well fence element (3L2). The method (1L) leaves the lower portion of the well (411) and the intermediate portion (4L2) above the production casing shoe 5 (16). During the process, the layers may have been fractured (18) with hazardous wastes and injected fluids (36W), through the intermediate annular space (24B) into the strata, with the next step of the method (1 L) being the abandonment of the 10 fractured portion of the well (4L3).
Figures 28 to 30 are schematic front views of a section through an underground shaft and strata showing embodiments of a method (1M) for using an axially slidable annular locking deflection member 15 (2M) with break lines which show sections removed from the well and from the strata. The figures illustrate a portion (4M) of the well, between the break lines, to be used and/or abandoned. The 20 element (2M) is capable of being placed with a flexitube column (187) descending tool (187A), in relation to the upper (129U) and lower (129L) penetrations in the production tube (11) inside the casing of production (12) cemented (20), 25 with column tension and a set pressure (31C3) applied to couple the tool serrated wedges (eg 180 of Figure 93) of a tool coupling portion (2ME) for the inner tube (11) . Thereafter, the descent tool (187A) can be retrieved with the flexitube column (187) by, for example, applying pressure to the innermost bore (25) against the closed wellhead valves of the annular space. (24), with percussion on top of the set. The axially slidable annular locking deflection element 5 (2M) can be operated through downward circulation (31C2) of the annular space (24) and upward through the innermost passage (25) through the upper penetrations (129U) and holes ( 2MP) in the sliding section and the coupling portion (2ME) of the element (2M), which couples to the pipe (11). The column of circulated fluid (31C2) can drive the slideable portion (2MS) of the element (2M) upwards to uncouple the lower penetrations (129L) for circulation through the 15 holes in its sliding portion.
Alternatively, the element (2M) can be operated by circulation down (131C) through the internal passage (25) and up through the annular space (24), through the upper (129L) and lower (129U) penetrations between the element (2M ), and the production piping (11) , in which the pressure of the column of circulated fluid (31C1) can drive the sliding portion (2MS) of the element (2M) downwards, to couple the lower penetrations25 (129L), thus closing the holes (2MP) inside its sliding portion. Method (1M) can be completed when a well barrier element :(3M) is circled (31C1) into the hole (25) and annular space (24) to leave a portion30 (4M) of the well. The element (2M) can be replaced, in the realization of the method (1M), by a non-sliding, cable-compatible, probe-operated gantry that can cover penetrations above (129U) and below 5 (129L) of the production shutter ( 40), for a fixed circulation path, for cleaning pipe walls and placing cement. The axially slideable annular locking deflection element (2M) can represent a significant improvement over a conventional fixed gantry because it can be used to hydraulically change the circulation path to clean pipe with reverse circulation and/or hydraulically tap and pack, for example, LCM, mixtures of graded particles 15 and/or piston elements into an annular space and/or the formation of permeable strata to seal the formation, while minimizing the risk of losing the ability to circulate.
For example, when circulating as described in Figure 29, the production valve can be closed as the valve shaft, which is coupled to the wellhead to apply pressure to the lower part of the sliding part (2 MS), pushing it. downwards, thus causing the lower 25 and striking lightly for production annulment purposes under the opening and closing of the production valve
Alternatively, when closed to hydraulically tap the portion of the well below the pipe (11). Finally, alternating between the circulations in Figures 29 and 30, combined with the closing of valves for light hydraulic percussion of packaging, allows the placement and compaction or packaging of a controllable recological fluid, mixture of graded particles, expandable materials and/or LCM for within a permeable formation until the formation locks up, or ceases to accept liquids, after which the circulation path can be re-established for the controlled placement of a well barrier element such as cement. In conventional forcing practice, this this is not possible, because when cement is being forced into a formation it “locks up”, with no means to re-establish circulation or clean the pipe. avoided with the use of the method (IMj for a conventional gantry element or an axially sliding annular locking deflection element (2M) , The element glideable then may allow an intermediate circulation point above the plug to remove a heavier liquid, eg cement, which for whatever reason ceases to flow, so as to remove the cement before it hardens with a second reverse circulation to restore the circulation ways, then remove the excessive hydraulic load from the heaviest cement above the plug.
In addition, axial sliding gantries and gantries can be placed through the innermost hole (25) and can be used in an enlarged innermost hole (25E, 25AE of Figure 72) to, for example, circle around an element of placed annular space blockage or a collapsed liner portion, using the increased diameter features of expandable plugs (eg 2X2 of Figure 46 or 2K of Figure 39) .
Figures 31 to 34 show schematic front cross-sectional views of embodiments of a method (1N) that can be used with an assembly (2N) of elements comprising an axially slidable annular locking offset 15 (2N2), annular piston (2N4) , controllable rheology fluid and placeable in annular spaces (2N1, 2N3, 2N5), attachable drill bit tube (2N6) , register (2N8) and peripheral grinding and grinding elements (2N7), The Figures show a 20 cut through the stratum and production casing of a drilled well (12) (129), coupled with a permeable formation (95F) previously produced through a tube (11) coupled to casing (12) with a shutter (40), with 25 pieces of equipment of production (11A), for example a nipple or valve, which forms part of the production column (11).
The lower part (4N1) of the well can be used and/or abandoned by cutting the lower end of the tube (11) with, for example, a rotary cable cutting tool (175 da
Figure 75) for placing reliable cement around the obturator (40), with a well barrier element (3N1), which comprises a fluid cementitious element with expandable particles (2N1). , for example, (2K1) of Figure 26A, placed with separating cement plugs (221A-221D of Figure 26) and mixed using various flow patterns of 223-227 (Figure 22)f dependent on rheology and degree of turbulent flow caused by the speed of pumping when it is forced into the permeable zone (95F). Clay-based slurry and graded swellable particles can be used to form a matrix of hard particles that can react with each other during mixing and/or after, for example, any hydrocarbon tries to migrate through the mixture to form a barrier ( 3N1) to support another permanent barrier (3N2), Alternatively, LCM, graded particles, other conventional compressible materials or embodiments of the present invention, can be placed, hydraulically tapped, and packed by an axially slidable annular blocking bypass (2N2).
The middle portion of the casing (12) of the well (4N2) can be cemented (20) inside the hole of the strata (17) by placing the upper (1290) and lower (129L) penetrations in the pipe (11), then , placing an axially slidable annular blocking bypass (2N2) through the plug (40) and penetrations to, in use, controllably place a permanent well barrier element (3N2) above the controllable rheology fluid and placeable in annular spaces (2N 1). Alternatively, the compactable materials can replace the element (2N1) with the axially slideable element (2N2), used to hydraulically strike and pack the materials within permeable perforations (129) for the reservoir, until support is obtained for the placement of the element. solid (3N2) well barrier, which prevents gas migration during cement application (212 of Figure 15), in order to control cement placement,
The upper part of the well (4N3), which comprises the intermediate (15) and uncemented production casing (12) inside the hole by the strata (17), can be used and/or abandoned by cutting the tube (11) and using an annular piston (2N4), comprising, for example, a conventional cement support in the form of an umbrella with a controllable rheology element and fluid placeable in the annular spaces (2N3) or an abandonment material element with conventional graded particles , which can be placed using various methods (1G of Figure 23, for example), or a clay-based goo embodiment that can be placed, for example, with the method of (II) of Figure 25, to compress the tube ( 11) and associated intrabore equipment (11A), axially downwards, under the annular piston (2N4), by placing pressure on the recirculating fluid column (31C) to the internal (25) and/or annular production space (24 ] , to provide space for the use of a system element record theme (2N8) . In this case, the recording element (2N8) has not found cement behind the production liner 5 (12), and the pinout of the drill bit attachable tube (2N6), eg (1Z) of Figure 49, can be used to to couple and support a well barrier element (3N4) and to secure the tubes (11, 12) during the removal of the lower ends 10 by a peripheral grinding and grinding element (2N7), for example, (2BP1-2BP4) of Figures 128 and 129, to place the well barrier element (3N4), thus leaving the portion (4N3) above the shoe (16) of the cemented casing (15).
Figures 35 to 37 show front views of a section through a well underground passage and strata, with break lines representing removed portions, and depict embodiments of a method (10) that can be used in an assembly (20) with an attachable peripheral element (201) comprising any tube cutting device, two annular piston elements (202, 203), and a registration tool element (.204 ), which describes the placement of, for example, a conventional plague of shaping cable, which can be used as an annular piston component (202) and which can mate with the annular space (24), after using the attachable peripheral cutting element (201), for example (175) of Figure 75, to cut the tube (110, 11L). The piston (202) can be used as a well barrier element (301) and can be used to compress the tubing (11L) below the piston element (202) for the placement of a second piston element (203) or , for example, a controllable rheology fluid and placeable in annular spaces above the compressed tubing to form an enlarged space in the innermost passage (25E) for cement, in addition to supporting the cement placed above the piston (202) and preventing 10 falling through the annular space (24) below. The second piston element (203) may comprise a loose bag made of, for example, Kevlar, to avoid puncturing by sharp edges in the borehole and being filled with a piston element. 15 controllable rheology and fluid placeable in the annular spaces of graded hard and expandable materials (2K of Figure 26A), which can move freely and fluidly within the bag to allow implantation through the innermost passage (25), using the pressure of flowable fluid column (31C). The liquid column force may be most useful for bursting a disk (2K1D) equipped with a screen to allow a reactant fluid of, for example, water or 25 hydrocarbons, to cause the internal grading particle mixture to swell, with a mesh to prevent grading particles from escaping (2K of Figure 26A). Pressure applied to the expanded or swollen bag can force flexion by compressing or crushing the tube, which may also have been cut and weakened prior to placement of the first piston (201), until, for example, sufficient space is created for use of a recording tool element (204) to determine whether a well barrier element (302), such as cement, can be placed, using the flowable fluid column (31C), to leave the bottom (40) of the pit.
Figure 38, a schematic isometric perspective view of a method embodiment (IP) may be used with an annular piston element (2P) embodiment, with segmented parts and a relief valve, illustrates the abandonment of the portion (4P) of an intermediate casing (15) of an uncemented well into the intermediate annular space (24A) by compressing the production casing (12) to form an enlarged inner passage (25E) with a segmented deformable bag (2PS 1 , 2PS2, etc.) which can be transported through a more internal passage (eg 11 of Figure 41) and used to retain the piston shape, and/or membrane filled with graded and/or expandable particles, for example ( 2K of Figure 26A). A one-way pressure regulated valve (2 PV) can be added to allow fluid movement through the piston bag element (2P) to, for example, allow a reactant fluid, eg water, to be introduced into the segments and react chemically with the expandable materials (2 of Figure 26A) and/or allow the fluid from below to escape upward when forced downward by the pressure of the flowable fluid column (31C) for placement of a barrier element. well (3 P) t In this case, the inner tubes (11 of Figure 36) were cut and the lower end (llu of Figure 37) pressed down, after weakening the casing (12) with the apparatus described in said application of GB 1011290.2, and/or using a tractor embodiment of the present invention to weaken or push the pipes to the bottom of the well.
Figure 39 shows a schematic front view of a section through an underground shaft and strata and describes embodiments of a method (1T) that can be used with an annular piston (2T) element, with break lines representing removed portions. The Figure shows the abandonment of a portion (4T) of a casing (12) which is cemented (20) into a hole of the layers (17), after the piston element has exited a cut tube (110). The piston element (2T) comprises a deformable bag (2QBJcoupled to, for example, wedges with serrations (2QS), to a tube (11L) and filled with conventional graded particles, for example, sand or graded cement, or an expandable particle element stepwise (21< of Figure 26A), in which a breakable membrane can be used to temporarily isolate, or an implantable tool can be used to couple, the bag or a tube connection (2QC) to provoke an expansion reaction when mixing with a gradual expandable mixture and reagent fluid, during or after said bag is implanted through the innermost passage (25J. from the upper end of an installed tube (11U) that has been cut. Coupling 5 (2QS) holds the end bottom of the cut tube (11L), and the pressure applied from the flowable fluid column (31C) the downward force by, for example, crushing or helical buckling of the column of the bottom tube (11L), until the bag exits 10of the top tube (11U) and falls into the annular space (24) inside the casing (12). After that, the trapped fluid can be released through the one-way pressure relief valve (2QV). After registering the cement (20) behind the casing (12) and placing a well barrier element (3Q), which comprises, for example, a cap or plug, to isolate the valve (2QV) coupled to the connector top (2QC), cement can be placed on top of the entire element 20 (2T) .
Figure 40 is a schematic cross-sectional front view with break lines representing upper and lower portions removed from a cut through an underground well 25, showing the embodiment of a method (IR) that can be used with an assembly (2R) of a gantry tube element (2R2) or axially slidable annular locking deflection embodiments, for example (2M) of Figures 28 to 30, fitted 30 with annular piston element (2R1). Embodiments of the annular piston element (2R1) can be used in combination, as a production plug, to form another element (2R) embodiment to fluidly isolate a lower portion of the well with a well barrier element (3R) that comprises a deformable bag (2RB) and/or other barrier of, for example, cement, supported axially from above by the bag. A lower portion of the piston (2RL) with a bag (2RB), filled with conventional graded packing material or filled with graded, expandable graded compactable materials capable of isolating fluid flow in the annular space (24) after falling from the upper tube bore cut (11U) and coupling with the perimeter of the casing (12), it is further coupled (2RS) to the lower end of a cut tube (11L). After forcing the piston element portion (2R1) down with the recirculating fluid column (31C), the register can confirm the cement behind the casing and a portion of the gantry element (2R2) and upper portion of the gantry (2RU) can be coupled to the piston element portion (2R1) and the top tube (11U) to form a production pseudo-obturator with an internal bore and blocked annular space.
Figure 41 is a schematic, left-hand front view of a section through the surface of an onshore well (121) or the seabed (122) of a subsea well, below the sea surface (122A) and strata. underground, describes controllable, and can be placed annular spaces (2S2), expandable expandable mesh membrane elements (233} and percussion elements (234). The Figure shows the placement of a well barrier element (3S) for the abandonment of a lower portion (4S) of the well. As shown, operations begin by cutting the pipe (llü, 11L), placing a piston element (2S1), and using a pressure applied to the column of flowable fluid (31C) to compress the lower portion of the pipe (11D) fixed to the casing (12), which is cemented (20) inside the holes by the layers (17), with a production plug (40) and shoe (16) of the casing (12) above a producible zone (95E). The annular space (24) is both enlarged by the pressure. are applied to the piston (2S1) and by percussion of the fluid column (31C) with a percussion tool element (2S4), which comprises any conventional slapper suitable for the task or an embodiment of the present invention, for example, (2T2) of Figure 42, operated by the innermost passage (25) of the tube (11U).
A register element can then be used within the widened internal passage space (25E) above the piston element (2S1) to determine the primary cement content (20) and/or the adhesion between the layer wall. (17) and the production liner (12), thus allowing selective placement of a lower penetration (129L) through the liner (12) to the required depth. For subsea wells, the annular space access passage to the annular spaces, with the exception of the annular production space (24), are generally not readily available. Thus, the intermediate ring (24A) between the production liner (12) and the intermediate liner (15) is not easily accessible. In surface wells, annular space access valves may also not be usable if, for example, the valves are stuck or have never been installed. Such conventionally inaccessible annular spaces can be accessed with, for example, a perforation element to penetrate the tube cavities.
Upper (129U) penetrations through production piping (11U) and casing (12) can then be placed and an expandable expandable mesh membrane element (2S3) can be placed to cover the piping penetrations (11U), so that a circulation path is possible through the intermediate annular space (24A) using the recirculating fluid column (31C). Overloaded abrasive cleaning and/or viscous fluids can be used to clog the expandable mesh pores or, for example, a washing reagent can activate the expansion of a membrane to close the mesh pores, after which circulation through the passages can continue until the surfaces are sufficiently clean and wettable to provide good adhesion with the subsequent well barrier fluid element (3S), potentially using the percussion element (2S4) to help initiate circulation within the annular space (24A) of the intermediate casing (15), after which the well barrier element member (3S) is placed.
Referring now to Figure 42, a schematic cross-sectional front view through an underground shaft and strata, with break lines representing the upper and lower portions removed, is shown and illustrates embodiments of a method (1T) , which can be used with an element assembly (2T), which comprises controllable rheology fluid and placeable in annular spaces (2T1), slapper 15 (2T2), annular piston (2T3) and expandable expandable mesh membrane (2T4) elements. A leak in the casing (228B) to an underground fracture (18) prevents the application of sufficient pressure (229) to force the piston element (2T3) axially 20 downward into the casing (12) with a circulating fluid column (31C). A swellable expandable mesh membrane element (2T4) can be placed through the leaking line (2 2 8 A) to allow pressurization of line 25 (11U) to drive a hydraulic sling element (2T2) that can be placed inside of the internal passage (25), and can be operated by the traction and pressure of fluid (229) of the deployment column (e.g., 18" of Figure 9) to act against a fluid element of controllable rheology of, e.g. , viscosifying circulable materials and LCM, or a gelatinous goo, which can be used to seal the leak (228), in the fracture (18) and any leak (228C) around the piston element (2T3), to compress the lower piping 5 (11L). With sufficient space created by driving the piston down, a recording element can be used to measure cement adhesion behind the casing (12) and a well barrier element (3T), such as cement, can 10 be placed for the abandonment of a the portion (4T) of the well, in which excess viscous fluids and LCM are circulated out or the goo is removed using a rotating cable configuration with, for example, a traction element, in which, after cleaning the tubes, piston elements (2T3), with any remaining viscous fluid or slime (2T1) above the crushed section, can be used to support support barrier (3T) placement to meet appropriate industry practices 20 (211- 220 of Figure 15).
The use of controllable rheology fluid (eg 2T1) and swellable expandable mesh membrane elements (eg 2T4), which comprise, for example, conventional high-viscosity materials, LCM, conventional expandable tubes and/or embodiments of the present invention, can be used in any of the present embodiments of the method of the invention (1A-1BU of Figures 16 to 147) to access and abandon wells where, during use, over the life of the well, its structural integrity may have been weakened or removed, thus preventing complete pressure control. Controllable rheology fluid and/or expandable expandable mesh membrane elements can be used to temporarily or permanently re-establish pressure control by, for example, placement of a well barrier element (3A-3BU of Figures 16- 147) to leave a portion ( 4 A-4 BÜ of Figures 16 to 147) of a well.10 The percussion element (2T2) can be driven and used, for example, with the pull of a cable string (187) to lift the lower portion of the percussion piston element and to compress its acceleration spring (144), which is locked in the upper portion and coupled to the piping (11U), after which pressure can be applied to the internal passage (25) to release a fluid depression pulse (230), which is increased by releasing the compressed spring, the striking piston acting against the rheological fluid element (2T1), coupled with the piston element (2T3), to further force it lower by hydraulic ram effect. The effect of the upwardly reflected hydraulic ram (230U) can be further controlled by, for example, placing a pressure relief valve at the outlet of the annular space (13 of Figure 16 or 13A of Figure 17).
Figure 43 shows a schematic front view of a section through a portion of the underground well hole and strata and describes embodiment a method (LU) that can be used with the embodiment of the set of elements (2U), comprising the embodiment of a slapper (2Ü2), a conventional percussion element (2U3) and an annular piston element (2U1 to illustrate that a significant length of the widened inner passage (25E), represented between the break lines, may be conceivable for deep wells of, for example, 10,000 feet or 3,000 meters, with long columns of tubes capable of being compressed, bent, crushed, crushed, milled or otherwise demolished. If, for example, several underground parameters are considered, such as the slope and frictional resistance inside the casing (12), the lower end of a cut tube (HL) can be compressed by 25% over a length of 1000 meters, one space. The 250 meter widened internal passageway can then be used for the cement register (20) behind the casing (12) and the placement of a well barrier element (3U) for the abandonment of a portion (40) of the well, where the adverse effects of various underground parameters, eg trajectory variation, slope and friction, can be reduced by several 25 percussion elements (202, 203). The percussion element (202), shown as a dashed line to represent any configuration that may be used, also applies to hydraulic percussion effects of explosive charge 30 on a piston element (201) to displace any tubes (11a) axially downwards, and thus provide a wider internal passage. (25E). Possible configurations that can be used include, among others: i) an arrangement that can be deployed with compressed air or ram-type gravity hammer, similar to a pile driver attached to the upper part of the wellhead or the shaft. valve to strike the entire column of fluid, ii) an explosive charge tool that uses a series of light explosives 10 capable of exploding within and striking the circulating fluid column (31C) without incurring lateral or upward damage to the well components, and iii) the sudden release of displacement gases within the flowable fluid column comprising, for example, compressed air and/or nitrogen which suddenly releases the displaced liquid fluid column, allowing a slapper punch or blow to accelerate downwards when releasing gases upward. The jar functions by the sudden release of energy stored in the deployment column, associated sub-assembly and/or flowable fluid column (31C) when the jar fires. In a similar way to using a hammer, kinetic energy is stored in the hammer as it is oscillated and suddenly released to the nail and plate when the hammer strikes the nail. The method (1U) comprises using a conventional mechanical or hydraulic slapper element (2D3) and/or an embodiment of slapper element (2U2) to further compress the piston element (2U1), e.g. (2X2) of the Figure 46, in which a conventional slapper element (2U3) can be coupled to the piston element (201) or a hydraulic ram slapper (202) is coupled to the flowable fluid column (310 to strike the piston element
Referring now to Figure 44, there is shown a schematic cross-sectional front view with break lines representing portions removed, and the Figure shows the embodiment of a method (IV) of embodiment of the separate portions of a slapper element (2V) that can be used to compress well barrier members and/or elements (3V), showing the slapper piston (2V1) in its locked position before being fired, above the dashed line representing the slapper piston (2V2) during the shooting. The piston housing (182) provides a cylinder for the impeller piston (2V2), which can be used with seals (66), to hold pressurization power (229), and compress the flowable fluid column (31C) from above. and against the piston, for example, with fluid communication through an internal orifice of the movable rod (184) from the fluid column until the springs (144B), which hold the dog latches (186), are forced away. of the movable piston rod (184) to release the energy of the compressed fluid column and trigger the striking piston, creating, with its movement, a fluid pulse (230), which is equivalent to a hydraulic ram with its initial movement assisted by an accelerator spring (144A), wherein the pulse of fluid passing through the holes (59) of the housing (182) can be used to fluidly impact or strike intrabore apparatus, e.g., 203 of Figure 36, axially downward.
A controllable rheological fluid element may be placed within the annular space (24) between the tubing (11) and the liner (12) to further increase the axial downward force of the percussion by retarding fluid movement and the compression upwards. Column tension line pull (187) can be used to hold the jar (2V1) in place while pressure (229) can be used to engage the serrated wedges 15 (180) and to anchor the jar to the perimeter of the tube (11 ), after which the movable rod (184) can be used to re-engage the dog locks (186), after the jar has been engaged. Pressure (229) can be used to hold the 20 serrated wedges (180 ) coupled to push the movable rod beyond the springs (144B) of the dogs (186), with the piston resting against the bottom of the orifice (59) of the housing (182).
Figure 45 illustrates a schematic front view 25 of a cut through a pipe installed in the well, with break lines representing a removed portion of a method embodiment (IV). The Figure shows the upper and lower portions of the percussion element (2W) embodiment, and illustrates the jar housing (182A) at the top of the figure and a percussion piston (2W2) that has been fired and now seats at the bottom of the movable piston rod (187) in the lower portion of the Figure. The percussion piston (2W2), when fired, moves along the percussion rod (184), and the rod (1B4) raises the piston (2W2l, after firing, to retract in the housing (187A). of repeat firing and relocking, the element (2W1) can be used to compress the well barrier members and/or elements (3W), for example, conventional cement mixes, controllable rheology graded particle and/or organofi clay. li.ca and cement elements, to leave a portion (4W) of a well.
The hammer (2W1) can be relocked by increasing the traction in the column line (187) to raise the movable piston rod (184) and the piston (2W2) at its lower end to engage and lock the dogs (186) inside of the recess (102) of the receptacle housing (2W3). During engagement and firing, pressure may be applied through the pressure port (2W4) to force the locking pin (2W5) down against the locking pin spring (144C). When in the engaged position, pressure can be removed with the locking pin (2W5) spring (144C), forcing the dogs (186) into the receptacle (102) of the housing (1B2A). Then, the movable piston rod (184) can be axially lowered to prepare the jar (2W1) for firing. The re-pressurization of the flowable fluid column {31C} above the element can be used to compress the flowable fluid column, thus storing energy and providing pressure through the holes (2W4) to the locking pin (2W5), which will compress the springs (144C ), at a well-defined pressure, and the locking pin to release the cylinders (196) from the receptacle (2W3, 102) and to fire the piston, which allows the sudden release of energy stored in the compressed fluid to actuate the piston and cause an axially downward pulse of fluid pressure when the piston (2W2) moves to the end of the rod (184). The amount of stored energy released is controllable with selective placement of the piston, by compressing a relatively large volume of fluid above the piston and its application to the relatively small amount of relatively incompressive fluid 1 below the piston, results in the greatest release of energy. As a consequence, the striking piston (2W2) can be used to induce a fluid pulse effect or hydraulic ram in in-bore apparatus axially below when, for example, the tool is arranged and positioned so as to place the lower end of the movable rod at rest in 25 tubes, apparatus or piston elements that will be struck, so that the piston moves a short distance to an intermediate stop coupling on the movable rod, so that the lower end of the rod provides a force 30 of mechanical percussion, when the piston reaches the intermediate stop coupling.
If the serrated wedges (180) extend, for example, through an expandable centralizer (2X3 of Figure 46) that can be fitted to the casing (12 of Figure 46) and the percussion piston circumference (2W2) can be used in the circumference of the casing (12 of Figure 46), for example (2X2) of Figure 46, the percussion element (2W1) can be used for hydraulic and/or mechanical percussion in the intrabore apparatus (for example 2U1 of Figure 43) within an enlarged inner passage (25E of Figure 37), the method (IV) can be used to easily couple the serrated wedges (1B0) with the circumference of the pipe (11) or casing (12 of Figure 46) when the piston is coupled (2W2) to the frame (182A), thus using pressure against the pull on the rope, and to uncouple the serrated wedges (180), by applying upward percussion using, for example, a conventional coupled mechanical/hydraulic hammer to the upper end of the element (2V1), when the flowable fluid column is not hydraulically pressurized. Thus, the element (2W1) can be used to hydraulically and mechanically strike pipes and associated equipment by pushing the compacted pipes and apparatus as they are forced to the bottom of the well.
Referring now to Figure 46, there is shown a front view of a section through two well installed pipes, slanted within a directional well, and the Figure describes embodiments of a method of (IX) which can be used with an assembly (2X) percussion (2X5 shown as dashed line), conventional register (2X6), annular separation (2X3, 2X4) and 5 piston elements (2X1, 2X2) complemented by a rheological controllable viscous fluid sealing element (2X7), which can be used to abandon a part (4X) of a well. As shown in Figure 46, an upper (11U, also shown in Figure 42) and a lower (11L) portion of the tube is cut and forced apart to form an enlarged inner passage (25E) by a piston element. (2X2) coupled to the cut-off lower end of the tube (HL) and forced downwards by the pressure exerted 15 on the circulating fluid column (31C) and a percussion element (2X5) for the placement of a well barrier element (3x) . After forming a sufficient height (219 of Figure 15) for placing a well barrier element, eg cement, within the widened inner passage (25E) between the innermost passage (25) and the space conventional size annular (24), a recording element (2X6) that can be used to confirm the cement (20) 25 between the casing (12) and the hole of the layers (17). Geological records during well drilling can be used to confirm a strong impermeable formation, with primary cementation behind the casing (218 of Figure 15) confirmed by the record (2X6). A hanger (2X4) and expandable separation element (2X3) can be used to provide a clearance (211 of Figure 15) to seal both sides of the pipe (110) with cement (217 of Figure 15), thus incorporating (215 of Figure 15) ) all pipes (11U, 12) in cement, once 5 placed through the perforation pipe (25) and penetrations (129), using an annular flow (226 of Figures 22 and 24) on the underside of the casing (12), with the lighter fluid from the flowable fluid column (31C) returning via the upper part of the ring (24).
Figure 47 is a schematic front view of a prior art example flexible shaft and drill bit (174), showing a rotary drill bit (174A) on a rotating flexible shaft (1743) that can be used to form penetrations. of well tube walls and strata selectively through a guide surface (2Y1, 2Y2 of Figure 48) .
With reference to Figure 43, a schematic isometric view is shown, showing embodiments of a method (1Y) that can be used with an assembly (2Y) of access to the annular perforation space (2Y3) and pieces of annular access elements oriented (2Y1, 2Y2), with only a portion 25 (4A) of the strata and barriers of the well (3Y, 20) . THE
Figure illustrates a flexible shaft and drill bit (174) guided by a junction chamber (43) and hole selector (47) which can be used to, for example, access and/or penetrate a wall 30 of the tube ( 11) through which it has been deployed, including, for example, any surrounding pipes, and the stratum wall (17) to place the recording elements (2Y4) and/or access to a productive zone (95FJ for production and later placement of a well barrier element (3a) The flexible shaft and the drill bit (174) can be rotatable (231), retrievable, and replaceable through the outlet tube (39) of the junction chamber (43) and of hole (59) of hole selector (47), which is also rotatable (231A) r when not in conflict with shaft and drill (174), using rotation guide pins (176) and surfaces guide lines (176) for aligning the hole selector hole (59) with the hole exit tube (39) when the hole selector (47) is placed. inside the junction chamber (43). With reciprocating motion of the bore selector (47), the flexible shaft and the drill bit (147), a plurality of penetrations, selectively positionable through the walls of the well tubes and underground strata, can be made.
Figures 76 and 77 are isometric views of a junction chamber (43) and a rotatable bore selector (47), respectively, with dashed lines showing the hidden surfaces in Figure 77, illustrating that a bore selector can be inserted into the chamber (41) of a junction chamber (43) and can be used as a selective guide element with the hole (59) of the junction chamber, and the hole selector can be tackable to selectively access a outlet tube from the hole (39) . For example, piston, separation, fluid, flexible shaft, and drill bit designs can be used with a chamber joint and the hole selector within the innermost passage of a well to selectively drill or enter a wall penetration, to access and re-access a plurality of penetrations through the walls of various tubes and holes through the strata, thus acting as a selectable penetration guiding element.
Referring now to Figures 78 and 79, isometric views of the rotation guide ratchet (176A (also shown in Figure 48) and 176b, respectively), depicting the upper or lower end (47) 15 of a bore selector and a chamber guide surface (41A) of a junction chamber, wherein any form of guide surface, such as a helical surface, can be used to align the hole of hole selector 20 (59 of Figure 77) with the hole (59 of Figure 76) of an output tube (39 of Figure 76) for selectively coupling the output tubes (39 of Figure 76) for coupling, for example, a drill bit to the wall of a tube or 25-strata wall when using or abandoning a well.
Figure 49 is a schematic front view of the embodiment of a method (12) that can be used with embodiments of a tube clamping and separating element (2Z) and 30 drill bit attachment tube elements (2Z1 and 2Z2), with only a portion (42) of the front radial cross-section of the well shown below a side cross-sectional view top right of the front cross-sectional side-section only of the diameters (2Z1, 2Z2, 2Z2A, 174b) of the pin shaft element on different sides left and right shaft pin configurations, shown on the upper right side, Figure illustrates how a flexible shaft and drill bit (174) can be used to drill through the tubes (11, 12, 15) with the flexible shaft ( 174B), which can be used alone or as a column of connected partial tube elements (2Z1) which can be combined with clamping and/or stiffening elements of partial tubes (2Z2, 2Z2A), The tube stiffening element (222) can be arranged with the attached element (2Z1) to secure the tubes (11, 12, 15) prior to their consolidated removal or to support a well barrier element (3Z) placed within an annular space. The stiffening element can become a fastening element (2Z2A) if its folding edges are clamped around the bonded element (2Z1) to prevent separation of the assembly. If the reinforcing element (2Z2) is not bent around the connected element (2Z1), then it may separate after passing through penetration into the wall of a surrounding pipe, preventing the drill bit (174A) from being retrieved and allowing that the flexible shaft (174B) is split to separate the tubes, thus creating the spacer (211 of Figure 15) for the placement and support of a piston element and/or well barrier element (3Z). Pipe element attachable to the drill bit, if it comprises pin holders or fluid passages, selectively placed from the innermost passage, can be used to couple and support the movable axial piston elements and/or well barrier elements , placed over the pinning elements of the coupler coupler tube to, in use, selectively axially place the piston and barrier elements at a selected depth within the annular spaces of a well.
Referring now to Figure 50, a left side front view of a cut 15 through an underground shaft and strata is shown, and describes embodiments of a method (1AA) that can be used with a set of elements (2AA) that comprise annular perforation access space (2AA1) and expandable mesh membrane elements (2AA2) illustrating drilling through tubing (11) and liners (12, 15) to access the annular spaces (24, 24A, 24B ), then place a swellable expandable mesh membrane (2AA2) to repair the hole through the tubing (11) . The flowable fluid column can be transmitted at (31C2), through the annular space accessions (24B) to the wellhead (7) and returned through wellhead accessions (13) from other annular spaces (24, 24A) to place heavy cement30 in, for example, well barrier elements (3AA1, 3AA2) to leave a part of the strata wall (17) of the well (4AA), where there is a water producing zone (95F) below the footing ( 16) of the intermediate liner (15), using channeled flow (226 of Figures 22 and 24) with 5 light fluids moving up and heavier liquids moving down. A series of perforations (2AA1) and expandable membranes (2AA2) can be used at different depths to systematically clean the pipe walls (11, 12, 10 15), with the fine particles resulting from sand sieve cleaning in the quality of mesh. expandable permeability, to provide clean water to wet surfaces for good adhesion (113 of Figure 15) of the 15-well barrier elements (3AA1, 3AA2), In addition, if the piping (11) is torn and the wells integrity is lost , method (1AA) can be used to restore well integrity for additional production from the producible zone (95E) by, for example, applying mesh membrane (2AA2) and using the sliding side door (123) to placing, for example, the cement in the production annular space (24) with the cement closing the mesh permeability to repair the breakage. The use of expandable swellable 25-mesh (2AA2) membrane for placing cement in the annular production space is a significant improvement over conventional expanded pipe patches because there is a high probability that the condition of the pipe that caused the The first break will lead to more breaks that cannot be repaired with a single patch, but can be repaired by the present method (1AA), because the permeability of the mesh provides pressure relief to prevent the tube from collapsing while the cement is in 5 hardening and allows the release of free water associated with cement hardening, as opposed to a solid pipe patch.
Figure 51 illustrates a schematic cross-sectional front view showing 10 embodiments of a method (1AB) that can be used with an assembly (2AB) of drilling access annular space element (2AB1), recording tool (2AB2) and recording elements. attachable drill bit tube (2AB3, 2AB4), with dashed lines15 showing the hidden surface of the flexible shaft (174B). The Figure illustrates the trajectory of the flexible shaft and drill bit (174) guided through holes (59) of a guide element, which selectively guides access to the annular space (24) of the tube carrying the drilling element (2AB1 ), adjusts the operating line voltage and pumping rate of the fluid column to selectively control the direction, and measure its position by reflecting (173D) of a signal (173C) back to the transmission element and reception of the registration tool (2AB2), coupled with serrated wedges (180) to the guiding element and to the tubing (11) . The transported tube element (2AB3) has a rotatable cutting portion 30 (2AC1 of Figure 52), rotated by the flexible shaft (174B) passing through the tube carried by the drill (174A), which can still be used for placing a well barrier element (3AB) for leaving a portion (4AB) of the well accessed by the pipe (2AB3). The flexible cable can be used with an expandable conveyor pipe by, for example, pulling the drill (174A), which acts as an expander, through the conveyor pipe (2AB3) to expand the pipe against the bypass hole (59T) of the pipe. (11), after which a secondary rotary cutter (2AB 4) can be used to separate the expanded conveyed tube (2AB3) coupled to the pipe (11) in the bypass (59T).
Referring now to Figure 52, there is shown a schematic front view of the embodiment of a cut through a tube element attachable to the drill bit (2AC), which can be used with an embodiment of the method (1AO, which describes a transported tube (2AC2) with an independent rotating cutting tube (2AC1) coupled (231) at its lower end, which can be actuated by coupling a toothed gear (174AT) to, by rotation, match and drill with the drill (174A) ) rotary (231) of the flexible shaft (174B) and the drill assembly (174). The column of circulatable fluid (31C) can be pumped (31P) through the holes (59) of a housing with the rotation of the drill (174A) ) to lubricate the borehole. Method (1AC) can be used to, for example, drill through one or more walls of a well to place a well barrier element (3AC) in a portion of the well (4AC) which it can be accessed through the wall penetration made by the element (2AC).
Figure 53, a schematic cross-sectional front view of an embodiment of a method (1AD) of an attachable separation of the drill bit or tube element embodiment (2AD), illustrates a flexible shaft (174B) and a rotary bit (174A) ), coupled to a rigid tube section (2AD3), bent casing (2AD2) and flexible tube section (2AD1), which can be used to control for drilling direction and orientation during drilling, for example with a perforation separating element (2AZ of the
Figure B0-82) that form the rigid section of the tube (2AD3). Thereafter, a separating element can be expanded or an apparatus element can be placed with a well barrier element (3AD) placed through a perforated portion of the wall (4AD) of the well,
Figure 54, a schematic front view of the left half of a section through an underground well and strata shows embodiments of a method (1AE) that can be used with a set of elements (2AE) of the annular space drilling access (2AE1) , annular piston (2AE2) and rheological controllable grading particle elements (2AE3), describes a hole drilled through the tubing (11) and casing (12, 15) that can be used to place the annular pistons (2AE2, 2AE3), by example, (2AG) of Figure 56 or (2AI) of Figure 58, in the annular production space (24) inflated to collide the tubing (11) to provide a radially inwardly movable piston, and which can still be used for the support to the well barrier element (3AE1, 3AE2, 3AE3) to prevent cement movement, by collapsing and gas migration, during hardening (212 of Figure 15), to leave a portion (4AE) of the well and to isolate the productive zone (95E). The well barrier elements (3AE1, 3AE2, 3AE3), eg cement, are amenable to placement below the intermediate casing (15 A) cement (20) shoe (16) using the flowable fluid column (31C) through the piping (11) bore (25) and annular spaces (24, 24A, 24B) exiting or entering the accesses of the annular spaces to the wellhead (13), depending on the orientation of the circulation, and settling to a common depth using forces from the U-tube (312 of Figure 25). In addition, the controllable rheological graded particle elements (2AE3) can be replaced by, for example, expandable bladder or pistons (2AF of Figure 55) or a wound bladder piston element (2AK of Figure 60).
Referring now to Figure 55, a schematic plan view of a section through a wellbore and strata showing one method embodiment (1AF) that can be used with an annular bladder or expandable piston element embodiment ( 2AF), showing inflatable bladder and/or expandable piston elements (2AF) that can be placed, for example, through the inner passage (25) of the tubing (11) and wall penetration hole made by a flexible shaft and element drill bit that can expand into the annular space (24) between the tubes, eg the pipe (11) and production casing (12) cemented (20) with a wall portion (4AF) of hole per strata (17) to act as, and/or support a well barrier element (3AF). If the elements (2AF) are inflated or otherwise expanded, they can be used to form (2ÃG) of Figure 56.
Figures 56 and 58 are schematic cross-sectional plan views of a well showing embodiments of a method (1AG, 1AI, 15 respectively) that can be used with an annular bladder or expandable annular piston element embodiments (2AG, 2AI, respectively), and the Figures illustrate inflatable bladder and/or expandable piston elements (2AG, 2AI) which can be 20 placed, for example, through the interior passage (25) of the pipe (11), and the penetration hole of the wall made by a flexible shaft and drill bit element, which can expand into the annular space (24), to crush the passage (25) of the pipe (11) by the expansion between the tubes, for example, the piping (11) and the production liner (12), cemented (20) into the wall portion (4AG, 4AI, respectively) of a hole through the strata (17), 30 to act as and/or support a barrier element of well (3AG, 3AI, respectively).
Controllable rheological fluid graded swellable particle members can be used above and/or around the elements (2AG, 2AI) to provide pressure carrying capacity and support barrier (3AG, 3AI).
Referring now to Figure 57, there is shown a schematic plan view of a cut through an underground wellbore. The Figure shows embodiment of a method (1AH) that can be used with an embodiment of annular passage separating element (2AH), illustrating an inflatable bladder or expandable piston element (2AH) that can be placed, for example, through of the passage (25) of the inner pipe (11) and the hole made by a flexible shaft and drill bit element, which can expand into the annular space (24) to separate the tubes, for example, the pipe (11 ) and the production casing (12), cemented (20) with a hole through the strata (17) in a well walled portion (4AFT), to provide clearance [211 of Figure 15) for placement of the well barrier element (3AH) . If element (2AH) is inflated, or otherwise expanded, it can be used to form (2AI) of Figure 58.
Referring now to Figure 59, there is shown a schematic isometric perspective view of an embodiment of a placement method (1AJ) which can be used with embodiments of an annular pass separating element assembly (2AJ) (2AJ1-2AJ3 ). The Figure shows an inflatable bladder or expandable piston element in various placement positions (2AJ1-2AJ3) after, for example, being transported through the lining (12) of the widened inner passage (25E), after compressing the tube with a different embodiment, and then exiting the wall penetration hole made by a flexible shaft and drill bit element through the production liner (12) with, for example, a guide element (28L of Figures 119 and 120) and with the pressure of the recirculating fluid column (10 of Figure 36), so as to be placed longitudinally (2AJ1) through the hole with ties (2AJ4, 2AJ5), and rotating the placement position (2AJ2), as the straps reach their extensions, to place the element circumferentially (2AJ3) within the annular space (24A) of the intermediate liner (15), to, for example, provide the placement of an inflatable bladder or expandable piston element (2AH) in Figure 57, and in which three of these These elements can be positioned as shown in (2AF) of Figure 55. The brace (2AJ4) can be used to inflate a type of inflatable bladder and/or expandable element by placing a fluid inside it, eg injection of a small amount of oil in an oil-expandable bladder and cause one portion to expand and push the oil into the next portion until the bladder is fully inflated. Alternatively, the hawser (2AJ4) may comprise a flexible shaft with a surrounding bladder and auger bit for drilling between tubes with the other hawser (2AJ5) causing a directional rotation within an annular space to drill between and raise or separate the liner of production (12) of the intermediate coating (15), thus providing separating support (211 of Figure 1). In addition, Figure 59 includes a well barrier element (3AJ), which can be supported by the production casing (12) and/or a wall portion HAJ) of the intermediate casing (15) or the well.
Figure 60 is a schematic plan view of an embodiment (1AK), with tubes (11, 12) represented as dashed lines, which may be used with an embodiment of an expandable tube element around a flexible and disposable axis and a flexible tube element. drill bit (2A) . The Figure shows a helical implantation pattern inside the annular space (24) from, for example, a helical path guide placed inside the tubing (11) that wraps the expandable tube (2AK) around the annular space between the tube (11) and casing (12), in which a sling (2AJ5 of Figure 59) can be used to wrap the expandable material around an approximate depth with an auger, similar to the drill bit (174A1) which can be used to drill between and separate the tubes (11, 12), to provide spacing (211 of Figure 15), while maintaining axial flow through the helical tube for placement of the well barrier element (3A). After placement, an expansion reagent, eg water to a tube that swells with water or oil to a tube that swells with oil, surrounds the flexible shaft of the auger drill bit (174A1) to provide more away from an unpacked flexitube coil, for example, in an axial downward orientation or sealing the passage if the coils are tight over the pipe (11) by, for example, drilling in an axial upward orientation using gravity and an element of hydraulic percussion to compress the coil, to support (212 of Figure 15) a well barrier element (3AK) placed with an annular flow regime and gravity strokes to leave a portion (4AK) of the well.
Referring now to Figure 61, there is shown a schematic plan view of an embodiment of a method (1AL) of placement that can be used with the bladder and expandable piston elements (2a1). The Figure shows the implantation of a fan or accordion type (1AL) from a compressed position, which can be used to place the element (2AL) through smaller penetration diameters and can be used for sealing or support ( 212 of Figure 15) of a well barrier element (3AL) to leave a portion (4AL) of a well, for example, with the elements (2AF, 2AG, 2AH, 2AI) of Figures 55 to 58, after they have been placed through, for example, a penetrating hole in the wall by a flexible shaft element and drill bit.
Figure 62 shows a left front side view of a cross-section through an underground shaft and strata, showing embodiments of a method (IAM) which can be used with an array (2AM) of axially slidable annular locking deflection elements ( 2AM1), annular space drilling access (2AM2), register (2AM3) and attachable drill bit tube (2AM4), which describes the first abandonment of a productive zone (95E), then the lateral deviation to a new zone producible (95g) for the additional production (34P), before the final abandonment of a wellhead (7) on land (121) or at sea at subsea level (122A) in the mud line (122).
The penetrations in the piping (11) can be placed above the production plug (40), 15 through the piping (11) and in the production liner (12), and below the plug (40), through the piping (11 ), using an annular space drilling access element (2AM2) with a flexible shank and drill bit (174), after which an axially slidable annular locking deflection element (2AM1) can be used to extend over the penetrations and place a cement well barrier element (3AM1) inside the annular spaces (24, 24A), next to the shoe (16) 25 of the cemented intermediate lining (15), and on the other side (3AM2) a producible zone (95E), to leave the bottom (4AM1) of the well using the flowable fluid column (310, to place the cement with any of several flow regimes, after which the U-tube effect causes o leveling of the cement within the annular spaces (24, 24A) occurs.
An attachable drill bit tube element (2AM4) can then be used to divert to the new producible formation (95g), leaving an expandable and/or expandable lined tube inside the bore to seal the bypass passage. lateral, after which a tool registration element (2AM3) can be used to confirm adhesion and to seal prior to production (34P) of the new producible zone (95g). While the new productive zone may not be assured of completion during well construction, for example, it may now provide sufficient marginal production to delay the cost of final abandonment and may now therefore be economically productive if it can be accessed using operations low-cost cable without probe compatible. Once production of the producible zone 20 is completed, the recording tool element (2AM3) can be re-used to determine an adhesion before placing a well barrier element (3AM3) to leave the (4AM2) portion of the 25 Referring now to Figure 63, there is shown a schematic isometric perspective view of a method embodiment (1AN) that provides a motorized access element to the annular space (2AN) that can be used with a plurality of 30 axes flexible and drill bits (174) . Figure 63 shows a plurality of hydraulic motors, comprising rotors (109) and stators (108) fitted between the anti-rotation elements (2AN1, 2AN2) and operable by a cable coupled to the upper rotary connection (72). The column 5 of circulatable fluid (31C) is pumpable and divertable by seals (2AN3), through holes (59), to rotate the rotors (109) within the stators (108) to therefore rotate a plurality of, per example, disposable flexible shafts and 10 drill bits (174D), which can be rotatably coupled to the lower end of the rotors (109) to drill through pipes, to access portions (4AN) of the well through the resulting wall penetrations and access to 15 annular spaces, for placing well barrier elements (3AN), Flexible shafts and disposable drill bits (eg 174D) can be used for various tasks, including pinning tubes 20 together before abrasive cutting and removing the wellhead and riser of, for example, a well offshore platform or providing register sensing elements if, for example, the flexible shaft also includes wires or, alternatively, transponders or 25 transmitters to pass it a measurement signal to a receiver connected to another part of the well, for example to measure adhesion and the existence of primary cementation behind the casing and between the casing and the stratum within any annular space.
As the outer diameter of conventional hydraulic motors can be, for example, 4.27 cm, they can be used for simultaneous in-hole drilling of a plurality of small-diameter holes, so it is possible to provide, for example, three fluid motors in the interior of a 11.86 cm diameter of, for example, a 13.97 cm tube (11), or significantly more with various guide elements, for example (2BM) of Figures 122 and 123, if the flexible shafts are extended to pass through the gaps (2 AP 7 ) between the hydraulic motors. While larger motors provide more power to drill larger fluid communication holes, a plurality of smaller motors with less power and smaller flexible shafts and drill bits can be used, for example, to provide a plurality of registration sensors to measure adhesion and existence of cement, or to improve helical winding (1AK of Figure 60) and bird's nest capacity for throttling an annular space to support, for example, placement of a controllable rheological grading element and/or permanent well barrier element through and/or above the plurality of shafts and disposable flexible drill bits in the bird's nest (174d).
Figure 64 is a schematic cross-sectional plan view through a pipe (11) installed in a well, showing the embodiment of a method (1A0) that can be used with a set (2A0) of elements, shown in a left view plane, comprising an embodiment of the annular guide element access portion (2A01) adjacent to embodiments of a right view plane with enlarged details of the flexible shaft (174B) and attachable drill bit tube (2AO2, 2AO3). The figure shows three serrated wedges (180) coupled to the guide of the wedge starting deviation for lateral deviation out of the pipe (11) by rotating (231) the drills at the end of the flexible shafts (17 4 B) for three different portions (4 AO1, 4AO2 ,4AO3) from a well. For example, one portion (4A01J 15 may be the conductive annular space (24C of Figure 65); another portion (4AO2) may be the annular space of the outer intermediate liner (24B of Figure 65), and the remaining portion (4A03) may be the annular space of the inner intermediate liner 20 (24A of Figure 65) The attachable outer drill bit (2AO2) tube can be, for example, a mechanically expandable metal tube, with the inner tube (2AO3) of a chemically expandable material , or vice versa, with the flexible rotating shaft (174B) inside it, wherein a single tube or any plurality of tubes, layers and types of materials are possible. The annular space between the tubes (2A02, 2AO3) and the shaft flexible (174B) can either be used for fluid communication, or can be filled with a well barrier element (3A0) to embed pipes (2AO2, 2AO3) emf eg cement (217 of Figure 15), where filling can also involve inflating a membrane, making it there is thus an annular piston element, similar to those described in Figures 55 to 60.
Referring to Figure 65, there is shown a plan view of an embodiment of a method (1AP) that can be used with embodiments of a set of elements (2AP) comprising an annular access guide (2AP) and annular space drilling access or Drill Bit Attachable Pipe Element (2AP1-2AP6) The Figure further shows a common conventional well pipe size configuration below a 76.2 cm OD (OD) wellhead of the conductor (14), with 50.8 cm of outer OD of the intermediate coating (15A), 33.97 cm of OD inner of the intermediate coating (15), 24.45 cm OD of the production coating (12), and 13.97 cm of OD and 11.86 cm inside diameter of the production pipeline, within which three hydraulic motors 4.27 cm OD can be installed inside a 9.21 cm lateral shift start (2AP) wedge guide element of outer diameter. Elements (2AP1-2AP6) can extend and access any annular space (24, 24A, 24B, 24C), to place a well barrier element (3AP) in a portion of the well (4AP1-4AP4) or to access a zone producible, rather than using conventional piercing weapons, to create longer and more producible wall penetrations than are possible with conventional tunnel piercing weapons, where the guide element (2AP) can be rotated to provide various arrangements radials, like the one shown, with a rotation of, for example, 60 degrees using two simultaneous drills of three or six individual holes.
Figure 66 shows a front view, with break lines, showing the removed sections of the well of a method embodiment (1AQ) that can be used with element embodiments of an annular access guide (2AQ) assembly (2AQ1) ) and attachable drill bit tube (2AQ2). The Figure shows an insulated motor element (2AQ3) and tube and drill assembly (2AQ2) with a flexible shank and drill bit (174) which can be used in two opposite positions, where the guide element (2AQ1) has been rotated 180 degrees, and furthermore can be used to access portions (4AQ1, 4AQ4) of the well, which comprise the annular spaces (24, 24A, 24B, 24C) between the well tubes (11, 12, 14, 15 , 15A), depending on the length of the flexible rod and drill bit or access of the drill bit to the annular space and used element of the attachable tube (2AQ2), in which a tube carried by the drill bit (2AQ2) can be left as a well barrier element (3AQ1) for placing a fluid well barrier element (3QA2) in portions (4AQ1-4AQ4) of the well.
Referring now to Figures 67 and 68, schematic isometric views are shown, with dashed lines showing surfaces and hidden figures 68A and 68B showing enlarged detail views of a method 1AR embodiment) of an element assembly embodiment ( 2AR), which comprises an expandable, expandable mesh membrane (2AR2). The figures show a swellable expandable mesh membrane (2AR2), which can be fitted with an expander (2AR1), explosive initiated slapper (2AR4) and bottom support seal (66A), and can be used as a temporary LCM barrier. until a substantial well barrier element (3AR) can be placed in the portion (4AR) of a well, which comprises a break or penetration into the pipe (11). A sealing coating or packaging (2AR5) of elastomeric material elements, LCM, grading particles and/or controllable rheological grading elements may also be present.
Although conventional pipe patching technology can be used with the present invention, its primary objective and associated cost is the application of a permanent adhesive to repair broken pipe to an operable production specification where the circulation method is lost (1AR ) can be used to place a strangling sand sieve te, such as mesh, to allow for pumping, while the annular space behind the break is filled with, for example, cement, not only to repair the obvious break, but also to eliminate the potential for further breakage within the worn tube. The swellable, expandable mesh membrane of the present invention provides a significant improvement over conventional expandable tube patches by providing a squeezable LCM mesh, which can be filled with expandable materials, graded particle mixtures, chemically reactive fluids, and/or conventional LCM for provide a thin membrane that can be used to resist circulating pressures for placing well barrier elements, e.g., placing cement within an annular production space through one. leak without creating a significant circumferential obstruction for later passage of the tool (AMI of Figure 50). Furthermore, for example, if the membrane is no longer needed or hinders operations, it can be more easily removed with rotating handle tools of the present invention, which can be useful for removing the structural integrity of the mesh with, for example, a drill bit and tractor. In addition, the membrane (2AR2) can be designed as a pressure-relieving membrane, if, for example, only swellable materials or LCM are placed within the mesh pore spaces, omitting the sealing cement, which allows that the pores a be cleaned or the membrane ruptured, with the excess pressure used, to dislodge or break portions of the seal.
Figure 67 illustrates the assembly of elements (2AR) comprising an expandable mesh membrane between an expander (2AR1) and deformable support seal (66A), which can be placed by a cable column (187). Figure 68 shows the arrangement of the set of elements (2AR) after the explosive-initiated jar is triggered and acts in an axial downward direction to break the casing or package (2AR5 of Figure 67), exposing expandable materials to an expanding reagent. , which forces the LCM and/or a controllable rheological fluid to chemically react through the disruption or penetration and couple the expandable top seal (66B) to the piping (11), providing sealing and allowing it to be applied axially downwards, to continue the mesh expansion with the column of recirculating fluid (31C) while maintaining tension in the column (187). If, for example, electricity is used, the explosive-initiated slapper can be detonated by a firing signal at surface level, or if non-electric wire or stranded wire is used, the explosive-initiated slapper can be detonated by a timer, pressure and/or other intra-hole parameters. The slapper explosion initially forces the upper seal (66B) and breaks the casing or casing (2AR5 of Figure 67) with the application of pressure from the flowable fluid column (31C), which can be used to operate the expander (2ARÍ) axially down onto the dance mast (2AR3) until the support seal (66A) engages the dance mast (2AR3) and ends fluid leakage through the breaks or penetrations (4AR) or through the innermost passage (25) below the assembly, which deforms the bearing seal (66A) downwardly as the expandable expandable mesh membrane (2AR2) is coupled with the circumference of the pipe (11) to form a well barrier element (3AR) over the gaps or penetrations (4aR). Any portion of the mesh (2AR2), not inflated by the expander (2AR1), can then be expanded by releasing column tension to allow the expander to move downward and/or through the downward curved surface of the deformable seal (66A), as the assembly is pulled up axially through the mesh (2AR2) with column line tension (187).15 Figure 68A shows an enlarged front view of part of the element assembly (2AR) ), which comprises the expandable expandable mesh membrane element (2AR2) with a metallic mesh (2ARX) similar to an expandable sand sieve and with encapsulated or coated expandable material (2ARS) or LCM coupled within its porous spaces, with the coating avoiding contact with expansion reagent, eg water. When the (2AR2) circumference of the expandable expandable mesh membrane is expanded (2ARE) to enclose the tubing (11 of Figures 67-68) within the circumference, the coating is broken, exposing the membrane to the expanding reagent, thus causing the material to expand (2ARS) to maintain the shape of the mesh, thereby providing pressure integrity as it seals against the metal mesh (2ARX). Pores of the mesh pore spaces (2ARX) may not be filled with swellable material (2ARS) until the material swells to seal the pore space forming a membrane, while other parts of the pore spaces may be filled to provide a force of retention once swollen. Alternatively, the expanded metal mesh (2ARX) can be designed to form selectively sized pores before and after expansion, so that, for example, recirculating LCM slurry is used to fill the pores.
Figure 68B shows an enlarged front view of the portion of the element assembly (2AR), which comprises the swellable expandable mesh membrane (2AR2), with a dashed line showing optional layers, in which the metal mesh (2ARX) may be used as the sole layer or can be placed inside, outside or between an expandable membrane (2ARS), with the diamond shape of Figure 68A being, for example, relief surfaces on a surrounding expandable membrane or occurring only in the 25 interior of the mesh pore spaces (2ARX) by, for example, pumping a fluid suspension of graded sized particles through the mesh to clog its pores, where a coating of graded expandable particles is likely to be disrupted by mesh to provide exposure to the expanding reagent within the column of circulatable fluid, thereby fixing the particles within the mesh and strengthening them.
Referring to Figures 69, 70 and 71, schematic front views of a cut through an underground shaft and strata are shown in the 3 phases of abandoning a portion (4AS) and accessing a new productive zone (95K) before of final abandonment. The figures depict embodiments of methods 10 (IAS, 1AT, 1AU, respectively) that can be used with sets of elements (2AS, 2AT, 2AU, respectively) comprising annular space drilling access (2AS1, 2AT1), mesh membrane expandable expandable (2AS2, 2AU2), annular piston or controllable rheological fluid (2AU 1), attachable drill bit tube (2AT1) and expandable flextube, flexible shaft and drill bit (2AT3) embodiments of elements, which can be used with recording tool (2AT2) 20 and attachable circumferential piercing elements (2AU3) . Figure 69 depicts cleaning a well to create wettable surfaces for good adhesion (213 of Figure 15). Figure 70 illustrates confirmation of sealing adhesion of primary cement adjacent to a formation that is impermeable and strong (214 of Figure 15). Figure 71 shows the provision of a circumferential separator tube to prevent channeling (212 of Figure 15), with the axially descending cement support, to prevent the movement of cement, collapsing and gas migration (212 of Figure 15) to provide casing and recessed piping (215 of Figure 15) at a minimum height of cement (219 of Figure 15), where marginal production can occur until final abandonment, when record 5 occurs to confirm adhesion, and cement is forced to the formation, filling the production pipe (11) to seal the pipes with cement into cement (217 of Figure 15). Thus, a permanent abandonment sealing plug (216 of Figure 15) is provided 10 at a depth of impermeability and strength of formation, with cement behind the liner (218 of Figure 15) to contain future pressure (220 of Figure 15 ) to, in use, meet the industry's published minimum 15 best practices.
Referring now to Figure 69, there is shown a set of elements (2AS) that can be used with tubing (11) that has been penetrated (129) or cut, with cleaning chemicals 20 added to the column of flowable fluid ( 31C) pumped (2SAP) to clean the liners (12, 14, 15), and the pipe (11) held at the lower end, by a production plug (40), of the production liner (12), in which an element 25 of the annular space drilling access (2AS1) was used to penetrate through the walls of the tubes (11, 12, 15), which were shown above and/or beside the placement of well barrier elements (3AS) to seal fractured strata (18), and 30 to potentially penetrate the stratum wall (17) to provide fluid communication (2ASP) through the innermost hole (25) and annular spaces (24, 24A, 24C), and elimination of fluid in the depleted permeable reservoir (95ED) and/or a portion of fractured (4AS) strata (18) of the well, with a membrane swellable expandable mesh (2AS2), which covers penetration through the tubing (11) to provide a circulation path for cleaning circulation prior to fracture sealing (3AS) .
Figure 70 shows a set of elements (2AT) that can be used for placement of a well barrier element (3AT) to isolate the depleted bottom reservoir and the use of an attachable drill bit tube (2AT1) to provide a guide tube for the annular production space (24) for a recording element (2AT2) for determining the presence and adhesion of cement (20) behind the production liner (12) of the annular space (24) or of the intermediate liner (15), if, for example, the tube extends to that annular space (24A). An expandable flexitube, flexible shaft and drill bit (2AT3) can then be used to wind an expandable coil around the tubing (11) for spacing and subsequent placement of a viscous mixture of, for example, conventional polymers, LCM and/or graded particulate material or embodiments of the present invention, to support a post-placed well barrier element (3AT) element which may be positioned within an annular space to support a well barrier element (4AT) inside the well.
Figure 71 illustrates the use of an assembly of elements (2AÜ) comprising an annular piston or controllable theological fluid (2AU1) placed on top of the expandable flexitube, flexible shaft and drill bit that can be used to form a bird's nest. permeable (AT 3 of Figure 70) to provide cement support within the annular spaces (24, 24A, 24C). A swellable, expandable mesh membrane (2AU2) can be held below the annular space access tubes (2AT1 of Figure 70), while cement (20), for example, is placed in the annular spaces (24, 24A, 15 24C), using the column of recirculating fluid (31C) pumped into one or more of the annular spaces and returned via the innermost passage (25), or vice versa, with an explosive-initiated percussion device and expanding the expandable mesh membrane expandable (2AU2), adjusted for activation by time and pressure. Before the designated time and pressure arrives. of detonation, the membrane (2AU2) can be raised to cover the penetration (2AT1 of Figure 70), after cementation, to expand and hold the cement inside the ring, having initially maintained the heavier cement with U-tube forces between spaces annulars, causing the upper part of the cement (20) to level off, thus providing a permanent well barrier element (3AT) along a portion (4AS) of the well. Once the cement has hardened, registration can confirm the cement's adhesion to the pipe and a perforation element (2AU3) can be used to penetrate the pipes (11, 12) and cement beside the new producible zone (95K). After producing the zone (95K), the recording elements can be rerun to confirm cement adhesion to the pipe (11), and the well barrier element (3AT) can be removed to force a theological controllable fluid reagent and hydrocarbon to react and block permeability when entering hydrocarbon production zones to, in use, prevent gas migration and withstand leaking cement during injection into new zone (95K) and exhausted production zone (95ED) and thus abandon permanently the remaining lower portions of the well.
With reference to Figure 72, there is shown a schematic left side front view of a cross-section through a well within the strata, showing embodiments of a method (1AV) that can be used with a set of elements (2AV) comprising crushing and peripheral grinding (2AV1), controllable rheological grading piston or particle (2AV2, 2AV5), peripheral grinding (2AV3), annular space drilling access (2AV4), attachable pin drill bit (2AV6) realizations of elements, which can be used with tubing plug (25A1-25A3) and cut by abrasive particles and/or explosive separation elements (2AV7). The Figure shows the sealing of the primary cement (3AV1, 3AV2, 3AV3), adjacent to the well formation portions (4AV1, 4AV2, 4AV3) that are impermeable and resistant (214 of Figure 15), and the supply of the circumferential separating tube 5 using various elements to prevent the piping (212 of Figure 15) with the axially descending cement support (2AV2, 2AV5) to prevent the movement of the cement, collapsing and gas migration (212 of Figure 15), thus providing 10 casings and embedded tubes (215 of Figure 15) within a minimum height of cement (219 of Figure 15). The production piping (11) can be sealed with cement on cement (217 of Figure 15), further providing a definitive abandonment sealing plug 15 (216 of Figure 15) at a depth of impermeability and strength formation with the primary cement behind the liner (218 of Figure 15) recorded to ensure it will contain future pressure (220 of Figure 15), thus meeting published industry best practices. The surface (121) is returnable to its original state by cutting the tubes coupled to the wellhead (11, 12, 15, 15A, 14) with a conventional probeless abrasive cutter or 25 explosives, after pinning (2AV6) of the multiple tubes (11, 12, 15) must be lifted as a unit to safely save separate handling costs. Furthermore, by recording the adhesion of the primary cement and the placement of 30 primary well barrier elements (3AV1,3AV2) within the wider inner passages (25E, 25AE), the present invention simulates the abandonment of a drilling rig ( 172A of Figure 10) with all its inherent advantages in a significantly lower level of resource use and associated costs.
One of the possible sequences for the method (1AV) is to place the plug element of the lowest tube (25A1) and then crush and/or mill the pipe (11) with element (2AV1), composed for example, by ( 2AW) of Figure 73, (2AY) of Figure 74 or (2BT) of Figure 146, followed by the use of a recording element within the widened internal passage (25E), after compressing any crushing and/or grinding down with an element to confirm the adhesion of the cement (213 of Figure 15) behind the production liner (12), and then place the well barrier element (3AV1), eg cement, inside the innermost passage widened (25E), to leave the bottom (4AV1) of the well. If a good adhesion of the cement behind the production liner (12) does not exist, it can be milled and/or crushed before placing a barrier Í3AV1).
In this embodiment, a review of the log performed during construction of the well shows that the necessary cement does not exist in the intermediate casing (15) of the annular space (24A), so the next step is to place an intermediate pipe plug element (25A2) , followed by the operation of a grinding element (2AV3) to destroy the pipe (11) and the production liner (12), allowing it to fall to the bottom of the well and/or compressing it with a piston element, after the that a recording element can be used within the widened innermost passage (25AE) to confirm cement adhesion behind the outer intermediate coating (15A), after which a rheological controllable fluid, graded expandable particle mixture and/or pistons (2AV2) are placed in the annular spaces [24, 24A), above all grinding debris, to support the well barrier element (3AV2) placed in the widened inner passage (25AE) to leave the plate. adjacent rte (4AV2) of the well.
With the primary (3AV1) and secondary (3AV2) permanent well barrier elements in place in the well, the next steps may involve using an annular space (2AV4) drilling access to provide fluid communication with the annular spaces (2 4 , 2 4 A, 2 4 B, 24C), after which piston and/or controllable rheological fluids, graded expandable particle elements (2AV5) can be used to provide support within the annular spaces to the well barrier element (3AV3) to abandon the final part (4AV3) of the well. In addition, if the penetrations are placed above and below the partially solidified and packed pistons and/or rheological fluids (2AV5), a method with an axial sliding annular deflection element (1M of Figures 28-30) can be used to extend over the holes (2AV4) and penetrations to hydraulically strike and pack the annular locks (2AV5) to ensure they can support the well barrier element (3AV3). After placing the final barrier, the surface level (121) can be returned to its original state, potentially using a drill bit attachable tube pinning element (2AV6), eg (2Z) of Figure 49, to fix the tubes together for lifting, followed by conventional abrasive cutting operation or explosive separation element (2AV7) to cut all tubes coupled to the wellhead (7), so that they can be lifted out using, by example, a mobile or floating crane for offshore wells to complete the abandonment of the well.
Figure 73 illustrates a schematic sectional view through installed well pipes and shows the embodiment of a method (1AW) that can be used with the set of elements (2AW) comprising peripheral Kelly milling (2AW1), pipe grinding axial (2AW2), mobile axial screw (2AW3) and/or conventional (2AW3C) tractor element embodiments, showing the crushing and milling of the pipe to create an enlarged inner passage (25E) that can be used to place the partially shown well barrier element (3AW) to leave a portion (4AW) of the well. The Kelly mill 30 (2AW1) operable by the cable column (197) can be turned by a Kelly bushing (2AW4), which can be operated by a rotor (109) rotated by pumping (31CP) of the circulating fluid column (310, deflected by seals (66) between a stator (108), held by a tractor (2AW3 or 2AW3C) that pulls the assembly axially upwards to couple crushing cutters (2AW2) with the piping (11) and the motor, an anti-rotation element (2AW5 ) with spring-operated anti-rotation wheels to overcome obstructions and prevent rotation of the cable string (187) , A constant force can be applied by the tractor to grind the pipe, while the rotary Kelly mill is axially operated by string pull (187) and the axial bearing peripheral anti-rotation turned element (2AW5) can be coupled between the stationary column (187) and the rotary Kelly mill, and further be used to couple and decouple the rotary mill to and from the tube, thus preventing interference from he milling milling machine (2AW). In various other embodiments, the traction unit (2AW3) can be used to weaken the piping prior to crushing and grinding.
Once activated, the element (2AW) can be operated with column pull, used to operate the milling machine and pressurize the fluid from the circulated fluid column (31C), used to operate the tractor and crusher assembly, after which the tool can be mechanically and/or hydraulically decoupled down to cut allowing it to be retrieved to the surface for repair and/or replacement. Alternatively, conventional disposable or releasable motors are used, with. low-cost crushing and grinding assemblies that are used to dispose of spent in-hole crushing, cutting and grinding equipment, which is possible by, for example, cutting the pipe to which they are attached and letting them fall into the passage. flared inner innermost formed by grinding and/or crushing to further support an axially placed rheological fluid element and/or well barrier element above.
Referring now to Figure 74, there is shown a schematic isometric perspective view of the embodiment of a method (1AY) which can be used with the peripheral milling element (2AY) embodiment comprising the annular separating elbow pieces (2AY2 ), roller milling machines (2AY3), elbow connector (2AY lj, shaft screw (2AY4) and elbow screw (2AY5) The figure includes forming an enlarged inner passage (25AE) that can be used for place the partially shown well barrier element 13AY] to leave a portion (4AY) of a well. The milling machine can be used with a motor element of a cable column (187M) to turn the shaft screw (2AY4) to screw, axially upwards, the lower elbow connector (2AY5), extending the separation elbows (2A.Y2) and roller milling machines (2AY3), and rotating on the upper elbow connector (2AY1) fixed to the screw shaft ( 2AY4) In this example, the tubing has already been compressed axia down, forming an enlarged production passage (25E) and a register element found that the cement adhesion was unacceptable or there was a lack of cementation behind the production liner (12), thus the grinding assembly (2AY) is being operated to extend (25AE) 10 the innermost passage in the annular space (24A) of the intermediate casing (15). The separation elbows and rotary milling sleeves (2AY 3) can extend until the mill engages the production liner (12) or the separation elbow couples the intermediate liner (15), where the joint expansion (2AY) ) centers and mills the production liner when rotated by the motor element (187M) coupled at its upper end to the cable column. The elbow mill 20 (2AY) is therefore operable with column line pull that holds the mill against the casing (12), while the motor using, for example, a positive displacement hydraulic motor, can be used to rotate the 25 rotary milling machines (2AY3). Retracting and recovering the milling machine is possible with opposite rotation by loosening the milling implant so that it can be retrieved using the cable column.
As rope compatible operations cannot generally be operated in the robust manner of a hinged tube operation on a drill rig, the purpose of rotating rope operations is less than the grinding of hinged tube by the conventional drill rig, and more like abrasive erosion of casing (12) and/or poor cementation with continuous milling rotation, while limiting the traction placed on coiled rope columns to prevent them from becoming stuck or unable to rotate. While conventional drilling operations can mill a sufficient length of casing, on average, with sufficient torque available, to provide an acceptable height barrier in a matter of hours and days, cable compatible operations can take much longer to abrade pipe using torque significantly smaller and can be measured in days and weeks. The costs of performing abrasive coating erosion compatible with low rope torque is, however, significantly less than using, for example, a drill rig, even with such differences in the time required for grinding.
Figures 80, 81 and 82 are plan, front and projected views, respectively, with section line AA of Figure 80 associated with the cross section along line AA of Figure 81, and Figure 82 is a projection of Figure 81, which shows the embodiment of a method (1AZ) of a collapsed annular passageway separating the embodiment from the element (2AZ). The Figures illustrate a flexible shaft connector (2AZ1) that can be used to drive a shaft (2AZ2) with threads and a drill bit (174C), in its lower threads, attachable to a nut (2AZ6) to compress, bend and /or bending a flexible blade (2AZ2) with fluid communication holes (2AZ4). Flexible blades (2AZ 2) can be held by hole (223) made by drill bit (174C) or passage; of a guide element (eg 2B of Figures 117-118) and can be used as drill assembly stabilizers, with the assembly (2AZ) being rotatably placed through a penetration (1AZH) made by rotating the bit drilling the assembly (1740) or, for example, using an auger drill to pull the assembly into a previously made wall penetration, or use the assembly and place it without a drill using a flexible shaft and rotation after insertion in an annular space to expand the flexible blades (2AZ2), by rotating the nut (2AZ6) over the threads of the thread, with the blades (2AZ 2, 2 AZ 6) used to provide clearance (211 of Figure 15) between the tubing (11) and the production liner (12) to place the partially shown well barrier element (3AZ) and leave a portion (4AZ) of the well. Referring now to Figure 83, an isometric cross-sectional view is shown. along line AA in Figure 60, which shows embodiment of a method (1BA) of a separating element (2AZ of Figures 80-82) of an expanded annular passageway. The figure includes a shaft (2AZ3) with sufficient stiffness to facilitate movement of the thread and nut that rotated the flexible shaft rotary connector (2AZ1) to cause the nut (2AZ6) to move over the threaded portion of the shaft, which causes the penetrated blades (2AZ2) (2AZ4) to bend and further provides clearance between, for example, the tubing (11) and casing (12), so that the partially shown well barrier element (3BA) can be placed to leave the portion (4BA) of the well, thus providing pipes sealed with cement-in-cement (217 of Figure 15). If a recording element is placed through penetration (1AZH r of Fig. 80), before placing the separating element (2AZ), and confirming the good adhesion of the cement (213 of Fig. 15), then the methods (1AZ and elB A) ) can be used to provide clearance between the liner (12) and the pipe (11), so that each can be embedded in the cement (215 of Figure 15). The element (2AZ) can be placed through penetrations formed by other drilling elements using an auger drill and/or using the flexible shaft coupled element for drilling and separation with a cable compatible motor that can be detachable and operable from the innermost passage.
Figure 84 shows a top view of an elevation view of the method (IBB, 1BC, 1BD) embodiments which can be used with annular passage separating element (2BB, 2BC, 2BD) embodiments, respectively, to describe a central part (element 2BB1, 2BC1, 2BD1) involved I ran to the left (2BB2, 2BC2, 2BD2) and (2BB3, 2BC3, 2BD3) Folding pieces, which can be placed and fit between circumferential walls of the production casing tube (12) and intermediate casing (15) to provide clearance (211 of Figure 15) between the tube, by displacing its walls to a more concentric position for the placement of the thus partially shown barrier elements (3bb, 3BC, 3bd) usable to leave a portion ( 4BB, 4BC, 4BD) from a well. The separator can be used to provide tubes, which are embedded in the cement (215 of Figure 15), which, when combined with the provision of a recording element to measure the existence of cement behind the cladding prior to placing the separating elements (2BB, 2BC, 2BD) can be used to provide a permanent well barrier element. Both the separation and the recording elements can be placed, for example, through holes made by other pipe wall penetration elements to access the annular spaces. The method (1BB) illustrates that right (2BB2) and left (2BB3) tube separating elements can be oriented according to the curvature of the concentric tubes of the annular spaces, around the central element (2BB1), to allow for expansion. complete the element. The method (1BC) shows that the part (2BC2) of the element (2BC) can be bent to fully expand and provide separation or, as shown, in the method on the right (1BD) one or more elbows can be added to an element part. to provide better expansion, dependent on the annular space, wherein the elements (2BB, 2BC, 2BD) are expanded for separation, wherein rotation of the central element (2BB1, 2BC1, 2BD1) by a flexible shaft extending from of a motor in the innermost hole, causes through penetration of a tube wall into an annular space, bends the separating element to provide the clearance between the associated parts and the tubes they separate.
With reference to Figures 85 and 86, cross-sectional plan and front views are shown with and along line BB, respectively, with break lines representing portions removed from the embodiment of a method (1BE) that can be used with the embodiment of the axially slidable annular locking deflection element (2BE). The figures illustrate the circulation through the penetrations, upper (129U) and lower (129'1), between the element (2BE) and the production piping (11) deviates from a production shutter (40) coupled between the piping (11) and the production liner (12) and placing the partially shown well barrier element (3BE) to leave a portion (4BE) of the well, the sliding tube (177), with upper (177UP) and lower (177LP) pistons, if moves inside the housing (178), which can be used to couple the tubing (11) with the serrated wedges (180), held by the sliding fingers of the piston (179) that pass through the sliding finger passages (179p) in the housing (178) wherein the element (2BE) can be positioned with a cable column using the receptacle (45E) and pressure applied against the top of the sliding fingers of the piston (179) to engage the knurled wedges (180) to the slip receptacle (180R in Figure 91), causing them to mate with the pipe, the post the element is anchored and the cable column can be removed. The upper (66U1) and lower (66L1) seals on the upper (177UP) and lower (177LP) pistons, respectively, react to the orientation and circulation pressure of the flowable fluid column (31C) to move the slide tube (177), dependent on the direction of circulation, to open and close the frame (178) of the upper circulation passage (31CP2) and the holes (59U1) in the slide tube (177), The frame (178) of the upper circulation passage (31CP2) and the holes (59U1) in the slide tube (177) are open during reverse circulation (31CR of Figures 89 and 90) and closed during forward circulation (31CF of Figures 89 and 90).
Once anchored with the top (66U2) and bottom (66L2) seals that span the penetrations (129U, 129L) and plug (40), the element (2BE) can be operated with the flowable fluid column (31C) using: forward circulation (31CF of Figures 89 and 90) axially downward through the tools of the innermost hole (25BE) and return the fluid axially upward through the annular production space to the lower penetration (129L), then between the element ( 2BE) and the pipe (11) until it exits the upper penetration (129), after having bypassed the obturator (40) and re-entered the annular production space and the reverse circulation (31CR of Figures 89 and 90), axially descending through the space production ring above the plug (40) and return axially upward through the top penetration (129U), the circulation passage (31CP) in the frame (178), and through the holes (59U1) in the slide tube (177) and into of the inner hole of the element (25BE).
Figure 87 shows a projected view of Figure 86, with cross sections removed corresponding to the associated break lines, with detail lines C and D associated with figures 88 and 89, respectively, of the axially slidable annular locking deflection element (2BE) . The Figure illustrates the slide tube (177) with the upper (177LP) (177UP) and lower pistons inside the housing (178 of Figure 91).
Referring now to Figures 88 and 89, there are shown enlarged views of the portion of the axially slidable annular locking deflection member (2BE) within detail lines C and D of Figure 87, respectively, illustrating the member (2BE) in the reverse circulation position (31CR) with upper sliding piston (1770P) allowing circulation to occur axially downwards through the annular production space and upper penetration (129U) above the plug (40) to return axially upwards through of the frame (178) of the upper fluid passage (31CP2), to be bypassed by the seals (66U1) of the pipe (11) into the holes (59U1) and then axially up or down through the hole (25B') of element 10 (2BE). As the maximum circulation pressure is exerted against the underside of the upper sliding piston (177UP), which is held in an elevated position, during reverse circulation, the reverse circulation position can be used to, for example, first place a plug. cement below the production plug (40) with direct circulation, and then reverse circulation to remove excess cement above the production plug, after which a plug can be placed 20 in the pipe to isolate the formation below the production plug . Alternatively, reverse circulation can be used for cleaning the annular production space prior to cementation, by directly injecting liquid cleaning residues into the permeable reservoir prior to direct circulation and packing a fluid element into the reservoir pores to support the cement inside the production pipeline and the annular production space and prevent gas migration.30 A. direct circulation moves axially downwards from above the upper sliding piston (177UP) held in the closed position and therefore closing the structure (178) of the orifice (59U2) of the upper fluid passage (31CP2) with the lower face of the piston, while placing the sliding holes (59U1) against the frame's hole to also close them. The circulation (31CF) continues axially downward until it reaches the annular space and returns axially upwards to the lower penetration (129L) and deviates, as a result of the production plug (40) or other annular block, into the space between the tubing and the element (2BE) to the lower part of the structure (178) of the fluid passage (31CP1), until reaching the upper closed fluid passage (31CP2) the holes (59Ü2) and then exiting through the upper penetrations (129U) to continue in the production ring space. This method of forward circulation can be used, for example, to clean the annular space of production and piping, while intermittently closing the annular space to inject waste fluids into the permeable reservoir, repeatedly, until circulation. of a clean fluid is achieved. Once clean, a cement, controllable rheological fluids and/or graded expandable particle elements can be intermittently pushed into the permeable reservoir until it blocks and is capable of supporting a cement column, after which the circulation can be switched between reverse circulation and direct, against alternately open and closed annular perforations and tubing, to hydraulically strike and compact the reservoir to fluidly isolate it enough and to prevent upward gas migration, while cleaning the circulation paths for subsequent placement of an element of well barrier, for example, cement.
Referring now to Figure 90, there is shown an isometric view associated with Figures 85 to 10 89 which shows reciprocating movement of the slidable gantry piston (177) within the axially slidable annular locking deflection member (2 BE) of the Figures 85 to 89, and depicting the upper (177UP) and lower (177LP) pistons with 15 intermediate circulation holes (5901).
Referring now to Figure 91, there is shown an isometric view of the sliding reciprocating gantry piston structure housing (178) associated with Figures 85 to 90 of the parts of the axially slidable annular locking deflection member (2be) which depicts the upper (31CP2) and lower (31CP1) fluid passages adjacent to the passages (179p) of the sliding coupling fingers (179 of Figure 92) for engaging the knurled wedges (180 of Figure 93) through the sliding receptacles (180R).
Figure 92 is an isometric view of a piston with sliding engagement fingers (179) for actuating the serrated wedges (180 30 of Figure 93) associated with Figures 85 to 91 of the axially slidable annular locking deflection member parts (2BE), shows a piston with circulation holes (59U1) above the upper (1800) and lower (1801) sliding surfaces (100 of Figure 93) that hold the serrated wedge in place when the upper piston is forced down by the circulation system pressure and in which the upward percussion that strikes the column can be used to remove the coupling from the serrated wedges for assembly recovery.
Figure 93 shows an isometric view associated with Figures 85 to 92 of parts of the axially slidable annular locking deflection element (2BE), which exhibit a serrated wedge segment, which can be used with the element (2BE) and various other embodiments. .
Referring now to Figs. 94 to 104, methods (1BF to 1BH) of using an annular space percussion element to provide an explosive hydraulic pulse with the column of flowable fluid to displace a tube element and/or its wall are shown. to, in use, provide space for the placement of well barrier elements to fluidly permanently insulate (211 to 220 of Figure 15) at least one producible zone or annular spaces of the well head.
Figures 94 to 96 illustrate embodiments of the method (1BF) for a cocked jar (2BF) and Figures 97 to 99 illustrate embodiments of the method of embodiment [1BG) for a fired jar (2BG) to illustrate the firing sequence in that the same apparatus is used in Figures 94 to 99 with different position relationships (2BF, 2BG), while the embodiment of the method (1BH) of Figures 100 to 104 illustrate the locked positions (2BH1 of Figure 102), in locking (2BH2 of the Figure 103) and unlocked (2BH3 of Figure 104) from the hydraulic housing and piston assembly (2BH).
Referring now to Figure 94, a front view with broken lines showing sections removed, associated with Figures 95 to 104, there is shown an embodiment of a method (1BF) which can be used with the percussion element embodiment ( 2BF), which displays the element (2BF) in the armed position within the upper end of the production piping (HU) cut and centered by two expandable frame elements (2BF2), which thus provide clearance (211 of Figure 15) of the piping to the production liner (12) above a piston element (2BF1) of the present inventor, coupled to the lower end (11L) of the cut production pipe, wherein the arrangement is used to form an enlarged inner passage (25E) for the placement of the partially shown well barrier element (3BF): to leave a portion (4BF) of an underground well. The widened inner passage (25E) is further widened by forcing the piston (2BF1): axially to b axis with the pressure exerted on the circulating fluid column (31C) and by the hydraulic slapper of the piston element (2BF1) by the other element (2BG of Fig. 97). with the serrated wedges 5 (180) of a suspension device (181) triggered by the rapid downward movement of the tension release in the cable column (187 of Figure 95) acting against the friction drag blocks (185), coupled the tubing (11U), after which pressure can be applied to the column of flowable fluid (31C). to fully actuate and prepare the hydraulic slapper (2BF) for subsequent operation. After the operation, the slapper is released with the upward pull of the cable string 15 (187), in which mechanical slappers can be added to the assembly (2BF) above of the suspension device (181) to aid recovery. The piston stroke rod (184) is retracted in its highest position, with pressure applied to the circulation column to ensure that the slapper piston (186 of Figure 96) is locked (2BF3) within the slapper piston housing ( 182).
Figure 95, a front view associated with Figures 94 and 97, shows the embodiment of a percussion element (2BF) removed from the housing (12 of Figure 94) and tubing (11U, 11D of Figure 94) in the locked position (2BF3). The upper end can be coupled to a cable column (187), a flexitube or articulated tube arrangement 30 with serrated wedges (180) extending from the suspension device (181), which is adjustable using the drag block ( 185). . The piston (183) of the hydraulic jar (2BF) is shown coupled to the interior of the piston housing (182), wherein the piston (183), when fired, moves from the housing (182) to the spring (144) in the lower end of piston stroke rod (184).
Figure 96, a front view associated with Figure 95, shows the parts (2BF4) of the percussion element (2BF of Figure 95), comprising the piston (183) with locking dogs (186) removable along the rod. of stroke of the piston (184) with a column connection (187) at its upper end and a damping spring (144) at its lower end, wherein the anchor (181 of Figure 95) and the piston housing (182 of the Figure 95) have been removed.
Referring now to Figure 97, there is shown a front view with break lines showing sections removed, associated with Figures 94 to 96 and Figures 98 to 100 of the embodiment of a method (1BG) of a percussion element (2BG6) . The Figure shows the element (2BG) in a fired position (2BG6) within the upper end (11Ü) of the cut production pipeline (2BG2), centered by two expandable frame elements (2BG4) above a piston and hanger element (2BG3) of the present inventor, coupled to the lower end (11L) of the cut and compressed production tubing (2BG1), wherein the arrangement is used to form an enlarged inner passage (25E) for the placement of the partially shown well barrier element (3BG) to abandon a portion (4BG) of an underground well. The widened inner passage (25E) is further widened by forcing the piston (2BG3) axially downward, with pressure exerted on the flowable fluid column (31C) with hydraulic percussion by the element (2BG) to compress or crush further (2BG1) the cut-off lower end (11D) (2BG2) of the production pipe.
After locking the hydraulic hammer (1BF in Figure 94), pressure is applied to the fluid column (3'IC), which acts against the seal (66P) of the piston (186) causing it to fire (2BG6), after the which moves along the rod (184) to engage the damping spring (144) at the lower end of the rod (184), after having delivered a sudden-percussion hydraulic pulse (2BGJ) to the upper end of the piston and element. hanger (2BG3) to further compress (2BG1) the cut pipe (11L) (2BG2) with, for example, helical buckling, failure and/or plastic contortion, thus causing the widened inner passage (25E) to become larger, so that a well barrier element (3BG) can be placed adjacent to a portion of the well (4BG), where a viscous rheological fluid (2BG5) can be used to bridge a gap (4BGX) in the casing. After increasing the space of the internal passage widened enough to allow registration, the vertical extension of the gap can be determined by squeezing the subsequent cement or cement adhesion can be confirmed behind the coating (12) . The centering element (2BG4) can be used during a percussion operation, but it is not necessary. If registration is required, the centering element (2BG4) could, for example, be removed to provide space for a registration element, then replaced to provide clearance for the tubing (11U).
Figure 98 is a front view, associated with Figures 94 and 97, of an embodiment of a percussion element (2BG) removed from the housing (12 of Figure 97) and tubing (11U, 11D of Figure 97) in fired position (2BG6 ). The piston (183), with the locking dogs (186) and seals (66P), can be positioned at the lower end of the piston stroke rod (184) adjacent to the impact damping and locking spring (144).
Figure 99 is a front view associated with Figure 98, showing the parts (2BG7) of the percussion element (2BG of Figure 97), comprising the piston (183) with locking dogs (186) movable along the rod of stroke of the piston (184) with a connection to the column (187) at its upper end and a locking and damping spring (144) at its lower end, wherein the anchor (181 of Figure 97) and the piston housing (182 of the Figure 97) have been removed.
With reference to Figures 100 and 101, plan and front cross-sectional views with line EE and along line EE, respectively, are shown with broken lines representing sections removed from embodiments of the method (1BH) and the percussion element (2BH), associated with Figures 94 to 99, where Figure 101 has a detail line F associated with Figures 102 to 104, which describes the locked position (2BH1) of the cable column (187) percussion element that can be deployed (2BH), used to extend the internal passage (25E of Figures 95 and 97) and to place a well barrier element (3BH) adjacent to the portion (4BH) of a well to be used or abandoned. The piston (183) can be used to create an explosive hydraulic percussion fluid pulse as it is actuated by a pressurized fluid compressed above the piston and exits the housing (182) which travels along the relock rod (184), until reaching the damping and locking spring(14 4) .
Figures 102, 103 and 104 are enlarged views of embodiments of the position of a portion within detail line F of Figure 101 of the percussion element locked (2BH1), in lock (2BH2) and unlocked (2BH3), respectively, showing a movable rod (184), which passes through the piston (183) with the piston seal (66P) secured to the piston body (183A), and with seals (66) and service connections (189), shown as screws for repair and replacement of parts such as the dog lock (186) inside the piston housing (182). A trigger cam (188) between the upper (1 4 4 □) and lower (144L) springs within the piston body (183A) to actuate and release the locking dogs (186) of the piston housing (182) during locking and firing of the percussion element.
Figure 102 shows the hydraulic percussion piston assembly (23H) in the locked position (2BH1) with the trigger cam (188) positioned via the upper and lower springs (144U, 144L) to extend the locking dogs (186) to a receptacle in the housing (182) to hold the piston assembly in place against the pressure of the column of recirculating fluid (31C) being hydraulically compressed throughout its volume to store energy to fire the percussion element, with the pressure tripping defined by spring resistance (144U, 144L).
Figure 103 shows the hydraulic percussion piston assembly (2BH) in the locked position (2BH2) with the trigger cam (188) pushed up by the column pull (187 of Figure 101) applied to the stroke rod (184), and the locking/cushioning spring (144) against the fluid column (31C) and the top spring (144U) to allow the locking dogs (186) to retract against the surface of the meat and enter the moving carcass (182) up until it reaches the housing in the housing (182), when the column tension is released and the top spring (144U) pushes the cam (188) down as the lock/damping spring (144) holds the piston (183) in place when the stroke rod (184) is lowered. Thus, the dogs (186) can extend into the housing receptacles (182) and the lock (2BH1 of Figure 102) of the piston assembly (2BH) in place.
Figure 104 shows the piston in the firing position (2BH3), where the pressure exerted on the column of recirculating fluid (31C) is increased until the trigger cam (188) is pushed down to release the locking dogs ( 186) from the receptacle in the housing (182), thus firing the hydraulic piston with the pressure of the column of compressed fluid that expands and acts first against the seals (66) in the piston body (183A) against the housing (182) and then in the seals (66P) on the piston (18 3) coupled against the tube (11 of Figure 101), thus forming an explosive hydraulic pressure pulse or hydraulic ram that acts on the trapped fluid and/or element of fluid below the piston, thus transferring a kinetic percussion force to the intrabore equipment (2BG3 of Figure 97, for example).
Referring now to Figures 105 to 122, methods (1BI, 1BJ) of using piercing access elements of the implantable annular space in a retracted position (2BI) and in an extended position of piercing (2BJ) are shown, with various other methods and cable-compatible probeless column-operated element embodiments to penetrate pipes and/or stratum walls, and to access annular spaces at one or 5 more underground depths (218 and 219 of the
Figure 15) to fluidly and permanently isolate (211 to 220 of Figure 15) at least one of the producible zones or annular spaces of the wellhead.10 With reference to Figures 105 and 106, plan and front cross-sectional views in line GG and along line GG, respectively, are shown and include the embodiment of a method (1BI) that can be used with embodiments of 15 annular space drilling access elements (2BI1), drill bit attachment tube (2B12) , expandable tube (2BI3), pressure assisted piston (2BI4), drill tube (2BI5) and annular access guide (2BI6), which are associated with Figure 107 to 111. The figures further show a flexible shaft (174B) and assembly (174) of drill bit (174A) in a retracted implantable position (2BI1), which can be operated with an in-hole motor (111) and using the line tension of the implantation column and the applied pressure of the circulating fluid column ( 31C) against an auxiliary piston (2BI4) by means of a guide (eg diverter) (2BI 6) to penetrate the pipe wall (11) at a selected depth,30 for placing the partially shown well barrier element (3BI) for use and/or abandoning a portion (4BI) of a well, the diverter guiding element (2BI6) may be deployed with the motor (111), e.g. a motor assembly of the present inventor (2BO of Figure 123), which can be used with any form of coupling (180A) between the diverter (2BI6) and the piping (11), this can be operated with column traction and/or fluid pressure, such as a serrated wedge or inflatable element grips , where after drilling the guide can be left in place by releasing the motor assembly (111) from the guide of a connector coupling (45R). As guides they can be used to, for example, place 15 recording elements or direct fluids such as cement, they can be left permanently inside the well or retrieved by their connector coupling (458) after disengaging the grip (180A) on the pipe in which they are placed.20 Conduits that can be placed (2BI2,2BI3) may or may not be present with the flexible shaft and drill bit (174) being retrievable or detachable and available through the guide and/or tubes. In some cases, flexible shafts 25 (174b) and/or drill bits (174 Al may be cut from the motor (111) and left inside the annular spaces to, for example, release a stuck assembly and/or provide spacing support (211 of Figure 15. A drill bit, also 30 can be used as a mechanical expander to expand an expandable tube (2BI2) placed inside a ring and secured by an auxiliary piston (2BI4), and thus the bit (174A). ) is retrieved from its bore by pulling the flexible shaft (1740). A guide (2BI6) can be relatively straight or curved, as shown in the described method (1BI), to accommodate tubes that are made of relatively materials. inflexible or malleable that require protection from adverse stresses during placement. Alternatively, if the axial length of the yaw is substantial, eg 10 meters, relatively straight tube elements can be used to guide and deploy eg f Long measuring tools within an annular space 15 can be used without adverse effect on most pipe materials because the associated slopes and curvature are relatively small.
Figure 107, a rotated isometric view of the embodiment of an annular space piercing access element (2311) associated with Figure 106 and the engageable elements of Figures 108 to 111, show a motor (111) assembly (174), with a flexible shaft (174B) and drill bit (174A) with holes (59B) through the drill for fluid communication and coupling holes (59A) for the drill pipe (2BI5 of Figure 111) with, for example, shear pins. The drill (174A) is shown without the cutting surfaces as it can be of any type or angularity, including, for example, a tractor or auger for slowly moving and/or drilling between the circumferences of adjacent pipes within. an annular space for creating spacing (211 of Figure 15) and separation or flow between eccentric tubes (167C of Figure 13), in which the auger pushes 5 through a core cut, for example by cutting a tube (2B15 of the Figure 111).
With reference to Figures 108 and 109, isometric views of embodiments of elements associated with Figures 105 and 106 of the attachable drill bit (2BI2) and expandable tube (2BI3) tube 10, respectively, are shown with dashed lines illustrating hidden surfaces, and showing tubes that can be, for example, rigid, flexible, expandable and/or expandable depending on use, for example, the expandable tube (2BI3) can create a pressure seal between the annular spaces, after it has been expanded against the hole through the tube walls by the expandable tube (2BI2), Depending on the application, the tubes can be rotated with the flexible shaft and the drill bit (174 of Figure 107) or kept stationary by the guide (2BI6 of Figures 105- 106). An abutment ring or bearing coupling (190B) at the lower end of the non-rotating tube (2BI2) allows the lower end tube (2BI5 of Figure 111) to rotate and drill a round coupon by an auger drill to advance with or assist a drill bit (174A of Figure 107) during drilling operations. An auxiliary piston (2BI4 of Figure 110) can be used for inserting the pipe into a hole and/or pressure assisting the penetration rate of the drill bit by coupling a push surface (96B of Figure 110) with the end. of the tube or a load shoulder (96A), which can be used further to couple the tube wall (11), thus determining when the tube is fully inserted and preventing over insertion. The tube lip (96A) also serves to connect the attachable tube drill (2BI2) to the perforated tube (11 of Figures 105-106) by, for example, molding the lip to the inside diameter of the perforated tube and placing a sealing material between the lip and the tube and/or by constructing the tube and the expandable metal lip to deform to the inside diameter of the installation, where the lip connector (96A) can maintain the fluid differential pressure . The attachable drill bit tube (2BI2) and the expandable tube (2BI3) may also comprise, for example, expandable expandable mesh membrane (97).
Fig. 110, an isometric view associated with Figs. 105 and 106 of an annular piece of pressure auxiliary piston (2BI4J of the annular gap mateable element that can be used to increase the force applied to the drill bit and tubes, illustrates an internal hole (59C) for passing the flexible shaft (174B of Figure 107), arranged with surfaces at angular misalignment within the hole to prevent binding of the flexible shaft when passing through the annular guide element (2BI6 of Figures 105 and 106 The piston portion (143) may be arranged to provide a continued pressure assist surface once the tube-engaging lip (96A) has left the guide (2B16 of Figures 105-106) with the surface of tube coupling (96B) for connecting the lip to tube (96A) to, for example, deform a sealable elastomeric or metal material to the tube perimeter (11 of Figures 105 and 106).
Figure 111 is an isometric view associated with Figure 105 and 106 of the embodiment of a rotating tube element attachable to the drill bit (2EI5) which can be coupled to the flexible shaft and bit (174 of Figure 107), with the holes (59A). ) to, for example, couple shear pins from the shear pins (100) of the rotating tube cutting frame (100) (2BI5) to the drill (17 4A of Figure 107), illustrating an axially secured tube coupling bearing or thrust ring C190A for rotating around a rotating or non-rotating tube (2BI2 of Figure 108), wherein the element (2BI5) can rotate with the drill bit (174A of Figure 107) to, for example, widen the through hole of the tube. drag (2BI2 of Figure 108).
With reference to Figures 112 and 113, partial and front cross-sectional plan views, to line HH and along line HH, respectively, associated with Figures 105-111 and enlarged views in Figures 114, 115 and 116, showing portions within of detail lines J, and L of Figure 113, respectively, are shown and describe a method (1BJ) and embodiments of the drill bit-coupled tube element (2BJ), illustrating flexible shaft arrangements and drilling (174) in a 5 extended position (2BJ1) that has been drilled through pipes installed in a well to access the annular spaces (24, 24A, 24B, 24C) and to place the partially shown well barrier element (3BJ), and thus using and/or leaving annular space 10 (24C) adjacent to a portion (4BJ) of the well.
The tubes can be placed with the drill bit or after removal of the bit and, depending on the nature of the pressure resistance of the tube along its axis, one or more annular spaces 15 can be fluidly accessed.
Straight or curved and relatively rigid or flexible conduits of malleable or rigid material can be used with the arrangement (1BJ1), showing that a rigid tube can be placed through the inner hole (25), concentric tubes (11, 12, 15, ISA) and annular spaces (24, 24A, 24B) to reach the external annular space (24C) within common-sized concentric tubes contained within, for example, 76.2 cm outside diameter of the conductor sheath (14). Alternatively, the curvature and inclination of the derailleur, (2BI6) implantable through and fit (180A) to the innermost tube (25), can be varied and arranged to access any number of concentric or eccentric tubes and their associated annular spaces with flexible or rigid tube elements.
Figures 114, 115 and 116 are enlarged detail views of the portions of the drill bit attachable tube element (2BJ) in an extended position (2BJ1) within detail line J of Figure 113 and detail lines K and L of Figure 114, respectively, illustrating a tube element (2BJ) comprising, for example, an expandable metal tube (2312) with an elastomeric liner tube (2013) or a rigid metal tube (2BJ2) with an elastomeric liner expandable (2BJ3), or other suitable combinations, which can be placed and sealed against holes that penetrate the walls of well tubes (11, 12, 15, ISA) to provide, for example, fluid communication between the innermost passage ( 25) and the outer annular space (24C), where the length and sealing capabilities of the tube wall (2312, 2BJ2, 2BI3, 2BJ3) can be varied to selectively access and communicate between the innermost passage (25 ) and one or more of the annular spaces (24, 24A, 24B, 24C) The flexible shaft and the drill bit assembly (174) are contained within a tube capable of fluid communication of the flowable fluid column (31C) to provide lubricating fluid and coolant to the drill bit while penetrating through the walls of the well tubes, with the liquid flowing between the flexible shaft (174B) and the auxiliary pressure piston (2BI4), transported tubes (2BI2, 2BJ2, 2BI3,2BJ3), and through holes (59B) and the drill ( 17 4A) . A rotary drill tube (2BI5) can be coupled to the drill (174A) with, for example, shear pins (92) through holes (59A), thus providing a hole of slightly larger diameter than the drill (174A) ), for ease of tube placement, tube expansion, 10 drill recovery and/or fluid circulation, cleaning, lubrication and/or cooling. The auxiliary pressure piston (2BI4) can be locked in the guide (2BI6) to hold tubes (2BI2, 2BJ2, 2BI3, 2BJ3) inside the hole by extracting the flexible shaft (174B) and drill bit (174A) .
The tubes can be clamped and sealed within the wall penetrations through the tubes (11, 12,15, 15A) using expandable metal tubes (2BI2) expanded for drill bit extraction, expanded expandable tube liners (2BJ3) by chemical reactions or any other means such as hardenable materials such as glues, cements or wedges within the space between the tubes. After clamping the placed tubes (2BI2, 25 2BJ2, 2BI3, 2BJ3) within the penetrations of the installed tube (11, 12, 15, 15 A), the drill and the auxiliary pressure piston can be retrieved with the guide element (2BI6) or the guide element can remain to guide the new elements or fluid communications, after which the guide (2BI6) can be left permanently in the well or retrieved.
Referring to Figure 117 and 118, plan and front cross-sectional views on the MM line and along the MM line, respectively, with dashed lines showing hidden surfaces of method embodiments (1BK) and the annular access to the guide element ( 2B), which can be used with flexible shafts and drill bits to access the annular spaces (24, 24A) of a well for their use and/or placement of a well barrier element (3BK) adjacent to a portion (4B ) of the well. Diverter guiding members, e.g. (2BK), can be used to access a plurality of annular spaces (24, 24A) with a plurality of perforations (232) through a plurality of tube peripheral walls (11, 12) at one or more underground depths to utilize the well and/or place a permanent barrier. Diverter guides can be placed, used and retrieved by coupling (180A) of various tubes (11), shown, for illustrative purposes as serrated wedges, and connections (45R), in which a check valve (84) operated by spring may be used for displacement of fluid from above when, for example, checking the pressure below the diverter and/or operating a positive liquid displacement motor.
The derailleur element (eg 2BK) may be part of a multi-engine assembly (2AN of Figure 63) or single engine assembly (2B0 of Figure 123) with multi-piece derailleurs (43, 47 of
Figure 49) and/or rotary (2A of Figure 48). The method (1BK) can also be combined with various rotary couplings (190 of Figure 51) and/or indexing means (eg 176A, 176B das
Figures 78-79) to produce the pattern shown in the method (1AP) of Figure 65, when rotated once to produce 6 holes or, for example, twice to produce 9 holes. A plurality of holes can be used for cleaning the tube walls to ensure a wettable surface for adhesion (213 of Figure 15) and, for example, placing controllable rheological fluid elements around the perimeter of the space tube walls annulars to support (212 of Figure 15) or form well barrier elements that bridge all annular spaces.
With reference to Figures 119 and 120, cross-sectional plan and front views on line N-N and along line N-N, respectively, are shown and are associated with Figures 121 and 122 with dashed lines representing hidden surfaces. The figures depict embodiments of the method (1BL) and annular access to the guiding element (2BL), which can be used to guide another annular space access element to place the partially shown well barrier element (3BLJ for use and/or abandonment of a portion (4BL) of the well,
The element (2BL) can be used with any conventional probeless transport and/or fastening apparatus (eg 45.R and 180B of Figures 117-118) to place an element in one or more selected depths, in which any attachable annular space (2BL4, 2BL5) or well barrier element (3BL) parts of elements, which are dimensioned transversely or fluidly movable, can pass through any of the guide passages (2BL1, 2BL2, 2BL3) of the element ( 2BL). Handles for recording elements (2BL5), flexible shafts for drill bits, or any suitable sized or fluidly acting element is both steerable and serviceable within the method (1BL).
Expandable and/or fluid members comprising, for example, expandable shutter element15 and/or graded expandable particles (2BL4) can be expelled from the main passage (2BL4) and forced downwards through the widened inner passage (25E) within the casing ( 12) using the density, rheological properties and/or pressure exerted by the column of flowable fluid at the lower end of the element (2BL), with swelling reagent fluids and/or segregated reactive reagents expelled through each of the smaller passages ( 2BL2, 25 2BL3) to mix inside the widened passage (25E), which forms a goo and/or expandable package that plugs the entire interior wall of the liner (12). Various conventional explosive pressure separation elements can be placed at the lower ends of, for example, the smaller passages (2BL2, 2BL3) to release the reactants at a defined pressure. In addition, a motor element (e.g., of Figure 2B0 123) can be coupled with and rotated the upper end of the element (2BL) to aid in mixing a controllable theological fluid element.
Figures 121 and 122 are plan and front views, respectively, with dashed lines indicating hidden surfaces of method embodiments (IBM) and annular access guide elements (2BM) illustrating a stack of angularly displaced elements (2BL of the Figures 119 and 120) which can be used with various other embodiments of accessing or placing other elements, including the partially shown well barrier element (3BM) within one (4BM) or more portions of a plurality of annular spaces, simultaneously . The guiding element comprises larger passages (2BM1, 2BM3, 2BM5) that can be used for gripping and implanting appropriately sized mechanical elements, elastomers or mateable fluids of the annular space, where larger passages extend axially downward from smaller passages connected (2BM2, 2BM4) that can be used to, for example, transmit pressure from the circulating fluid column and deploy mechanical or electrical cables, flexible shafts, or other element parts that can be used from within spaces, in which a A plurality of angularly offset passages can be used, at various depths, to guide the annular coupling of another element, and where the guiding element can be selectively rotatable, repeatedly around the perimeter at the same depth as, for example, ratchet devices ( 176A, 176B of Figures 78, 79).
The (IBM) method can be used, for example, to orient larger drill bits than possible from (2B) of Figures 117 and 10 118, on which flexible shafts (174B, 2BM6, 2BM7) can be placed through passages (2BM 2 , 2BM4) to engage larger diameter drill bits (174A) and extending from within associated larger passages (2BM1, 2BM3, 2BM5)15 and can be used to drill a larger through pipe internal (11), which couples to the annular space (24) between the tube and the casing (12), for the placement of the well barrier element, partially shown (3BM), to leave a 2nd portion (4BM) of the pit. Service breaks (2BMS,2BM9) can be used to access flexible shafts and drill bits for repair and replacement, with associated tubes and passages that can be placed between service breaks 25 to vary depths between penetrations.
Furthermore, by rotating the element (2BM), it is possible to form a plurality of passages (eg 1AP Fig. 65) simultaneously at different depths using a motorized element 30 (eg 2 AN of Fig. 63).
Referring now to Figures 123 to 147, methods (1BO to 1BU) of using annular space attachable elements to mill and grind tubes to form an enlarged inner passage are depicted and can be used for recording and placing cement to insulate permanently fluidly (211-220 of Figure 15) at least one producible zone or annular spaces of the wellhead and to emulate a drill rig abandonment, where the methods and elements can also be used in several other embodiments >
Figure 124 is an isometric view of the method (1BN) and tractor screw axial element (2BN) embodiments with an intermediate section removed to show the inner rotor (109) and stator (109), in which the detail lines P, Q and R are associated with Figures 125, 126 and 127 respectively. The upper end rotary connector (72Ü) can be attached to a wire or braided wire rope that uses anti-rotation devices to prevent unwanted twisting of the cable in case of tractor slippage (2BN) and the lower end rotary connector can be used with , for example, a milling machine (1BT of Figs. 143-145) provides suitable crossing and/or vibration damping devices, wherein the assembly can be used with, for example, a tube milling element (1BR of 135-140 ) to form an enlarged inner passage (25E of Figure 127) for placing the partially shown well barrier element (3BN of Figure 127} for Use and/or leaving a portion (4BN of Figure 127} .
Referring now to Figures 125, 126 and 127, enlarged views of the axial movable screw portion or tractor element (2BN of Figure 124), within detail lines P, Q, R of Figure 124, respectively, are shown and illustrate the use of the fluid flow of the circulating column (31C), bypassed by an upper seal (2BN1), in upper passages (2BN2) and an internal positive displacement hydraulic motor comprising a rotor (109} within a stator (108) , to drive the lower rotary connector (72L), which can be coupled to, for example, rotary cleaning, cutting and drilling elements, axial tractor within an underground pipe coupled to a wellhead, such as a well pipe (11) or buried pipeline coupled through a production head pipe and valve shaft to the wellhead, to move the assembly (2BN) axially up, down or laterally within the vertical and horizontal portions ( 4BN) of the innermost passage of a well or pipeline depending on the orientation of the screw arrangements (2 BQ) against the wall of the underground pipe and, of course, the orientation of the underground pipe itself.
The method (1BN) and apparatus (2BN) can be used to access and use a portion (4BN) of an underground pipe coupled to a workable zone and/or abandon a well pipe with a well barrier element (3BN). The tractor (2BN) works with the reactive torque of the rotor (109), with the tractor screw (2BQ) fixed to the stator (108), in which the fluid is positively displaced between the rotor and the stator through the fluid, the stator of the drives the screw (2BQ) for coupling the tractor (2BN) with the pipe (11) and pushing or pulling drives the tractor axially to operate, for example, cutters (2BP2 of Figure 129) limited by crushing the pipe or other devices .
Hydraulic motor fluid can be discharged through side holes (2BN3) and/or axially downwards around a solid shaft or through a rotating fluid-through tube coupled to, for example, a drill bit or brush. cleaning with fluid blast nozzles pulled by the tractor axially downward, where the discharged fluid can be used by the drill bit to cool, lubricate and blast downward to remove a buried object, eg previously placed expandable tubes; mesh and/or expandable cement, or, for example, a squirt brush can be used to mechanically brush and hydraulically blast to clean scale from an installed pipe to provide a clean, wettable surface for permanent cement adhesion. .
Figures 128 and 129 are front views, with the layers and half of the tube section removed, wherein the lower portion of the break line at the bottom of Figure 128 is connected to the portion shown below the break line at the upper end of Figure 129 The method embodiment (IBP) can be used with the peripheral milling (2BP1) assembly (2BP1), tube axial milling (2BP2) and mobile axial screw (2BP3) elements of probe-operated embodiments, using the traction of the cable columns and the circulating fluid column, to drive the hydraulic motor and Kelly (233) . The fluid column (310 can be circulated through the innermost passage (25), diverted by seals (2BP6) through holes (2BP5) to drive the hydraulic motor (239), conventional milling machine (238) and tractor screws (2BP3, 2BP4 ) which pull the tube crusher (2BP2), in which the fluid circulated fluid returns past the lower end of the innermost tube tllü), through the annular space (24), which results in the formation of an enlarged inner passage arrangement (25E ), which can be used to place the partially shown well barrier element (3B.P) and leave a portion (4BP) of the well.
The elements (2BP) can be used to mill the lower end of the production tubing (11U) to form an enlarged innermost annular space (25E) coupled with the. production annular space (24) using a conventional milling machine (238) or embodiments (eg from Figure 74 2AY or 2BT of Figure 14b) wherein a
Inner kelly (233) extends through the motor (239) to the lathe (234) can be rotated by a Kelly bushing coupled to the rotor inside the motor such that the Kelly and mill are axially movable (237) to the milling of the tube (llü) 5 after it has been crushed by an embodiment (2BP2) pulled, above (2BP4) and below (2BP3), by screw tractors with fixed or wheeled radial and circumferential cutter screws, operated with the reactive torque of the esrator, to 10 cut and helically weaken (236) the tube. The helical weakening (236) of the tube (III) helps the crusher (2BP2) to grip, and traction by the tractor to split the tube while the mill (238) is rotated by the motor and alternated up and 15 down (237) , to minimize the jamming and blocking of the motor, thus deconstructing the piping (11U) with the assembly (2BP).
The rotations of the alternating Kelly (233) (237) and milling machine (238) are prevented from transferring, damaging and potentially breaking the wound wire or stranded wire rope column (187) using the turning bearings and thrust rings. (234) with an additional anti-rotation device (235): used to secure the upper end 25 of the swivel 234, thus preventing the transfer of rotation. Anti-rotation devices of the present inventor's rotary handle tool couple the tube wall (llü) with spring-operated rollers to allow the tools to pass through restrictions such as nipples without damaging the inner wall, which may still be needed.
With reference to Figures 130 and 131, front and cross-sectional plan views are shown, on line SS and along line SS, respectively, of embodiments of method (1BQ) and movable axial screw element (2BQ) with dashed lines indicating hidden surfaces in Figure 130, and the detail line T of Figure 131 associated with Figure 133. The figures illustrate a series of helically placed rotary screw cutting discs (240) arranged to act as a movable rotary tractor screw within. of the walls of the containment and implant tube (11) which cuts and weakens (236) the wall using its helically placed rotating screw disks. The upper end (2BQ1) or lower end (2BQ2) of the tractor screw (2BQ) can be coupled to the stator of a hydraulic motor or to the frame of an electric well motor and arranged to move upwards, for example, with a crusher of pipe, or downwards, with, for example, a drill bit, where a solid shaft or fluid tube coupled to the drill, milling machine or other rotating device can rotate within the central passage (247) when the tractor pushes. or pulls the device. The tractor (2BQ) can therefore be used to apply an axial force to a rotary device with the reactive torque of any in-hole motor against the wall of an underground shaft, for example, to form a wider inner passage (2B P3 of Figure 129) for placing the partially shown well barrier element (3BQ) to use or abandon a portion (4BQ) of a well.
Figures 132, 133 and 134 show a projected isometric view of Figure 131, an enlarged portion of Figure 131 within line T and an exploded view of the components of the axially movable screw (2BQ of Figure 130), respectively, showing that the tractor (2BQ) can be arranged with implantable and returnable wall couplings to overcome restrictions such as subsurface safety valves and nipples, using, for example, returnable and implantable cam cutting discs (240) to weaken (236 of Figure 129) a wall or not to damage the tightening disk consisting of a tire, or pneumatic, elastomeric reinforced, attachable and detachable material from the wall using the reactive torque applied to the upper (2BQ1) or lower (2BQ2) connection with the perimeter of the tool acting as a traction block. For example, when used with the present inventor's cable implantable in-bore motor, the tractor (2BQ) can be deployed with the wheels retracted to overcome restrictions within the production pipeline (11 of Figure 130), then deployed to push or pull the hydraulic motor with reactive motor torque, activated by fluid circulation to a selected depth, to rotate the inner dog plates (242 ü, 2 4 2L) and attach the wheels (240) to the tube wall (11).
The top connector (2BQ1J may have gear teeth (245) or splines mateable with associated gear teeth or splines (246) of cam plates (241, 241U, 241L) to drive the screw disc shafts (243) within the associated disc guides with cams on platforms or inclined (2420, 242L), arranged to drive the screw discs (240) with the right rotation of the reactive torque of an engine and to retract the discs with the left rotation of the engine reactive torque rotating in the opposite direction or vice versa, depending on the rotary connections involved and the direction of the tractor's axial travel. The helical curve of the discs (240), for configuring the screw to push or pull the tractor along the wall, is moldable with the upper (242U) and lower (242L) cam guide in platform using eccentric shim washers (244) to angularly align the discs to form a helical thread around the circumference of the element. For example, the surface can be sloped instead of the platform, without the need for eccentric shim washers, where an eccentric bearing passage through the disc (240) to the shaft (243) is used to form the helical screw.
With reference to Figures 135, 136, 137 and 138, plan, front, isometric and isometric exploded projection views, respectively, are shown with the half of the section of the pipes installed in the well removed, and the ü-U line of the
Figure 135 associated with figures 139 and 140. The Figures show embodiments of a method (1BR) and tube axial milling element (2BR), with a rotatable upper end (2BR1) passing through the inner axial cam (260) of the shaft (251) attachable, for example, to a tractor, the motor or braided cable pulled by a surface capstan unit capable of providing sufficient line traction to destroy the same tube through which the element was deployed to, after use, place the partially shown well barrier element (3BR) to permanently seal a portion (4BR) of the well. The method described (1BR) uses element 15 (2BR) to cut or crush the weakened (11U) pipe ( 236), in an axial direction using line tension applied to the top end or tension applied by a coupled device, eg, a tractor coupled to the top end. 20 The extendable and retractable cutting knives (248) can extend inward and engage the annular space (24) within the production liner (12) to produce a cut (250) in which the associated cutting discs (24) can also be used to weaken the tube (11U) prior to knife engagement (248).
A series of cutting discs (249) can be coupled and deployed with the articulated arms (258) by a pin (not shown) through a shaft support (261) on the frame (252) from within the recesses (255), which can be driven by the axial cam (260), wherein the cam (260) is also used to drive the knives (249) with a similar shaft support (253) and knife recesses (254) from within of structure 5 (252). The recesses (254, 255) of the frame (252) are supported by upper (257) and lower (259) plates secured with connectors (256) to the frame (252).
Referring now to Figures 139 and 140, 10 cross-sectional front views along the U-U of Figure 135 show the method (1BR1) associated with the tube axial grinding element (2BR) and the method (1BR) associated with the element axial tube milling tool (2BR) of Figures 135 to 138, which15 illustrate a rotating shaft (251 of Figure 139) and meat (260 of Figure 139) in an inactivated deployment position (2BR3), with cutting discs (249) and knives (248) that can be deployed through the internal passage (25) of the tube plus 20 internal (llü) and in an activated position (260 of Figure 140), and with the cutters (249) and knives (248) positioned to cut ( 250) and crush the tube (11(1), which in Figure 140 has been weakened (136) by screw cutters of a tractor.25 The method (1BR1) can be used with a coiled cable column and capstan pulling the deployed unit inside a pre-cut tube (11 shown as dashed lines), in which the meat can be arranged to extend the 30 cutters with string pull applied using, for example, a mechanical and/or hydraulic hammer to selectively drive the tool, at a depth with ascending acceleration and/or striking and releasing the tool from the tube wall, with, for example, descending percussion. A grinding element is moldable with one or both knives (248) and cutting discs (148), with or without cutter-to-tractor weakening (136). In this method, the element can be deployed as soon as the assembly (1BR, 2BR) exits the cut tube (11U) with a compressed lower end, or, for example, directly from inside an uncut tube (11) using lifting the surface and/or capstan unit. Furthermore, the complexity and construction costs associated with the element may be such that they can be disposed of downhole, in the well to be abandoned after it has served its purpose. For example, a crusher can be activated with a small explosive charge after being placed to the desired depth, followed by crushing the tube with a capstan, which uncouples coiled cable string and leaves the crusher in the hole, once a sufficient length of tube has been crushed. This can be followed by circulation, cleaning and application of cement, or, for example, by cutting the pipe above the crushed portion of the tube and disposing of the element, followed by placing a piston element to compress the crushed tube leaving a further hole. internal production liner to simulate drill abandonment (172A of Figure 10) .
Figures 141 and 142 are front isometric views of an adjustable axial cam arrangement (IBS) method for a Kelly sliding cam element (2BS) that can be used with the axial crush tube element (2BR, 2BR1 of Figures 135 to 140) and hexagonal Kelly (233 of Figure 129) to allow the passage of a Kelly (233) through the sleeve (262) of an axial cam (260) to drive a tube element. axial grinding between grinding (2BR) and implantation (2BR1). The meat can be coupled to any element, for example a tractor (2BP2 of Figure 129) to allow axial movement (237 of Figure 129) and rotation of the Kelly assembly with actuation and deactivation of a crusher when moving the sleeve ( 262) up or down. The method can be used with rotary and axially moving cutters, cutters, drilling devices and/or other annular space access elements to displace at least one wall of a well for the placement of the partially shown well barrier element (3BS) , which can be used to leave a part (4BS) of a well inside, for example, a strata wall (17) of the well.
With reference to Figures 143, 144 and 145, front plan views of isometric cross-section exploded on line VV, along line VV and associated with Figure 143, respectively, are shown and depict the embodiment of a peripheral grinding element ( 2BT.) which can be used in method IIBT of Figure 146) to place a well barrier element (3BT of Figure 146) to leave a portion (4BT of Figure 146) of a well, wherein the apparatus represents an element of low cost milling that is disposable to the in-hole in case it gets stuck.
An upper rotary connector (72) can be used to couple the milling machine, for example, a cable implantable hydraulic motor (2B1 of Figure 17) with rotating upper ball joint housing (263) and ball joints that can be used for position the grinding arms (2BT3) outwards by the centrifugal force of rotation, with the grinding sleeves (2BT2) rotating around the arms (2BT3), such that the ball joints (265) at the upper end of the grinding arm and the rotating sleeves (2BT2) and associated cutting frames reduce the required torque and propensity to lock milling machines, because locking forces are limited by centrifugal implantation and rotating sleeves.
Release screws (266), which couple the lower ball joint housing (264) to the upper ball joint housing (263), resist shear during rotation but can be knocked out of the lower ball joint housing (264) to recover the remaining portion of the engine assembly if the grinding arms (2BT2, 2BT3) become stuck.
The flexibility of ball joints (265), abrasive rotating sleeves (2BT2) and smaller disposable milling machines provide an economical means of milling liner (12) and/or poorly adhered cement because the method is usable with limited space requirements. and torque available in single rotating wire operations, yet additional time is required at significantly less daily cost than a drill rig. Where conventional probeless methods use tools that generally require more torque than is bearable in, for example, minimal installations (170A and 170B of Figures 4 and 6, respectively), the coating milling methods of the present invention can be used to grinding over a sufficient period of time, in which if tools become stuck, they can be abandoned in the well, without significant consequences for the cost of operations or the well being abandoned.
Figure 146 is an isometric view associated with Figures 143 to 145 of the embodiment of a method (1BT) within a plurality of pipes installed, with half of the section removed, to show a peripheral milling element (2BT), which illustrates the milling machine in a position determined by the centrifugal force (2 BT1) after having milled the tubes 111, 12) and coupled the spacers (24, 24A) by means of the rotation of the motor coupled to the rotary connector (72) to allow the placement of the element. well barrier shown partially (3BT) in the annular spaces (2 4, 24 A) and in the widened inner passage (25AE) within the intermediate casing (15) to leave a portion (4BT) of the well.5 Figure 147 is an isometric view of the embodiment of the method (1B0) and peripheral grinding and milling arm element (2BU) representing an arm with a ball joint (265) that can be used with the milling machine of figures 143 10 to 146. The arm ( 2BU1) has a shaft (268) for cutting discs rotary (267) that can be used to reduce the torque requirements and lockout or standstill of a milling machine in order to mill or grind inside including the conductor [14] and 15 to place the partially shown well barrier element (3BU ) to leave a portion (4BU) of the well.
Embodiments of the present invention thus: provide a system of e20 elements methods that can be used in any order, depth or well configuration as demonstrated in Figures 16 to 19, Figures 21 to 46, Figures 48 to 74 and Figures 80 -147 to access rigless annular spaces to use and/or abandon a well with greater economy than possible with conventional drilling rig operations, said system can be used with minimal support facilities and within a space reduced and/or in environmentally sensitive areas, such as the sea 30 or the Arctic, to suspend, laterally swerve and/or abandon drillholes by placing a permanent barrier in accordance with published minimum industry requirements.
While various embodiments of the present invention have been emphatically described, it is to be understood that within the scope of the appended claims, the present invention may be practiced in ways other than those specifically described in the present application.
Numerical references have been incorporated into the claims purely to aid understanding during the prosecution.

权利要求:
Claims (48)
[0001]
1. Method (1A-1BU) of providing (220) or permitting (211-219) of permanent restoration of rock layer of at least a part (4A-4BU) of a production zone of an underground well that penetrates said rock layer , after production of said production zone through installed concentric conduits, wherein the method is characterized by comprising the steps of: placing and sustaining at least one equivalent cement well barrier member (3A-3BU, 20, 216) inside of an operable usable space formed by at least one member engageable with an annular space operable by probeless column and operable by cable (2A-2BU) comprising components that are transportable by cable and columnless probe through an inner passage (25, 25E , 25AE) surrounded by at least one annular space of a plurality of annular spaces formed by said installed concentric conduits (11, 12, 14, 15, 15A, 19) extending downwardly from a wellhead (7) within strata subter mates (17) to form a plurality of passageways (24, 24A, 24B, 24C, 25, 25E, 25AE) in fluid communication with said production zones through said rock layer; using energy conducted through said column without probe or through moving fluid from a column of circulatable fluid (31C) within said plurality of passages for operating said at least one member engageable with an annular space operable by probeless column and operable by cable; Using said at least one cable-operated column-operable annular space-operable member without probe to probe-less access said at least one annular space from said innermost passage, displacing at least a portion of a wall of at least a conduit around said innermost passageway to provide an operable space, which traverses said operable space, and placing said at least one equivalent cement well barrier member through said operable space adjacent to said rock layer to form at least one four-dimensional geological time span usable to fluidly isolate said at least a portion of said underground well without removing said installed concentric conduits and associated debris from one or more underground depths (218) associated with the rock capping to provide or allow for said permanent restoration of said rock layer, wherein said at least one well barrier member equivalent to cement is supported (212) in said subterranean depth adjacent to said rock layer.
[0002]
The method of claim 1, further comprising the step of providing said fluid isolation and bypass drilling to access another of said production zones to provide underground well production (34P).
[0003]
The method of claim 1, further comprising providing said permanent fluid insulation and said permanent restoration of said rock layer by using said operable space to measure (2A1-2A3, 2L1, 2AB2, 2AM3, 2AT3) or provide (214) cement-like connection (213) (216) through a sufficient axial length (219) of embedded conduits (215) or filled in and embedded in (217) cementation with clearance (211) between conduits and support ( 212) of said cementation at said underground depth (218) adjacent to impermeable strata covering rock prior to performing said placement of said at least one equivalent cement well barrier member through said operable four-dimensional geological time span to allow for said restoration of said rock layer above said production zone.
[0004]
The method of claim 1, further comprising providing an abrasive, explosive or shear component for said accessing said at least one annular space from said innermost passage, or said displacement of said at least one part of said wall of said at least one conduit for providing said operable space.
[0005]
The method of claim 1, further comprising the step of providing a motorized member (2B1, 2AN, 2AM2, 2BN, 2BO, 2BP) comprising at least one downhole motor that can be suspended by a cable operable with the energy of said probeless column or said circulatable fluid column to drive at least one rotary cut-off member or a mechanical coupling member.
[0006]
The method of claim 5, further comprising the step of providing an axially operable tractor member (2AW3, 2BN, 2BP3-2BP4, 2BQ) comprising said mechanical linking component or at least one cutting component which is engageable with said wall of said at least one conduit to move axially through said innermost passage to displace another barrier member or said wall.
[0007]
The method of claim 4, wherein said cutting member comprises a duct grinding member (2E2, 2AW2, 2BP2, 2BR) comprising one or more peripheral cutting edge components, said one or more further peripheral cutting edge components comprise wheels, blades or combinations thereof, and wherein said conduit grinding member is implantable axially and radially outside said innermost passage with a solid passage cam or kelly to grind and displace the said wall.
[0008]
The method of claim 4, characterized in that said cutting member comprises an annular milling member (2E6, 2AV3. 2AW1, 2AY1, 2BP1, 2BT1-2BT3) comprising one or more swiveling peripheral cutting edge components, wherein said one or more swiveling peripheral cutting edge components comprise wheels, blades or combinations thereof usable to axially, swivel and cut said wall axially, swivelly and circumferentially.
[0009]
The method of claim 1, further comprising the step of providing a guiding member (2C1, 2D3, 2E4, 2N6, 2Y1, 2Y2, 2Z1, 2AB3-2AB4, 2AC, 2AM2, 2AO1, 2AP, 2AQ1 , 2AQ2, 2AT1, 2BI2-2BI3, 2BJ, 2BI6, 2BK, 2BL, 2BM) which comprises a selectively orientable guide derailleur (2Y2, 2AB1, 2AQ1, 2BI6, 2BK, 2BL, 2BM, 47), a conduit (2D2, 2AE3 ,2AF, 2AK, 2AL, 2AO3, 2AS2, 2AT3, 2AV2, 2AV5, 2BI3, 2AB3, 2AC1,2BI5), an annular bridge (2X3, 2AH, 2AJ1-2AJ3, 2AU1, 2AY2, 2AZ,2BB, 2BC, 2BD, 2BM2) or combinations thereof, which is engageable and orientable within said innermost passage to urge a passage of another well barrier member or said moving fluids through said wall using an alignable bore selector between said innermost passage. and at least one penetration into said wall.
[0010]
The method of claim 9, characterized in that at least a portion of said selectively orientable guide diverter or said guide conduit is rotatably orientable and selectable with said bore selector between a plurality of penetrations in said wall from from the interior of said innermost passage.
[0011]
The method of claim 9, further comprising the step of providing a fluid communication conduit member which is positionable within said space operable through said innermost passage or through said guide member with fluid pressure. movable against a wall of said fluid communication conduit member.
[0012]
Method according to claim 11, characterized in that the wall of said guide conduit comprises a rigid material, a mechanically expandable material, a chemically expandable material or a rigid and expandable material, which is sealable against the wall of said conduit installed.
[0013]
The method of claim 5, characterized in that the step of providing a motorized member further comprises providing a motorized annular drill access member (2B3, 2C1, 2E4, 2L3, 2Y3, 2Z1, 2Z2, 2AA1, 2AB1, 2AC , 2AD, 2AE1, 2AN, 2AM2, 2AQ2, 2AS1, 2AV4 and 2BI1) comprising at least one rotary cutting component with a flexible shaft and perforation tip for penetrating and displacing a part of the dictawall of said installed duct.
[0014]
The method of claim 5, characterized in that the step of providing a motorized member further comprises providing a motorizable pierceable mechanical connecting member to displace at least a portion of said wall of said conduit to provide a offset displacement or to prevent further displacement of at least a part of said wall of said installed duct from another part.
[0015]
The method of claim 11, further comprising providing said fluid communication conduit component, a pierceable mechanical connecting component or a pierceable fluid communication conduit mechanical connecting component within said operable space to traverse or through at least two passages of said plurality of passages to access said operable space.
[0016]
The method of claim 15, further comprising the step of providing a fluid communication network conduit component with at least a portion of a wall of said fluid communication conduit component, wherein the fluid communication conduit component fluid communication network conduit comprises permeable pore spaces sized to pack and unpack particles or compositions that are usable to selectively prevent or provide fluid communication through said permeable pore spaces using a flow orientation of said column of circulable fluid, said sizing of pore space or said particles or compositions.
[0017]
The method of claim 11, further comprising the step of providing a plug member (2B4, 2C2, 2D1, 2E1, 2E5, 2L2, 2M, 2N2, 2R2) of said fluid communication conduit component to traverse at least two perforations in said wall of said at least one conduit for segregating flow between said at least two perforations and another passage of said plurality of passages for fluidly connecting an annular space above and below a lock in said annular space to fluidly communicate around said annular lock.
[0018]
The method of claim 17, further characterized in that said closure member comprises a slidable piston for displacing or impacting said moving fluids or other well barrier member within the plurality of passageways using pressure from said column of flowable fluid. , wherein said slidable piston forms an opening and closing valve of at least one penetration in said wall of said conduit to selectively and fluidly divert a portion of said column of flowable fluid in a circulation orientation through said at least a penetration or to fluidly communicate through a longer part of said column of flowable fluid in the opposite circulation orientation.
[0019]
The method of claim 1, further comprising providing a mechanically or fluidly positionable pressure bearing packing member (2F-2K, 2N5, 2S2, 2T1, 2B7, 2D4, 2E7, 2N4, 2O2, 2P, 2Q , 2R1, 2S1,2T3, 2U, 2V1-2V2, 2W2, 2X2, 2AE2, 2AG, 2AI, 2AK, 2AL, 2BF1,2BF3, 2BI4) which is expandable within said operable space and is axially fixable or movable within at least one of said plurality of passageways to provide: said displacement gives at least a portion of said wall of said at least one conduit to provide said operable space, said traversal of said operable space or said positioning of said at least one member of cement equivalent well barrier across said operable space to fluidly isolate said at least a portion of said underground well.
[0020]
The method of claim 19, wherein the fluidly positionable pressure bearing packing member comprises a mechanical packer with cylindrical, pouch or umbrella shaped components.
[0021]
The method of claim 19, wherein the fluidly positionable pressure bearing packing member comprises a gelatinous packer having fluidly positionable and gelatinously fixable rheological fluid particles or components within at least one of said plurality of passageways.
[0022]
The method of claim 21, characterized in that the particles comprise graded particles with intermediate pore spaces that can be filled by a mixture of chemical reagents to form said gelatinous packer.
[0023]
The method of claim 19 further comprising axially compressing adjacent well components into axially adjacent operable spaces with said fluidly positionable pressure bearing packing member to form or widen said operable space.
[0024]
The method of claim 19, further comprising the step of laterally compressing well component into radially adjacent operable spaces with said fluidly positionable pressure bearing packing member to form said operable space for said positioning from said at least one equivalent cement well barrier member through said operable space to fluidly isolate said at least a portion of said underground well.
[0025]
25. The method of claim 1, further comprising the step of providing a striker member (2E3, 2S3, 2T2, 2U2, 2V1, 2W1, 2X5, 2BF3, 2BG6, 2BH1-2BH3) comprising a lockable and releasable piston , sealable within said innermost passage, and operable with energy released from the compression of said column of circulating fluid, to travel along a post or relock rod and to deliver an explosive hydraulic slapper pulse, a mechanical impact or combinations thereof, to objects below said releasable piston.
[0026]
26. System for using the method, according to claim 1, of providing (220) or allowing (211-219) the rock layer restoration of at least a part (4A-4BU) of a production zone of an underground well penetrating said rock layer, characterized in that it comprises: at least one cable compatible apparatus member (2A-2BU) which is operable by cable and probeless column and engageable to the annular space to form an operable space, the at least one A cable compatible apparatus member comprises an assembly of positionable, disposable and retrievable components that is transportable by cable and probeless column through an inner passage (25, 25E, 25AE) surrounded by at least one annular space of a plurality of spaces annulars formed by a plurality of installed concentric conduits (11, 12, 14, 15, 15A, 19) extending downwardly from a wellhead (7) within the underground strata (17), and at least one member of barrier of cement equivalent well (3A-3BU, 20, 216) positioned in said operable space formed by the operation of the system comprising at least one of: electrical conductors of a cable or probeless column, tension of the cable or probeless column and moving fluids of a column of recirculating fluid (31C) in the underground well, which supplies power to drive said at least one cable-compatible, annular space-engaging apparatus member, said driving at least one space-engaging apparatus member annular and cable-compatible is adapted to displace at least a portion of a wall of at least one conduit around said innermost passage to provide said operable space adjacent to said rock layer and to traverse said operable space to form at least a four-dimensional geological time span usable to position said at least one equivalent cement well barrier member, and wherein said at least one member of cement equivalent well barrier within said operable space is adapted to fluidly isolate said at least a portion of said underground well without removing said plurality of installed concentric conduits and associated debris from below one or more underground depths ( 218) associated with rock capping.
[0027]
27. The system of claim 26, further comprising at least one cutting member comprising a rotatable or pullable cutting edge for accessing at least one annular space from said innermost passage, or for said displacement from said at least a portion of said wall of said at least one conduit to provide said operable space.
[0028]
The system of claim 26, further comprising a motorized member comprising at least one downhole motor, said motorized member being suspended from a cable and operable on said power. probeless column or flowable fluid column for driving said at least one rotatable or pullable cutting member with a mechanically connecting member.
[0029]
29. The system of claim 28, further comprising an axial bolting tractor operable with the reactive torque of said at least one downhole motor to drive an array of bolts to engage said wall of said at least a conduit and for bolting said innermost passage to displace said wall or pull said at least one rotatable or pullable cutting member.
[0030]
The system of claim 27, characterized in that said cutting member comprises a duct grinding member comprising one or more peripheral cutting edge wheels, one or more blades or combinations thereof, wherein said duct grinding member is implantable axially and radially outwardly of said innermost passage with a solid passage cam or for grinding and displacing said wall.
[0031]
The system of claim 27, characterized in that said cutting member comprises an annular milling member comprising a kelly implantable and fixedly engageable ball joint cutting arrangement with one or more wheels or blades. rotary peripheral cutting edge usable for penetrating and cutting axially, rotary and circumferentially said wall of said conduit with said downhole motor or said downhole motor and another member.
[0032]
32. The system of claim 26, further comprising a guide member comprising a selectively orientable guide derailleur, a guide conduit or a conduit and diverter, wherein the guide member is engageable and orientable within the said innermost passage for urging the passage of another well barrier member, said moving fluids or combinations thereof, through said at least one wall using a bore selector alignable between said innermost passage and at least one penetration in the said wall.
[0033]
The system of claim 32, characterized in that at least a portion of said selectively orientable guide diverter or said guide conduit is rotatably orientable and selectable with said bore selector between a plurality of penetrations in said wall to from within said innermost passage.
[0034]
The system of claim 32, further comprising a fluid communication conduit component positionable within said space operable through said innermost passage or through said guide member with said moving fluids pressing against a wall of said fluid communication conduit component.
[0035]
35. The system of claim 34, characterized in that the wall of said fluid communication conduit component comprises a rigid material, a mechanically expandable material, a chemically expandable material or a rigid expandable material, which is sealable against at least one of said plurality of installed concentric conduits.
[0036]
The system of claim 28, wherein the motorized member comprises a motorized annular drill access member with at least one rotatable cutting member comprising a flexible shaft and drill tip for penetrating and displacing at least a portion. of said at least one wall.
[0037]
The system of claim 28, characterized in that the motorized member comprises a motorizable pierceable mechanical connecting member to displace at least a portion of said wall of said conduit to provide offset displacement or to prevent further displacement of at least one part of said wall from another part.
[0038]
The system of claim 34, characterized in that said fluid communication conduit components, pierceable mechanical connection components or pierceable mechanical connection components of fluid communication conduit are within said operable space.
[0039]
The system of claim 38, characterized in that the fluid communication conduit component comprises permeable pore spaces within a portion of a wall of said fluid communication conduit component that are sized to pack and unpack particles or compositions usable to selectively prevent or provide fluid communication through said pore spaces using flow orientation of said column of circulatable fluid, said pore space sizing and said particles or compositions.
[0040]
The system of claim 34, further comprising a closure member comprising said fluid communication conduit member passing through at least two perforations in said wall.
[0041]
41. The system of claim 40, characterized in that a slidable piston displaces or impacts said moving fluids, another fluid member or combinations thereof.
[0042]
42. The system of claim 41, characterized in that said slidable piston is usable to form a valve to open and close at least one penetration in said wall of said conduit to selectively and fluidly divert a portion of said column of flowable fluid in a flow orientation through said penetration or to fluidly communicate through a portion of said column of flowable fluid in the opposite flow orientation.
[0043]
The system of claim 26, characterized in that a pressure bearing seal is formed by a packer with a bag or a packer bag and pressure relief valve component that are filled with non-chemically reactive particles, chemically particles reactives or combinations thereof and coupled to said wall.
[0044]
44. The system of claim 26, further comprising a rheological fluid composition packer and fluidly positionable graded particle packer components fluidly positionable within said space operable in segmented parts to form a pressure bearing bridge between said part and other part of said wall of said conduit, said intermediate pore spaces of packageable graded particle being filled by the rheological fluid composition comprising a mixture of chemical reagents or sludge.
[0045]
The system of claim 44, characterized in that a chemical reagent composition of the mixture of chemical reagents or sludge comprises: a first fluid mixture of organophilic clay comprising from 5% to 60% by weight of a composition mixed with a hydratable gelling agent sufficient to suspend said clay with weighing material and components of alkaline origin placed in water comprising from 15% to 60% by weight of the composition, said first fluid being mixable and chemically reacted with: by minus a second fluid comprising water comprising 15% to 60% by weight of a composition mixed with a hydraulic cement comprising 15% to 75% by weight of the composition or an oil-based slurry comprising 15% to 60% by weight of the composition mixed with weighing materials comprising from 15% to 75% by weight of the composition.
[0046]
The system of claim 43, further comprising an axial piston component usable to axially displace at least a part of said wall, said movable fluids or combinations thereof, by axial compression of axially adjacent components within a axially adjacent space to form or widen said operable space.
[0047]
47. The system of claim 43 further comprising a side piston member for laterally compressing well components into radially adjacent operable spaces with said packer to form operable space for positioning said well barrier member to fluidly isolate said at least a portion of said underground well without removing said plurality of installed concentric conduits and associated debris from below one or more underground depths (218) to provide or enable said restoration of said rock layer above the said production area.
[0048]
48. The system of claim 26, further comprising a slapper member comprising a lockable and releasable piston, the slapper member being sealable within said innermost passageway and operable with energy released from the compression of said column of circulable fluid, to travel along a post or relock rod and to deliver an explosive hydraulic slapper pulse, a mechanical impact or combinations thereof, to another member, said moving fluids or combinations thereof.

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同族专利:

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公开号 | 公开日

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MX2014000079A|2014-05-01|

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GB2492663B|2014-01-29|

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BR112014001623A2|2017-02-21|

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AU2012279476B2|2017-08-31|

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EP2729662A2|2014-05-14|

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EP2729657B1|2019-09-04|

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EP2729662B1|2017-10-04|

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GB201212008D0|2012-08-22|

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CA2841144C|2019-06-04|

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MX2014000080A|2014-05-01|

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EP2729662A4|2016-05-18|

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CN103764940A|2014-04-30|

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GB2492663A|2013-01-09|

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WO2013006208A2|2013-01-10|

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AU2012278973A1|2014-02-06|

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AU2012278973B2|2016-07-28|

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CN103764940B|2020-10-16|

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EP2729657A2|2014-05-14|

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AU2012279476A1|2014-02-06|

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MX354003B|2018-02-08|

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法律状态:
2018-12-11| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

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2019-11-05| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|

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2021-07-13| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 05/07/2012, OBSERVADAS AS CONDICOES LEGAIS. |

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