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    • 专利摘要:
    LASER ASSISTED SYSTEM FOR CONTROL OF EMERGENCY DRILLING SITUATIONS IN DEEP WATERS.The present invention relates to a high power laser riser eruption preventer system and a controller for its operation. The system uses high-powered laser cutters that are associated with the riser and eruption preventer to provide an integrated operation to weaken or quickly cut tubulars to resolve emergency or potentially emergency situations that may arise during deepwater drilling.
    公开号:BR112013021530A2
    申请号:R112013021530-5
    申请日:2012-02-24
    公开日:2020-09-29
    发明作者:Mark S. Zediker
    申请人:Foro Energy Inc.；Chevron U.S.A. Inc；
    IPC主号:
    专利说明:

    Invention Patent Descriptive Report for "LASER ASSISTED SYSTEM FOR CONTROL OF EMERGENCY DRILLING SITUATIONS IN DEEP WATERS". Background of the technique 5 Field of the Invention The present inventions refer to systems used for marine exploration and production of hydrocarbons, such as oil and natural gas.
    Therefore, and in particular, the present inventions refer to innovative systems that use high power laser cutters to quickly assist in the management and control of emergency maritime drilling events.
    As used in this document, unless otherwise specified, the terms "rash preventer", "BOP" and "BOP set" should be interpreted as broadly as possible and include: (i) devices positioned on or near the surface of a well hole, for example, the seabed, which are used to contain or manage pressures or flows associated with a well hole; (ii) devices to contain or manage pressures or flows in a borehole that are associated with an underwater riser; (iii) devices that have any number of combinations of ports, valves or elastomeric obstructions to control or manage well hole pressures or flows; (iv) a submarine BOP set, the set of which may contain, for example, drawer shears, tube drawers, blind drawers and annular preventers; and, (v) other combinations and similar assemblies of flow and pressure management devices to control pressures or well bore flows, or both, and, in particular, to control or manage emergency flow or pressure situations.
    As used herein, unless otherwise specified, "offshore" and "offshore drilling activities" and similar terms are used in their broadest sense and would include drilling activities on, or within any body of water, whether fresh or salt water, whether artificial or natural, such as rivers, lakes,
    canals, inland seas, oceans, seas, bays and gulfs, such as the Gulf of Mexico.
    As used in this document, unless otherwise specified, the term "marine drilling rig" should be interpreted in its widest possible meaning and would include fixed towers, small vessels, platforms, rafts, self-elevating platforms, floating platforms, drilling vessels, dynamically positioned drilling vessels, semi-submersible and dynamically positioned semi-submersibles.
    As used herein, unless otherwise specified, the term "seabed" should be interpreted as broadly as possible and would include any surface on land that rests under or as the bottom of any body of water, whether fresh or salt water, whether artificial or natural.
    As used in this document, unless otherwise specified, the terms "well" and "well bore" should be interpreted as widely as possible and include any holes that are drilled or otherwise made. on the surface of the earth, for example, the seabed or seabed, and would also include exploratory, production, abandoned, reactivated, reworked and injection wells.
    As used in this document, the term "riser" should be interpreted as broadly as possible and would include any tubular connecting a platform to, on or above the surface of a body of water, including a marine drilling rig, a watercraft. floating and unloading production storage (FPSO) and a floating and unloading gas storage vessel (FGSO), to a structure at, on, or near the seabed for the purposes of activities such as drilling, production , reconditioning, service, service, intervention and well completion.
    As used herein, the term "drill pipe" should be interpreted as broadly as possible and includes all forms of pipe used for drilling activities; and refers to a single section or part of the tube.
    As used herein, the terms "drill pipe support", "drill pipe support", "pipe support", "support" and terms of similar types should be used
    their broadest possible meaning and include two, three or four sections of drill pipe that have been connected, for example, joined together, typically by joints that have threaded connections.
    As used in this document, the terms "drill column", "column", 5 "drill pipe column", tube column "and terms of similar types should be interpreted as broadly as possible and would include a support or supports joined for the purpose of being used in a well bore.
    Therefore, a drill string would include many supports and many hundreds of drill pipe sections.
    As used herein, the term "tubular" should be interpreted as broadly as possible and includes drill pipe, liner, riser, coiled pipe, composite pipe, production pipe, vacuum insulated pipe (VIT) and any similar structures that have at least one channel in them that is, or can be used in, the drilling industry.
    As used in this document, the term "gasket" should be interpreted as broadly as possible and includes all types of devices, systems, methods, structures and components used to connect the tubulars to each other, for example, gaskets. threaded pipe and bolted flanges.
    For drill pipe jutes, the joint section typically has a thicker wall than the rest of the drill pipe.
    As used in this document, the wall thickness of the tubular is the thickness of the material between the inner diameter of the tubular and the outer diameter of the tubular.
    As used in this document, unless otherwise specified, "high power laser energy" means a laser beam that is at least about 1 kW (kilowatt) in power.
    As used in this document, unless otherwise specified, "great distances" means at least about 500 m (meter). As used herein, the term "substantial loss of potential", "substantial loss of power" and similar expressions mean a loss of power of more than about 3.0 dB / km (decibel / kilometer) for a length selected waveform.
    As used herein, the term "substantial power transmission" means at least about 50% transmittance.
    Discussion of the related technique Drilling in deep water 5 Exploration and offshore production of hydrocarbons has moved into ever deeper waters.
    Currently, drilling activities at depths of 1,524 meters (5,000 feet), 3,048 meters (10,000 feet) and even greater depths are contemplated and carried out.
    For example, it has been reported by RIGZONE, www.rigzone.com, that there are more than 330 probes evaluated for drilling in water depths greater than 182.88 meters (600 feet), and of those probes, there are more than 190 probes evaluated - for drilling in water depths greater than 1,524 meters (5,000 feet) and of those rigs, more than 90 of them are classified for drilling in water depths of 3,048 meters (10,000 feet). When drilling takes place at these deep, very deep and ultra-deep depths, the drilling rig is subjected to extreme conditions found in the depths of the ocean, including high pressures and low temperatures on the seabed.
    In addition, these deepwater drilling rigs are capable of advancing through well holes that can be 3,048 meters (10,000 feet), 6,096 meters (20,000 feet), 9,144 meters (30,000 feet) and even deeper below the sea floor .
    As such, drilling equipment, such as drill pipe, casing, risers and BOP, are subjected to substantial forces and extreme conditions.
    To address these forces and conditions, drilling equipment, for example, risers, drill pipes and drill columns are designed to be stronger, rougher and, in many cases, heavier.
    In addition, the metals that are used to manufacture the drill pipe and casing have become more malleable.
    Typically, and as a general illustration, when drilling a subsea well, an initial well hole is drilled in the seabed and then subsequent wells of smaller diameter are drilled to extend
    the depth of the well hole.
    Thus, as the general well hole becomes deeper, its diameter becomes smaller, resulting in what can be considered as a telescopic assembly of holes with the largest diameter being at the top of the well hole closest to surface 5 of the Earth.
    Therefore, as an example, the initial stages of a seabed drilling process can be explained, in general, as follows.
    Once the drilling rig is positioned on the water surface over the area where drilling is to take place, an initial well hole is drilled by drilling a 91.4 cm (36 inch) hole in the ground to a depth from about 60.96 to 91.44 meters (200 to 300 feet) below the sea floor.
    A 76.2 cm (30 inch) liner is inserted into this initial well hole.
    This 76.2 cm (30 inch) coating can also be called a conductor.
    The 76.2 cm (30 inch) conductor may or may not be cemented in place.
    During this drilling operation, a riser is generally not used and the cuttings from the borehole, for example, earth and other materials removed from the borehole by drilling activity are returned to the seabed.
    Next, a 66 cm (26 inch) diameter borehole is drilled into the 76.2 cm (30 inch) casing, extending to the depth of the well hole at about 304.8 to 457 , 2 meters (1,000 to 1,500 feet). This drilling operation can also be carried out without using a riser.
    A 50.8 cm (20 inch) coating is then inserted into the 76.2 cm (30 inch) and 66 cm (26 inch) well hole conductor. This 50.8 cm (20 inch) coating is cemented in place.
    The 50.8 cm (20-inch) liner has a wellhead attached to it. (In other operations, a smaller diameter well hole can be drilled and a smaller diameter liner inserted into that well hole with the wellhead being attached to that smaller diameter liner.) A BOP is then attached to a riser and lowered by the riser to the bottom of the sea; where the BOP is attached to the wellhead.
    From that point on, in general, all drilling activity in the borehole occurs through the riser and the BOP.
    The BOP, along with other equipment and procedures, is used to control and manage pressures and flows in a well.
    In general, a BOP is a stack of several mechanical devices that have a connected internal cavity that extends through these devices.
    BOPs can have cavities, for example, hole diameters ranging from about 10.6 cm (4.16 inches) to 67.9 cm (26.75 inches). The tubular is advanced from the marine drilling rig down into the riser, through the BOP cavity and into the well hole.
    Returns, for example, drilling mud and cuttings, are removed from the well bore and transmitted through the BOP cavity, upwards by the riser, and up to the marine drilling rig.
    The BOP set typically has an annular preventer, which is an expandable obstructor that works like a giant sphincter muscle around the tubular.
    Some annular preventers can also be used or be able to seal the cavity when the tubular is not present.
    When activated, this obstructor seals against tubulars that are in the cavity of the BOP cavity, preventing material from flowing through the annular space formed between the outer diameter of the tubular and the wall of the BOP cavity.
    The BOP set also typically has drawer preventers.
    As used in this document, unless otherwise specified, the term "drawer preventer" should be interpreted as broadly as possible and would include any mechanical devices that grab, catch, retain, cut, break, crush or combinations thereof, tubular in a BOP set, such as shear drawers, blind drawers, shear-blind drawers, tube drawers, variable drawers, variable tube drawers, shear sheath drawers and preventers, such as Hydril's HYDRIL PRESSURE CONTROL COM- PACT Ram, Hydril Pressure Control Conventional Ram, HYDRIL PRESSU-RE CONTROL QUICK-LOG and HYDRIL PRESSURE CONTROL SENTRY Workover, SHAFFER Ram preventers and drawer preventers manufactured by Cameron.
    Therefore, the BOP set typically has a tube drawer preventer and can have more than one of these.
    Tube drawer preventers are typically two half-circle-like gripping devices that are driven against the outside diameter of the tubular in the BOP cavity.
    The tube drawer preventers can be seen as two large hands that grip against the tubular and seal the annular space between the tubular and the BOP cavity wall.
    Blind drawer preventers can also be contained in the BOP assembly, and these drawers can seal the cavity when no tubular is present.
    Tube drawer preventers and annular preventers can typically seal only the annular space between a tubular in the BOP and the BOP cavity; they cannot seal the tubular.
    Therefore, in emergency situations, for example, when a "gas jet" (a sudden influx of gas, fluid, or pressure into the well bore) occurs, or situations of potential eruption (blowout) occur, flows from high well bore pressures may return through the interior of the tubular, the annular space between the tubular and the riser, and rise up to the riser, to the drilling rig.
    Additionally, in emergency situations, the annular tube drawer and preventers may not be able to form a strong enough seal around the tubular to prevent flow through the annular space between the tubular and the BOP cavity.
    Therefore, BOP assemblies include a mechanical shear drawer assembly.
    Mechanical shear drawers are typically the last line of defense for emergency situations, for example, gas jets or potential eruptions. (As used in this document, unless otherwise specified, the term "shear drawer" would include blind shear drawers, blind sealing drawers, shear seal drawers, shear drawers and any drawer that is intended for or capable of cutting or shearing a tubular). The mechanical shear drawers function as giant gate valves that must quickly close the BOP cavity to seal it.
    They are designed to cut through any tubular in the BOP cavity that would potentially block the shear drawer from completely sealing the BOP cavity.
    BOP sets can have many different configurations,
    which are dependent on the conditions and risks that are expected during use and use. These components include, for example, a ring-type preventer, a swivel head, a single-head preventer with a set of drawers (blind or tube), a double-drawer preventer that has two sets of drawers, a triple drawer type that has three sets of drawers and a cylinder with side outlet connections for restrictor and kill lines. Examples of existing configurations of these components could be: a BOP set that has a 17.9 cm (7.062 inch) bore and from the bottom to the type a single drawer, a cylinder, a single drawer, a single drawer and an annular preventer and which has an estimated working pressure of 34,473.78 kPa (5,000 psi); a BOP set that has a 34.6 cm (13.62 inch) hole and, from the bottom to the top, a cylinder, a single drawer, a single drawer, a single drawer and a ring preventer and which has an estimated working pressure of 68,947.57 kPa (10,000 psi); and a set of BOP that has a hole of 47.6 cm (18.75 inches) and, from bottom to top, a single drawer, a single drawer, a single drawer, a single drawer, an annular preventer and an annular preventer that has an estimated working pressure of 103,421.35 kPa (15,000 psi). (As used in this document the term "preventer" in the context of a BOP set, would include all drawers, shear drawers and annular preventers, as well as any other structure similar to the mechanical valve used to restrict, disable or control the flow in a BOP hole). BOPs need to contain the pressures that could be present in a well, and the pressures could be as great when
    103,421.35 kPa (15,000 psi) or more. Additionally, there is a need for shear drawers that are able to quickly and reliably cut through any tubular, including drill commands, pipe joints, and downhole assemblies that may be present at the BOP when an emergency situation arises or otherwise situation in which it is desirable to cut tubulars in the BOP and seal the well. With the increasing strength, thickness and ductility of tubulars and, in particular, of deep, very deep and ultra-deep water drilling tubes, there is a growing need for stronger, stronger and better shear drawers.
    This need for such shear drawers, as well as other information about the physics and engineering principles 5 underlying the existing mechanical shear drawers, is presented in: West Engineering Services, Inc., "Mini Shear Study for U.S.
    Minerals Management Services "(Application No. 2-1011-1003, December 2002); West Engineering Services, Inc.," Shear Ram Capabilities Study for U.S.
    Minerals Management Services "(Application No. 3-4025-1001, September 2004); and, Barringer & Associates Inc.," Shear Ram Blowout Preventer Forces Required "(June 6, 2010, revised August 8, 2010 In an attempt to meet these ongoing and increasingly important needs, BOPs have become bigger, heavier and more complicated.
    Therefore, the BOP sets that have two annular preventers, two shear drawers and six tube drawers have been suggested.
    These BOPs can weigh many hundreds of tons and have a support 15.24 meters (50 feet) high or higher.
    The ever-increasing size and weight of BOPs presents a significant problem, however, for older drill rigs.
    Many of the existing marine probes do not have deck space, lifting capacity or, for other reasons, the ability to handle and use these larger and more complicated BOP sets.
    As used in this document, the term "riser" should be interpreted as broadly as possible and would include any tubular that connects to a platform on, over or above the surface of a body of water, including a marine drilling rig, a floating production storage and unloading vessel ("FPSO") and a floating gas storage and unloading vessel ("FGSO"), to a structure at, on or near the seabed for the purposes of activities such as drilling , production, reconditioning, service, well service, intervention and completion.
    Risers, which would include marine risers, submarine risers, and
    drilling rigs are essentially large tubulars that connect a marine drilling rig, vessel or platform to a well hole.
    Typically, a riser is connected to the probe above water level and to a BOP under the sea.
    Risers can be seen as essentially a very large tube, which has an internal cavity through which the tools and materials needed to drill a well are sent down from the marine drilling rig to the well hole at the bottom of the well. sea and residual material and tools are extracted from the well bore and back to the offshore drilling rig.
    Therefore, the riser functions as an umbilical cord that connects the marine probe to the well bore through, potentially, thousands of feet of water.
    Risers can vary in size, type and configuration.
    All risers have a central or large center tube that can have outside diameters ranging from about 34.6 cm (13.62 inches) to about 61 cm (24 inches) and can have wall thicknesses of about from 1.6 cm (0.62 inch) to 2.2 cm (0.87 inch) or more.
    Risers come in sections that can vary in length from about 14.93 meters (49 feet) to about 24.99 meters (82 feet) and, typically, for ultra-deep water applications, are 22.86 meters ( 75 feet) in length.
    Therefore, to have a riser that extends from the probe to a BOP on the seabed, the riser sections are connected to each other by the probe and lowered to the seabed.
    The ends of each riser section have riser couplings that allow the large center tube of the riser sections to be connected.
    The term "riser coupling" should be interpreted as broadly as possible and includes several types of coupling that use mechanical means, such as flanges, screws, clips, bowen fittings, lubricants, locks, keys, threads, pins and other means of fixation known in the art or further developed by the art.
    Thus, for example, riser couplings would include flange style couplings, which use flanges and screws; latch-style couplings that use latches in a box, which are brought into engagement by a drive screw
    ment; and key style couplings, which use a key mechanism that rotates for the locking hitch.
    An example of a flange style coupling would be the VetcoGray HMF.
    An example of a lock-style coupling would be the VetcoGray MR-10E.
    An example of a key 5 style coupling would be the VetcoGray MR-6H SE.
    Each riser section also has external tubes associated with the large central tube.
    These tubes are attached to the outside of the large central tube, run down the entire length of the tube or rider section, and have their own connections that are associated with the riser section connections.
    Typically, these tubes would include a restrictor line, kill line, intensifier line, hydraulic line and, potentially, other types of lines or cables.
    The restrictor, kill, intensifier and hydraulic lines have internal diameters of about 7.6 cm (3 inches) (hydraulic lines can be as small as about 6.4 cm (2.5 inches) to about 16 , 5 cm (6.5 inches) or more and wall thicknesses from about 1.3 cm (0.5 inch) to about 2.5 cm (1 inch) or more). Situations arise in which it may be necessary to disconnect the rig from the marine drilling rig, vessel or platform.
    In some of these situations, for example, bypassing a floating probe, there may be little or no time to properly disconnect the riser.
    In other situations, such as weather-related situations, there may not be enough time to pull the riser column once enough weather information is obtained; thus forcing a decision to pull the riser potentially and unnecessarily.
    Therefore, and particularly for drilling in deep, very deep and ultra-deep waters, there is a need to disconnect a riser from a marine drilling rig quickly and with minimal damage.
    In offshore drilling activities, critical and frequent emergency situations arise.
    These situations can occur quickly, unexpectedly, and require immediate attention and remedial action.
    Although these possible maritime emergency situations may have downhole causes similar to emergency onshore drilling situations, maritime activities are much more difficult and complicated to manage and control.
    For example, it is generally more difficult to evacuate rig workers to a location away from the drilling rig in a marine environment.
    Environmentally, it is also substantially more difficult to mitigate and manage the inadvertent release of hydrocarbons, such as an oil spill, or eruption, for a maritime situation than one that occurs on land.
    The drilling rig, in a marine environment, can be many tens of thousands of feet away from the wellhead.
    In addition, the marine drilling rig is attached to the well hole by the riser and any tubulars that may be in the well hole.
    Such tubulars can also interfere with, inhibit, or otherwise prevent well-controlled equipment from functioning properly.
    These tubulars and the riser can act as a conduit that brings dangerous hydrocarbons and other materials into the center of the probe and exposes the probe and its employees to extreme dangers.
    Therefore, there has long been a need for systems that can quickly and reliably treat, assist in the management of and mitigate emergency and critical marine drilling situations.
    This need has become more and more important as maritime drilling activities have progressed to deeper and deeper waters.
    In general, it is believed that the technique tried to address this need by having heavier and larger pieces of equipment, in essence, for what can be described as the use of brute force in an attempt to meet this need.
    Such brute-force methods, however, have failed to fulfill this important and long-standing need.
    High power laser beam transmission Previous to the innovations of inventor Dr.
    Mark Zediker and those who work with him at Foro Energy, Inc., Littleton CO, believed that the transmission of high-powered laser energy over long distances without substantial loss of power was not achieved. level.
    Its innovations in high power laser energy transmission and, in particular, energy levels greater than about 5 kW, are presented
    partly in the new and innovative teachings contained in U.S. patent application publications 2010/0044106 and 2010/0215326 and in Rinzler et. al, pending patent application U.S. Serial No. 12 / 840,978, entitled "Optical Fiber Configurations for Transmission of Laser Energy Over Great 5 Distances" (filed July 21, 2010). The descriptions of these three U.S. patent applications, to the extent that they refer to or relate to the transmission of high power laser energy, and lasers, fibers and cable structures to perform such transmissions, are hereby incorporated by reference. It should be noted that this incorporation as a reference does not provide any right to practice or use the inventions of these applications or any patent that may be issued from them does not grant or open precedents for any licenses under them.
    SUMMARY In offshore drilling operations, it has long been desirable to have the ability to cut or weaken quickly and in a controlled manner tubulars extending from a offshore drilling rig to, and inland, a borehole to assist in the control and management of emergency situations that arise during deepwater drilling activities. The present invention, among other things, addresses this need by supplying the articles of manufacture, devices and processes taught in this document. Therefore, an eruption preventer and laser riser system is provided here for use with a marine drilling rig to control and manage emergency or potentially emergency situations, with the laser riser eruption preventer system having: a laser High power; a high power beam switch that is optically associated with the high power laser; a riser; a rash preventer; a first laser cutter and a second laser cutter, in optical association with the high power beam switch; wherein the first laser cutter is positioned adjacent to the riser, where the first laser cutter can direct the first high-powered laser beam towards a component of the riser; where the second laser cutter is positioned on the eruption preventer, where the second laser cutter can direct a second high-powered laser beam towards a tubular in the eruption preventer; and a control network in control of communication and data with the laser, the beam switcher and the eruption preventer, in which the 5 control network provides the laser firing and the eruption preventer action.
    In addition, a system is provided in which the control network has a programmable logic controller; where the control network has a user interface; wherein the control network includes a memory device that has a series of instructions for executing the predetermined firing sequence for the first laser cutter, the second laser cutter and the eruption preventer action; wherein the control network includes a plurality of controllers; where the high power laser has at least about 10 kW of power; where the high power laser has at least about 20 kW of power; or where the high power laser has at least about 40 kW of power.
    In addition, a system is provided that has a plurality of high power lasers; where only one of a plurality of high-power lasers is aligned at any time; or that has a third laser cutter, where one of the second or third laser cutters is associated with an upper portion of the rash preventer and the other of the second or third laser cutters is associated with a lower portion rash preventer.
    Additionally, an eruption preventer and laser riser system is provided for use with a marine drilling rig to control and manage emergency or potentially emergency situations, and the laser riser eruption preventer system has: a pri - high power laser and a second high power laser; a riser; a rash preventer; a first laser cutter and a second laser cutter, the first laser cutter being in optical association with the first high power laser and the second optical cutter is in optical association with the second high power laser; and where the first
    The laser cutter is associated with the riser, and the second laser cutter is associated with the eruption preventer.
    In addition, an eruption preventer and laser scanner system is provided for use with a marine drilling rig to control and 5 manage emergency or potentially emergency situations, with the laser riser eruption preventer system having: high power laser; a high power beam switch in optical and control association with the high power laser; a riser that has a first laser cutter, where the first laser cutter can direct a first high-powered laser beam towards a component of the riser; an eruption preventer that includes a second laser cutter, in which the second laser cutter can direct a second high-powered laser beam towards a tubular in the eruption preventer; and, the first and a second laser cutter in optical association with the high power laser.
    In addition, a marine drilling rig is provided that has a laser riser and eruption preventer system to control and manage emergency or potentially emergency situations, and the laser eruption and riser preventer system has: a high-powered laser in optical association with a high power beam switch; a riser that includes a plurality of riser sections, in which a plurality of riser sections are configured to be lowered from and operably connected to the marine drilling rig at a depth at or near a seabed; an eruption preventer configured to be operably connected to the riser and lowered by the riser from the marine drilling rig to the seabed; and, one of a plurality of riser sections, including a first laser cutter to emit the first laser beam that defines a first beam path, the first beam path being directed towards the riser section ; the eruption preventer, including a second laser cutter to emit a second laser beam that defines a second beam path, in which the second beam path is directed towards a cavity defined by the eruption preventer; and, a control system; where, when the riser and eruption preventer are positioned and operably associated with the marine drilling rig and a well hole in the seabed, the control system is configured to control the firing of the first and second cutters laser. Additionally, this system can be configured to control the action of the eruption preventer. In addition, a method is provided for performing drilling, reconditioning, intervention, completion or service in an underwater well when using a laser riser and eruption prevention system in conjunction with a marine drilling rig to control and manage situations emergency or potentially emergency, the method including: lowering an eruption preventer, a marine drilling rig, vessel or platform to a seabed using a riser, including a plurality of riser sections; where the eruption preventer includes: an eruption preventer cavity defined by the eruption preventer; and a first laser cutter to emit a first laser beam that defines a first beam path, wherein the first beam path is directed towards the eruption preventer cavity; wherein the riser includes: a riser cavity defined by the riser; and a second laser cutter to emit the second laser beam that defines a second beam path, wherein the second beam path is directed towards a riser component; operably connecting a high power laser to a control system; attaching the eruption preventer to a well hole, in which the well hole cavity and the riser cavity are in fluid and mechanical communication; and, performing operations at the well hole by lowering the structures of the marine drilling rig down through the riser cavity, the eruption preventer cavity and into the well hole; and, in which the control system is configured to trigger the high power laser. In addition, the structures can be selected from the group consisting of: tubular, steel cable, spiral tubing and piano string.
    BRIEF DESCRIPTION OF THE DRAWINGS Figures 1 and 1A are perspective views of an embodiment of a system of the present invention.
    Figure 2 is a partial cross-sectional view of one embodiment of a laser shear drawer assembly of the present invention to be used with the system of Figures 1 and 1A. Figure 3A is a partial cross-sectional view of another embodiment of a laser shear drawer assembly of the present invention to be used with the system of Figures 1 and 1A.
    Figure 3B is a detailed cross-sectional view of a portion of the laser shear drawer assembly of Figure 3A.
    Figures 4A, 4B, 4C & 4D are cross-sectional views of the laser shear drawer assembly of Figure 3A.
    Figure 5 is a cross-sectional view of another embodiment of a laser shear drawer assembly of the present invention to be used with the system of Figures 1 and 1A.
    Figure 6 is a cross-sectional view of another embodiment of a laser shear drawer assembly of the present invention to be used with the system of Figures 1 and 1A.
    Figure 7 is a partial cross-sectional view of another embodiment of a laser shear drawer assembly of the present invention to be used with the system of Figures 1 and 1A.
    Figure 8 is a partial cross-sectional view of another embodiment of a laser shear drawer assembly of the present invention to be used with the system of Figures 1 and 1A.
    Figure 9 is a partial cross-sectional view of another embodiment of a laser shear drawer assembly of the present invention to be used with the system of Figures 1 and 1A.
    Figures 10A, 10B and 10C are seen from a section of one embodiment of a laser shear drawer that has laser cutters of the present invention to be used with the system of Figures 1 and 1A.
    Figures 11A, 11B and 11C are seen from a section of another embodiment of a laser shear drawer that has laser cutters of the present invention to be used with the system of Figures 1 and 1A.
    Figures 12A, 12B & 12C are seen from a section of another embodiment of a laser shear drawer that has laser cutters of the present invention to be used with the system of Figures 1 and 1A. Figures 13A, 13B and 13C are seen from a section of another embodiment of a laser shear drawer that has laser cutters of the present invention to be used with the system of Figures 1 and 1A.
    Figure 14 is a schematic plan view of a mode of a pair of opposing laser shear drawers that have laser cutters of the present invention to be used with the system of Figures 1 and 1A.
    Figure 15 is a schematic plan view of another embodiment of a pair of opposing laser shear drawers that have laser cutters in one of the drawers of the present invention to be used with the system of Figures 1 and 1A.
    Figure 16 is a schematic of an embodiment of a laser-assisted BOP set of the present invention to be used with the system of Figures 1 and 1A.
    Figure 17 is a schematic of another embodiment of a laser-assisted BOP set of the present invention to be used with the system of Figures 1 and 1A.
    Figure 18 is an illustration of another embodiment of a laser-assisted BOP kit of the present invention to be used with the system of Figures 1 and 1A.
    Figure 19 is a partial cross-sectional view of a section of a modality of a laser shear module ("S-LM") of the present invention to be used with the system of Figures 1 and 1A.
    Figure 20 is a partial cross-sectional view of a section of another embodiment of an SLM of the present invention to be used with the system of Figures 1 and 1A.
    Figure 21 is a partial cross-sectional view of a section of another embodiment of an SLM of the present invention to be used.
    with the system of Figures 1 and 1A. Figures 21A, 21B and 21C are cross-sectional views of the SLM of Figure 21 taken along line B-B. Figures 22, 22A and 22B are schematic illustrations of laser beam costumes-5 of the present invention. Figure 23A is a partial sectional view of an embodiment of a laser module and riser sections of the present invention for use with the system of Figures 1 and 1A. Figure 23B is a cross-sectional view of the laser module and riser sections of Figure 23A. Figure 23C is an enlarged view of section C of Figure 23A. Figure 24A is a partial sectional view of another embodiment of a laser module and riser sections of the present invention for use with the system of Figures 1 and 1A. Figure 24B is a cross-sectional view of the laser module and riser sections of Figure 24A. Figure 25A is a perspective view of an embodiment of a laser riser section of the present invention to be used with the system of Figures 1 and 1A. Figure 25B is a cross-sectional view of the laser riser section of Figure 25A.
    DESCRIPTION OF THE PREFERRED EMBODIMENTS In general, the present inventions refer to multiple laser beam delivery systems that can deliver controlled, precise and predetermined laser energy to address crises and emergency situations during drilling activities maritime Therefore, by way of example, a modality of a marine drilling rig that has a laser beam delivery system is shown schematically in Figure
    1. In this modality, a dynamically positioned drilling vessel (DP) 100 was provided that has a drilling floor 101, a drilling mast 102 above the drilling floor, and hull window 103 (as
    seen through the cut in the Figure showing the inside of the drilling vessel 100) below the drilling floor 101 and other drilling and support equipment and devices used for the operation, which are known in the marine drilling technique, but not 5 are shown in the Figure. The drilling vessel includes a riser 104 and a BOP set
    105. Although a drilling vessel is shown in this modality, any other type of marine drilling rig, vessel or platform, including FPSOs or GGSOs, may be used. Riser 104 is positioned and connects drilling vessel 100 to a well hole 124 that extends below the seabed 123. The upper portion, that is, the portion of the riser when positioned that is closest to the surface 125 of the water , of riser 104, is connected to drilling vessel 100 by tensioners 126 that are attached to a tension ring 127. The upper section of riser 104 can have a diverter 128 and other components (not shown in this figure) that are commonly used and employed with risers and are well known to those skilled in the marine drilling technique. The riser 104 extends from the hull window 103 of the drilling vessel 100 and is connected to the BOP 105 assembly. The riser 104 is made up of riser sections, for example, 107, 109, which are connected to each other by riser couplings, for example, 106, 108, 110 and recessed through the hull window 103 of drilling vessel 100. Therefore, riser 104 can also be called a riser column. The lower portion, that is, the portion of the riser that, when positioned, is closest to the seabed, of the riser 104 is connected to the BOP 105 assembly via the riser-BOP 115 connector. The riser-BOP 115 connector it is associated with flexible joint 116, which can also be called flexible connection or ball joint. The flexible joint 116 is designed to accommodate movements of the drilling vessel 100 from positions that are not directly above the laser-assisted BOP assembly 105; and therefore accommodate riser 104 that enters the BOP 105 assembly at an angle. The BOP 105 set can be characterized as having two
    the component assemblies: an upper component assembly 117, which can be called a lower marine riser package (LMRP), and a lower component assembly 118, which can be called a lower BOP assembly or BOP itself. The BOP 105 assembly has a 5-head connector 135 that is attached to the well-head 136, which is attached to the well-hole 124. The LMRP 1 17 of the BOP 105 assembly may have a housing frame, for example , a null preventer. The lower component assembly 118 of the BOP 105 may have a frame that houses an annular preventer, a laser shear drawer assembly, a laser shear module ("SLM") and a drawer preventer. During positioning, the BOP 105 set is attached to riser 104, lowered to the bottom of the sea 123 and attached to a wellhead
    136. Wellhead 136 is positioned and attached to a liner (not shown), which has been cemented into a wellbore 124. From this point on, in general, all drilling activity in the wellbore occurs through - through riser and BOP. Such drilling activity would include, for example, lowering a column of drill pipe that has a drill bit at its end from drill vessel 100 down into the internal cavity of riser 104, through the cavity of the BOP assembly 105 and into the well bore 124. Therefore, the drilling column would run from the drilling vessel 100 on the surface 125 of the water to the bottom of the well bore, potentially many tens of thousands of feet below the surface of the well. water 125 and seabed 123. The drill bit would be turned against the bottom of the well hole, while drill mud is pumped down into the drill pipe and out of the drill bit. The drilling mud would carry the cuttings, for example, well-hole material removed by the rotary drill, upwards until the annular space between the well-hole wall and the outer diameter of the drilling column, continuing upwards through the annular space between the BOP cavity wall and the outer diameter of the drilling column, and continuing upwards through the annular space between the inner diameter of the riser cavity and the outer diameter of the drilling column, until the perfu-
    feed and cuttings are directed, in general, through a bell housing (not shown), or, in extreme situations, a diverter 128, for drilling vessel 100 for handling or processing.
    Therefore, the drilling mud is pumped from the drilling vessel 100 through a drilling column in the riser to the bottom of the well hole and returned to the drilling vessel, in part, by the riser 104 and BOP 105. The riser sections are typically stored vertically on the offshore drilling rig.
    Once the drilling rig has reached a drilling location, the riser package and BOP are positioned on the seabed.
    In general, it is recognized that different, varied and more detailed procedures can be followed, as a first step in positioning the BOP, the BOP set is prepared and positioned under the drilling floor and under the turntable.
    A spider and a gimbal suspension are positioned in relation to the turntable.
    The lower section of the riser that is attached to the BOP is moved to the drilling mast and lowered by the suspension device on the drilling mast through the spider and down to the BOP below the drilling floor, where it is connected to the BOP.
    The riser and BOP are then lowered to a point where the upper coupling of the riser section is at a height above the drill floor where it can be readily connected to the next section of the riser.
    The spider keeps it in that position.
    Once the connection has been made, the two sections and the BOP are then lowered and this process is repeated until enough sections of the riser have been added and lowered to allow the BOP to reach and be landed on (attached to) the wellhead on the seabed.
    During this process, laser cutters can be attached to the riser or below the drilling floor, if they are too large to fit through the spider, or above the drilling floor if they can fit through the spider.
    Additionally, during the assembly of the BOP, laser cutters can be attached or stacked, as assembled.
    Laser cutters could also be contained in the stack and in a riser section, so they do not require any additional assembly time or time to fix the cutter during the positioning of the riser and BOP.
    High power cables will preferably be attached to and maintained by external supports or riser mounts.
    Preferably, the cables are attached to the riser in the hull window area before the riser section is lowered into the water.
    In this way, the high-power cables can be terminated from a cylinder as the BOP and riser are lowered to the seabed.
    High-power cables with high-power laser couplers at each end can be externally mounted on each riser section, in the same way that the restrictor and kill lines are attached to the riser sections.
    In this way, the final optical connection of the uppermost riser section to the laser can be made below the drilling floor and after the riser and BOP are landed at the wellhead.
    The riser has an internal cavity, not shown in Figure 1, which is in fluid and mechanical communication with an internal cavity, not shown in Figure 1, in the BOP set.
    Therefore, as positioned, riser 104 and BOP 105 provide a cavity or channel that places the drilling vessel in fluid and mechanical communication with well hole 124. The BOP assembly frames protect the BOP, and they may have lifting and handling devices, a connection and control module and other equipment and devices used in subsea operation, which are known in the maritime drilling technique, but are not shown in the Figure.
    The internal cavity in the pile goes through the pile from its top (closest to the water surface 125) to its bottom (closest to the seabed 123). In the example mode shown in Figure 1, the riser is a 53.3 cm (21 inch) riser and the BOP is a 47.6 cm (18.75 inch) BOP. The term "53.3 cm (21 inch) riser" and 47.6 cm (18.75 inch) BOP can be considered as generic and cover risers where the large central tube has an outside diameter in the general range of 53 , 3 cm (21 inches) and BOPs where the center cavity or hole diameter is in the general range of 47.6 cm (18.75 inches). The use of risers of smaller and larger diameters, different types and configurations of risers, BOPs that have cavities of smaller and larger diameters and different types and configurations of BOPs are contemplated and the teachings and inventions of this specification are not limited. a, or by, the size, type 5 or configuration of a particular riser or BOP. In Figure 1, the riser and BOP package is configured along the lines of a drilling riser-BOP package with the BOP positioned at or near the seabed, typically attached to a wellhead, as, for example, seen in some drilling activities. The present systems, laser modules, laser cutters, laser assemblies and laser riser assemblies of the present inventions have applications in other types of risers, riser-BOP packages and activities. Therefore, they have applications in relation to drilling, reconditioning, service, testing, intervention and completion of activities. They also have applications for surface BOPs, for example, where the BOP is positioned above the water surface and the ridge extends from the BOP to the seabed, where a BOP is not employed, where drilling it is performed in the riser, where the riser is a production riser, and other configurations known to or developed later by the technique. The laser beam delivery system in the modality shown in Figure 1, and seen in more detail in Figure 1A, has a laser room
    140. The laser room 140 contains a 40 kW fiber laser 141, a high power beam switch 142, a cooler 143, and a laser controller system 145, which has an operator interface 146. It is also a deck 137 of drilling vessel 100 is shown below the floor of rig 101, and another deck 138 of drilling vessel 100 which is below deck 137. supports 139 for drilling floor 101 and the drill mast 102 are also shown. The laser system controller 145, the cooler 143, laser 141 and the beam switch 142 are in communication via a network, cables, fiber or other manufacturing, marine or industrial data and control signal communication medium , shown as dashed lines 144.
    Controller 145 is in communication, as shown by line 147, through a network, cables, fiber or other type of fabrication, marine or industrial data and the control signal communication medium with the BOP control system and, potentially, other systems on the 5 marine drilling rig (not shown in this Figure). Controller 145 may also be in communication (as described above) with a first high power laser cylinder cable 149, a second high power laser cylinder cable 150 and a third high power laser cylinder cable 151. High-powered laser optical fibers 152, 153, 154, respectively, connect beam switch 142 to cylinders 149, 150,
    151. The high-powered firms 152, 153, 154 enter the cylinders 149, 50, 151 and are placed in optical and rotary association with the high-power cables 158, 159,160 on the cylinders 149, 150, 151 through slip rings optical 155, 156, 157. High power cables 158, 159, 160 can be supported by support 161 and held in riser 104 by the retainer
    162. Although not shown in the Figures, cables 158, 159, 160 should have a means to accommodate the change in riser length between the BOP and the probe floor 101 which occurs due to the vertical movement (lifting) of a marine probe floating, like drilling vessel 100. The change in riser length is accommodated by a riser-telescope joint (not shown in the drawings). Therefore, extra cable length could be employed or the cylinders could be in variable controlled drives that maintain the correct cable length and tension. The high-power cables 158, 159, 160 follow the riser down to three laser cutters: a first laser cutter 165 is associated with riser 104 and is provided to assist in quick disconnection of the riser; a second laser cutter 166 is associated with the BOP 105 cavity and provided to assist in the quick disconnection of any tubulars that are in the BOP cavity; and a third laser cutter 167 is contained in a shear drawer and provided to assist the shear drawer from quickly breaking any tubular in the path of the drawers and sealing the BOP hole.
    Although three laser cutters are shown, more or less can be used.
    Furthermore, the positions of laser cutters 5 in relation to the components of the riser-BOP package can be varied and may also depend on the particular components that are used in the riser-BOP package.
    An advantage of the present system is that its components can be tailor-made to be compatible with a particular BOP configuration or riser-BOP package.
    An additional advantage of the present inventions is that the pre-selected sequences of laser firing and activation of the preventer can be tailored to be compatible with these configurations, as well as with the applications in which these configurations can be used.
    The laser room, for example, 140, can be modular, that is, the room can be a self-contained unit, like a container used for navigation that has been adjusted with electrical, communication and optical settings.
    In this case, it is also preferable that the container has climate control characteristics, for example, heaters and air conditioning units, built-in or otherwise incorporated into the room.
    The laser room could be a structure that is integral to the marine drilling rig, or it could be a combination of modular components and integral components.
    Any such structure will be sufficient and any positioning, including on a laser boat separate from the marine drilling rig, can be employed, as long as the laser equipment operators are sufficiently protected from environmental and operating marine conditions and the laser system be readily capable of being integrated with, or with, the other marine drilling rig systems.
    The controller, for example, 145, can be any type of processor, computer, programmed logic controller (PLC), or similar computer device that has memory and a processor; that can be, or is, used for industrial, marine or factory control and automation purposes.
    In the system, the controller should preferably be in co-operation
    control of communication and data with the equipment of the marine drilling rig, in particular the BOP control systems.
    Although shown as a separate room in the Figures, the home controller system, for example, 145, could be integrated with, or the same as, the BOP controller, or another controller or probe control system. drilling rigs.
    The laser controller system can also be in communication with, integrated with, or in association with, well capture and monitoring equipment, rig floor monitoring and capture equipment and mud return capture and monitoring equipment.
    In this way, the laser system is integrated with, or, preferably, fully integrated with, BOP control systems and other systems in the offshore drilling rig.
    In addition, the controller can be part of a control network that includes the BOP control system, monitors and sensors for well conditions, monitors and controllers for drilling systems and other marine drilling rig systems.
    Therefore, in a potential emergency situation, or a real emergency situation, laser and BOP cutters can preferably be controlled from the BOP control panel, the laser room, the drilling console, or other locations on the offshore drilling rig.
    This fully integrated control system network can additionally have a laser trigger, a preventive action and a predetermined kill, restraint and intensifier control procedure that could be automatically activated and executed by means of a predetermined command sent to or inserted into the network.
    In addition, the network, by detecting a specific set of conditions, can initiate a predetermined command that is sent and causes a laser shot, preventer action, and predetermined kill and choke and sequence.
    The laser systems of the present invention can use a single high power laser and, preferably, can have two or three high power lasers, and can have several high power lasers, for example, six or more.
    High power solid state lasers, specifically semiconductor lasers and fiber lasers are preferred, due to their short boot time and essentially instantaneous capabilities.
    High power lasers can, for example, fiber lasers or semiconductor lasers that have 10 kW, 20 kW, 50 kW or more of power and emit 5 laser beams with wavelengths, preferably in the bands of about 1550 nm (nanometer) or 1083 nm.
    Examples of preferred lasers and, in particular, solid-state lasers, such as fiber lasers, are presented in US patent application publications 2010/0044106 and 2010/0215326 and in pending patent application serial number US 12 / 840,978. The laser, or lasers, can be located on the marine drilling rig, above the water surface and optically connected to laser modules in the riser via a high-power long-distance laser transmission cable , preferred examples of this are shown in US Patent Application Publications 2010/0044106 and 2010/0215326 and in the pending patent application for serial number US 12 / 840,978. the laser transmission cable can be contained in a cylinder and be unwound and attached to the riser sections as they are lowered to the bottom of the sea.
    Lasers can also be contained in, or associated with, the BOP board, and which have optical cables that run from the BOP board, going up the riser to the laser module located in the riser.
    Even to the extent that the lasers are not located on the marine drilling rig, more care needs to be taken to enable these remote lasers to be integrated into the control or network system.
    By positioning the laser at or near the sea floor, there is the potential to eliminate the need for a long distance of high power optical cable to transmit the laser beam from the water surface down to the sea floor.
    In view of the extreme conditions in which laser modules are required to operate and the need for high reliability in their operation, such a configuration of a laser-riser-BOP package must have at least one high-power laser located in the probe. drilling rig and connected to the laser module by a high power transmission cable and to have at least one laser on, or associated with, the BOP frame under the sea and connected to the laser module by a cable high power transmission.
    The laser cutters used in the laser systems of the present inventions can be any device suitable for delivering high power laser energy.
    Therefore, any configuration of optical elements to culminate and focus the laser beam can be employed.
    An additional consideration, however, is the management of the optimal effects of fluids, for example, seawater, mud or other material from a cut restrictor line, cut kill line or cut center tube from a riser, or fluid hydraulic of a cut hydraulic line, which can be located in the beam path between the laser cutter and the object to be cut, such as a tubular, a riser, coupling, central pipe, external pipe, screw, thread or other structure to be cut.
    Such fluids could include, for example, water, sea water, salt water, brine, drilling mud, nitrogen, inert gas, diesel, fog, foam or hydrocarbons.
    It is also likely that wellhead cuttings, for example, residues are present in these drilling fluids, which are being removed from, or created by, wellhead advancement or other operations in the well.
    Two-phase fluids and three-phase fluids may be present, which could be mixtures of two or three different types of materials.
    Riser fluids can interfere with the laser beam's ability to cut through the tubular, or other structure to be cut.
    Such fluids may not transmit, or may only partially transmit, the laser beam and therefore interfere with or reduce the power of the laser beam when the laser beam is passed through them.
    If these fluids are flowing, such a flow can further increase your inability to transmit.
    The inability of transmission and partial transmission capacity of these fluids can result from several phenomena, including, without limitation, absorption, refraction and diffusion.
    Furthermore, the inability to transmit and the partial transmission capacity can be, and will probably be dependent on, the wavelength of the laser beam.
    Depending on the configuration of the laser cutters, the riser and the BOP package, the laser beam could be required to pass through approximately 8 inches of riser fluids.
    In other configurations, laser cutters can be positioned in close or close proximity to the structure to be cut and moved so that this close proximity is maintained.
    In these configurations, the distance for the laser beam to travel between the laser cutters and the structure to be cut can be maintained between about 5.08 cm (2 inches), less than about 5.08 cm (2 inches) ), less than about 2.54 cm (1 inch) and less than about 1.27 cm (0.5 inch), and kept in ranges of less than about 7.62 cm (3 inches) at less than about 1.27 cm (0.5 inch), and less than about 5.08 cm (2 inches) unless about 1.27 cm (0.5 inch). In particular, for those configurations and modalities where the laser has a relatively long distance to travel, for example, greater than about 2.54 cm (1 inch) or 5.08 cm (2 inches) (although this distance could be greater or lesser, depending on the laser power, wavelength and type of drilling fluid, as well as other factors) it is advantageous to minimize the harmful effects of such riser fluids and substantially guarantee, or guarantee that such fluids do not interfere with the transmission of the laser beam, or that sufficient laser power is used to overcome any losses that may occur from the transmission of the laser beam through such fluids.
    For this purpose, mechanical pressure and jet-type systems can be used to reduce, minimize or substantially eliminate the effect of fluid perforation in the laser beam.
    For example, mechanical devices can be used to insulate the area where the laser cutting is to be performed and the riser fluid removed from that isolation area, for example, by inserting an inert gas, or a fluid optically transmissible, such as an oil or diesel fuel.
    The use of a fluid in this configuration has the added advantage that it is essentially incomprehensible.
    In addition, a device similar to a mechanical straw, or tube, that is filled with an optional fluid
    transmissible (gas or liquid) can be extended between, or, if not, placed in an area between the laser cutter and the structure to be cut.
    In this way, the laser beam is transmitted through the straw or tube to the structure. 5 A high pressure gas jet can be used with the laser cutter and the laser beam.
    The high pressure gas jet can be used to clear a path, or partial path of the laser beam.
    The gas can be inert or it can be air, oxygen or another type of gas that speeds up laser cutting.
    The relatively low amount of oxygen required and the rapid rate at which it would be consumed by burning the tubular through the laser-metal-oxygen interaction, should not present a risk or fire hazard to the drilling rig, surface equipment, personnel or components. submarine components.
    The use of oxygen, air, or the use of high-powered laser beams themselves, for example, greater than about 1 kW could create and maintain a plasma bubble or a gas bubble in the cutting area, which could partially or completely displace the drilling fluid along the laser beam path.
    A high pressure liquid laser jet that has a single liquid current can be used with the laser cutter and laser beam.
    The liquid used for the jet should be transmissive, or at least substantially transmissive, to the laser beam.
    In this type of jet laser beam, the combination of the laser beam can be coaxial with the jet.
    This configuration, however, has the disadvantage and the problem that the fluid jet does not act as a waveguide.
    An additional disadvantage and the problem with this unique jet configuration is that the jet must provide both the force to keep the drilling fluid away from the laser beam and be the medium for beam transmission.
    A laser jet of compound fluid can be used as a laser cutter.
    The jet of compound fluid has an inner core jet that is surrounded by annular outer jets.
    The laser beam is directed by optical elements in the nuclear jet and transmitted by the nuclear jet, which acts as a waveguide.
    A single annular jet can surround the nucleus, or a plurality of nested annular jets can be employed.
    Therefore, the jet of compound fluid has a nuclear jet.
    This nuclear jet is surrounded by a first annular jet.
    This first annular jet 5 can also be surrounded by a second annular jet; and the second annular jet can be surrounded by a third annular jet, which can be surrounded by additional annular jets.
    The external annular jets work to protect the internal nuclear jet from the drilling fluid present in the annular space between the laser cutter and the structure to be cut.
    The nuclear jet and the first annular jet should be made of fluids that have different refractive indices.
    In the situation where the compound jet has only one core and an annular jet surrounding the core, the refractive index of the fluid that makes up the core should be greater than the refractive index of the fluid that makes up the annular jet.
    In this way, the difference in refractive indices allows the core of the compound fluid jet to act as a waveguide, maintaining the laser beam contained in the nuclear jet and transmitting the laser beam in the nuclear jet.
    Furthermore, in this configuration, the laser beam does not leave the nuclear jet noticeably dry and enters the annular jet.
    The pressure and speed of the various jets that make up the compound fluid jet may vary, depending on the applications and environment of use.
    Therefore, by way of example, the pressure can range from about 435.11 kPa (3,000 psi), to about 580.15 kPa (4,000 psi) to about 4351.13 kPa (30,000 psi), preferably about 10,152.64 kPa (70,000 psi), at higher pressures.
    The nuclear jet and annular jet (s) can have the same pressure or different pressures, the nuclear jet can have a higher pressure or the annular jets can have a higher pressure.
    Preferably, the nuclear jet has a higher pressure than the annular jet.
    For example, in a multiple jet configuration, the nuclear jet could have 10,152.64 kPa (70,000 psi), the second annular jet (which is positioned adjacent to the core and the third annular jet) could have 8,702.26 kPa ( 60,000 psi) and the third (external, which is positioned adjacent to the second
    of the annular jet and is in contact with the working environment) annular jet could have 7,251.88 kPa (50,000 psi). Jet speeds can be the same or different.
    Therefore, the velocity of the nucleus may be greater than the velocity of the annular jet, the velocity of the annular jet may be greater than the velocity of the nuclear jet, and the velocities of the multiple annular jets may be different or the same.
    The speeds of the nuclear jet and the annular jet can be selected, so that the nuclear jet comes into contact with the drilling fluid, or so that contact is minimized.
    Jet speeds can vary from relatively low to very high and, preferably, in the range of about 1 m / s (meters / second) to about 50 m / s, about 200 m / s, at about 300 m / s and higher.
    The order in which the jets are first formed can be the first nuclear jet, followed by the annular rings, the first annular ring jet following the nucleus, or the nuclear jet and the annular ring formed simultaneously.
    To minimize or eliminate the interaction of the core with the drilling fluid, the annular jet is created first followed by the nuclear jet.
    When selecting the fluids to form the jets and when determining the amount of difference in the refractive indices for the fluids, the laser beam wavelength and the laser beam power are factors that should be considered.
    So, for example, for a high-powered laser beam that has a wavelength in the range of 1,080 nm (nanometer), the nuclear jet can be made from an oil that has a refractive index of about 1.53 and the annular jet can be made of a mixture of oil and water that has a refractive index of about 1.33 to about 1.525. Therefore, the nuclear jet for this configuration would have an NA (numerical opening) of about 0.95 to about 0.12, respectively.
    Further details, descriptions and examples of such a compound fluid laser jet are contained in Zediker et. al, Provisional Patent Application Serial No. U.S. 61 / 378,910, entitled Waveguide Laser Jet and Methods of Use, filed on August 31, 2010, the description of which is incorporated herein in its entirety for reference.
    It should also be noted that said incorporation as a reference does not provide any right to practice or use the information
    said application or any patents that may be issued thereafter and does not grant or set a precedent for any licenses under them.
    In addition to the use of high power laser beams to cut the 5 tubes, other forms of directed energy or means to supply them can be used in the BOP set.
    Such directed energy means that it would include plasma cutters, arc cutters, high-powered water jets, water particle jets.
    Each of these media, however, has disadvantages when compared to high power laser energy.
    In particular, high power laser energy has greater control, reliability and is substantially potentially less harmful to the components of the BOP system than these other means.
    Still, the use of these other less desirable means is contemplated in the present document by the present inventions as a means of directed energy to cut tubulars in a BOP cavity.
    The angle at which the laser beam comes into contact with the structure to be cut can be determined by the optical elements in the laser cutter or it can be determined by the angle or position of the laser cutter itself.
    Various angles that are advantageous to or based on the configuration of the riser, external pipe, coupling or combinations thereof can be used.
    The number of laser cutters used in a configuration of the present inventions can be a single cutter, two cutters, three cutters, up to and including 12 or more cutters.
    As discussed above, the number of cutters depends on several factors and the optimum number of cutters for any particular configuration and end use can be determined based on the requirements for end use and the descriptions and teachings provided in this specification. .
    The cutters can also be additionally positioned so that their respective laser beam paths are parallel, or at least do not intersect with the central geometric axis of the riser.
    Examples of laser power, creep and cut rates, based on published data, are shown in Table I.
    Table I Type Thickness Power Size Creep Gas Rate (mm) of the laser point of the cut laser (watts) (microns) (MW / cc²) (m / min) Mild steel 15 5,000 300 7.1 O2 1.8 Stainless steel 15 5,000 300 7.1 N2 1.6
    Laser cutters have a discharge end from which the laser beam is propagated.
    Laser cutters also have a 5 beam path.
    The beam path is defined by the path that the laser beam is intended to take, and extends from the discharge end of the laser cutter to the material or area to be cut.
    The angle at which the laser beam comes into contact with a tubular can be determined by the optical elements in the laser cutter or it can be determined by the angle or position of the laser cutter itself.
    Figure 22 shows a schematic representation of a 2200 laser cutter with a beam path 2201 that exits the cutter at various angles.
    When fired or launched from the laser cutter, a laser beam would travel along a beam path.
    The beam path is additionally shown in relation to the BOP cavity or a vertical geometric axis of the riser cavity (dashed line) 2211. As seen in the enlarged views of Figures 22A and 22B, the angle that the beam path 2201 forms with the vertical geometric axis 2211, and therefore the angle that a laser beam that travels along that beam path forms with the vertical geometric axis 2211, can be an acute angle 2205 or an obtuse angle 2206 in relation to the portion of the 2211 geometry axis furthest from the 2210 wellhead connection side. A normal or 90 ° angle can also be used.
    The BOP 2210 wellhead connection side is shown in the Figures as a reference point for the angle determinations used in this document.
    The angle between the beam path (and a laser beam that runs along that beam path) and the vertical or BOP or riser geometric axis corresponds, in general, to the angle at which the beam path and the laser beam will reach a tubular that is present in the BOP or riser cavity.
    However, the use of a reference point that is based on the BOP or riser to determine the determine angle is preferred, because tubulars can move or, in the case of joints, or a damaged tubular, present a surface that has varied planes that are not parallel to the central geometric axis of the BOP cavity; similarly, the riser will rarely be straight and may have folds or movements in it.
    As the angle formed between the laser beam and the vertical geometric axis can vary and be predetermined, the position of the laser cutter, or, more specifically, the point at which the laser beam leaves the cutter, does not necessarily have to be normal in relation to the area to be cut.
    Therefore, the position of the laser cutter or the beam launch angle can be such that the laser beam travels from: above the area to be cut, which could result in an acute angle being formed between the laser beam and the vertical geometric axis; the same level as the area to be cut, which would result in an angle of 90 ° being formed between the laser beam and the vertical geometric axis; or below the area to be cut, which would result in an obtuse angle being formed between the laser beam and the vertical geometric axis cavity.
    In this way, the relationship between the shape of the drawers, the surfaces of the drawers, the forces that the drawers exert, and the location of the area to be cut by the laser can be evaluated and refined to optimize the relationship of these factors for a particular application.
    The flexible support cables for laser cutters provide the laser energy and other materials that are needed to carry out the cutting operation.
    Although shown as a single cable for each laser cutter, multiple cables could easily be used.
    So, for example, in the case of a laser cutter that employs a composite fluid laser jet, the flexible support cable would include a high power optical fiber, a first line for the nuclear jet fluid and a second line for the fluid from the annular jet.
    These lines could be combined into a single cable or can be kept separate.
    Additionally, for example, if a laser cutter that uses an oxygen jet is used
    the cutter would need a high-powered fiber optic and an oxygen line. These lines could be combined into a single cable or could be kept separate, like multiple cables. The lines and optical fibers should be covered in flexible protective covers or external housings to protect them from riser fluids, the underwater environment and the movement of laser cutters, while at the same time remaining flexible enough to accommodate the orbital movement of laser cutters. As the support cables next to the power supply assembly for flexibility decrease, more rigid means to protect it can be used. For example, the optical fiber can be placed in a metal tube. The duct that leaves the foot through the assembly adds additional protection to the support cables, during the assembly of the laser module and the riser, against the handling of the riser or module, positioning of the riser, and underwater environmental conditions. It is preferable that the supply assemblies, conduits, support cables, laser cutters and other subsea components associated with the operation of the laser cutters, are made to meet the pressure requirements for the intended use. Components related to the laser cutter, if they do not meet the pressure requirements for a particular use, or if redundant protection is desired, can be contained in or covered by a structure that does not meet the requirements. For deep and ultra-deep waters, components related to the laser cutter should preferably be able to operate under pressure of
    13,789.51 kPa (2,000 psi), 31,026.40 kPa (4,500 psi), 34,473.78 kPa (5,000 psi) or more. The materials, adjustments and assemblies useful to meet these pressure requirements are known to those of ordinary skill in the marine drilling technique, related technique of underwater remotely operated vehicle ("ROV") and in the high power laser technique. The laser cutters that are used in the laser systems of the present invention can be incorporated into laser shear drawers, laser shear modules and laser riser modules. These devices and other configurations that use direct power cutters
    laser-cutters such as laser cutters in association with a riser and BOP components are provided in patent applications for serial numbers US 13 / 034,175, 13 / 034,183 and 13 / 034,017, each filed on February 24, 2011, and the descriptions of each of these patent applications 5 are here incorporated in their entirety as a reference.
    Going back to Figure 2, an example of a laser shear drawer assembly model that could be used in a BOP set is shown.
    The laser shear drawer assembly 200 has a body 201. Body 201 has a lower shear drawer 202, (closer to the wellhead) and an upper shear drawer 203 which, upon activation, are forced into the inner cavity 204 by the lower piston assembly 205 and the upper piston assembly 206. Upon activation, the combination surfaces 207, 208 of the shear drawers 202, 203 engage with each other and seal the internal cavity 204 therefore, the well.
    The internal cavity 204 has an internal cavity wall 227. A laser delivery assembly 209 is also provided. The laser delivery assembly 209 is located on body 201 of the laser shear drawer assembly 200. A laser delivery assembly 209 can be, for example, an annular assembly that surrounds, or partially surrounds, the internal cavity 204. This assembly 209 is located above the shear drawers 202, 203, that is, the side furthest from the wellhead.
    The laser delivery assembly 209 is optically associated with at least one high power laser source.
    During drilling and other activities, tubulars, not shown in Figure 2, are typically positioned in inner cavity 204. An annular space is formed between the outer diameter of the tubular and the inner cavity wall 227. These tubulars have a diameter external which can vary in size from about 120.32 cm (8 inches) to a few inches and, in particular, can typically range from about 40.74 cm (16.04 inches) to about 12.7 cm (5 inches) or smaller.
    When the pipes
    are present in cavity 204, by activating the laser shear drawer assembly 200, the laser delivery assembly 209 delivers high power laser energy to the tubular located in the cavity
    204. High power laser energy cuts the tubular completely, or to a minimum that structurally weakens the tubular, to allow the shear drawers 202, 203 to quickly seal cavity 204, moving any remaining tubular sections out from the path of the shear drawers if the tubular is completely broken by laser energy, or break the tubular if only weakened by the laser and move the sections of tubular out of the path of the shear drawers. Therefore, the laser shear drawer 200 assembly ensures that the surface of the shear drawers 207, 208 engages, seals and therefore seals the BOP 204 cavity and the well. Although a single laser delivery assembly is shown in the example of Figure 2, multiple laser delivery assemblies, assemblies of different shapes and assemblies in different positions can be employed. In addition, configurations in which the laser delivery assembly is located below the shear drawers, that is, the side closest to the wellhead, as well as configurations in which the laser delivery assemblies are located above , below, in, or combinations of, the shear drawers, or other sections or modules of the BOP set can also be employed. The ability of laser energy to cut, remove, or substantially weaken the tubular in the internal cavity allows for the potential use of a single shear drawer, in which two shear drawers may otherwise be ordered or necessary, thus reducing the number of moving parts, reducing the weight of the BOP, reducing the height of the BOP and reducing the footprint of the deck for the BOP, as well as other benefits, in general assembly. In addition, the ability to produce precise, predetermined laser energy delivery patterns for tubulars and the ability to produce accurate, predetermined cuts in and through tubulars, provides the ability for the shear drawer to cut and match surfaces - tion configured to combine, complement or otherwise work more efficiently with the laser energy delivery pattern.
    Therefore, the combined or custom made shear drawer configurations for the laser energy delivery pattern are contemplated by the present inventions.
    Furthermore, the ability to produce precise, predetermined cuts in and through tubulars provides the ability, even in an emergency situation, to break the tubular without crushing it and to have a predetermined shape for the broken end of the tubular to aid in posterior fixation of a fishing tool to recover the broken tubular from the well hole.
    In addition, the ability to rupture the tubular, without crushing it, provides a larger area, that is, a larger opening, in the lower section of the ruptured tubular through which drilling mud, or other fluid, can be pumped into the interior of the cavity by the kill line associated with the BOP set.
    The body of the laser shear drawer assembly can have a single piece that is machined to accommodate the laser delivery assembly or it can be made of multiple pieces that are fastened together in a way that provides enough strength for its intended use and , in particular, to withstand pressures of 34,473.78 kPa (5,000 psi), 68,947.57 kPa (10,000 psi), 103,421.35 kPa (15,000 psi), 137,895.14 kPa (20,000 psi), and greater.
    The body area that contains the laser delivery assembly can be machined or otherwise manufactured to accommodate the laser delivery assembly, while maintaining the strength requirements for the intended use of the body.
    The body of the laser shear drawer assembly can also be two or more separate components or modules, for example, one component or module for the laser delivery assembly and another for the shear drawers.
    These modules could be fastened to each other by, for example, bolted flanges, or other suitable fastening means known to those skilled in the marine drilling technique.
    The body, or a module that makes up the body, can have a passage, passages, channels, or other such structures to transport
    fiber optics for transmitting the laser beam from the laser source into the body and for the laser delivery assembly, as well as other cables that refer to the operation or monitoring of the laser delivery assembly and its operation cut. 5 In Figure 3A is shown an example of a modality of a laser shear drawer assembly that could be used in a laser-assisted BOP.
    Therefore, a laser shear drawer assembly 300 is shown which has a body 301. The body has a cavity 304, the cavity having a central geometric axis 311 (dashed line) and a wall 341. The BOP cavity also it has a vertical geometric axis and, in this modality, the vertical geometric axis and the central geometric axis are the same, which is, in general, the case for BOPs. (The names of these geometrical axes are based on the BOP configuration and are relative to the BOP structures themselves, not the position of the BOP in relation to the earth's surface.
    Therefore, the vertical geometric axis of the BOP will not change if the BOP, for example, is lying on its side). Typically, the central geometric axis of the well 311 is on the same geometric axis as the central geometric axis of the wellhead cavity or opening through which the tubulars are inserted into the wellbore.
    The body 301 contains and supports the lower shear drawer 302 and the upper shear drawer 303, the drawers having piston assemblies 305 and 306 associated with them.
    In operation, piston assemblies 305, 306 drive the drawers 302, 303 towards the central geometrical axis 311, engaging, cutting and moving through the tube 312, and sealing the cavity 304, and thus, the well.
    The body 301 also has a feed assembly 313 to manage pressure and allow fiber optic cables and other cables, tubes, wires and transmission media, which may be required for the operation of the laser cutter, to be inserted into the body 301. The body houses an upper laser delivery assembly 309 and a lower laser delivery assembly 310. Returning to Figure 3B, a more detailed illustration of the combination surfaces of the shear drawer 308, 307 of the modality is shown shown in Figure 3A.
    Therefore, the combination surfaces 308 of the upper shear drawer 303 have a top surface 322, a bottom surface 323, a face 321, a leading edge 319, the edge being between the bottom surface 323 and the face 321, and a rear edge 320, the edge being between the upper surface 322 and the face 321. The combination surfaces 307 of the lower shear drawer 302 have an upper surface 317, a lower surface 318, a face 316, a leading edge 314, the edge being between the upper surface 317 and the face 316, and a trailing edge 315, the edge being between the face 316 and the bottom surface 318. Figures 4A to 4D are cross-sectional views of the mode shown in Figures 3A and 3B taken along line 4-4 of Figure 3A and show the sequence of operation of the laser shearing drawer 300 when cutting the tubular 312 and sealing the cavity 304. In Figures 4A to 4D it is also shown with more details of the upper laser delivery assembly 309 than the laser drawer assembly 300. In this embodiment, the lower laser assembly 310 could have components and configurations similar to those of the upper laser delivery assembly 309. However , the lower laser assembly 310 could have different configurations and more or less laser cutters.
    The laser delivery assembly 309 has four laser cutters 326, 327, 328 and 329. Flexible support cables are associated with each of the laser cutters.
    Therefore, the flexible support cable 331 is associated with the laser cutter 326, the flexible support cable 332 is associated with the laser cutter 327, the flexible support cable 333 is associated with the laser cutter 328, and the flexible support cable 330 is associated with the laser cutter 329. The flexible support cables are located in channel 339 and enter a feed assembly 313. In the general area of the feed assembly 313, the support cables carry transition from flexible to semi-flexible and can additionally be included in conduit 338 for transmission to a high-powered laser, or other material sources for the cutting operation.
    Flexible support cables
    330, 331, 332 and 333 have extra or additional length, which accommodate the orbit of the laser cutters 326, 327, 328 and 329 around the geometric axis 311 and around the tubular 312. Figures 4A to 4D show the sequence of activation of the laser shear drawer assembly 5 to break a tubular 312 and seal the cavity 304. In this example, the first view (for example, a frozen image, since the sequence is preferably continuous instead of stopping or in stages) of the sequence is shown in Figure 4A.
    Activated, the four laser cutters 326, 327, 328 and 329 fire laser beams 334, 335, 336 and 337, respectively.
    The beams are directed towards the central geometric axis 311. Thus, the beams are fired from inside the BOP, from outside the cavity wall 327, and travel towards the central geometric axis of the BOP.
    The laser beams reach the tubular 312 and begin to cut, that is, remove material from the tubular 312. If the cavity 304 is viewed as the face of a watch, the laser cutters 326, 327, 328 and 329 could be viewed as being positioned, initially, in 12 hours, 9 hours, 6 hours and 3 hours, respectively.
    Upon activation, the laser cutters and their respective laser beams begin to orbit around the central geometric axis 311 and the tubular 312. (In this configuration, the laser cutters would also rotate about their own geometric axes. as they orbit and therefore if they moved through a full orbit, they would also have moved through a full rotation). In the present example, the cutters and bundles orbit in a counterclockwise direction, as shown in the figures; however, a clockwise rotation can also be used.
    As the laser beams are fired and orbit occurs, the shear drawers 303, 302 are triggered towards each other and towards the tubular 312. Therefore, as seen in the next view of the sequence, Figure 4B, the laser cutters, 326, 327, 328 and 329 rotated 45 degrees, with laser beams that travel along the beam path 334,335, 336 and 337 that cut through four 1/8 sections (that is, a total of half)
    of the circumference of the tubular 312. Figure 4C then shows the cutter having moved through a quarter turn.
    Therefore, in Figure 4C, laser cutters 326, 327, 328 and 329 rotated a quarter turn, with laser beams 334, 335, 336 and 337 cutting through tubular 312. Therefore, cutter 326 they could be seen as having moved from the 12 o'clock position to the 9 o'clock position, with the other cutters similarly changing their respective clock face positions.
    The upper surface 322, the rear edge 320, the face 321 and the front edge 319 of the upper drawer and the upper surface 317 and the front edge 314 of the lower drawer are further shown as they approach and engage the tubular 312 and the area where the laser beams cut through the tubular.
    Figure 4D then shows the last view of the sequence with the laser cutters that have been deactivated and are no longer firing their laser beams and shear drawers in sealing engagement.
    Cavity 304 is completely filled and blocked by the shear drawers 303, 302. In Figure 4C, only the upper surface 322, the rear edge 320 and the front edge 319 of the upper drawer 303 and a portion of the upper surface are seen 317 of the lower drawer 302, the other portions of the upper surface 317 being in engagement with the lower surface 323 of the drawer 302. During the cutting operation and, in particular, for circular cuts that are intended to break the tubular, it is preferable that the tubular does not move in a vertical direction.
    Therefore, on or before the laser cutters are triggered, the tube drawers, the annular preventer or a separate support device should be activated to prevent vertical movement of the barrel during the laser cutting operation.
    The rate of orbital movement of laser cutters depends on the number of cutters used, the power of the laser beam when it reaches the surface of the tubular to be cut, the thickness of the tubular to be cut, and the rate at which the laser cuts the tubular .
    The rate of orbital movement should be slow enough to ensure that intentional cuts can be completed.
    The orbital movement of the laser cutters can be carried out by
    mechanical, hydraulic and electromechanical topics known in the art.
    The use of the term "completed" cut and such similar terms includes breaking the object to be cut into two sections, for example, a cut that goes up to the wall and around the entire circumference of the tubular, as well as cuts with the which enough material is removed from the tubular to sufficiently weaken the object to ensure it separates as intended.
    Depending on the particular configuration of the laser cutters, the riser and the BOP and their intended use, a complete cut could be, for example: breaking a tubular into two separate sections; removing a ring of material around the outer portion of the tubular, from about 10% to about 90% of the wall thickness; a number of perforations created in the wall, but which do not extend through the wall of the tubular; a number of perforations that completely cross the tubular wall; a number of cracks created in the wall, but which do not extend through the wall of the tubular; a number of slits that completely cross the wall of the tubular; the material removed by shooting patterns or laser cutter positions presented in this patent application and incorporated as a reference in co-filed applications; or other material removal patterns and combinations of the above.
    It is preferable that the complete cut is done in less than a minute and, more preferably, the complete cut is done in 30 seconds or less.
    The rate of orbital movement can be set at the rate needed to complete a cut for the most extreme tubular or tubular combination or the rate of rotation could be variable or predetermined to match the particular tubular, or tubular types, that will be present on the BOP during a particular drilling operation.
    The greater the number of laser cutters in a rotating laser delivery assembly, the slower the rate of orbital movement can be to complete a cut in the same amount of time.
    In addition, increasing the number of laser cutters shortens the time to complete a tubular cut, without having to increase the orbital rate.
    Increasing the power of the laser beams will allow the tubulars to be cut faster and,
    thus, allowing faster rates of orbit, less laser cutters, shorter time to complete a cut or combinations thereof.
    Variable drawer preventers could be used in conjunction with oxygen (or air) and laser cutters.
    Therefore, a single variable drawer could be used to catch a seal against a tubular in the BOP cavity.
    The variable drawer would form a small cavity in the drawers when engaged against the tubular, the cavity surrounding the tubular.
    This cavity could then have its pressure reduced to or almost atmospheric when ventilating the cavity.
    Oxygen, or air, (or other transmitting gases or liquids) could be added to the cavity before laser cutters, which could be contained in the drawers, are released.
    In this way, the variable drawers would have laser cutters in them, would form an insulation cavity when attached to a tubular, and would provide a means to quickly cut the tubular with minimal interference from fluids.
    Two variable drawers, one above the other, can also be used if a larger insulation cavity is desirable or if additional space is required for laser cutters.
    Furthermore, although the cavity could be vented to or about atmospheric pressure, increased pressure can be maintained, for example, to reduce or slow down the inflow of any drilling fluid from within the tubular as it is being cut.
    Figure 5 shows an example of a laser drawer assembly modality that could be used in a laser-assisted BOP.
    Thus, a laser shear drawer assembly 500 having a body 501 is shown. The body has a cavity 504, the cavity having a central geometrical axis 511. The body 501 also has a feed assembly 513 for managing pressure and allow fiber optic cables and other cables, tubes, wires and transmission means, which may be necessary for the operation of the laser cutter, to be inserted into the body 501. Drawer piston assemblies 505, 506, which are partly shown in this Figure, they are associated with the body 501. The body houses a laser delivery assembly 509. The laser delivery assembly 509 has eight laser cutters 540, 541, 542, 543, 544, 545, 546 and 547. Flexible support cables are associated with each of the laser cutters. The flexible support cables are long enough to accommodate the laser cutters' orbit 5 over the central geometric axis 511. In this mode, cutters only need to travel 1/8 of a complete orbit to obtain a cut around of the entire circumference of a tubular. The flexible support cables are located in a channel and enter the 513 feed assembly. The feed assembly is pressure rated to the same level as the BOP and therefore should be able to withstand pressures of 34,473.78 kPa (5,000 psi),
    68,947.57 kPa (10,000 psi), 103,421.35 kPa (15,000 psi), 137,895.14 kPa (20,000 psi) and greater. In the general area of the 513 power supply assembly, the support cables transition from flexible to semi-flexible and can also be included in conduit 538 for transmission to a high-power laser or other sources. A 570 shield was also provided. This 570 shield protects laser cutters and laser delivery assembly from drilling fluids and tubular movement through the BOP cavity. It is preferably positioned so that it does not extend into or otherwise interfere with the BOP cavity or the movement of the tubulars through that cavity. It is preferably classified by pressure at the same level as the other components of BOP. Upon activation, it may be mechanically or hydraulically away from the laser beam path or the laser beam can propagate through it, cutting and removing any shield material that would initially obstruct the laser beam. Upon activation, laser cutters propagate laser beams (which can also be referred to as firing the laser or firing the laser to create a laser beam) from outside the BOP cavity into that cavity and in towards any tubular that may be in that cavity. Therefore, there are laser beam trajectories 580, 581, 582, 583, 584, 585, 586, and 587, and the trajectories revolve around the central geometric axis
    511 during operation. In general, the operation of a laser-assisted BOP array in which at least one laser beam is directed towards the center of the BOP and at least one laser cutter is configured to orbit (partially or 5 completely) around the center of the BOP to obtain circumferential cuts, that is, cuts around the circumference of a tubular (including slits such as cuts that extend partially around the circumference, cuts that extend completely around the circumference, cuts that cross partially the thickness of the tubular wall, cut that completely crosses the thickness of the tubular wall or combinations of the above) can occur as follows. Upon activation, the laser cutter fires a laser beam towards the tubular to be cut. Within a period of time after the laser beam is first released, the cutter begins to move, orbiting around the tubular, and therefore the laser beam is moved around the circumference of the tubular, cutting the material of the tubular. The laser beam will stop firing at the point where the cut in the tubular is complete. At some previous point, during or after firing the laser beam, the drawer shears are activated, breaking, displacing, or both, any tubular material that may still be in its path path, and sealing the BOP cavity and the well. Figure 6 shows an example of a laser drawer assembly modality that has laser cutters attached, for use in a BOP-assisted BOP. Therefore, a laser shear drawer assembly 600 that has a body 601 is shown. The body has a cavity 604, the cavity having a central geometric axis
    611. The body 601 also has a feed assembly 613 to manage pressure and allow fiber optic cables and other cables, tubes, wires and transmission media, which may be required for the operation of the laser cutter, to be inserted on the body 601. The piston assemblies 605, 606, which are partially shown in this Figure, are associated with the body 601. The body houses a 609 laser delivery assembly. The 609 laser delivery assembly has eight laser cutters 640, 641, 642,
    643, 644, 645, 646 and 647. In this mode, the cutters do not orbit or move. The cutters are configured so that their beam paths (not shown) are radially distributed around and through the central geometric axis 611. The support cables 650, 651, 652, 653, 654, 5 655, 656 and 657 are associated with each of the 640, 641, 642, 643, 644, 645, 646 and 647 laser cutters, respectively. Support cables in this mode do not need to accommodate the orbit of the laser cutters around the central axis 611, because the laser cutters are fixed and do not orbit. Furthermore, because the laser cutters are fixed, the support cables 650, 651, 652, 653, 654, 655, 656 and 657 can be semi-flexible or grooved and the entire assembly 609 can be contained in an epoxy from another protective material. The support cables are located in a channel and enter the 613 feed assembly. The feed assembly is pressure rated at the same level as the BOP and therefore should be able to withstand pressures of 34,473.78 kPa ( 5,000 psi), 68,947.57 kPa (10,000 psi), 103,421.35 kPa (15,000 psi), 137,895.14 kPa (20,000 psi) and greater. In the general area of the 613 power supply assembly, the transition from support cables from flexible to semi-flexible and can also be included in conduit 638 for transmission to a high-powered laser, or other sources. A shield, like the 570 shield in Figure 5, can also be used with this and other modalities, but it is not shown in this Figure. Although eight evenly spaced laser cutters are shown in the example of a fixed laser cutter modality in Figure 6, other configurations are contemplated. Less or more clean cutters can be used. The cutters can be positioned so that their respective laser beam paths are parallel, or at least do not cross within the BOP, instead of crossing radially with each other, as may be the case for the modality shown in the Figure
    6. Going back to Figure 7, an example of a modality of a laser shear drawer set that can be used in a laser assisted BOP is shown. The laser shear drawer assembly 700 has a body 701. Body 701 has a lower shear drawer 702, (closer to the wellhead) and an upper shear drawer 703 which at activation are forced into the internal cavity 704 5 through the lower piston assembly 705 and the upper piston assembly
    706. Laser delivery sets 741, 742 are also provided. Laser delivery sets 741, 742 are located in drawers 702, 703 respectively. The laser delivery assemblies 741, 742 have flexible support cables 745, 746 respectively, which run through the passage assemblies 743, 744 respectively, in the respective conduits 747, 748, conduits that are optically associated with at least one laser source of High power. Passage assemblies as well as all locations where the flexible support cable passes through must be classified by pressure to meet the BOP requirements and specifically the pressure requirements associated with the structures through which the cable is passed. Sufficient lengths of flexible support cables 745, 746 are provided to accommodate the movement of shear drawers 702, 703 and piston assemblies 705,706. During drilling and other activities, tubulars, not shown in Figure 7, are typically positioned inside the internal cavity
    704. When tubulars are present in cavity 704, upon activation of the laser shear drawer assembly 700, laser delivery sets 741, 742 emit high power laser energy to the tubular located in cavity 704. The laser energy high power cuts the tubular completely, or at least weakens the tubular, to allow the shear struts 702, 703 to quickly block cavity 704, moving the tubular sections out of the way of the shear drawers if cut completely by laser energy, or by cutting the tubular if only weakened by the laser and moving the tubular sections out of the way of the shear drawers and thereby ensuring that the surface shear dips 707, 708 engage , seal and thereby block the BOP 704 cavity and well.
    Having the laser delivery sets in the drawers, such as laser delivery sets 741, 742 of the embodiment seen in Figure 7, the distance of the laser beam path through any drilling fluids can be extremely reduced if not eliminated . Consequently, the firing of the laser beam can be delayed until the drawers are very close, or touching, the tubular to be cut. The shields for laser cutters or laser delivery sets can also be used with laser drawer configurations, such as the mode shown in Figure 7, where cutters or sets are located in the drawers. Consequently, such shields can be associated with the drawer faces and removed on activation or cut by the laser beam. Returning to Figure 8, an example of a modality of a laser shear drawer set that can be used in a laser assisted BOP is shown. The laser shear drawer assembly 800 has a body 801. Body 801 has a lower shear drawer 802, (closer to the wellhead) and an upper shear drawer 803 which at activation are forced into the internal cavity 804 through the lower piston assembly 805 and the upper piston assembly
    806. Laser delivery kits 841, 842, 850,
    852. Laser delivery sets 841, 850 are located in the drawer
    802. Laser delivery sets 842, 852 are located in the drawer
    803. The laser delivery sets 841, 842, 850, 852 have flexible support cables 845, 846, 851, 853 respectively, which run through the passage assemblies 743 (cables 845, 851), 844 (cables 846, 853), for the respective conduits 847, 848, conduits that are optically associated with at least one high power laser source. Passage assemblies, as well as all locations where the flexible support cable passes through, must be pressure classified to meet the BOP requirements and specifically the pressure requirements associated with the structures through which the cable it is past. Sufficient lengths of the flexible support cables 845, 746, 851, 853 are provided to accommodate the movement of the shear drawers 802, 803 and the plate assemblies 805, 806. During drilling and other activities, tubulars are not shown in Figure 8, are typically positioned inside the internal cavity 5 804. When the tubulars are present in cavity 804, when activating the laser shear drawer set 800, the laser delivery sets 841, 842, 850, 852 emit high power laser energy to the tubular located in cavity 804. High power laser energy cuts the tubular completely, or at least weakens the tubular, to allow the 802, 803 shear drawers to quickly block the cavity 804, moving the tubular sections out of the way of the shear drawers if completely cut by laser energy, or cutting the tubular if only weakened by the laser and moving the tubular sections out the path of the shear drawers and thereby ensuring that the shear drawers engage, seal and thereby block the BOP 804 cavity and the well.
    Returning to Figure 9, an example of a modality of a laser shear drawer set that can be used in a laser assisted BOP is shown.
    The laser shear drawer assembly 900 has a body 901. Body 901 has a lower shear drawer 902, (closer to the wellhead) and an upper shear drawer 903 which at activation are forced into the internal cavity 904 through the lower piston assembly 905 and the upper piston assembly 906. Laser delivery assemblies 941, 942 and 909 are also provided. Laser delivery assemblies 941, 942 are located at gave- 902, 903. The laser delivery set 909 is located on the body 901. The laser delivery sets 941, 942 have flexible support cables 945, 946 respectively, which run through the passage sets 943, 944, to the respective conduits 947, 948, conduits that are optically associated with at least one high power laser source.
    The 909 laser assembly has flexible support cables and a passage assembly associated with it, but which are not shown in the Figure.
    The con-
    next to laser 909 can be of any type of laser set shown or taught for use on the body by, in this specification, such as, for example, the sets in the modalities shown in Figures 4A, 5 or 6. The sets Passage, as well as all places where the flexible support cable 5 passes, must be classified by pressure to fulfill the BOP requirements and specifically the pressure requirements associated with the structures through which the cable is passed.
    Sufficient lengths of flexible support cables 945, 946 are provided to accommodate the movement of shear drawers 902, 903 and piston assemblies 905, 906. During drilling and other activities, tubulars are typically positioned within internal cavity 904. When tubulars are present in cavity 904, when activating the 900 laser shear drawer assembly, the laser delivery sets 941, 942, 909 emit high power laser energy to the tubular located in cavity 904. High power laser energy cuts through the tubular completely, or at the very least weakens the tubular, to allow the shear drawers 902, 903 to quickly block cavity 904, moving the tubular sections out of the way of shear drawers if completely cut by laser energy, or by cutting the tubular if only weakened by the laser and moving the tubular sections out of the way of the shear drawers and thereby ensuring that the shear drawers engage, seal and thereby block the BOP 904 cavity and well.
    Figures 10A-C, 11A-C, 12A-C, 13A-C, 14 and 15 show illustrative examples of laser cutter configurations for laser sets in shear drawers.
    Although some of these Figures can be seen as an upper drawer and in some of these Figures the lower and upper drawers are designated, these Figures and their teachings are applicable to lower and upper drawers, and various locations in those drawers, such as as, for example, the locations of sets 850 and 841 of the modality shown in Figure 8. In addition, smaller or larger numbers of laser cutters can be used, the locations of the cutters can be varied, the position of the cutters can be dis- - distributed evenly or non-uniformly across the face of the drawer, and other variations of laser cutter placement can be employed. 5 In addition, these drawers or laser cutters may also have shields associated with them, to protect cutters from tubular and well-hole fluids.
    Figures 14 and 15 also provide examples of the various shapes that the contact surfaces of a shear drawer can employ.
    The laser shear drawers of the present invention can use any contact surface shape now known to the art or further developed.
    In Figures 10A to 10C a configuration of laser cutters is shown in a shear drawer, only the main portion of the drawer is shown, for example, the portion intended to engage a tubular.
    Specifically, Figure 10A shows a perspective view of the drawer.
    Figure 10B shows a cross-sectional view taken along line B-B of Figure 10A and Figure 10C shows a vertical cross-sectional view taken along line C-C of Figure 10A.
    The shear of the shear drawer 1090 has a trailing edge 1020, a trailing edge surface 1032, a leading edge 1019, a leading edge surface 1023 and a face surface 1021 positioned between and connecting the leading edge 1019 and the trailing edge 1020. The 1090 shear drawer has 10 laser cutters 1051, 1052, 1053, 1054, 1055, 1056, 1057, 1058, 1059 and 1060. These laser cutters are positioned on the face surface 1021 about 1 / 3 to 1/4 of the path along the face from the main edge 1019, as is generally shown in the Figures.
    Each of the laser cutters 1051, 1052, 1053, 1054, 1055, 1056, 1057, 1058, 1059 and 1060 has a support cable 1061, 1062, 1063, 1064, 1064, 1065, 1066, 1067, 1068, 1069 and 1070 associated with them.
    The laser cutters are also essentially evenly spaced across the face surface 1021. In Figures 11A to 11C a cutter configuration is shown
    laser paints in a shear drawer, only the main portion of the drawer is shown, for example, the portion intended to engage a tubular.
    Specifically, Figure 11A shows a perspective view of the drawer.
    Figure 11B shows a cross-sectional view taken along line B-B of Figure 11A and Figure 11C shows a vertical cross-sectional view taken along line C-C of Figure 11A.
    The shear drawer 1190 has a trailing edge 1120, a trailing edge surface 1132, a leading edge 1119, a leading edge surface 1123 and a face surface 1121 positioned between and connecting leading edge 1119 and trailing edge 1120. The 1190 shear drawer has six laser cutters 1151, 1152, 1153, 1154, 1155 and 1156. These laser cutters are positioned on the face surface 1121 on half of the face closest to the trailing edge 1120, as it is generally represented in the Figures.
    Each of the laser cutters 1151, 1152, 1153, 1154, 1155 and 1156 has a support cable 1161, 1162, 1163, 1164, 1164, 1065 and 1166 associated with it.
    Laser cutters are also essentially spaced evenly across face surface 1121. In Figures 12A to 12C a configuration of laser cutters is shown in a shear drawer, only the main portion of the drawer is shown, for example, the portion intended to engage a tubular.
    Specifically, Figure 12A shows a perspective view of the drawer.
    Figure 12B shows a cross-sectional view taken along line B-B of Figure 12A and Figure 12C shows a vertical cross-sectional view taken along line C-C of Figure 12A.
    The shear drawer 1290 has a trailing edge 1220, a trailing edge surface 1232, a leading edge 1219, a leading edge surface 1223 and a face surface 1221 positioned between and connecting leading edge 1219 and the edge breakout 1220. The shear drawer 1290 has two laser cutters 1251 and 1252. These laser cutters are positioned on face surface 1221 on the half side closest to trailing edge 1220 and adjacent to side surfaces 1280, 1281 , as is generally represented in the Figures.
    Each of the 1251 and 1252 laser cutters has a support cable 1261 and 1262 associated with it. Laser cutters are also essentially evenly spaced across face surface 1221. In Figures 13A to 13C a configuration of laser cutters is shown in a shear drawer, only the main portion of the drawer is shown , for example, the portion intended to engage a tubular. Specifically, Figure 13A shows a perspective view of the drawer. Figure 13B shows a cross-sectional view taken along line B-B of Figure 13A and Figure 13C shows a vertical cross-sectional view taken along line C-C of Figure 13A. The drawer 1390 has a trailing edge 1320, a trailing edge surface 1332, a leading edge 1319, a leading edge surface 1323 and a face surface 1321 positioned between and connecting leading edge 1319 and the trailing edge 1320. The 1390 shear drawer has two laser cutters 1351 and 1352. These laser cutters are positioned on the face surface 1321 in the general area of the midpoint of the face between the trailing edge 1320 and the leading edge 1319, removed from the surfaces lateral 1380, 1381 and adjacent to the midpoint 1383 of the face between the lateral surfaces 1380, 1381 as generally shown in the Figures. Each of the 1351 and 1352 laser cutters has a support cable 1361 and 1362 associated with it. The laser cutters are also essentially spaced evenly across the face surface 1321. In Figure 14, a configuration of cutters to be shown on opposite shear drawers 1402, 1403 is shown, whose drawers are in initial engagement with a tubular 1402. Shear drawer 1403 is the top drawer, having two sides 1481, 1480 and a contact surface
    1408. The shear drawer 1402 is the bottom drawer, having two sides 1483, 1482 and a contact surface 1407. The contact surface 1408 has laser cutters 1451, 1452, 1453, 1454, 1455, 1456 and 1457 associated associated with it. These cutters have support cables associated with them, cables that are not shown in this Figure. The contact surface 1409 has laser cutters 1471, 1472, 1472, 1374, 1475, 1476,
    1477 and 1478 associated with it. These cutters have support cables associated with them, cables that are not shown in this figure. The cutters in the shear drawer 1402 are in a staggered relationship with the cutters in the shear drawer 1403. As such, the beam path that leaves a cutter in the shear drawer 1402, for example, the beam path 1425 of cutter 1455, cannot cross any cutters in shear drawer 1403. Similarly, the beam path that leaves a cutter in shear drawer 1402, for example, beam path 1436 of cutter 1476, cannot cross any cutters in the shear drawer 1402. The laser cutters are essentially spaced evenly across their respective contact surfaces 1408, 1407. In Figure 15, a configuration of cutters to be shown on the opposite shear drawers 1502 is shown , 1503, drawers that are in initial engagement with a tubular 1502. The shear drawer 1503 is the top drawer that has two sides 1581, 1580 and a contact surface
    1508. The shear drawer 1502 is the bottom drawer that has two sides 1583, 1582 and a contact surface 1507. The contact surface 1508 has laser cutters 1551, 1552, 1553, 1554, 1555, 1556, 1557, 1558 and 1559 associated with it. These cutters have support cables associated with them, cables that are not shown in this Figure. Laser cutters are also essentially spaced evenly in relation to each other and are spaced non-uniformly across contact surfaces 1508, 1407, that is, the cutters are spaced in relation to both sides 1581, 1580. The order or firing sequence of the cutter firing to be in the configurations shown in Figures 10A to C, 11A to C, 12A to C, 13A to C, 14 and 15, can be in series, sequentially, simultaneous, from the outside to the inside, from the inside to the outside, from one side to the other, or combinations and variations thereof. Preferably, laser cutters can be fired sequentially with the center cutters firing first and the adjacent cutters firing next.
    Consequently, returning to the configuration shown in Figures 10A to 10C, by way of illustration, the cutters can be fired in pairs with the inner cutters 1055, 1056 being fired first, then cutters 1057, 1054 can then fire, followed by 1058, 1053 etc.
    A high speed beam switch can be employed to control this firing sequence.
    In addition, the laser cutters' firing time should be such that the first cutters cut completely through the tubular wall, for example, they make a hole through the tubular, the next cutters will then fire using or otherwise creating a travel cut front in the tubular.
    Exemplary arrangements and configurations of BOP assemblies that have shear laser modules (SLM) are contemplated.
    For example, pre-existing drawer shears can be replaced with a shear laser module or multiple shear laser modules, a combination of shear drawers and shear laser modules can be added, a drawer set Shear laser can be added, multiple laser modules can be added and combinations of those mentioned above can be made as part of a retrofitting process to obtain a retrofitted laser assisted BOP set.
    In addition, newer and larger BOP sets can also benefit from having a shear laser module added to the set components.
    Going back to Figure 16, an example of a laser assisted BOP set modality is shown.
    Consequently, a laser assisted BOP set 1600 is shown which has, from top 1619 to bottom 1620, a flexible joint 1601 with connectors 1602, 1603, a ring preventer 1604 with connectors 1605, 1606, a shear drawer 1607 with connectors 1608, 1609, a shear laser set 1621 with connectors 1622, 1623 (which has a laser delivery set 1624 shown in phantom lines) and the tube drawer 1613 and the tube drawer 1614 with connectors 1615, 1616 The connectors,
    for example, 1602 can be any type of connector known or used by those skilled in marine drilling techniques, such as, for example, a bolted flange that meets the pressure requirements for the BOP.
    Each of the components, for example, the 5-shear drawer 1607, in the BOP 1600 assembly has an internal cavity, or hole, having a wall, which when mounted on the BOP assembly forms an internal cavity 1617 that has a wall 1618 (shown as the ghost lines in the drawing). In Figure 17, an example of a laser-assisted BOP set is shown.
    Consequently, a laser assisted BOP set 1700 is shown which has, from the top 1719 to the bottom 1720, a flexible joint 1701 with connectors 1702, 1703, an annular preventer 1704 with connectors 1705, 1706, a laser set of shear 1721 with connectors 1722, 1723 (which has a laser delivery set 1724 shown in phantom lines), a shear drawer 1707 with connectors 1708, 1709, a spacer 1710 with connectors 1711, 1712, and tube drawers 1713, 1714 with connectors 1715, 1716. Connectors, for example, 1702 can be any type of connector known or used by those versed in marine drilling techniques, such as, for example, a flange with screws, which fills pressure requirements for the BOP.
    Each of the components, for example, the shear drawer 1707, in the BOP 1700 assembly has an internal cavity or hole, having a wall, which when mounted on the BOP assembly forms an internal cavity 1717 that has a wall 1718 (shown as ghost lines in the drawing). In Figure 18, an example of a laser-assisted BOP set for operations in ultra-deep water of 10,000 feet and above is shown, although this set can also operate and be useful at shallower depths.
    The component listing from the top of the 1801 set to the bottom of the 1815 set, the 1800 laser-assisted BOP set, has a flexible joint 1803, an annular preventer 1804, a shear laser module 1805, an annular preventer 1806 , a 1807 shear laser module, a 1808 shear drawer, a 1809 shear drawer, an 1810 shear laser module, an 1811 spacer, the 1812, 1813 tube drawers and the 1814, 1815 tube drawers Each of these components has holes and when mounted on the set, 5 the holes form a cavity (not shown in this Figure) that extends from the top 1801 to the bottom 1815 of the set.
    The shear laser modules have laser delivery sets (not shown in this figure). The components are connected together with connectors of any type suitable for, and which can meet, marine drilling requirements and, for this particular example, which can meet marine drilling requirements in ultra-deep water.
    Laser-assisted BOP sets can be used to control and manage both pressure and flow in a well; and can be used to manage and control emergency situations, such as a potential outbreak.
    In addition to the shear laser module, laser-assisted BOP assemblies can have an annular preventer.
    The annular preventers can have an expandable seal that seals against a tubular in the BOP cavity preventing material from flowing through the annular formed between the outer diameter of the tubular and the internal cavity wall of the laser assisted BOP.
    In addition to the shear laser, laser-assisted BOP sets can have drawer preventers.
    The drawer preventers can be, for example: tube drawers, which can have two semicircles as fixing devices that are activated against the outside diameter of a tubular that is in the BOP cavity; a blind drawer that can seal the cavity when none of the tubulars are present, or they can be the sets of shear drawers that can cut the tubulars and block the BOP cavity; or they can be the shear laser drawer sets.
    In general, laser shear drawer assemblies use a laser beam to cut or weaken a tubular, including controls, pipe joints and bottom orifice assemblies that may be present in the BOP cavity.
    Going back to Figure 19, an example of a
    of a shear laser module ("SLM") that can be used in a laser assisted BOP set. The SLM 1900 has a body
    1901. The 1901 body has a first 1905 connector and a second connector
    1906. Inner cavity 1904 has an inner cavity wall 1941. 5 A 1909 laser delivery set is also provided. The 1909 laser delivery set is located on body 1901. The 1909 laser delivery set can be, for example, For example, an annular set that surrounds, or partially circles, the internal cavity 1904. This set 1909 is optically associated with at least one high power laser source. Turning to Figure 20, an example of a modality of a shear laser module ("SLM") that can be used in a laser assisted BOP set is shown. The SLM 2000 has a body
    2001. Body 2001 has a first connector 2005 and a second connector
    2006. The internal cavity 2004 has an internal cavity wall 2041. A 2009 laser delivery set is also provided. The 2009 laser delivery set is located on the 2001 body. The 2009 laser delivery set can be, for example , an annular set that surrounds, or partially circles, the internal cavity 2004. This set 2009 is optically associated with at least one high-powered laser source. The modality of Figure 20 additionally contains a shield 2014 for the 2009 laser delivery set. The shield 2014 is positioned inside the body 2001, so that its wall or internal surface 2015 is flush with the cavity wall 2041. In this way, the shield does not form any protrusion or obstruction in the cavity 2004. The shield can protect the 2009 laser delivery set from drilling fluids. The shield can also manage pressure or contribute to pressure management for the 2009 laser delivery set. The shield can additionally protect the 2009 laser delivery set from tubular, such as tubular 2002, as they are transported, inside or outside cavity 2004. The shield can be made of a material, such as steel or another type of metal or other material, that is so robust enough to protect the laser delivery set 2009 as well as easily cut by the laser beam when it is fired towards the tubular 2002. The shield can also be removable from the beam path of the laser beam.
    In this configuration, when activating the 2009 laser delivery set, the shield can be moved away from the beam path.
    In the removable shield configuration, the shield does not have to be cut easily by the laser beam.
    During drilling and other activities, tubulars are typically positioned within the internal BOP cavity.
    An annular is formed between the tubular outer diameter and the inner cavity wall.
    These tubulars have an outside diameter that can vary in size from about 45.720 cm (18 ") to below a few inches and, in particular, typically varies from about 40.74 cm (16 2/5) (16.04) ") weighted at about 12.70 cm (5") or less.
    When tubulars are present in the cavity, upon SLM activation, the laser delivery set delivers high-power laser energy to the tubular located in the cavity.
    The high power laser energy cuts through the tubular completely allowing the tubular to be moved or dropped from the drawers or annular preventers in the set, allowing the BOP to quickly block the internal BOP cavity and thus the well, without any interference from the tubular.
    Although a single laser delivery set is shown in the example of Figures 19 and 20, multiple laser delivery sets, sets of different shapes and sets in different positions can be employed.
    The ability to create predetermined and accurate laser energy delivery patterns for tubulars and the ability to create predetermined and accurate cuts in and through the tubers, provides the ability, even in an emergency situation, to cut the tubular without crushing the same and to have a predetermined shape so that the cut end of the tubular helps in the posterior fixation of a fishing tool to recover the cut tubular from the well hole.
    Furthermore, the ability to cut the tubular, without crushing it, provides a larger area, that is, a larger opening, in the lower section of the tube.
    bular cut through which the drilling mud, or other liquid, can be pumped into the well, through the line of attack associated with the BOP assembly. The SLM body can be a single piece that is machined to accommodate the laser delivery set, or it can be made from multiple pieces that are fastened together in a way that provides sufficient strength for their intended use and , in particular, to withstand pressures of 34,473.78 kPa (5,000 psi), 68,947.57 kPa (10,000 psi),
    103,421.35 kPa (15,000 psi), 137,895.14 kPa (20,000 psi) and higher. The area of the body that contains the laser delivery set can be machine-made or otherwise manufactured to accommodate the laser delivery set, while maintaining the strength requirements for the intended use of the body. The SLM body can also be two or more separate parts or components, for example, one component for the upper half and one for the lower half. These components can be fastened to each other using, for example, bolted flanges or other suitable fastening means known to an individual skilled in marine drilling techniques. The body, or a module that integrates the body, may have a passage, passageways, channels or other such structures, to carry optical fiber cables for the transmission of the laser beam from the laser source to the body and to the assembly laser delivery, as well as other cables related to the operation or monitoring of the laser delivery set and its cutting operation. Returning to Figures 21 and 21A at 21 C, an example of an SLM modality that can be used in a laser assisted BOP set is shown. Consequently, an SLM 2100 is shown which has a body 2101. The body has a cavity 2104, a cavity that has a central geometric axis (dotted line) 2111 and a wall 2141. The BOP 2104 cavity also has a vertical geometric axis and, in this modality, the vertical geometric axis and the central geometric axis 2111 are the same, which is generally the case for BOPs. (The naming of these geometrical axes is based on the configuration of the BOP and is
    it refers to the BOP structures themselves, not the position of the BOP in relation to the Earth's surface.
    Consequently, the vertical geometric axis of the BOP will not change if the BOP, for example, is seated on its side). Typically, the central geometric axis of cavity 2111 is on the same geometrical axis as the central geometric axis of the wellhead opening or cavity through which tubulars are inserted into the wellbore.
    Body 2101 contains laser delivery set 2109. A tubular 2112 is also shown in cavity 2104. Body 2101 also has a 2113 pass-through set to manage pressure and allow fiber optic cables and other cables, tubes, wires and means of transport, which may be necessary for the operation of the laser cutter, to be inserted in the body 2101. The passage assembly 21 13 connects with the conduit 338 for transport to a high-power laser or other sources of materials for the cutting operation.
    Figures 21A to 21C show cross-sectional views of the embodiment shown in Figure 21 taken along line B-B.
    Figures 21A to 21C also show the SLM 2100 operating sequences, when cutting the tubular 2112. In this embodiment, the laser delivery set 2109 has four laser cutters 2126, 2127, 2128 and 2129. The support cables flexible are associated with each of the laser cutters.
    Consequently, the flexible support cable 2131 is associated with the laser cutter 2126, the flexible support cable 2132 is associated with the laser cutter 2127, the flexible support cable 2133 is associated with the laser cutter 2128 and the flexible support cable 2130 is associated with the laser cutter 2129. The flexible support cables are located in channel 2139 and enter the passage set 2113. In the general area of the pass set 2113, the support cables move from flexible for semi-flexible and can be additionally included in the conduit 338 for transport to a high-powered laser or other material sources for cutting operation.
    The flexible support cables 2130, 2131, 2132 and 2133 have extra or additional length, which accommodates the orbit of laser cutters 2126, 2127, 2128 and 2129 around the geometry axis 2111 and around the tubular
    2112. Figures 21A to 21C show the SLM 2100 activation sequence to cut a tubular 2112. In this example, the first view (for example, a snapshot, since the sequence is preferably continuous 5 instead of scaled or graded ) of the sequence is shown in Figure 21A. When activated, the four laser cutters 2126, 2127, 2128 and 2129 propagate (which can also be referred to as firing or firing the laser delivering or emitting a laser beam) laser beams that travel along the beam paths 2150, 2151 , 2152 and 2153. The beam paths 2150, 2151, 2152 and 2153 extend from the laser cutters 2126, 2127, 2128 and 2129 towards the central geometric axis 2111 and thus cross the tubular 2112. The beams are directed towards the central geometric axis 2111. As such, the beams are thrown from inside the BOP, from outside the cavity wall 2141 and travel along their respective beam paths towards the central geometric axis of the BOP. The laser beams strike the tubular 2112 and begin to cut, that is, removing the material from the tubular 2112. If cavity 2104 is seen as the face of a watch, laser cutters 2126, 2127, 2128 and 2129 can be viewed as being initially positioned at 12 o'clock, 9 o'clock, 6 o'clock and 3 o'clock, respectively. Upon activation, the laser cutters and their respective laser beams, begin to orbit around the central geometrical axis 2111 and the tubular
    2112. (In this configuration, laser cutters can also rotate around their own geometry axis as they orbit, so if they moved through a full orbit, they may also have moved through a full rotation .) In the present example, the cutters and bundles orbit in a counterclockwise direction, as seen in the Figures; however, a clockwise rotation can also be used. Consequently, as seen in the next view of the sequence, Figure 21B, the laser cutters, 2126, 2127, 2128 and 2129 rotated 45 degrees, with laser beams that travel along beam paths 2150, 2151, 2152 and 2153 having cut through four 1/8 sections (that is, a total of half) of the circumference of the tubular 2112. Then, Figure 21C shows the cutter having moved through a quarter of a turn.
    Consequently, cutter 2126 can be observed to have moved from the 2 o'clock position to the 9 o'clock position, with the other cutters having similarly altered their respective clock face positions.
    Consequently, moving through a quarter turn, the beam paths 2150, 2151, 2152 and 2153 may have crossed the entire circumference of the tubular 21 12 and the laser beams that travel along these beam paths may cut the tubular.
    During the cutting operation and, in particular, for circular cuts that intend to cut the tubular, it is preferable that the tubular does not move in a vertical direction.
    Consequently, the moment that either before the laser cutters are fired, the tube drawers, the annular preventer, or a separate holding device must be activated to prevent vertical movement of the tube during the cutting operation. laser.
    The separate retention device may also be contained in the SLM.
    The rate of orbital movement of laser cutters is dependent on the number of cutters used, the power of the laser beam when it strikes the surface of the tube to be cut, the thickness of the tube to be cut and the rate on the which the laser cuts the tubular.
    The rate of orbital movement must be slow enough to ensure that the intended cuts can be completed.
    The orbital movement of laser cutters can be performed using mechanical, hydraulic and electromechanical systems known in the art.
    In Figures 23A to C and 24A to B, exemplary embodiments of laser modules associated with a riser having a flanged coupling, such as an HMF coupling, are shown.
    Figures "A" show the riser flanges in continuous lines and the related tubes and the laser module in phantom lines.
    Figures "A" also have a sectional view with the section taken along lines A-A of Figures "B" removed from the view.
    In Figures "B", a cross section of the flange and laser module taken along the cross connection between two flanges is shown. Consequently, going back to Figures 23A and 23B, a central tube of riser section 2300 is provided which has a flange 2301 fixed at its lower end. The center tube of riser section 2303 has a flange 2302 attached to its upper end. (Although not shown in this Figure, it is recognized that the center tube of riser section 2300 may have a flange attached to its upper end and that the center tube of riser section 2303 may have a flange attached to its lower end.) The flange 2301 is fixed to the upper flange 2302 using screws and nuts 2304, 2305, 2306, 2307, 2308,
    2309. Also associated with riser sections 2300, 2303 and extending through flanges 2301, 2302 are a choke line 2310, an intensifier line 2311, an attack line 2312, a hydraulic line 2313 and empty spaces (for example, unfilled holes opened in the flange) 2314, 2315. Flange 2301 has an outer surface 2316, a contact surface 2335 and a shoulder surface 2336. Flange 2303 has an outer surface 2317, a contact surface 2337 and a shoulder surface 2338. When flanges 2301 and 2302 are engaged and connected, surface 2335 is engaged against surface 2337 and surface 2336 is engaged against surface 2338. Laser cutters 2320, 2321, 2322, 2323, 2324, 2325 have flexible support cables 2326, 2327, 2328, 2329, 2330, 2331 respectively. Laser cutters are optically associated with at least one high power laser. The laser cutters are contained within the 2319 laser module housing 2318. In this mode, the laser cutters are positioned adjacent to the screw heads, see, for example, the laser cutter 2324 and the screw 2308, and have beam paths directed towards the screws. Returning to Figure 23C, which is an enlarged view of a section of Figure 23A, a laser discharge tip 2350 from the laser cutter 2324 is shown. A beam path 2351, which a laser beam propagates from the cutter to laser 2324 can follow, extends between the laser discharge tip 2350 and the component of the riser section to be cut which, in this illustration, may be the screw 2308. Housing 2319 has an internal area 2352 that is configured or, otherwise, adapted to make contact, be associated with or engage the components of the riser 5 that must be cut by the laser.
    Housing 2319 has an outer area 2353 that is removed from inner area 2352. In general, the inner area of the housing will be closer to the riser and the outer area of the housing will be further from the riser.
    Returning to Figures 24A and 24B, a central tube of riser section 2400 is provided that has a flange 2401 attached to its lower end.
    The center tube of riser section 2403 has a flange 2402 attached to its upper end. (Although not shown in this Figure, it is recognized that that central 2400 riser section may have a flange attached to its upper end and that central riser section 2403 may have a flange attached to its lower end.) flange 2401 is fixed to the upper flange 2402 using screws and nuts 2404, 2405, 2406, 2407, 2408, 2409. Also associated with riser sections 2400, 2403 and extending through flanges 2401, 2402 are one throttle line 2410, intensifier line 2411, attack line 2412, hydraulic line 2413 and empty spaces (for example, unfilled holes opened in the flange) 2414, 2415. Flange 2401 has an outer surface 2416, a surface contact surface 2435 and a shoulder surface 2436. Flange 2403 has an outer surface 2417, a contact surface 2437 and a shoulder surface 2438. When flanges 2401 and 2402 are engaged and connected, surface 2435 is engaged against the surface 243 7 and the surface 2436 is engaged against the surface 2438. The laser cutters 2420, 2421, 2422, 2423, 2424, 2425, 2426, 2427, 2428, 2429 each have a flexible support cable ( not shown). Laser cutters are optically associated with at least one high power laser.
    The laser cutters are contained within the 2419 laser module housing 2418. In this mode, the laser cutters are positioned adjacent to the screw heads, see, for example, the laser cutter
    2424 and screw 2408, and adjacent to the external tubes, see, for example, laser cutter 2426 and intensifier line 2411. Laser cutters have beam paths directed at the screws and outer tubes. 5 In another embodiment, the laser cutters are positioned adjacent to the connection of the two flanges, that is, a ring where the external surfaces and the contact surfaces converge.
    Consequently, in this modality, laser cutters are directed to the flange and have beam paths that cross or follow the annular disk created by engaging contact surfaces.
    In another embodiment, the laser cutters are positioned adjacent to the shoulders.
    In this way, the laser has a beam path that is directed from the laser cutter to the area where the shoulders engage with each other.
    Additionally, in this modality, the beam path is directed through the thinnest area of the flange connections and, thus, presents the laser cutters with the least amount of material to remove.
    In an additional embodiment, the laser cutters are positioned adjacent to the screw nuts and have beam paths directed towards the nuts.
    A housing for a laser module can form a single piece with one of the flanges.
    The housing can be of two parts, each of the parts being integral with a flange and, therefore, the housing parts will be joined together as the flanges are connected.
    The housing can extend inward and join with the central tube, above or below the flange.
    When the housing extends inward, it can be configured to keep water out of the beam path between the laser cutter and the material to be cut, for example, a screw head.
    However, in this housing configuration, care must be taken so that the housing is mounted in a way that provides access to the screws and nuts, as well as a passage for the external tubes.
    The housing can be of a segmented ring type configuration or it can be of two or more semicircular sections, sections that are connected together around the flanges after the flanges have been screwed together, or around the central tube or riser.
    Preferably, on activation, laser cutters will propose (also commonly referred to as firing or firing the laser to create a laser beam) their respective laser beams along their respective beam trajectories.
    The cutters will then rotate around the riser causing the beam path to cut through the additional material.
    Non-rotating laser cutters can be used, however, in such a case, to ensure quick, clean and controlled cutting of the riser, larger numbers of cutters must be used.
    The delivery of the high power laser energy beam will cut or otherwise remove the material that is in the beam path.
    Consequently, high-powered laser energy, for example, can cut the screws that hold two riser flanges together; and separate or cut the two riser sections that were held together by those screws.
    Although not shown in the Figures, the laser modules and the teachings in this specification can be used with any type of riser coupling currently available, including toothed style and rotary switch style couplings, as well as laser coupling systems. future risers, still to be developed, and riser coupling systems, which the teachings in the present document can originate.
    Figures 25A and 25B show an embodiment of a laser riser disconnection section.
    Figure 25B is a cross-sectional view of the laser riser disconnection section taken along line B-B of Figure 25A.
    A 2500 riser section is provided. The 2500 riser section has a central tube 2503 that has an upper coupling 2501 and a lower coupling 2502 at its ends. These couplings can be of any type of riser coupling known to those versed individuals. in drilling techniques and can include a flange style, tooth style and rotary key style couplers.
    The 2500 riser section has four outer tubes associated with it, an attack line 2504, a choke line 2505, an intensifier line 2506 and a hydraulic line 2507. The 2500 riser section has a 2508 laser module that has a 2509 housing. The external tubes are configured to be arranged around, for example, outside the laser housing.
    Consequently, the laser cutters 2510, 2511 can be attached to the central tube 2503 of the riser section 2500. The laser cutters have flexible support cables 2512, 2513 that are fed through the passage set 2514 and into the duct 2515 for connection to a high power laser power source and other materials that can be used in the operation or monitoring of laser cutters.
    The flexible support cables have an extra length or gap to accommodate the rotation of the 2510, 2511 laser cutters around the circumference of the center tube 2503. In the embodiment of Figure 25B, the cutters may have to move about 1/2 of a rotation to cut the central tube 2503. It is desirable to have sets or quick-disconnect valves on the external tubes to facilitate their disconnection, and closing or closing, when the central riser tube, the external tubes, the screws or other means that holds the riser sections together, or all of them are cut.
    These disconnecting means for the external tubes must be positioned in a way that prevents spillage of the material they are carrying if the laser module is activated and cut the riser or, otherwise, weaken the riser so that a quick disconnect is possible.
    Laser modules or laser cutters may contain a shield to provide protection to laser cutters, to a lesser or greater extent, from water, pressure or other underwater environmental conditions in which the riser is to be deployed.
    The shield can be part of the housing or it can be a separate component.
    It can assist in pressure management or contribute to pressure management for the laser module.
    The shield can be made of a material, such as steel or another type of metal or other material, which is both robust enough to protect laser cutters and still be easily cut by the laser beam when it is fired.
    The shield can also be removable from the beam path of the laser beam. In this configuration, when activating the laser module, the shield can be moved away from the beam path. In the removable shield configuration, the shield does not have to be cut easily by the laser beam. 5 Although single laser modules are shown for a single riser section, multiple laser modules, modules of different formats and modules in different positions can be used. In addition, multiple riser sections, each with its own laser module, can be used in a riser in various positions between the marine probe and the BOP. The ability to create predetermined and accurate laser energy delivery patterns for the riser and the ability to create predetermined and accurate cuts in and through risers, provides the capability, even in an emergency, to cut the riser without crushing it and to do so with minimal damage to the riser. The riser laser module can be a single piece that is used to accommodate laser cutters, or it can be done from multiple pieces that are fastened together in a way that provides sufficient strength for your intended use and, in particular, to withstand pressures of 6,894.75 kPa (1,000 psi), 13,789.51 kPa (2,000 psi),
    31,026.40 kPa (4,500 psi), 34,473.78 kPa (5,000 psi) and higher. The modules need to be capable of operating at pressures that will occur at depths where the BOP is located, consequently, for example, at depths of 304.80 m (1,000 feet), 1,524.0 m (5,000 feet),
    3,048.0 m (10,000 feet) and potentially higher. The area of the housing containing the laser cutter can be machine-made or otherwise manufactured to accommodate laser cutters, while maintaining strength requirements for the intended use of the body. The laser module housing can also be two or more separate parts or components, for example, one component for the upper half and one for the lower half, or one more component for the section of a ring that is connected around of the riser. These components can be fastened to each other using, for example, bolted flanges, or another suitable fastening means known to an individual skilled in marine drilling techniques.
    The laser module or the housing may have a passage, passages, channels or other such structures, to carry the fiber optic cables for the transmission of the laser beam from the laser source to the housing and to the cutter laser, as well as other cables related to the operation or monitoring of the laser delivery set and its cutting operation.
    The greater the number of laser cutters in a rotating laser module, the slower the rate of orbital movement can be to complete a cut in the same amount of time.
    In addition, increasing the number of laser cutters decreases the time to complete a riser cut, without having to increase the orbital rate.
    Increasing the power of the laser beams will make it possible to cut tubulars faster and, consequently, allow faster orbit rates, less laser cutters, shorter time to complete a cut or combinations of them.
    The invention can be incorporated in other ways than those specifically disclosed in this document without departing from its spirit or essential characteristics.
    The described modalities should be considered in all aspects only as illustrative and not restrictive.
    权利要求:
    Claims (20)
    [1]
    1. Laser riser and eruption preventer system for use with a marine drilling rig, vessel or platform to control and manage emergency or potentially emergency situations, with the laser riser eruption preventer system which comprises: a. a high-powered laser; B. a high power beam switch that is optionally associated with a high power laser; ç. a riser; d. a rash preventer; and. a first laser cutter and a second laser cutter, in optical association with the high power beam switch; f. wherein the first laser cutter is positioned adjacent to the riser, the first laser cutter being able to direct a first high power laser beam to a component of the riser; g. wherein the second laser cutter is positioned on the eruption preventer, the second laser cutter being able to direct a second high power laser beam to a tubular one inside the eruption preventer; and, h. a control network in control of communication and data with the laser, the beam switch and the eruption preventer, in which the control network provides the laser firing and the action of the eruption preventer.
    [2]
    2. System according to claim 1, wherein the control network comprises a memory device comprising a series of instructions for executing a predetermined firing sequence of the first laser cutter and the second laser cutter and the prevention action - eruption torus.
    [3]
    System according to claim 1, in which the high power laser has at least about 10 kW of power.
    [4]
    4. System according to claim 1, wherein the high power laser has at least about 20 kW of power.
    [5]
    5. System according to claim 1, in which the high power laser has at least about 40 kW of power.
    [6]
    6. System according to claim 1, comprising a second high power laser. 5
    [7]
    7. System according to claim 6, in which only one of the high power laser and the second high power laser is in line at any given time.
    [8]
    8. Laser riser and eruption preventer system to control and manage emergency or potentially emergency situations, and the laser riser eruption preventer system comprises: a. a first high power laser and a second high power laser; B. a riser; ç. a rash preventer; d. a first laser cutter and a second laser cutter, the first laser cutter being in optical association with the first high power laser and the second optical cutter is in optical association with the second high power laser; and is. where the first laser cutter is associated with the riser and where the second laser cutter is associated with the rash preventer.
    [9]
    9. System according to claim 8, comprising a third laser cutter, wherein one of the second or third laser cutters is associated with an upper portion of the eruption preventer and another among the second or the second third laser cutters are associated with a lower portion of the rash preventer.
    [10]
    A system according to claim 8, wherein the first high-powered laser has at least about 20 kW of power.
    [11]
    System according to claim 8, in which the first high-power laser has at least about 40 kW of power.
    [12]
    12. Laser riser and eruption preventer system to control and manage emergency or potentially emergency situations, and the laser riser eruption preventer system comprises:
    The. a high-powered laser; B. a high power beam switch in optical and control association with the high power laser; ç. a riser comprising a first laser cutter, the first laser cutter being able to direct a first high power laser beam to a component of the riser; d. an eruption preventer comprising a second laser cutter, the second laser cutter being able to direct a second high power laser beam to a tubular one inside the eruption preventer; and is. the first laser cutter and the second laser cutter are in optical association with the high power laser.
    [13]
    13. The system according to claim 12, wherein the high power laser has at least about 10 kW of power.
    [14]
    14. System according to claim 12, wherein the high power laser has at least about 20 kW of power.
    [15]
    15. The system according to claim 12, wherein the high power laser has at least about 40 kW of power.
    [16]
    16. System according to claim 12, comprising a second high power laser.
    [17]
    17. Marine drilling rig, vessel or platform that has an eruption preventer and laser riser system to control and manage emergency or potentially emergency situations, with the eruption preventer and laser riser system comprising: a. a high-power laser in optical association with a high-power beam switch; B. a riser comprising a plurality of riser sections, wherein the plurality of riser sections is configured to be lowered from and operably connected to the marine drilling rig at a depth at or near the seabed; ç. an eruption preventer configured to be operably connected to the riser and lowered by the riser from the marine drilling rig to the seabed; and, d. one of the plurality of riser sections comprising a first laser cutter to emit a first laser beam that defines a first beam path, wherein the first beam path is directed towards one of the plurality of sections of riser; and. the eruption preventer comprising a second laser cutter to emit a second laser beam that defines a second beam path, in which the second beam path is directed to a cavity defined by the eruption preventer; and, f. a control system; g. where, when the riser and the eruption preventer are positioned and operably associate the marine drilling rig and a well hole in the seabed, the control system is configured to control the firing of the first and of the second laser cutters.
    [18]
    18. Eruption preventer and laser riser system, according to claim 17, in which the control system is configured to control the performance of the eruption preventer.
    [19]
    19. Method of performing drilling, reconditioning, intervention, completion or service in an underwater well with the use of an eruption preventer and laser riser system in conjunction with a marine drilling rig to control and manage emergency situations or potentially emergency, and the method comprises: a. lowering an eruption preventer from a marine drilling rig, vessel or platform to the bottom of the sea with the use of a riser comprising a plurality of riser sections; B. wherein the eruption preventer comprises: an eruption preventer cavity defined by the eruption preventer; and a first laser cutter to emit a first laser beam that defines a first beam path, in which the first beam path is directed towards the eruption preventer cavity; ç. where the riser comprises: a riser cavity defined by the riser; and a second laser cutter to emit a second laser beam that defines a second beam path, wherein the second beam path is directed towards a riser component; d. connect a high-power laser operably to a control system; 5 e. attach the eruption preventer to a well bore, the well bore cavity and the riser cavity being in fluid and mechanical communication; and, f. carry out operations in the borehole by lowering structures from the marine drilling rig through the descending cavity, the eruption preventer cavity and into the well bore; and, g. where the control system is configured to trigger the first and second laser cutters.
    [20]
    20. Method, according to claim 19, in which the structures are selected from the group consisting of: tubular, steel cable, spiral pipe and piano string.
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    同族专利:
    公开号 | 公开日
    WO2012148546A1|2012-11-01|
    SG192917A1|2013-09-30|
    CN103492667A|2014-01-01|
    CA2827961C|2016-11-15|
    CA2827961A1|2012-11-01|
    US8720584B2|2014-05-13|
    US20120217017A1|2012-08-30|
    US9291017B2|2016-03-22|
    US20140345872A1|2014-11-27|
    EP2678518B1|2019-05-29|
    AU2012249147A1|2013-09-12|
    EP2678518A1|2014-01-01|
    EP2678518A4|2018-03-07|
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    法律状态:
    2020-10-06| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2021-01-19| B11B| Dismissal acc. art. 36, par 1 of ipl - no reply within 90 days to fullfil the necessary requirements|
    2021-11-23| B350| Update of information on the portal [chapter 15.35 patent gazette]|
    优先权:
    申请号 | 申请日 | 专利标题
    US13/034,037|2011-02-24|
    US13/034,037|US8720584B2|2011-02-24|2011-02-24|Laser assisted system for controlling deep water drilling emergency situations|
    PCT/US2012/026494|WO2012148546A1|2011-02-24|2012-02-24|Laser assisted system for controlling deep water drilling emergency situations|
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