Patent Application
20120217018
1. Field of the Invention
The present inventions relate to blowout preventers and, in particular, subsea blowout preventers used for the offshore exploration and production of hydrocarbons, such as oil and natural gas. Further, the present inventions relate to the implementation of high power lasers in association with the blowout preventer's mechanical well control assemblies. Thus, and in particular, the present inventions relate to novel laser assisted subsea blowout preventers and methods of using such devices to manage and control offshore drilling activities.
As used herein, unless specified otherwise the terms “blowout preventer,” “BOP,” and “BOP stack” are to be given their broadest possible meaning, and include: (i) devices positioned at or near the borehole surface, e.g., the seafloor, which are used to contain or manage pressures or flows associated with a borehole; (ii) devices for containing or managing pressures or flows in a borehole that are associated with a subsea riser; (iii) devices having any number and combination of gates, valves or elastomeric packers for controlling or managing borehole pressures or flows; (iv) a subsea BOP stack, which stack could contain, for example, ram shears, pipe rams, blind rams and annular preventers; and, (v) other such similar combinations and assemblies of flow and pressure management devices to control borehole pressures, flows or both and, in particular, to control or manage emergency flow or pressure situations.
As used herein, unless specified otherwise “offshore” and “offshore drilling activities” and similar such terms are used in their broadest sense and would include drilling activities on, or in, any body of water, whether fresh or salt water, whether manmade or naturally occurring, such as for example rivers, lakes, canals, inland seas, oceans, seas, bays and gulfs, such as the Gulf of Mexico. As used herein, unless specified otherwise the term “offshore drilling rig” is to be given its broadest possible meaning and would include fixed towers, tenders, platforms, barges, jack-ups, floating platforms, drill ships, dynamically positioned drill ships, semi-submersibles and dynamically positioned semi-submersibles. As used herein, unless specified otherwise the term “seafloor” is to be given its broadest possible meaning and would include any surface of the earth that lies under, or is at the bottom of, any body of water, whether fresh or salt water, whether manmade or naturally occurring. As used herein, unless specified otherwise the terms “well” and “borehole” are to be given their broadest possible meaning and include any hole that is bored or otherwise made into the earth's surface, e.g., the seafloor or sea bed, and would further include exploratory, production, abandoned, reentered, reworked, and injection wells. As used herein the term “riser” is to be given its broadest possible meaning and would include any tubular that connects a platform at, on, or above the surface of a body of water, including an offshore drilling rig, a floating production storage and offloading (“FPSO”) vessel, and a floating gas storage and offloading (“FGSO”) vessel, to a structure at, on, or near the seafloor for the purposes of activities such as drilling, production, workover, service, well service, intervention and completion.
As used herein the term “drill pipe” is to be given its broadest possible meaning and includes all forms of pipe used for drilling activities; and refers to a single section or piece of pipe. As used herein the terms “stand of drill pipe,” “drill pipe stand,” “stand of pipe,” “stand” and similar type terms are to be given their broadest possible meaning and include two, three or four sections of drill pipe that have been connected, e.g., joined together, typically by joints having threaded connections. As used herein the terms “drill string,” “string,” “string of drill pipe,” string of pipe” and similar type terms are to be given their broadest definition and would include a stand or stands joined together for the purpose of being employed in a borehole. Thus, a drill string could include many stands and many hundreds of sections of drill pipe.
As used herein the term “tubular” is to be given its broadest possible meaning and includes drill pipe, casing, riser, coiled tube, composite tube, vacuum insulated tubing (“VIT), production tubing and any similar structures having at least one channel therein that are, or could be used, in the drilling industry. As used herein the term “joint” is to be given its broadest possible meaning and includes all types of devices, systems, methods, structures and components used to connect tubulars together, such as for example, threaded pipe joints and bolted flanges. For drill pipe joints, the joint section typically has a thicker wall than the rest of the drill pipe. As used herein the thickness of the wall of a tubular is the thickness of the material between the internal diameter of the tubular and the external diameter of the tubular.
As used herein, unless specified otherwise “high power laser energy” means a laser beam having at least about 1 kW (kilowatt) of power. As used herein, unless specified otherwise “great distances” means at least about 500 m (meter). As used herein the term “substantial loss of power,” “substantial power loss” and similar such phrases, mean a loss of power of more than about 3.0 dB/km (decibel/kilometer) for a selected wavelength. As used herein the term “substantial power transmission” means at least about 50% transmittance.
2. Discussion of Related Art
Deep Water Drilling
Offshore hydrocarbon exploration and production has been moving to deeper and deeper waters. Today drilling activities at depths of 5000 ft, 10,000 ft and even greater depths are contemplated and carried out. For example, its has been reported by RIGZONE, www.rigzone.com, that there are over 300 rigs rated for drilling in water depths greater than 1,000 ft (feet), and of those rigs there are over 190 rigs rated for drilling in water depths greater than 5,000 ft, and of those rigs over 90 of them are rated for drilling in water depths of 10,000 ft. When drilling at these deep, very-deep and ultra-deep depths the drilling equipment is subject to the extreme conditions found in the depths of the ocean, including great pressures and low temperatures at the seafloor.
Further, these deep water drilling rigs are capable of advancing boreholes that can be 10,000 ft, 20,000 ft, 30,000 ft and even deeper below the sea floor. As such, the drilling equipment, such as drill pipe, casing, risers, and the BOP are subject to substantial forces and extreme conditions. To address these forces and conditions drilling equipment, for example, drill pipe and drill strings, are designed to be stronger, more rugged, and in many cases heavier. Additionally, the metals that are used to make drill pipe and casing have become more ductile.
Typically, and by way of general illustration, in drilling a subsea well an initial borehole is made into the seabed and then subsequent and smaller diameter boreholes are drilled to extend the overall depth of the borehole. Thus, as the overall borehole gets deeper its diameter becomes smaller; resulting in what can be envisioned as a telescoping assembly of holes with the largest diameter hole being at the top of the borehole closest to the surface of the earth.
Thus, by way of example, the starting phases of a subsea drill process may be explained in general as follows. Once the drilling rig is positioned on the surface of the water over the area where drilling is to take place, an initial borehole is made by drilling a 36″ hole in the earth to a depth of about 200-300 ft. below the seafloor. A 30″ casing is inserted into this initial borehole. This 30″ casing may also be called a conductor. The 30″ conductor may or may not be cemented into place. During this drilling operation a riser is generally not used and the cuttings from the borehole, e.g., the earth and other material removed from the borehole by the drilling activity, are returned to the seafloor. Next, a 26″ diameter borehole is drilled within the 30″ casing, extending the depth of the borehole to about 1,000-1,500 ft. This drilling operation may also be conducted without using a riser. A 20″ casing is then inserted into the 30″ conductor and 26″ borehole. This 20″ casing is cemented into place. The 20″ casing has a wellhead secured to it. (In other operations an additional smaller diameter borehole may be drilled, and a smaller diameter casing inserted into that borehole with the wellhead being secured to that smaller diameter casing.) A BOP is then secured to a riser and lowered by the riser to the sea floor; where the BOP is secured to the wellhead. From this point forward all drilling activity in the borehole takes place 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 inner cavity extending through these devices. BOP's can have cavities, e.g., bore diameters ranging from about 4⅙″ to 26¾.″ Tubulars are advanced from the offshore drilling rig down the riser, through the BOP cavity and into the borehole. Returns, e.g., drilling mud and cuttings, are removed from the borehole and transmitted through the BOP cavity, up the riser, and to the offshore drilling rig.
The BOP stack typically has an annular preventer, which is an expandable packer that functions like a giant sphincter muscle around a tubular. Some annular preventers may also be used or capable of sealing off the cavity when a tubular is not present. When activated, this packer seals against a tubular that is in the BOP cavity, preventing material from flowing through the annulus formed between the outside diameter of the tubular and the wall of the BOP cavity. The BOP stack also typically has ram preventers. As used herein unless specified otherwise, the term “ram preventer” is to be given its broadest definition and would include any mechanical devices that clamp, grab, hold, cut, sever, crush, or combinations thereof, a tubular within a BOP stack, such as shear rams, blind rams, variable rams, variable pipe rams, blind-shear rams, pipe rams, casing shear rams, and preventers such as Hydril's HYDRIL PRESSURE CONTROL COMPACT Ram, Hydril Pressure Control Conventional Ram, HYDRIL PRESSURE CONTROL QUICK-LOG, and HYDRIL PRESSURE CONTROL SENTRY Workover, SHAFFER ram preventers, and ram preventers made by Cameron.
Thus, the BOP stack typically has a pipe ram preventer, and my have more than one of these. Pipe ram preventers typically are two half-circle like clamping devices that are driven against the outside diameter of a tubular that is in the BOP cavity. Pipe ram preventers can be viewed as two giant hands that clamp against the tubular and seal-off the annulus between the tubular and the BOP cavity wall. Blind ram preventers may also be contained in the BOP stack, these rams can seal the cavity when no tubulars are present.
Pipe ram preventers and annular preventers typically can only seal the annulus between a tubular in the BOP and the BOP cavity; they cannot seal-off the tubular. Thus, in emergency situations, e.g., when a “kick” (a sudden influx of gas, fluid, or pressure into the borehole) occurs, or if a potential blowout situation arises, flows from high downhole pressures can come back up through the inside of the tubular, the annulus between the tubular and riser, and up the riser to the drilling rig. Additionally, in emergency situations, the pipe ram and annular preventers may not be able to form a strong enough seal around the tubular to prevent flow through the annulus between the tubular and the BOP cavity. Thus, BOP stacks include a mechanical shear ram assembly. (As used herein, unless specified otherwise, the term “shear ram” would include blind shear rams, shear sealing rams, shear seal rams, shear rams and any ram that is intended to, or capable of, cutting or shearing a tubular.) Mechanical shear rams are typically the last line of defense for emergency situations, e.g., kicks or potential blowouts. Mechanical shear rams function like giant gate valves that are supposed to quickly close across the BOP cavity to seal it. They are intended to cut through any tubular in the BOP cavity that would potentially block the shear ram from completely sealing the BOP cavity.
BOP stacks can have many varied configurations and components, which are dependent upon the conditions and hazards that are expected during deployment and use. These components could include, for example, an annular type preventer, a rotating head, a single ram preventer with one set of rams (blind or pipe), a double ram preventer having two sets of rams, a triple ram type preventer having three sets of rams, and a spool with side outlet connections for choke and kill lines. Examples of existing configurations of these components could be: a BOP stack having a bore of 7 1/16″ and from bottom to top a single ram, a spool, a single ram, a single ram and an annular preventer and having a rated working pressure of 5,000 psi; a BOP stack having a bore of 13⅝″ and from bottom to top a spool, a single ram, a single ram, a single ram and an annular preventer and having a rated working pressure of 10,000 psi; and, a BOP stack having a bore of 18¾″ and from bottom to top, a single ram, a single ram, a single ram, a single ram, an annular preventer and an annular preventer and having a rated working pressure of 15,000 psi.
BOPs need to contain the pressures that could be present in a well, which pressures could be as great as 15,000 psi or greater. Additionally, there is a need for shear rams that are capable of quickly and reliably cutting through any tubular, including drilling collars, pipe joints, and bottom hole assemblies that might be present in the BOP when an emergency situation arises or other situation where 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 tubulars of deep, very-deep and ultra-deep water drilling, there has been an ever increasing need for stronger, more powerful, and better shear rams. This long standing need for such shear rams, as well as, other information about the physics and engineering principles underlying existing mechanical shear rams, is set forth in: West Engineering Services, Inc., “Mini Shear Study for U.S. Minerals Management Services” (Requisition No. 2-1011-1003, December 2002); West Engineering Services, Inc., “Shear Ram Capabilities Study for U.S. Minerals Management Services” (Requisition No. 3-4025-1001, September 2004); and, Barringer & Associates Inc., “Shear Ram Blowout Preventer Forces Required” (Jun. 6, 2010, revised Aug. 8, 2010).
High Power Laser Beam Conveyance
Prior to the recent breakthroughs of co-inventor Dr. Mark Zediker and those working with him at Foro Energy, Inc., Littleton Colo., it was believed that the transmission of high power laser energy over great distances without substantial loss of power was unobtainable. Their breakthroughs in the transmission of high power laser energy, in particular power levels greater than 5 kW, are set forth, in part, in the novel and innovative teachings contained in US patent application publications 2010/0044106 and 2010/0215326 and in Rinzler et. al, pending U.S. patent application Ser. No. 12/840,978 titled “Optical Fiber Configurations for Transmission of Laser Energy Over Great Distances” (filed Jul. 21, 2010). The disclosures of these three US patent applications, to the extent that they refer or relate to the transmission of high power laser energy, and lasers, fibers and cable structures for accomplishing such transmissions, are incorporated herein by reference. It is to be noted that this incorporation by reference herein does not provide any right to practice or use the inventions of these applications or any patents that may issue therefrom and does not grant, or give rise to, any licenses thereunder.
The utilization and application of high power lasers to BOP and risers is set forth in US patent application attorney numbers 13938/34 Foro s15, 13938/35 Foro s16, and 13938/36 Foro s17 filed concurrently herewith, the entire disclosures of which are incorporated herein by reference.
In drilling operations it has long been desirable to have a BOP that has the ability to quickly, reliably, and in a controlled manner sever tubulars and seal off, or otherwise manage the pressure, flow, or both of a well. As the robustness of tubulars, and in particular tubulars for deep sea drilling, has increased, the need for such a BOP has continued, grown and become more important. The present invention, among other things, solves this need by providing the articles of manufacture, devices and processes taught herein.
Thus, there is provided herein a blowout preventer stack having: a ram movable from a first position to a second position; and, a laser cutter for emitting a laser beam defining a beam path positioned relative to the ram and facing a cavity formed within the stack, wherein the beam path enters into the cavity and the second position is located within the cavity.
There is also provided a blowout preventer stack including a ram preventer; the stack defining a cavity; and, a laser cutter, wherein the laser cutter is positioned to deliver a laser beam along a beam path. Further, the ram preventer may be a shear ram assembly and the stack may also include: an annular preventer assembly; a pipe ram assembly; and, the annular preventer assembly, shear ram assembly and pipe ram assembly share the cavity, the cavity having an axis.
Still further, there is provided a subsea blowout preventer stack in which the beam path may be directed toward the axis of the cavity, may be directed towards the cavity, or wherein the beam path intersects the axis of the cavity.
Additionally, there is provided a blowout preventer in which the a laser cutter has a shield located adjacent to the cavity, wherein the laser cutter shield protects the laser cutter from damage from the conditions present in the BOP cavity, such as pressure, temperature, tubular or line structures moving through or rotating within the cavity, cuttings, hydrocarbons, and drilling fluids, the laser cutter from drilling fluids, while not appreciably interfering with the movement of tubulars through the cavity.
Further still, there is provided a blowout preventer having: a laser cutter; a ram preventer including a ram; a cavity within the stack for passing tubulars through the cavity; the laser cutter having a beam path; the ram capable of movement into the cavity; an area within the cavity for engagement of the ram with a tubular; and, the beam path positioned between the laser cutter and intersecting the area in the cavity for the ram engagement with a tubular.
Furthermore, there is provided a blowout preventer for use on land, sea or both, having a laser cutter; a ram preventer, having a ram; a cavity within a stack for passing tubulars therethrough; the laser cutter having a beam path; the ram capable of movement into the cavity; an area within the cavity for engagement of the ram with a tubular; and, the beam path directed above the area within the cavity for engagement of the ram with the tubular.
There is yet further provided a laser assisted blowout preventer, for use on land, on the sea or both, the blowout preventer having: an annular preventer; a pipe ram assembly; and, a laser shear ram assembly having: a ram movable from a first position to a second position; and, a laser cutter positioned relative to the ram and facing a cavity formed within the laser assisted blowout preventer, wherein the laser cutter emits a laser beam that defines a, laser cutter beam path that enters into the cavity and the second position is located within the cavity. As a subsea blowout preventer this preventer may also have: a shear ram assembly and a second pipe ram assembly; wherein the annular preventer, laser shear ram assembly, shear ram assembly, pipe ram assembly and second pipe ram assembly form a stack of components.
Still additionally, there is provided a laser assisted blowout preventer wherein the laser cutter beam path extends toward a center axis of the cavity, wherein the cavity has a vertical axis and the laser cutter beam path forms an acute angle with the vertical axis, wherein the cavity has a vertical axis and the laser cutter beam path that forms an obtuse angle with the vertical axis, or wherein the body cavity has a vertical axis and the laser cutter beam path forms about a 90 degree angle with the vertical axis.
Moreover, there is also provided a laser assisted blowout preventer wherein the laser cutter is capable of at least partially orbiting an axis of the cavity while firing the laser beam. This cutter may also have a second laser cutter. These laser assisted blowout preventers may be configured such that it takes about ½ of an orbit to complete a cut of a tubular, it takes about ⅓ of an orbit to complete a cut of a tubular, it takes about ¼ of an orbit to complete a cut of a tubular.
Further, there is provided a laser assisted blowout preventer wherein the laser cutter is contained in a ram. Further, the ram may have a path of travel for movement of the ram from the first position to the second position, the laser cutter beam path may be transverse to the ram path of travel, or the laser cutter beam path may be parallel to the ram path of travel.
Still further, there is provided a laser assisted blowout having: a plurality of laser cutters, wherein each laser cutter emits a laser beam that defines a beam path, wherein the cavity is substantially circular; and each of the plurality of laser cutters is adjacent to but not in the cavity, and the beam paths are configured in a spoke like configuration.
Yet further, there is provided a laser assisted blowout preventer having: a frame; a blowout preventer stack associated with the frame, the blowout preventer stack having; a cavity formed within the blowout preventer for passing tubulars therethrough; and, a laser delivery assembly positioned outside of the cavity when not activated.
There is also provided a laser assisted subsea blowout preventer drilling system, the system having: a subsea riser; a blowout preventer stack having: a cavity for passing tubulars through the blowout preventer stack, wherein the cavity is in mechanical communication with the subsea riser, wherein tubulars can be passed to and from the subsea riser into the cavity for the purpose of advancing a borehole; a laser delivery assembly; a shear ram assembly, wherein the laser delivery assembly is optically and mechanically associated with the shear ram assembly; whereby, upon activation the laser delivery system delivers a high power laser beam to a tubular within the blowout preventer cavity resulting in cutting the tubular to reduce the risk that the tubular would prevent the closing of the shear ram assembly. Regarding this laser assisted subsea blowout preventer drilling system, the high power laser beam forms a laser delivery pattern to sever the tubular in the blowout preventer cavity, wherein the high power laser beam forms a laser delivery pattern to weaken the tubular in the blowout preventer cavity, or wherein the high power laser beam forms a laser delivery pattern to remove two discrete areas of the tubular.
Yet further, there is provided a laser assisted subsea blowout preventer drilling system, the system having: a subsea riser; a blowout preventer stack; the blowout preventer stack having: a cavity for passing tubulars therethrough, wherein the cavity for the blowout preventer stack is in fluid communication with the subsea riser; a laser delivery assembly; and, a shear ram assembly having an opposed pair of shear rams, wherein the laser delivery assembly is associated with the shear ram assembly.
Moreover, there is provided an offshore drilling rig having a laser assisted subsea blowout preventer system for the rapid cutting of tubulars in the blowout preventer during emergency situations, the laser system having: a riser capable of being lowered from and operably connected to an offshore drilling rig to a depth at or near a seafloor; a blowout preventer capable of being operably connected to the riser and lowered by the riser from the offshore drilling rig to the seafloor; a high power laser in optical communication with a laser cutter; and, the laser cutter operably associated with the blowout preventer and riser, whereby the laser cutter is capable of being lowered to at or near the seafloor and upon activation delivering a high power laser beam to a tubular that is within the blowout preventer.
Additionally, there is provided an offshore drilling rig having a laser assisted subsea blowout preventer system for the rapid cutting of tubulars in the blowout preventer during emergency situations, the laser system having: a riser positioned at a depth at or near a seafloor, wherein the riser is operably connected to an offshore drilling rig; a blowout preventer positioned at or near the seafloor, wherein the blowout preventer is operably connected to the riser; a high power laser in optical communication with a laser cutter; and, the laser cutter operably associated with the blowout preventer and riser and positioned at or near the seafloor, whereby upon activation the laser cutter delivers a high power laser beam to a tubular that is within the blowout preventer.
Still additionally, there is provided an offshore drilling rig having a laser assisted subsea blowout drilling system, the system having: a riser capable of being lowered from and operably connected to an offshore drilling rig to a depth at or near a seafloor; a blowout preventer capable of being operably connected to the riser and lowered by the riser from the offshore drilling rig to the seafloor; the blowout preventer including a shear ram capable of mechanically interacting with an area of a tubular that is within the blowout preventer; the shear ram being associated with a laser cutter; a high power laser in optical communication with the laser cutter; and, the laser cutter operably associated with the blowout preventer and riser, whereby the laser cutter is capable of being lowered to at or near the seafloor and upon activation delivering a high power laser beam to the tubular that is within the blowout preventer and to an area on the tubular that is at or near the area of mechanical interaction with the shear ram.
Further, there is provided a deep water offshore drilling rig capable of drilling in over 5000 feet of water, having a laser delivery assembly associated with a blowout preventer and a riser for the rapid cutting of tubulars in the blowout preventer stack, the offshore drilling rig having: a hoisting means and a high power laser having at least 20 kW of power; at least 5000 feet of riser sections, capable of being connected together and lowered to a depth at or near a seafloor; a blowout preventer capable of being operably connected to the riser and lowered to the seafloor; the high power laser in optical communication with a laser cutter; the laser cutter opto-mechanically associated with the blowout preventer, whereby the laser cutter is capable of being lowered to at or near the seafloor and upon activation delivering a high power laser beam to a tubular that is within the blowout preventer and to an area on the tubular that is intended to be cut. And, further this drilling rig may have the hoisting means including a derrick a drawworks and a top drive.
Yet further, there is provided a subsea blowout preventer stack having: a ram and a laser cutter positioned within the stack; the laser cutter having a means to deliver a predetermined laser beam cutting pattern; whereby the predetermined laser beam cutting pattern corresponds to an area of a tubular to be removed within the stack.
There is also provided a method of drilling subsea wells by using a laser assisted blowout preventer and riser, the method including: lowering a laser assisted blowout preventer having a first inner cavity from an offshore drilling rig to a seafloor using a riser having a second inner cavity, the seafloor having a borehole; securing the blowout preventer to the borehole, whereby the borehole, the first inner cavity and the second inner cavity are in fluid and mechanical communication; and, advancing the borehole by lowering tubulars from the offshore drilling rig down through the second inner cavity, the first inner cavity and into the borehole; wherein, the laser assisted blowout preventer has the capability to perform laser cutting of a tubular present in the first inner cavity. The blowout preventer used in this method may be a laser assisted blowout preventer having: a frame; a blowout preventer stack associated with the frame; the blowout preventer stack including a third cavity for passing tubulars therethrough, which third cavity is at least a part the first cavity; and, the blowout preventer stack including the laser delivery assembly, wherein the laser delivery assembly is positioned outside of the first and third cavities when not activated.
In general, the present inventions relate to a BOP having high power laser beam cutters that are used in conjunction with mechanical closing devices to manage the conditions of a well, such as pressure, flow or both. Thus, by way of example, an embodiment of a laser assisted subsea BOP drilling system 150 is schematically shown in
Typically, in deep sea drilling operations a 21″ riser and an 18¾″ BOP are used. The term “21″ riser” is generic and covers risers having an outer diameter in the general range of 21″ and would include for example a riser having a 21¼″ outer diameter. Wall thickness for 21″ risers can range of from about ⅝″ to ⅞″ or greater. Risers and BOPs, however, can vary in size, type and configuration. Risers can have outer diameters ranging from about 13⅜″ to about 24.″ BOP's can have cavities, e.g., bore diameters ranging from about 4⅙″ to 26¾.″ Risers may be, for example, conventional pipe risers, flexible pipe risers, composite tube structures, steel cantenary risers (“SCR”), top tensioned risers, hybrid risers, and other types of risers known to those skilled in the offshore drilling art or later developed. The use of smaller and larger diameter risers, different types and configurations of risers, BOPs having smaller and larger diameter cavities, and different types and configurations of BOPs, are contemplated; and, the teachings and inventions of this specification are not limited to, or by, the size, type or configuration of a particular riser or BOP.
The top 125 of the laser assisted BOP 100 is secured to a riser 116 by a flex joint 115. The flex joint 115, which may also be referred to as a flex connecter or ball joint, allows the riser 116 to be at an angle with respect to the laser assisted BOP 100, and thus, accommodates some movement of the riser 116 and the drilling rig 118 on the surface of the water 124. The riser 116 is connected to the drilling rig 118 by riser tensioners 117 and other equipment known to those of skill in the offshore drilling art, but not shown in this figure. The drilling rig 118, which in this example is shown as a semi-submersible, has a moon pool 119, a drill floor 120, a derrick 121, and other drilling and drilling support equipment and devices utilized for operation, which are known to the offshore drilling art, but are not shown in the figure. Athough a semi-submersible is shown in this embodiment, any type of offshore drilling rig, vessel, or platform may be utilized and thus may have a laser assisted BOP drilling system.
When deployed, as shown in
In general, and by way of example, during deployment a laser assisted BOP (such as the embodiment of
The laser assisted BOPs of the present inventions, for example the laser assisted BOP 100 of
Laser assisted BOPs, for example the laser assisted BOP 100 of
Laser shear ram assemblies may be the last line of defense for emergency situations, e.g., kicks or potential blowouts. In general, laser shear rams assemblies use a laser beam to cut or weaken a tubular, including drilling collars, pipe joints, and bottom hole assemblies that might be present in the BOP cavity 123 when an emergency situation arises, or other situation where it would be advantageous to cut tubulars in the BOP, so that the rams can quickly and reliably close across the BOP cavity 123 to seal it, and thus, seal the well. The laser BOP should contain the pressures that could be present in a well, and for example, should be capable of withstanding pressures of 5,000 psi, 10,000 psi, 15,000 psi, preferably 20,000 psi for deep sea drilling, or greater. Thus, laser assisted BOPs will have the capability to reliably and quickly seal a well, regardless of the thickness and type of tubular that is present in the BOP when an emergency or other situation arises.
In
Laser assisted subsea BOP drilling systems may have a single high power laser, and preferably may have two or three high power lasers, and may have several high power lasers, for example, six or more. High power solid-state lasers, specifically semiconductor lasers and fiber lasers are preferred, because of their short start up time and essentially instant-on capabilities. The high power lasers for example may be fiber lasers or semiconductor lasers having 10 kW, 20 kW, 50 kW or more power and, which emit laser beams with wavelengths preferably in about the 1550 nm (nanometer), or 1083 nm ranges. Examples of preferred lasers, and in particular solid-state lasers, such as fiber lasers, are set forth in US patent application publications 2010/0044106 and 2010/0215326 and in pending U.S. patent application Ser. No. 12/840,978. The laser, or lasers, may be located on the offshore drilling rig, above the surface of the water, and optically connected to the BOP on the seafloor by way of a high power long distance laser transmission cable, preferred examples of which are set forth in US patent application publications 2010/0044106 and 2010/0215326 and in pending U.S. patent application Ser. No. 12/840,978. The laser transmission cable may be contained in a spool and unwound and attached to the BOP and riser as they are lowered to the seafloor. The lasers may also be contained in, or associated with, the BOP frame, eliminating the need for a long distance of high power optical cable to transmit the laser beam from the surface of the water down to the seafloor. In view of the extreme conditions in which the laser shear rams are required to operate and the need for high reliability in their operation, one such configuration of a laser assisted subsea BOP drilling system is to have at least one high power laser located on the offshore drilling rig and connect to the BOP by a high power transmission cable and to have at least one laser in, or associated with, the BOP frame on the seafloor.
Turning to
During drilling and other activities tubulars, not shown in
Although a single laser delivery assembly is shown in the example of the embodiment of
The body of laser shear ram assembly may be a single piece that is machined to accommodate the laser delivery assembly, or it may be made from multiple pieces that are fixed together in a manner that provides sufficient strength for its intended use, and in particular to withstand pressures of 5,000 psi, 10,000 psi, 15,000 psi, 20,000 psi, and greater. The area of the body that contains the laser delivery assembly may be machined out, or otherwise fabricated to accommodate the laser delivery assembly, while maintaining the strength requirements for the body's intended use. The body of the laser shear ram assembly may also be two or more separate components or modules, e.g., one component or module for the laser delivery assembly and another for the shear rams. These modules could be attached to each other by, for example, bolted flanges, or other suitable attachment means known to those of skill in the offshore drilling art. The body, or a module making up the body, may have a passage, passages, channels, or other such structures, to convey fiber optic cables for transmission of the laser beam from the laser source into the body and to the laser delivery assembly, as well as, other cables that relate to the operation or monitoring of the laser delivery assembly and its cutting operation.
In
The body 301 contains and supports lower shear ram 302 and upper shear ram 303, which rams have piston assemblies 305 and 306 associated therewith. In operation, the piston assemblies 305, 306 drive the rams 302, 303 toward the center axis 311, engaging, cutting and moving through tubular 312, and sealing the cavity 304, and thus, the well. The body 301 also has a feed-through assembly 313 for managing pressure and permitting optical fiber cables and other cables, tubes, wires and conveyance means, which may be needed 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.
Turning to
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. Thus, flexible support cable 331 is associated with laser cutter 326, flexible support cable 332 is associated with laser cutter 327, flexible support cable 333 is associated with laser cutter 328, and flexible support cable 330 is associated with laser cutter 329. The flexible support cables are located in channel 339 and enter feed-through assembly 313. In the general area of the feed-through assembly 313, the support cables transition from flexible to semi-flexible, and may further be included in conduit 338 for conveyance to a high power laser, or other sources of materials for the cutting operation. The flexible support cables 330, 331, 332, and 333 have extra, or additional length, which accommodates the orbiting of the laser cutters 326, 327, 328 and 329 around the axis 311, and around the tubular 312.
Thus, as seen in the next view of the sequence,
During the cutting operation, and in particular for circular cuts that are intended to sever the tubular, it is preferable that the tubular not move in a vertical direction. Thus, at or before the laser cutters are fired, the pipe rams, the annular preventer, or a separate holding device should be activated to prevent vertical movement of the pipe during the laser cutting operation.
The rate of the orbital movement of the laser cutters is dependent upon the number of cutters used, the power of the laser beam when it strikes 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 the orbital motion should be slow enough to ensure that the intended cuts can be completed.
In addition to orbiting cutters, the laser beam can be scanned, e.g., moved in a fan like pattern. In this manner the beam path would be scanned along the area to be cut, e.g., an area of a tubular, while the cutter, or at least the base of the cutter, remained in a fixed position. This scanning of the laser beam can be accomplished, for example, by moving the cutter back and forth about a fixed point, e.g, like the movement of an oscillating fan. It may also be accomplished by having optics contained within the cutter that scans the beam path, e.g., a laser scanner, and thus the laser beam in the fan like pattern. For example a multi-faceted mirror or prim that is rotated may be utilized as a scanner. It should be noted, however, that scanning processes in general might be less efficient the other cutting approaches provided in this specification. Additional scanning patterns for the beam path and laser beam many also be employed to accomplished or address a specific cutting application or tubular configuration in a BOP cavity.
The orbital or other movement of the laser cutters can be accomplished by mechanical, hydraulic and electro-mechanical systems known to the art. For example, the cutters can be mounted to step motors that are powered by batteries, in the BOP, electrical cables from the surface, or both. The step motors may further have controllers associated with them, which controllers can be configured to control the step motors to perform specific movements corresponding to specific cutting steps. Cam operated systems may be employed to move the cutters through a cutting motion or cycle. The cams may be driven by electric motors, hydraulic motors, hydraulic pistons, or combinations of the forgoing, to preferably provide for back-up systems to move the cutters, should one motive means fail. A gearbox, a rack gear assembly, or combinations thereof may be utilized to provide cutter movement, in conjunction with an electric motor, hydraulic motor or piston assembly. The control system may be integral to the cutter motive means, such as a step motor control combination, may be part of the BOP, such as being contained with the other control system on the BOP, or it may be on the rig, or combinations of the forgoing.
The use of the term “completed” cut, and similar such terms, includes severing the tubular into two sections, i.e., a cut that is all the way through the wall and around the entire circumference of the tubular, as well as, cuts in which enough material is removed from the tubular to sufficiently weaken the tubular to ensure that the shear rams are in sealing engagement. Depending upon the particular configuration of the laser shear ram assembly, and the BOP's intended use, a completed cut could be, for example: severing the tubular into two separate sections; the removal of 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 not extending through the wall of the tubular; a number of perforations going completely through the wall of the tubular; a number of slits created in the wall, but not extending through the wall of the tubular; a number of slits going completely through the wall of the tubular; the material removed by the shot patterns disclosed in this specification; or, other patterns of material removal and combinations of the foregoing. It is preferred that the complete cut is made in less than one minute, and more preferable that the complete cut be made in 30 seconds or less.
The rate of the orbital motion can be fixed at the rate needed to complete a cut for the most extreme tubular or combination of tubulars, or the rate of rotation could be variable, or predetermined, to match the particular tubular, or types of tubulars, that will be present in 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 motion can be to complete a cut in the same amount of time. Further, increasing the number of laser cutters decreases the time to complete a cut of a tubular, without having to increase the orbital rate. Increasing the power of the laser beams will enable quicker cutting of tubulars, and thus allow faster rates of orbiting, fewer laser cutters, shorter time to complete a cut, or combinations thereof.
The laser cutters used in the examples and illustrations of the embodiments of the present inventions may be any suitable device for the delivery of high power laser energy. Thus, any configuration of optical elements for culminating and focusing the laser beam can be employed. A further consideration, however, is the management of the optical effects of fluids and materials that may be located within the annulus between the tubular and the BOP inner cavity wall.
Such drilling fluids could include, by way of example, water, seawater, salt water, brine, drilling mud, nitrogen, inert gas, diesel, mist, foam, or hydrocarbons. There can also likely be present in these drilling fluids borehole cuttings, e.g., debris, which are being removed from, or created by, the advancement of the borehole or other downhole operations. There can be present two-phase fluids and three-phase fluids, which would constitute mixtures of two or three different types of material. These drilling fluids can interfere with the ability of the laser beam to cut the tubular. Such fluids may not transmit, or may only partially transmit, the laser beam, and thus, interfere with, or reduce the power of, the laser beam when the laser beam is passed through them. If these fluids are flowing, such flow may further increase their non-transmissiveness. The non-transmissiveness and partial-transmissiveness of these fluids can result from several phenomena, including without limitation, absorption, refraction and scattering. Further, the non-transmissiveness and partial-transmissiveness can be, and likely will be, dependent upon the wavelength of the laser beam.
In an 18¾″ BOP, i.e., the cavity or bore has a diameter of about 18¾,″ depending upon the configuration of the laser cutters and the size of the tubular in the cavity, the laser beam could be required to pass through over 6″ of drilling fluids. In other configurations the laser cutters may be positioned in close, or very close, proximity to the tubular to be cut and moved in a manner where this close proximity is maintained. In these configurations the distance for the laser beam to travel between the laser cutters and the tubular to be cut may be maintained within about 2″, less than about 2″, less than about 1″ and less than about ½″, and maintained within the ranges of less than about 3″ to less than about ½″, and less than about 2″ to less than about ½″.
In particular, for those configurations and embodiments where the laser has a relatively long distance to travel, e.g., greater than about 1″ or 2″ (although this distance could be more or less depending upon laser power, wavelength and type of drilling fluid, as well as, other factors) it is advantageous to minimize the detrimental effects of such borehole fluids and to substantially ensure, or ensure, 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 transmitting the laser beam through such fluids. To this end, mechanical, pressure and jet type systems may be utilized to reduce, minimize or substantially eliminate the effect of the drilling fluids on the laser beam.
For example, mechanical devices such as packers and rams, including the annular preventer, may be used to isolate the area where the laser cut is to be performed and the drilling fluid removed from this area of isolation, by way of example, through the insertion of an inert gas, or an optically transmissive fluid, such as an oil or diesel fuel. The use of a fluid in this configuration has the added advantage that it is essentially incompressible. Moreover, a mechanical snorkel like device, or tube, which is filled with an optically transmissive fluid (gas or liquid) may be extended between or otherwise placed in the area between the laser cutter and the tubular to be cut. In this manner the laser beam is transmitted through the snorkel or tube to the tubular.
A jet of high-pressure gas may be used with the laser cutter and laser beam. The high-pressure gas jet may be used to clear a path, or partial path for the laser beam. The gas may be inert, or it may be air, oxygen, or other type of gas that accelerates the laser cutting. The relatively small amount of oxygen needed, and the rapid rate at which it would be consumed by the burning of the tubular through the laser-metal-oxygen interaction, should not present a fire hazard or risk to the drilling rig, surface equipment, personnel, or subsea components.
The use of oxygen, air, or the use of very high power laser beams, e.g., 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 in the path of the laser beam.
Variable ram preventers could be used in conjunction with oxygen (or air) and laser cutters. Thus, a single variable ram could be used to grasp and seal against a tubular in the BOP cavity. The variable ram would form a small cavity within the rams, when engaged against the tubular, which cavity would surround the tubular. This cavity could then have its pressure reduced to at or near atmospheric, by venting the cavity. Oxygen, or air, (or other gases or transmissive liquids) could be added to the cavity before the laser cutters, which would contained within the rams, are fired. In this manner the variable rams would have laser cutters therein, form an isolation cavity when engaged with a tubular, and provide a means to quickly cut the tubular with minimal interference from drilling fluids. Two variable rams, one above the other may also be used, if a larger isolation cavity is desirable, or if additional space is needed for the laser cutters. Moreover, although the cavity could be vented to at or about atmospheric pressure, an increased pressure may be maintained, to for example, reduce or slow the influx of any drilling fluid from within the tubular as it is being cut.
A high-pressure laser liquid jet, having a single liquid stream, may 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 combination the laser beam may be coaxial with the jet. This configuration, however, has the disadvantage and problem that the fluid jet does not act as a wave-guide. A further disadvantage and problem with this single 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 transmitting the beam.
A compound fluid laser jet may be used as a laser cutter. The compound fluid jet has an inner core jet that is surrounded by annular outer jets. The laser beam is directed by optics into the core jet and transmitted by the core jet, which functions as a waveguide. A single annular jet can surround the core, or a plurality of nested annular jets can be employed. As such, the compound fluid jet has a core jet. This core jet is surrounded by a first annular jet. This first annular jet 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 outer annular jets function to protect the inner core jet from the drill fluid present in the annulus between the BOP cavity wall and the tubular. The core jet and the first annular jet should be made from fluids that have different indices of refraction. In the situation where the compound jet has only a core and an annular jet surrounding the core the index of refraction of the fluid making up the core should be greater than the index of refraction of the fluid making up the annular jet. In this way, the difference in indices of refraction enable the core of the compound fluid jet to function as a waveguide, keeping the laser beam contained within the core jet and transmitting the laser beam in the core jet. Further, in this configuration the laser beam does not appreciably, if at all, leave the core jet and enter the annular jet.
The pressure and the speed of the various jets that make up the compound fluid jet can vary depending upon the applications and use environment. Thus, by way of example the pressure can range from about 3000 psi, to about 4000 psi to about 30,000 psi, to preferably about 70,000 psi, to greater pressures. The core jet and the annular jet(s) may be the same pressure, or different pressures, the core jet may be higher pressure or the annular jets may be higher pressure. Preferably the core jet is higher pressure than the annular jet. By way of example, in a multi-jet configuration the core jet could be 70,000 psi, the second annular jet (which is positioned adjacent the core and the third annular jet) could be 60,000 psi and the third (outer, which is positioned adjacent the second annular jet and is in contact with the work environment medium) annular jet could be 50,000 psi. The speed of the jets can be the same or different. Thus, the speed of the core jet can be greater than the speed of the annular jet, the speed of the annular jet can be greater than the speed of the core jet and the speeds of multiple annular jets can be different or the same. The speeds of the core jet and the annular jet can be selected, such that the core jet does contact the drilling fluid, or such contact is minimized. The speeds of the jet can range from relatively slow to very fast and preferably range from about 1 ms (meters/second), to about 50 m/s, to about 200 m/s, to about 300 m/s and greater. The order in which the jets are first formed can be the core jet first, followed by the annular rings, the annular ring jet first followed by the core, or the core jet and the annular ring being formed simultaneously. To minimize, or eliminate, the interaction of the core with the drilling fluid, the annular jet is created first followed by the core jet.
In selecting the fluids for forming the jets and in determining the amount of the difference in the indices of refraction for the fluids the wavelength of the laser beam and the power of the laser beam are factors that should be considered. Thus, for example for a high power laser beam having a wavelength in the 1080 nm (nanometer) range the core jet can be made from an oil having an index of refraction of about 1.53 and the annular jet can be made from a mixture of oil and water having an index of refraction from about 1.33 to about 1.525. Thus, the core jet for this configuration would have an NA (numerical aperture) from about 0.95 to about 0.12, respectively. Further details, descriptions, and examples of such compound fluid laser jets are contained in Zediker et. al, Provisional U.S. Patent Application Ser. No. 61/378,910, titled Waveguide Laser Jet and Methods of Use, filed Aug. 31, 2010, the entire disclosure of which is incorporated herein by reference. It is to be noted that said incorporation by reference herein does not provide any right to practice or use the inventions of said application or any patents that may issue therefrom and does not grant, or give rise to, any licenses thereunder.
In addition to the use of high power laser beams to cut the tubulars, other forms of directed energy or means to provide the same, may be utilized in the BOP stack. Such directed energy means would include plasma cutters, arc cutters, high power water jets, and particle water jets. Each of these means, 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 damaging to the BOP system components than are these other means. Nevertheless, the use of these others less desirable means is contemplated herein by the present inventions as a directed energy means to cut tubulars within a BOP cavity.
The angle at which the laser beam contacts the tubular may be determined by the optics within the laser cutter or it may be determined by the angle or positioning of the laser cutter itself. In
The laser cutters have a discharge end from which the laser beam is propagated. The laser cutters also have a 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; and potentially beyond.
The angle between the beam path (and a laser beam traveling along that beam path) and the BOP vertical axis, corresponds generally to the angle at which the beam path and the laser beam will strike a tubular that is present in the BOP cavity. However, using a reference point that is based upon the BOP to determine the angle is preferred, because tubulars may shift or in the case of joints, or a damaged tubular, present a surface that has varying planes that are not parallel to the BOP cavity center axis.
Because the angle formed between the laser beam and the BOP vertical axis can vary, and be predetermined, the laser cutter's position, or more specifically the point where the laser beam leaves the cutter does not necessarily have to be normal to the area to be cut. Thus, the laser cutter position or the beam launch angle can be such that the laser beam travels from: above the area to be cut, which would result in an acute angle being formed between the laser beam and the BOP vertical axis; the same level as the area to be cut, which would result in a 90° angle being formed between the laser beam and the BOP vertical axis; or, below the area to be cut, which would result in an obtuse angle being formed between the laser beam and the BOP cavity vertical axis. In this way, the relationship between the shape of the rams, the surfaces of the rams, the forces the rams 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 ability to predetermine the angle that the laser beam forms with the BOP vertical axis provides the ability to have specific and predetermined shapes to the end of a severed tubular. Thus, if the laser beam is coming from above the cutting area an inward taper can be cut on the upper end of the lower piece of the severed tubular. If the laser beam is coming from below the area to be cut an outward taper can be cut on the upper end of the lower piece of the severed tubular. If the laser beam is coming from the same level as the cutting area no taper will be cut on the ends of the severed tubulars. These various end shapes for the severed lower tubular maybe advantageous for attaching various types of fishing tools to that tubular to remove it from the well at some later point in time.
The number of laser cutters utilized in a configuration of the present inventions can be a single cutter, two cutters, three cutters, and up to and including 12 or more cutters. As discussed above, the number of cutters depends upon several factors and the optimal number of cutters for any particular configuration and end use may be determined based upon the end use requirements and the disclosures and teachings provided in this specification.
Examples of laser power, fluence and cutting rates, based upon published data, are set forth in Table I.
The flexible support cables for the laser cutters provide the laser energy and other materials that are needed to perform the cutting operation. Although shown as a single cable for each laser cutter, multiple cables could be used. Thus, for example, in the case of a laser cutter employing a compound fluid laser jet the flexible support cable would include a high power optical fiber, a first line for the core jet fluid and a second line for the annular jet fluid. These lines could be combined into a single cable or they may be kept separate. Additionally, for example, if a laser cutter employing an oxygen jet is utilized, the cutter would need a high power optical fiber and an oxygen line. These lines could be combined into a single cable or they may be kept separate as multiple cables. The lines and optical fibers should be covered in flexible protective coverings or outer sheaths to protect them from borehole fluids, the BOP environment, and the movement of the laser cutters, while at the same time remaining flexible enough to accommodate the orbital movement of the laser cutters. As the support cables near the feed-through assembly the flexibility decreases and more rigid means to protect them can be employed. For example, the optical fiber may be placed in a metal tube. The conduit that leaves the feed-through assembly adds additional protection to the support cables, during assembly of the BOP, handling of the BOP, deployment of the BOP, and from the environmental conditions at the seafloor.
It is preferable that the feed-through assemblies, the conduits, the support cables, the laser cutters and other subsea components associated with the operation of the laser cutters, should be constructed to meet the pressure requirements for the intended use of the BOP. The laser cutter related components, if they do not meet the pressure requirements for a particular use, or if redundant protection is desired, may be contained in or enclosed by a structure that does meet the requirements. Thus, if the BOP is rated at 10,000 psi these components should be constructed to withstand that pressure. For deep and ultra-deep water uses the laser cutter related components should preferably be capable of operating under pressures of 15,000 psi, 20,000 psi or greater. The materials, fittings, assemblies, useful to meet these pressure requirements are known to those of ordinary skill in the offshore drilling arts, related sub-sea Remote Operated Vehicle (“ROV”) art, and in the high power laser art.
In
There is also provided a shield 570. This shield 570 protects the laser cutters and the laser delivery assembly from drilling fluids and the movement of tubulars through the BOP cavity. Is it preferably positioned such that it does not extend into, or otherwise interfere with, the BOP cavity or the movement of tubulars through that cavity. It is preferably pressure rated at the same level as the other BOP components. Upon activation, it may be mechanically or hydraulically moved away from the laser beam's path or the laser beam may propagate through it, cutting and removing any shield material that initially obstructs the laser beam. Upon activation the lasers cutters propagate laser beams (which also may be referred to as shooting the laser or firing the laser to create a laser beam) from outside of the BOP cavity into that cavity and toward any tubular that may be in that cavity. Thus, there are laser beam paths 580, 581, 582, 583, 584, 585, 586, and 587, which paths rotate around center axis 511 during operation.
In general, operation of a laser assisted BOP stack where at least one laser beam is directed toward the center of the BOP and at least one laser cutter is configured to orbit (partially or completely) around the center of the BOP to obtain circumferential cuts, i.e., cuts around the circumference of a tubular (including slot like cuts that extend partially around the circumference, cuts that extend completely around the circumference, cuts that go partially through the tubular wall thickness, cut that go completely through the tubular wall thickness, or combinations of the foregoing) may occur as follows. Upon activation, the laser cutter fires a laser beam toward the tubular to be cut. At a time interval after the laser beam has been first fired the cutter begins to move, orbiting around the tubular, and thus the laser beam is moved around the circumference of the tubular, cutting material away from the tubular. The laser beam will stop firing at the point when the cut in the tubular is completed. At some point before, during, or after the firing of the laser beam, ram shears are activated, severing, displacing, or both any tubular material that may still be in their path, and sealing the BOP cavity and the well.
In
Although eight evenly spaced laser cutters are shown in the example of a fixed laser cutter embodiment in
In the operation of such fixed laser cutter embodiments, the laser cutters would fire laser beams, along beam paths. The beam paths do not move with respect to the BOP. The laser beams would cut material from the tubular substantially weakening it and facilitating the severing and displacement of the tubular by the shear ram. Depending upon the placement of the laser beams on the tubular, the spot size of the laser beams on the tubular, and the power of the laser beam on the tubular, the cutters could quickly sever the tubular into two sections. If such a severing laser cut is made above the shear rams, the lower section of the tubular may drop into the borehole, provided that there is sufficient space at the bottom of the borehole, and thus out of the path of the shear rams, a blind ram, or both. A similar cut, which completely severs the tubular into two pieces, could be made by the orbiting cutter embodiments, for example the embodiment shown in
Turning to
During drilling and other activities tubulars, not shown in
By having the laser delivery assemblies in the rams, such as laser delivery assemblies 741, 742 of the embodiment seen in
Shields for the laser cutters or laser delivery assemblies may also be used with laser ram configurations, such as the embodiment shown in
Turning to
During drilling and other activities tubulars, not shown in
Turning to
During drilling and other activities tubulars, not shown in
In
In
In
In
In
In
Shear ram 1503 is the upper ram, having two sides 1581, 1580, and a mating surface 1508. Shear ram 1502 is the lower ram, having two sides 1583, 1582 and a mating surface 1507. Mating 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, which cables are not shown in this figure. The laser cutters are also essentially evenly spaced with respect to each other and are unevenly spaced across the mating surfaces 1508, i.e., the cutters spacing in relation to the two sides 1581, 1580.
The firing sequence or order of the firing of laser cutters in the configurations shown in
Arrows 1810, 1809 show the direction of movement of the shear rams 1808, 1807 upon activation and engagement with the tubular 1812. The areas of laser removal can be viewed as forming a number of channels or holes in the tubular having an orientation that is parallel to the movement of the rams, which movement is shown by arrows 1810, 1809. By controlling the laser cutters that fire, and the timing and duration of the laser cutter firing, this type of laser delivery pattern can be delivered by, for example, the configurations shown in
In
The body 2201 contains and supports lower shear ram 2202 and upper shear ram 2203, which rams have piston assembly 2205 and 2206 associated therewith. In operation, the piston assemblies 2205, 2206 drive the rams 2202, 2203 toward the center axis 2211, engaging, cutting and moving through tubular 2212, and sealing the cavity 2204, and thus, sealing the well. The body 2201 also has a feed-through assemblies 2213, 2214 for managing pressure and permitting optical fiber cables and other cables, tubes, wires and conveyance means, which may be needed for the operation of the laser cutter, to be inserted into the body 2201. The body, as seen in
The laser delivery assembly 2224 has three laser cutters 2226, 2227 and 2228. Flexible support cables are associated with each of the laser cutters. Flexible support cable 2235 is associated with laser cutter 2226, flexible support cable 2236 is associated with laser cutter 2227 and flexible support cable 2237 is associated with laser cutter 2228. The flexible support cables are located in channel 2250 and enter feed-through assembly 2213. In the general area of the feed-through assembly 2213 the support cables transition from flexible to semi-flexible, and may further be included in conduit 2233 for conveyance to a high power laser, or other sources of materials for the cutting operation.
The laser delivery assembly 2225 has three cutters 2231, 2230, and 2229. Flexible support cables are associated with each of the laser cutters. The flexible support cable 2240 is associated with laser cutter 2231, flexible support cable 2239 is associated with laser cutter 2230 and flexible support cable 2238 is associated with laser cutter 2229. The flexible support cables are located in channel 2251 and enter feed-through assembly 2214. In the general area of the feed-through assembly 2214 the support cables transition from flexible to semi-flexible, and may further be included in conduit 2234 for conveyance to a high power laser, or other sources of materials for the cutting operation.
The members 2618, 2619 may be movable, adjustable and preferably biased, so that as the rams 2602, 2603 engage the tubular 2612, inner surfaces 2622, 2623 engage and remain in contact with the tubular 2612. For example a cam follower may be utilized. In this manner the distance between the laser cutters and the tubular is substantially reduced and kept to a minimum as the laser cutters are moved across the tubular.
Preferably, the beam path(s) may be configured to provide a completed cut at the area where the mechanical forces for the shear rams, the tension that the tubular may be under, or both, are the greatest. In this way, the likelihood that unwanted material may be left in the ram interface to obstruct or inhibit the sealing of the rams is reduced or eliminated. As described herein, other laser cutter placements, firing sequences, shear arrangements, or combinations of thereof, also address this issue of providing greater assurances that the rams enter into sealing engagement.
In this example the amount of material to be removed from a 5″ drill pipe by delivery of a high power laser pattern to the tubular is evaluated. In general the laser pattern is the type shown in
The configurations of and arrangement of the various components in a laser assisted BOP stack provide the capability of many varied sequences of laser cutter firing and activation of ram preventers and annular preventers. Thus, the sequence of laser firings and activations can be varied depending upon the situation present in the well or the BOP, to meet the requirements of that situation. Thus, for example, pipe rams could engage a tubular, laser cutters could sever the tubular without crushing it. In another example, where a casing and a tubular in that cases are in the BOP, the laser cutters could be fired to sever the casing, which then is pulled or dropped away, laser shear rams are then used to sever the tubular and seal the BOP cavity. In yet another example, in a situation where the BOP has for unknown reasons failed to seal off the well, all laser cutters can be repeatedly fired, removing whatever tubular may be obstructing the various rams, permitting the to seal the well. The present inventions provide the ability to quickly provide laser, laser-mechanical, and mechanical cutting and sealing actions in a BOP to address situations that may arise in offshore drilling. As such, the scope of the present inventions is not limited to a particular offshore situation or sequence of activities.
The invention may be embodied in other forms than those specifically disclosed herein without departing from its spirit or essential characteristics. The described embodiments are to be considered in all respects only as illustrative and not restrictive.
