shear laser module and retrofit and use method

专利摘要:
SHEAR LASER MODULE AND RETROFIT AND USE METHOD.It is a high power shear laser module, which can be readily included in a set of eruption preventers. The shear laser module has the ability to deliver high power laser energy to a tubular inside a rash preventer cavity, cut the tubular and then reduce the likelihood that the tubular will inhibit the rash preventer's ability to seal a well.
公开号:BR112013021521A2
申请号:R112013021521-6
申请日:2012-02-24
公开日:2020-09-29
发明作者:Mark S. Zediker；Henry A. Bergeron；Philip V. Clark；Joel F. Moxley；Paul D. Deutch；Charles C. Rinzler
申请人:Foro Energy Inc.；Chevron U.S.A. Inc.；
IPC主号:

专利说明:

Descriptive Report of the Invention Patent for "SHEAR LASER MODULE AND RETROFIT AND USE METHOD". Background of the Invention Field of the Invention 5 The present inventions relate to eruption preventers and, in particular, underwater eruption preventers used for marine exploration and production of hydrocarbons, such as oil and natural gas.
Thus and in particular, the present inventions relate to novel innovative shear laser modules for subsea eruption preventer sets and retrofit methods for existing eruption preventer sets with these shear laser modules and the use of such devices to manage and control offshore drilling activities.
As used in this document, unless otherwise specified, the terms "rash preventer", "BOP" and "BOP set" should give the broadest possible meaning and include: (i) devices positioned on the 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 well bore that are associated with an undersea riser; (iii) devices that have any number and combination of gates, valves or elastomeric plug to control or manage well hole pressures or flows; (iv) a submarine BOP set, such set could contain, for example, drawer shears, tube drawers, blind drawers and annular preventers; and (v) other such similar combinations and assemblies of pressure and flow management devices to control pressures, well bore flows or both and, in particular, to control or manage emergency pressure or flow situations.
As used herein, unless otherwise specified, "offshore" and "offshore drilling activities" and such similar terms are used in their broadest sense and would include
19515881v1 drilling activities on or inside any body of water, fresh or salt water, of natural or artificial occurrence, such as, for example, rivers, lakes, channels, 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 give its broadest possible meaning and would include fixed towers, barges, platforms, ferries, elevations, floating platforms, cargo ships. - drilling, dynamically positioned, semi-submersible and semi-submersible drilling vessels positioned dynamically.
As used in this document, unless otherwise specified, the term "seabed" should give its broadest possible meaning and would include any surface of the earth that is established under or at the bottom of any body of water. , water or fresh or salt, occurring or artificial or natural.
As used in this document, unless otherwise specified, the terms "well" and "well bore" should give their broadest meaning and include any bore that is drilled or otherwise drilled in the land surface , for example, the seabed or seabed and would additionally include exploratory, production, abandoned, re-entered, reworked and injection wells.
As used herein, the term "riser" should give its broadest possible meaning and would include any tubular that connects a platform to, on or above the surface of a body of water, including a marine drilling rig, a floating production, storage and transfer unit vessel ("FPSO") and a floating gas storage and transfer unit vessel ("FGSO"), to a structure at, on or near the seabed for the purposes of activities such as drilling, production, repair, service, well service, intervention and completion.
As used in this document, the term "drill pipe" should give its broadest possible meaning and include all forms of pipe used for drilling activities; and refers to a single section or piece of pipe.
As used in this document
the terms "drill pipe train", "drill pipe train", "pipe train", "train" and terms of a similar type should give the widest possible meaning and include two, three or four drill pipe sections that have been connected, for example, joined together, typically by 5 joints that have threaded connections.
As used in this document, the terms "drill column", "column", "drill pipe column", "tube column" and terms of a similar type should provide their broadest definition and would include a train or trains united for the purpose of being used in a well bore.
Thus, a drill string would include many trains and many hundreds of sections of the drill pipe.
As used in this document, the term "tubular" should give its widest possible meaning and includes drill pipe, housing, riser, spiral pipe, composite pipe, production pipe, vacuum insulated pipe (VIT) and any similar structures that have at least one channel in them that are or could be used in the drilling industry.
As used in this document, the term "gasket" should provide its widest possible meaning and include all types of devices, systems, methods, structures and components used to connect tubulars together, such as, for example, gaskets. threaded tubes and bolted flanges.
For drill pipe joints, the joint section typically looks thicker than the rest of the drill pipe.
As used in this document, the wall thickness of a 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 (meters). As used herein, the term "substantial loss of power", "substantial loss of power" and such similar phrases mean a loss of power of more than about 3.0 dB / km (decibel / kilometer) by one selected wavelength.
As used in this document, the term "substantial power transmission" means at least about 50% transmittance. 5 Description of the Related Technique Deepwater Drilling Marine hydrocarbon exploration and production has been moving into ever deeper waters.
Today, drilling activities at depths of 1.52 km (5,000 feet), 3.05 km (10,000 feet) and even greater depths are contemplated and performed.
For example, it has been reported by RIGZONE, www.rigzone.com, that there are more than 300 rigs rated for drilling in water depths greater than 0.305 km (1,000 ft (feet)) and among these rigs there are more than 190 rigs rated for drilling in water depths greater than 1.52 km (5,000 ft) and among these rigs more than 90 of them are classified for drilling at depths of 3.05 km (10,000 ft). When drilling in these deep, very deep and ultra-deep depths, the drilling rig is subjected to the extreme conditions found in the depths of the ocean, including higher pressures and lower temperatures on the seabed.
In addition, these deep-water drilling rigs can advance well holes that can be 3.05 km (10,000 ft), 6.096 km (20,000 ft), 9.14 km (30,000 ft) and even further below the bottom of the sea.
As such, drilling equipment, such as the drill pipe, housing, risers and the BOP are subjected to substantial forces and extreme conditions.
To cope with these forces and conditions, drilling equipment, for example, the drill pipe and drill columns, is designed to be stronger, more robust and, in many cases, heavier.
In addition, the metals that are used to make the drill pipe and housing have become more malleable.
Typically and by way of general illustration, when drilling an underwater well, an initial well hole is drilled in the seabed and then subsequent wells of smaller diameter are drilled to extend the total depth of the well hole.
Thus, as the total well hole becomes deeper, its diameter becomes smaller; resulting in what can be predicted as a telescopic assembly of the holes with the largest diameter hole being at the top of the well hole closest to the earth's surface.
Thus, as an example, the initial stages of a subsea 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 91.44 cm (36 inch) hole in the ground at a depth of about 0.06 to 0.09 km (200 to 300 feet) below the seabed.
A 76.2 cm (30 inch) housing is inserted into this starting well hole.
This 76.2 cm (30 inch) housing 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 not generally used and debris from the well hole, for example, earth and other material removed from the well hole by drilling activity is returned to the seabed.
Then, a well hole with a diameter of 66.04 cm (26 inches) is drilled into the 76.2 cm (30 inch) housing, extending the depth of the well hole to about 0.305 to 0.457 km (1,000 1,500 feet). This operation can also be carried out without using a riser.
A 50.8 centimeter (20 inch) housing is then inserted into the 76.2 cm (30 inch) conductor and a 66.04 cm (26 inch) well hole. This 50.8 cm (20 inch) housing is cemented in place.
The 50.8 cm (20 inch) housing has a wellhead attached to it. (In other operations, an additional smaller diameter well hole can be drilled and a smaller diameter housing inserted into this well hole with the wellhead being attached to this smaller diameter housing). 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 this point on, all drilling activity in the well bore occurs through the riser and the BOP.
BOP, along with other procedures and equipment, is used to control and manage pressures and flows in a well.
In general, a BOP is a set of several mechanical devices that have a connected internal cavity that extends through these devices.
The tubulars are advanced from the marine drilling rig to the riser, through the BOP cavity and into the well bore.
The returns, for example, debris and drilling mud, are removed from the well bore and transmitted through the BOP cavity to the riser and to the offshore drilling rig.
The BOP set typically has an annular preventer, which is an expandable plug that works like a giant sphincter muscle around a tubular.
Some annular preventers can also be used or can seal the cavity when a tubular is not present.
When activated, this plug seals against a tubular that is in the BOP cavity preventing the 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 a tube drawer preventer and can have more than one of these.
Tube drawer preventers are typically two semi-circles as clamping devices that are driven against the outside diameter of a tubular that is in the BOP cavity.
The tube drawer preventers can be seen as two giant hands that squeeze 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 set, these drawers can seal the cavity when no tubular is present.
Tube drawer preventers and annular preventers can typically only seal the annular space between a tubular in the BOP and the BOP cavity; they cannot seal the tubular.
Thus, in emergency situations, for example, when a "header" (a sudden influx of gas, fluid or pressure into the well bore) occurs or if a potential eruption situation arises, lower bore pressure flows high can come back through the interior of the tubular, from the annular space between the tubular and the riser and even the riser for the drilling rig.
In addition, in emergency situations, annular and drawer 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.
Thus, BOP assemblies include a mechanical shear drawer assembly. (As used herein, unless otherwise specified, the term "shear drawer" would include blind shear drawers, shear seal drawers, shear drawers and any drawer that is intended for or you can cut or shear a tubular.) Mechanical shear drawers are typically the last line of defense for emergencies, for example, headaches or potential eruptions.
The mechanical shear drawers function as gate valves that are supposed to close quickly through the BOP cavity to seal it.
They are intended to cut through any tubular that is in the BOP cavity that would potentially prevent the shear drawer from completely sealing the BOP cavity.
BOP sets can have many different configurations and components, depending on the conditions and hazards that are expected during placement and use.
These components could include, for example, an annular type preventer.
A rotating head, a single drawer preventer with a series of drawers (blind or tube), a double drawer preventer with two series of drawers, a triple drawer preventer with three series of drawers and a spool with connections side outlets for attack and discharge lines.
Examples of the existing configurations of these components could be: a BOP set that has a 17.94 cm (7 1/16 inch) hole and, from bottom to top, a single drawer, a spool, a single drawer, a single drawer and an annular preventer that has a rated working pressure of 34.47 MPa (5,000 psi); a BOP set that has a 34.61 cm (13 5/8 inch) hole and, from the bottom to the top, a spool, a single drawer, a single drawer, a single drawer and an annular preventer and which has a rated working pressure of 68.94 MPa (10,000 psi); and, the set of
BOP that has a hole of 47.62 centimeters (18 3/4 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 and has a rated working pressure of 103.421 MPa (15,000 psi). 5 BOPs need to contain the pressures that could be present in a well, such pressures could be as large as 103.421 MPa (15,000 psi) or greater.
In addition, there is a need for shear drawers that can cut quickly and safely through any tubular, including drill collars, pipe joints and lower hole mounts that may be present in the BOP when a situation emergency situation or other situation in which it is desirable to cut the tubulars in the BOP and seal the well.
With the increasing strength, thickness and malleability of tubulars and particularly drilling tubes in deep, very deep and ultra-deep waters, there has been an increasing need for stronger, more powerful and better shear drawers.
This long-standing need for shear drawers as well as other information on the engineering and physics principles underlying existing mechanical shear drawers are defined in: West Engineering Services, Inc., "Mini Shear Study for U.S.
Minerals Management Services "(Request No. 2-1011-1003, December 2002); West Engineering Services, Inc.," Shear Ram Capabilities Study for U.S.
Minerals Management Services "(Request 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.
Thus, 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 stand at 15.24 m (50 feet) in height or more.
The constantly increasing size and weight of BOPs presents significant problems, 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 manipulate and use these larger and more complicated BOP sets. High Power Laser Beam Driving 5 Prior to the recent progress of co-inventor Dr. Mark Zediker and those who worked with him at Foro Energy, Inc., Littleton CO, it was believed that the transmission of laser energy from high power over great distances without substantial loss of power was impossible to obtain. Its progress in transmitting high-power laser energy, and particularly at power levels greater than 5 kW, are partly defined in the innovative and inventive lessons contained in US 2010/0044106 and 2010 / patent application publications 0215326 and in Rinzler et. al, pending patent application serial number US 12 / 840,978 entitled "Optical Fiber Configurations for Transmission of Laser Energy Over Great Distances" (filed July 21, 2010). The disclosures of these three US patent applications, insofar as they refer to or relate to the transmission of high power laser energy and lasers, cable and fiber structures to carry out such transmissions, are incorporated into the present reference document. It should be noted that this incorporation as a reference in this document does not provide any right to practice or use the inventions of these applications or any patents that they may issue from them and does not grant or originate any licenses under them. The use and application of high-powered lasers to BOP and risers are defined in US Serial No. 13 / 034,175, 13 / 034,017 and 13 / 034,037 patent applications, each filed on February 24, 2011, the entire disclosures of each of which are incorporated by reference in this document.
SUMMARY In drilling operations it has long been desirable to have a BOP that has the ability to quickly and reliably, and in a controlled manner, break through tubulars and seal or otherwise manage the pressure.
are, flow or both from a well.
As the strength of tubular and particularly tubular for deep sea drilling increased, the need for such a BOP continued, grew and became more important.
The present invention, among other things, solves this need by supplying the articles of manufacture, devices and processes taught in this document.
Thus, a set of eruption preventers for land-based operations, maritime-based operations or both with a drawer preventer, an annular preventer and a shear laser module is provided in this document.
The eruption preventer can also be configured in such a way that its annular preventer, gauge preventer and shear laser module have a common cavity that has a geometric cavity axis.
The shear laser module of the eruption preventer set can also have a laser cutter that has a beam path that extends from the laser cutter to the common cavity and in some instances, where the beam path intersects the axis geometric shape.
A shear laser module is also provided for use in a set of eruption preventers, this module has a body, the body that has a first connector and a second connector, the connectors adapted for connection to components in a set of eruption preventers, the body having a cavity to pass tubular, line structures or both through the cavity; and a laser cutter on the body, such a laser cutter has a beam path.
In this way, the beam path can travel from the laser cutter to the cavity and to any tubular that may be in the cavity.
Furthermore, it is determined that the shear laser module and the laser cutter may have a shield located adjacent the cavity, such shield protects the laser cutter from damage to the conditions present in the cavity eruption preventer, such as pressure, temperature , tubular or line structures that move through or rotate within the cavity, debris, hydrocarbons and drilling fluids,
when it does not significantly interfere with the movement of tubulars and other structures or materials through the cavity.
It is further determined that the drawer preventer can be a shear drawer and that the eruption preventer can also have a second annular preventer, a second shear drawer, a first tube drawer, a second tube drawer and a third tube drawer.
In addition, it is determined that the eruption preventer and the laser shear module may have a plurality of laser cutters, which may include a first and a second laser cutter, in which the first laser cutter has a first beam path that extends from the first laser cutter to the cavity, where the second laser cutter has a second beam path that extends from the second laser cutter to the cavity.
In addition, the first, second or both beam paths can intersect within the cavity, can be directed to the geometric axis of the cavity and can intercept the geometric axis of the cavity.
In addition, a first and a second beam path may not intersect within the cavity and they may be substantially parallel, they may form a normal angle with a central geometric axis of the cavity, such an angle may be an angle obtuse with the geometric axis, an acute angle with the geometric axis or be a right angle.
An eruption preventer is also provided in which a second annular preventer, a second shear drawer, a first tube drawer, a second tube drawer and a third tube drawer are present.
It is further determined that the eruption preventer or laser shear module can have the first and second laser cutters that are configured to rotate around the cavity eruption preventer upon activation, orbit at least partially around the cavity during activation and can be positioned outside the cavity or adjacent to the cavity.
In addition, a shearing laser module is provided which has a support cable optically associated with the laser cutter and a through feed assembly mechanically associated with the support cable.
The modules can be rated at an operating pressure of more than 34.47 MPa (5,000 psi), an operating pressure of more than 68.94 MPa (10,000 psi) or an operating pressure of more than 103.421 MPa (15,000 psi). A marine drilling rig is also provided that has a laser assisted underwater eruption drilling system to perform activities near a seabed, the system having a riser that can be lowered and operationally connected to a drilling rig. sea drilling at or near the seabed; an eruption preventer that can be operatively connected to the riser and lowered by the riser of the marine drilling rig to the seabed; the eruption preventer includes a shear laser module and a drawer preventer; the shear laser module includes a laser cutter; a high-powered laser in optical communication with the laser cutter; and since the laser cutter is operationally associated with the eruption preventer and the riser, through which the laser cutter can be lowered to or near the bottom of the sea and upon activation deliver a high laser beam power to a tubular that is inside the eruption preventer.
Additionally, a retrofit method of a pre-existing eruption preventer set ("BOP") is provided with a shear laser module to produce a laser assisted BOP set, the method having the following activities: a set of pre-existing BOP; determine that the pre-existing BOP set does not meet the requirements for a potential intended use; and retrofit the pre-existing BOP set by adding a shear laser module to the pre-existing BOP set; whereby the retrofitted BOP set meets the requirements for the intended use.
In addition, a method is also provided to produce a laser assisted BOP set, in which an annular preventer, a drawer preventer, a shear laser module are obtained and to assemble a BOP set that includes the annular preventer, the drawer and the shear laser module. 5 Additionally, a method is provided for drilling underwater wells by using a laser-assisted eruption preventer and riser, the method including lowering a laser-assisted eruption preventer from a marine drilling rig to the seabed with the use of a riser, in which the riser has an internal cavity and in which the laser-assisted eruption prevention includes a shear laser module that has an internal cavity; attach the eruption preventer to a well hole in the seabed, for example, to a well head, through which the well hole, the shear laser module cavity and the cavity riser are in mechanical and fluid communication; and, where, the shear laser module has the ability to laser cut a tubular present in the laser-assisted eruption preventer cavity.
In addition, a method is provided for drilling underwater wells using a laser-assisted riser and eruption preventer, the method including lowering a laser-assisted eruption preventer, with the assisted eruption preventer by laser includes a shear laser module that has an internal cavity, from a marine drilling rig to the seabed using a riser that has an internal cavity; attach the eruption preventer to a wellhead at the top of a wellbore, through which the wellbore, the shear laser module cavity and the riser cavity are in fluid and mechanical communication; and, advancing the borehole by lowering the tubing of the marine drilling rig down through the riser cavity, the shear laser module cavity and into the well bore; where the shear laser module can laser cut any tubular present in the laser-assisted eruption preventer cavity.
In addition, an underwater Christmas tree is provided
in which it has a mechanical valve and a laser cutter, where the mechanical valve can be a flapper valve or a ball valve.
The underwater Christmas tree may additionally have an external wall configured to be placed adjacent to a BOP cavity wall; 5 an internal wall that defines an internal cavity of the underwater Christmas tree; and internal and external walls that define an annular area between them; wherein the laser cutter is contained substantially within the annular space defined by the inner and outer walls.
In addition, a beam path can be defined between an area adjacent to the operating area for the mechanical valve and the laser cutter.
In addition, a method is provided to perform work in an underwater well by using high-powered laser-assisted technology, including lowering an eruption preventer that has an inner cavity, from a marine drilling rig to a bottom the sea; attaching the eruption preventer to a well hole in the seabed, for example, attaching to a christmas tree or removing the christmas tree and attaching to a well head, through which the well hole and cavi - inner health are in fluid and mechanical communication; position a test underwater Christmas tree inside the cavity eruption preventer that has an internal cavity and includes a laser cutter; and lowering the marine drill rig pipes or line structures down through the internal cavity of the test underwater Christmas tree; where, the test underwater Christmas tree can perform laser cutting of any tubular or line structure present in the internal cavity of the test underwater Christmas tree.
Additionally, an eruption preventer that has a laser shear module that can cut the underwater Christmas tree can also be used.
Brief Description of the Drawings Figure 1 is an illustration of an embodiment of a laser assisted BOP drilling system of the present invention.
Figure 2 is a schematic view of a pre-existing BOP set known in the art.
Figure 3 is a schematic of a first embodiment of a retrofit laser assisted BOP set of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 4 is a schematic of a second embodiment of a 5 Laser-assisted BOP set of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 5 is a schematic of a third embodiment of a laser-assisted BOP set of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 6 is a schematic of a first embodiment of a laser-assisted BOP assembly of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 7 is a schematic of a second embodiment of a laser assisted BOP assembly of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 8 is an illustration of a second modal age of a laser assisted BOP drilling system of the present invention.
Figure 9 is a schematic of a first embodiment of a laser assisted BOP assembly of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 10 is a partial cross-sectional view of a section of a first modality of a shear laser module ("SLM") of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figures 10A, 10B and 10C are seen in cross section of the SLM of Figure 10 taken along the BB line of Figure 10. Figure 11 is a partial cross-sectional view of a section of a second embodiment of an SLM of the present invention to be used with the drilling systems of BOP of Figures 1 and 8. Figure 12 is a partial cross-sectional view of a section of a third embodiment of an SLM of the present invention to be used with the BOP drilling systems of Figures 1 and 8.
Figures 13, 13A and 13B are schematic illustrations of the laser beam trajectories of the present invention.
Figure 14 is a cross-sectional view of a fourth SLM model of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 15 is a cross-sectional view of a farm. modality of an SLM of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Figure 16A is a partial cross-sectional view of a section of a sixth embodiment of an SLM of the present invention a be used with the BOP drilling systems of Figures 1 and 8. Figures 16B, 16C and 16D are seen in cross section of the SLM in Figure 16 taken along the BB line in Figure 16. Figure 17 is a sectional view cross-sectional view of a submarine laser test Christmas tree of the present invention to be used with the BOP drilling systems of Figures 1 and 8. Description of Preferred Modalities In general, the present inventions refer to modules shear laser for assembly s of BOP and a set of BOP that have high power laser beam cutters.
These BOP sets are used to manage the conditions of a well, such as pressure, flow, or both.
Thus, as an example, a modality of a submarine laser-assisted drilling system is shown schematically in Figure 1. In this modality of this drilling system, a dynamically positioned drilling vessel (DP) 100 is provided that has a drilling floor 129, tower 131, a hull window 130 (as seen from the cut in the Figure showing the inside of drilling vessel 100) and other drilling devices and drilling equipment and support used for the operation that are known in marine drilling techniques, but are not shown in the Figure.
The drilling system also has a BOP package and 150 laser-assisted submarine riser. Although a drilling vessel is shown in this modality, any other type of marine drilling rig, vessel or platform can be used. The BOP and submarine riser package assisted by laser 150, as shown in this Figure, is positioned and connecting drilling rig 100 to a well hole 124 that extends below the seabed 5 123. The BOP and laser-assisted riser 150 have a riser 105 and a laser-assisted BOP set 108. The upper portion, that is, the portion of the riser when positioned closest to the water surface 104, of the riser 105, is connected to the drilling vessel 100 by tensioners 103 that are attached to the tension ring 102. The upper section of the riser 105 may have a diverter 101 and other components (not shown in this Figure) that are commonly used and used with risers and are well known to those skilled in the maritime drilling technique. The riser 105 extends from the hull window 130 of the drilling vessel 100 and is connected to the laser-assisted BOP assembly
108. The riser 105 is made up of riser sections, for example, 106, which are connected together by riser couplings, for example, 107 and lowered through the hull window 130 of drilling vessel 100. The lower portion, that is, the riser portion, which when positioned is closest to the seabed, of the riser 105 is connected to the laser-assisted BOP assembly 108 via the riser-BOP 111 connector. The riser connector -BOP 111 is associated with flexible joint 112 which can also be referred to as a flexible connection or ball joint. The flexible joint 12 is intended to accommodate the movements of the drilling vessel 100 from positions that are not directly above the laser assisted BOP assembly 108; and, thus, accommodate the riser 105 coming to the laser assisted BOP assembly 108 at an angle. The laser-assisted BOP assembly can be characterized as having two component assemblies: an upper component assembly 109, which can be referred to as the lower marine riser package (LMRP) and a lower component assembly 110 that it can be referred to as the lower BOP set or the appropriate BOP. In this modality
In fact, the upper component assembly 109 has a frame 113 that houses an annular preventer 115. The lower component assembly 110 has a frame 114 that houses an annular preventer 116, a shear laser module ("SLM") 117, a first drawer preventer 118, a second drawer preventer 119 and a third drawer preventer 120. As used herein, unless otherwise specified, the term "drawer preventer" should provide its broadest definition and would include any mechanical devices that attach, grab, hold, cut, break, crush or crush a tubular within a BOP set, such as shear drawers, blind drawers, blind shear drawers, tube drawers, housing shear drawers and drawer eruption preventers such as Hydril's HYDRIL PRESSURE CONTROL COMPACT Drawer, Hydril Conventional Pressure Control Drawer, HYDRIL PRESSURE CONTROL QUICK-LOG and Re- HYDRIL PRESSURE CONTROL SENTRY, SHAFFER drawer preventers and drawer preventers made by Cameron.
The laser-assisted BOP assembly 108 has a wellhead connector 121 that attaches to the wellhead 122 that is attached to the wellbore 124. The riser has an internal cavity, not shown in Figure 1, which is in communication fluid and mechanical with an internal cavity, not shown in Figure 1, in the laser assisted BOP set.
Thus, as positioned, the BOP and laser-assisted riser package 150 provides a cavity or channel that places drilling vessel 100 in fluid and mechanical communication with the well bore.
The laser assisted BOP assembly frames 113, 114 protect the BOP and may have lifting and handling devices, a control and connection module and other equipment and devices used in subsea operation, which are well known in the art. , but are not shown in the Figure.
The internal cavity in the set passes through the set from its top (closest to the water surface 104) to its bottom (closest to the seabed 123). This cavity, for example, could be about 47.62 centimeters (18 3/4 inches) in diameter and has a cavity wall.
Typically, in deep sea drilling operations a 53.34 cm (21 inch) riser and a 47.62 cm (18 3/4 inch) BOP are used.
The term "53.34 cm (21 inch) riser" is generic and covers risers that have an outside diameter in the overall 53.34 cm (21 inch) range and would include, for example, a riser that has 53 , 97 centimeters (21 1/4 inches) in outside diameter.
The wall thickness for risers from 53.34 centimeters (21 inches) can vary from about 1.59 centimeters (5/8 inches) to 2.22 centimeters (7/8 inches) or more.
Risers and BOPs, however, can vary in size, type and configuration.
The risers can have diameters ranging from about 33.97 centimeters (13 3/8 inches) to about 60.96 centimeters (24 inches). BOPs can have cavities, for example, hole diameters ranging from about 10.58 centimeters (4 1/6 inches) to 67.94 centimeters (26 3/4 inches). The risers can be, for example, conventional tube risers, flexible tube risers, composite tube structures, steel catenary risers ("SCR"), upper tensioned risers, hybrid risers and other types of risers known to those skilled in maritime drilling techniques or later developed.
The use of risers of smaller and larger diameters, different types and configurations of risers, BOPs that have cavities of smaller and larger diameter 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.
During positioning, the BOP-assisted BOP set 108 is attached to riser 105, lowered to the bottom of the sea 123 and attached to a wellhead 122. Wellhead 122 is positioned and attached to a housing (not shown) ), which was cemented into a wellbore 124. From this point on, in general, all drilling activity in the wellbore occurs through the riser and the BOP.
Such drilling activity would include, for example, lowering a column of the drill pipe that has a drill bit at its end of the drill vessel 100 below the interior cavity of riser 105, through the cavity of the associated BOP assembly.
laser-assisted 108 and to the well bore 124. Thus, the drill column would run from the drilling vessel 100 on the surface of the water 104 to the bottom of the well bore, potentially many tens of thousands of feet below the surface of the well. water 104 and seabed 123. Drill bit 5 would be rotated against the bottom of the well hole, while the drilling mud is pumped down from inside the drill pipe and out of the drill bit. The drilling mud would carry the debris, for example, the well-hole material removed by the rotary drill until the annular space between the well-hole wall and the outer diameter of the drilling column, continuing through the annular space between the BOP cavity wall and the outside diameter of the drilling column and continuing through the annular space between the inside diameter of the riser cavity and the outside diameter of the drilling column, until the debris and drilling mud are usually directed by a bell housing (not shown), or in extreme situations a diverter 101 for drilling vessel 100 for handling or processing. Thus, 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 drilling package. BOP and laser assisted riser 150. Now going back to Figure 8, an example of a submarine BOP drilling system assisted by laser 850 is shown. As an example, a laser assisted BOP is provided
800. The 800 laser assisted BOP has an 801 frame, which protects the BOP, has lifting and handling devices (not shown), an 802 control and connection module and other devices and equipment used in subsea operation that are known in offshore drilling techniques, but not shown in the Figure. The laser assisted BOP 800 in this example has an annular preventer 803, an SLM 853, a shear drawer assembly 804 laser, a first drawer tube 805 and a second drawer tube 806. This assembly of preventers and drawers it could also be referred to as a laser-assisted BOP set. The set has a cavity or passage 823 that passes its top 825 (closest to the water surface 824) to its bottom 826 (closest to the bottom of the sea 808). This 823 passageway, for example, could be about 47.62 centimeters (18 3/4 inches). The passage 823 could have a passage wall or cavity 827. 5 The top 825 of the laser-assisted BOP 800 is attached to a riser 816 by a flexible joint 815. The flexible joint 815 which can also be referred to as a flexible connector or ball joint allows the riser 816 to be at an angle to the BOP assisted by laser 800 and thus accommodates some movement of the riser 816 and the drilling probe 818 on the water surface 824. The riser 816 is connected to the drilling probe 818 by riser tensioners 817 and other equipment known to those skilled in marine drilling techniques, but not shown in this Figure.
The drilling rig 818, which in this example is shown as a semi-submersible, but could be any type of platform or device for drilling in or above water, has a hull window 819, a drilling floor 820, a tower 821 and other drilling devices and equipment and drilling support used for the operation that are known in marine drilling techniques, but are not shown in the Figure.
When positioned, as shown in Figure 8, the laser-assisted BOP 800 is attached to riser 816, lowered to the seabed 808 and attached to a wellhead 807. Wellhead 807 is positioned and attached to a housing 814, which was cemented, in a well bore 812 and in a larger diameter housing 811 per cement 812. The larger diameter housing 811 is cemented in a well hole of larger diameter 809 per cement 810. Thus, as a For example, housing 814 may be a 50.8 cm (20 inch) housing and well hole 812 may be a 66.04 cm (26 inch) diameter well hole, housing 811 may be a housing 76.2 centimeters (30 inches) and well bore 809 can be a well hole of 91.44 centimeters (36 inches) in diameter.
From this point on, in general, all drilling activity in the borehole occurs through the riser and the BOP.
In Figures 1 and 8, the riser and the BOP are configured along the lines of a drilling riser BOP package with the BOP positioned on or near the seabed, typically attached to a wellhead, as seen drilling activities. The present 5 laser modules, laser cutters, laser assemblies and laser BOP assemblies of the present inventions have applications to other types of risers, packages and riser-BOP activities, both on land and at sea. Thus, they have applications in relation to drilling, recovery, service, testing, intervention and completion activities. They also have applications to surface BOPs, for example, where the BOP is positioned above the water surface and the riser extends from the BOP to the seabed, where drilling is done in the riser, in that the riser is a production riser and other configurations known or further developed by the technique. Figure 2 shows an example of a pre-existing BOP set. Thus, a set of BOP 200 is shown which has, from top 219 to bottom 220, a flexible joint 201 with connectors 202, 203, an annular preventer 204 with connectors 205, 206, a shear drawer 207 with connectors 208, 209 , a spacer 210 with connectors 211, 212 and a tube drawer 213 and a tube drawer 214 with connectors 215,
216. Connectors, for example, 202, can be any type of connector known or used by those skilled in marine drilling techniques, such as, for example, a flange with bolts that meet the pressure requirements for the BOP . Each of the components, for example, the shear drawer 207, in the BOP 200 assembly has an internal cavity or hole that has a wall that when mounted on the BOP assembly forms an internal cavity 217 that has a wall 218 (shown as imaginary lines in the drawing). As noted in this specification, older BOPs, such as the pre-existing BOP set shown in Figure 2, have increasingly difficult times in cutting the newest and heaviest tubulars that are being used for offshore drilling, and particularly , the tubular ones that are used for drilling deep water, very pro-
deep and ultra deep.
These disadvantages can be overcome by retrofitting these BOPs with the shear laser module of the present invention.
The shear laser modules can be inserted into a pre-existing BOP set.
These modules can deliver the energy of 5 high-power lasers to a tubular that is the BOP set, quickly breaking that tubular.
The shear laser modules can be constructed so that they are smaller and preferably substantially less (distance from top to bottom) than a tube drawer or a shear drawer.
Thus, by adding the laser shear module to the BOP assembly, the total height of the assembly (distance from top to bottom) will not be substantially increased.
The height of the set for a BOP set with the laser shear module will also be substantially less if an added shear drawer has been added to the set.
The shear bond module can also be constructed to be lighter than and, preferably, substantially lighter than a shear drawer.
Thus, adding the shear laser module to the assembly must have a minimal effect on the total weight of the assembly; and it will have a substantially less effect on the total weight of the set than if an additional shear drawer were added to the set.
The high-power laser energy delivered from the shear laser module will be able to cut and break the tubulars found in the BOP at a rate and reliability equal to or better than the shear drawers.
Turning to Figure 3, an example of a retrofitted BOP set is provided.
In Figure 3, the pre-existing BOP set in Figure 2 was retrofitted by adding a shear laser module between two of the pre-existing components in the set (the pre-existing components in Figure 2 have the same numbers in Figure 3). Thus, in Figure 3, a retrofit laser assisted BOP set 300 is provided that has a shear laser module 301 with connectors 302, 303 and that has a laser delivery assembly 309 (which is contained within the module and so shown in imaginary lines). The shear laser module that was inserted between and connected to a pre-existing flexible joint 201 and the pre-existing annular preventer 204. The shear laser module connector 302 being configured to match and attach to or be attached to the flexible joint connector 203 and the shear laser module connector 303 being configured to match and attach to or be attached to the ring preventer connector 205. Turning to Figure 4, an example of a set of retro-adjusted BOP.
In Figure 4, the pre-existing BOP set in Figure 2 was retrofitted by adding a shear laser module between two of the pre-existing components in the set (the pre-existing components in Figure 2 have the same numbers in the Figure 4). Thus, in Figure 4, a set of retrofit laser assisted BOP 400 is provided that has a 401 shear laser module with connectors 402, 403 and that has a 409 laser delivery assembly (which is contained within the module and so shown in phantom lines). The shear laser module that was inserted between and connected to a pre-existing flexible joint 204 and the pre-existing annular preventer 207. The shear laser module connector 402 being configured to match and attach to the preventer connector ring 206 and the shear laser module connector 403 being configured to match and attach to or be attached to the shear drawer connector 208. Turning to Figure 5, an example of a retrofitted BOP set is provided.
In Figure 5, the pre-existing BOP set in Figure 2 has been retrofitted by adding a shear laser module between two of the pre-existing components in the set (the pre-existing components in Figure 2 have the same numbers in the Figure 4). Thus, in Figure 5, a set of retro-adjusted laser assisted BOP 500 is provided that has a 501 shear laser module with connectors 502, 503 and that has a 509 laser delivery assembly (which is contained within the module and so shown in imaginary lines). The shear laser module that was inserted between and connected to the pre-existing shear drawer 207 and the pre-existing spacer 210 and the tube drawer 213
(Spacer 210 was left in the retrofit set 500. It could be removed if the height is a limitation and its removal with the addition of the shear laser module would not adversely affect the operation otherwise.) The module connector shear laser 502 being configured 5 to match and attach to the shear drawer connector 209 and the shear laser module connector 503 being configured to match and attach to the spacer connector 211. In addition to the forging examples for retrofitting BOP sets, other configurations and arrangements are contemplated.
For example, pre-existing drawer shears can be replaced by a shear laser module or multiple shear laser modules, a combination of shear drawers and shear laser modules can be added, a drawer assembly Shear laser can be added, multiple laser modules can be added and background combinations can be made as part of a retrofit process to obtain a BOP set assisted by retrofitted laser.
In addition, larger and newer BOP sets can also benefit from having a shear laser module added to the set components.
The present specification, however, is not limited to retrofitting pre-existing BOPs.
The specification also includes laser-assisted BOP sets, made from pre-existing or new and reconditioned materials or components.
Turning to Figure 6, an example of a modality of a laser assisted BOP set is shown.
Thus, a set of laser assisted BOP 600 is shown which has, from top 619 to bottom 620, a flexible joint 601 with connectors 602, 603, an annular preventer 604 with connectors 605, 606, a shear drawer 607 with connectors 608, 609, a shear laser assembly 621 with connectors 622, 623 (having a laser delivery assembly 624 shown in imaginary lines) and a tube drawer 613 and tube drawer 614 with connectors 615, 616. The connectors, for example, 602 can be any type of connector known or used by those versed in marine drilling techniques, such as, for example, a flange with pins, which meets the pressure requirements for the BOP.
Each of the components, for example, the shear drawer 607, in the BOP assembly 5 600 has an internal cavity or hole that has a wall that when assembled in the BOP assembly forms an internal cavity 617 that has a wall 618 ( shown as imaginary lines in the drawing). Figure 7 shows an example of a laser-assisted BOP set.
Thus, a set of BOP assisted by laser 700 is shown which has, from top 719 to bottom 720, a flexible joint 701 with connectors 702, 703, an annular preventer 704 with connectors 705, 706, a shear laser assembly 721 with connectors 722, 723 (having a laser delivery assembly 724 shown in imaginary lines), a shear drawer 707 with connectors 708, 709, a spacer 710 with connectors 711, 712 and a tube drawer 713, 714 with connectors 715, 716. Connectors, for example, 702 can be any type of connector known or used by those skilled in marine drilling techniques, such as, for example, a flange with dowels, which meets the requirements pressure for the BOP.
Each of the components, for example, the shear drawer 707, in the BOP 700 assembly has an internal cavity or hole that has a wall that when mounted on the BOP assembly forms an internal cavity 717 that has a wall 718 (shown imaginary lines in the drawing). In Figure 9, an example of a laser-assisted BOP set for deepwater operations of 3,048 km (10,000 feet) or more is shown, although this set would also operate and would be useful in shallower depths.
Listing the components of the set type 901 to the bottom of the set 916, the laser assisted BOP set 900 has a flexible joint 903, a ring preventer 904, a shear laser module 905, a ring preventer 906, a shear laser module 907, a shear drawer 908, a shear drawer 909, a shear laser module 910, a spacer 911, tube drawers
912, 913 and tube drawers 914, 915. These components each have holes and when mounted in the assembly, the holes form a cavity (not shown in this Figure) that extends from the top 901 to the bottom 916 of the assembly. The shear laser modules have laser delivery assemblies 5 (not shown in this Figure). The components are connected together with connectors of any type suitable for and that would meet the requirements of marine drilling and for this example in particular that would meet the requirements of marine drilling in ultra-deep waters. The laser-assisted BOP sets of the present inventions 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. Annular preventers may have an expandable obturator that seals against a tubular that is in the BOP cavity preventing material from flowing through the annular space formed between the outer diameter of the tubular and the laser-assisted BOP inner cavity wall . In addition to the shear laser module, laser-assisted BOP assemblies can have drawer preventers. The drawer preventers can be, for example: tube drawers that can have two semicircles as clamping devices that are oriented against the outside diameter of a tubular that is in the BOP cavity; blind drawers that can seal the cavity when no tubular is present, or the same can be a shear drawer that can cut the tubular and seal the BOP cavity; or they can even be a laser shear drawer assembly. In general, laser shear drawer assemblies use a laser beam to cut or weaken a tubular, including drill collars, pipe joints and lower hole assemblies that may be present in the BOP cavity, which are disclosed in patent application No. US 13 / 034,175, filed February 24,
2011.
The submarine BOP drilling systems assisted by laser and, in particular, the shear laser modules 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-powered solid-state lasers, specifically semiconductor lasers and fiber lasers are preferred, because of their short start-up time and essentially instantaneous capabilities.
High power lasers, for example, can be fiber lasers or semiconductor lasers that have 10 kW, 20 kW, 50 kW or more of power, and that emit laser beams with wavelengths preferably in the ranges of about 1,550 nm (nanometer) or 1083 nm.
Examples of preferred lasers, and particularly solid-state lasers, such as fiber lasers, are set out in US patent application publications 2010/0044106 and 2010/0215326 and pending patent application in US series 12 /840,978. The laser or lasers can be located on the offshore drilling rig, above the water surface and connected optically to the BOP at the bottom of the sea via a long distance, high power laser transmission cable, the preferred examples of which are established in US patent application publications 2010/0044106 and 2010/0215326 and in pending patent application US serial 12 / 840,978. The laser transmission cable can be contained in a spool and unwound and attached to the BOP and riser as they are lowered to the bottom of the sea.
Lasers can also be contained in or associated with the BOP frame, eliminating the need for a long distance from the high power optical cable to transmit the laser beam from the water surface to the seabed.
In view of the extreme conditions in which the shear laser modules and the laser shear drawers are required to operate and the need for high reliability in their operation, such a configuration of a laser assisted submarine BOP drilling system is have at least one high power laser located on the marine drilling rig and connected to the BOP by a high power transmission cable and have at least one laser on or associated with the BOP frame on the seabed.
Turning to Figure 11, an example of a modality of a shear laser module ("SLM") that could be used in a laser assisted BOP array is shown. The SLM 1100 has a body 1101. The body 1101 has a first connector 1105 and a second connector 1106. The internal cavity 1104 has an internal cavity wall
1141. A laser delivery assembly 1109 is also provided. The laser delivery assembly 1109 is located on the body 1101. The laser delivery assembly 1109 can be, for example, an annular assembly that surrounds or partially surrounds the internal cavity 1104. This assembly 1109 is optically associated with at least one high power laser source. Turning to Figure 12, an example of a modality of a shear laser module ("SLM") that could be used in a laser assisted BOP assembly is shown. The SLM 1200 has a body 1201. The body 1201 has a first connector 1205 and a second connector 1206. The internal cavity 1204 has an internal cavity wall
1241. A laser delivery assembly 1209 is also provided. The laser delivery assembly 1209 is located on the body 1201. The laser delivery assembly 1209 can be, for example, an annular assembly that surrounds or partially surrounds the internal cavity 1204. This assembly 1209 is optically associated with at least one high power laser source. The SLM also has an 1113 through-feed assembly and a 1138 conduit for transporting a high-powered laser or other material sources for the cutting operation. The embodiment of Figure 12 additionally contains a shield 1214 for the laser delivery assembly 1209. The shield 1214 is positioned inside the body 1201, such that the inner wall or surface 1215 is flush with the cavity wall 1241. In this way, the shield does not form any protrusion or obstruction in the 1204 cavity. The shield can protect the 1209 laser delivery assembly from the drilling fluids. The shield can also manage pressure or contribute to pressure management, for mounting laser delivery
1209. The shield can additionally protect the 1209 laser delivery assembly from the tubular, such as the 1202 tubular, as they are moved through, inside or outside the 1204 cavity. The shield can be made of a material, such as steel or another type of metal or other material, 5 which is both strong enough to protect the 1209 laser delivery assembly and is still cut quickly by the laser beam when it is fired towards the 1202 tube. The shield could also be removed - visible from the beam path of the laser beam.
In this configuration by activating the laser delivery assembly 1209, the shield would be moved away from the beam path.
In the removable shield configuration, the shield would not have to be easily cut by the laser beam.
The SLM also has a 1213 through-feed assembly and a 1238 conduit for transporting a high-powered laser or other material sources for the cutting operation.
During drilling or other activities, tubulars are typically positioned within the internal BOP cavity.
An annular space is formed between the outer diameter of the tubular and the inner cavity wall.
These tubulars have an outside diameter that can vary in size from about 45.72 centimeters (18 inches) to a few centimeters less and, in particular, typically ranges from about 40.74 centimeters (16 2/5 (16 , 04) inches) to about 12.7 centimeters (5 inches) or less.
When the tubulars are present in the cavity, by activating the SLM, the laser delivery assembly delivers the high power laser energy to the tubular located in the cavity.
The high-power laser energy cuts through the tubular allowing the tubular to be completely moved or released from the drawers or annular preventers in the set, allowing the BOP to quickly seal the internal BOP cavity and thus the well without any interference from the tubular.
Although a single laser delivery assembly is shown in the examples of the modalities in Figures 11 and 12, multiple laser delivery assemblies, assemblies of different shapes and assemblies in different positions can be employed.
The ability to make precise and predetermined laser energy delivery patterns for tubulars and the ability to make precise, predetermined cuts in and through the tubulars provide the ability, even in an emergency situation, to break through the tubular without crushing it and to have a predetermined shape for the broken end of the tubular to assist in the subsequent fixing of a finishing tool to recover the broken tubular from the well hole.
Furthermore, 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 the drilling mud or other fluid can be pumped into the well. , by the discharge line associated with the BOP set.
The SLM body can be a single part that is machined to accommodate the laser delivery assembly or it can be made of multiple parts that are clamped together in a way to provide sufficient strength for its intended use and, particularly, to resist pressures of 34.47 MPa (5,000 psi), 68.95 MPa (10,000 psi), 103.42 MPa (15,000 psi), 137.89 MPa (20,000 psi) and greater.
The area of the body that contains the laser delivery assembly can be machined or manufactured in another way to accommodate the laser delivery assembly, while maintaining the strength requirements for the intended use of the body.
The SLM body can also be two or more components or separate parts, for example, one component for the upper half and one for the lower half.
These components could be fastened to each other, for example, by bolted flanges or other suitable fastening means known to one skilled in marine drilling techniques.
The body or a module that makes up the body may have a passageway, passageways, channels or other such structures for conducting fiber optic cables for transmitting the laser beam from the laser source to the body and for 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.
Turning to Figure 10 and Figures 10A to 10C, an example of an SLM modality that could be used in a laser assisted BOP set is shown. Thus, an SLM 1000 is shown which has a body 1001. Body 1001 has two connectors 1006, 1005 to connect to other components of a BOP set, thus allowing the SLM 1000 to be incorporated into or become part of a set of 5 BOP. The body has a cavity 1004, such a cavity has a central geometric axis (dashed line) 1011 and a wall 1041. The cavity of BOP 1004 also has a vertical geometric axis and, in this modality, the vertical geometric axis and the geometric axis center 1011 are the same, which is generally the case for BOPs. (The naming of these axes is based on the BOP configuration and is relative to the BOP structures themselves, not the position of the BOP in relation to the earth's surface. Thus, the vertical geometric axis of the BOP will not change if the BOP, for example , is placed on your side). Typically, the central geometric axis of cavity 1011 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. Body 1001 contains laser delivery assembly 1009. A tubular 1012 is also shown in cavity 1004. Body 1001 also has a through feed assembly 1013 to manage pressure and allow fiber optic cables and other cables, tubes, conduction wires and means, which may be necessary for the operation of the laser cutter, are inserted in the body 1001. The feed assembly 1013 and connects to a conduit 1038 for the conduction of a high power laser or other material sources for the cutting operation. Figures 10A to 10C show cross-sectional views of the modality shown in Figure 10 taken along line B-B of Figure
10. Figures 10A to 10C also show the SLM 1,000 operating sequences, in the cut of tubular 1012. In this embodiment, the laser distribution assembly 1009 has four laser cutters 1026, 1027, 1028, and
1029. The flexible support cables are associated with each of the laser cutters. In this way, the flexible support cable 1031 is associated with the laser cutter 1026, the flexible support cable 1032 is associated with the cutter.
laser painter 1027, flexible support cable 1033 is associated with laser cutter 1028, and flexible support cable 1030 is associated with laser cutter
1029. The flexible support cables are located in channel 1039 and fit into the 1013 through-feed assembly. In the general area of the 1013 through-feed assembly, the transition from flexible to semi-flexible support cables, and can be additionally included in conduit 1038 for transporting high-powered laser or other material sources for the cutting operation. The flexible support cables 1030, 1031, 1032, and 1033 have extra or additional length, which accommodates the orbit of the laser cutters 1026, 1027, 1028 and 1029 around the geometry axis 1011, and around the tubular 1012. Figures 10A to 10C show the SLM activation sequence
1,000 to break a tubular 1012. In this example, the first view (for example, photo capture, since the sequence is preferably continuous rather than staggered or in stages) of the sequence is shown in Figure 10A . As activated, the four laser cutters 1026, 1027, 1028 and 1029 propagate (which can also be referred to as launching or firing the laser to distribute or emit a laser beam from the laser) laser beams that travel 1050 beam paths , 1051, 1052 and 1053. The beam paths 1050, 1051, 1052 and 1053 extend from the laser cutters 1026, 1027, 1028 and 1029 towards the central geometric axis 1011, and thus cross the tubular 1012. The bundles are directed towards the central geometric axis 1011. As such, the bundles are launched from inside the BOP, outside the cavity wall 1041, and travel their respective beam trajectories towards the central geometric axis of the BOP. The laser beams reach the tubular 1012 and start cutting, that is, removal of material from the tubular 1012. If the cavity 1004 is seen as the face of a watch, laser cutters 1026, 1027, 1028 and 1029 could be seen 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 geometric axis 1011, and the tubular 1012. (In this configuration, the laser cutters would also rotate around their own geometric axis as they orbit, and thus, if they moved through a complete orbit in which they would also have moved through a complete rotation.) 5 In the present example, the cutters and beams orbit in a counterclockwise direction, as seen in Figures; however, a clockwise rotation can also be used.
Thus, as seen in the next view of the sequence, Figure 10B, the laser cutters, 1026, 1027, 1028 and 1029 rotated at 45 degrees, with laser beams that traverse beam paths 1050, 1051, 1052 and 1053 having cut through four sessions of 1/8 (that is, a total of half) of the circumference of the tubular 1012. Figure 10C then shows the cutter having moved through a quarter turn.
In this way, cutter 1026 could be seen as having moved from the 12 o'clock to the 9 o'clock position, with the other cutters having similarly moved their respective clock face positions.
In this way, moving through a quarter turn, the beam paths 1050, 1051, 1052 and 1053 would have crossed the entire circumference of the tubular 1012 and the laser beams that travel along these beam paths would break the tubular.
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, during or before the laser cutters are triggered, the tube drawers, the annular preventer or a separate clamping device must be activated to prevent vertical movement of the tube during the laser cutting operation.
The separate fixture could also be contained in the SLM.
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 tube to be cut, the thickness of the tube to be cut, and the rate at which the laser cuts the tubular.
The rate of orbital motion must be slow enough to ensure that the intended cuts are completed.
In addition to orbit cutters, the laser beam can be scanned, for example, moved in a pattern similar to ventilation.
In this way, the beam path would be swept along the area to be cut, for example, 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 completed, for example, by moving the cutter back and forth around a fixed point, for example, similar to the movement of an oscillating ventilation.
This can be accomplished by having optics contained within the cutter that sweeps the beam path, for example, a laser scanning reader, and thus the laser beam in a pattern similar to ventilation.
For example, a multi-sided or primary mirror that is rotated can be used as a scanner.
It should be noted, however, that scanning processes, in general, may be less efficient than the other cutting approaches provided in this specification.
Additional scanning patterns for the beam path and laser beam can also be employed to complete or direct a specific cut application or tubular configuration in a BOP cavity.
The orbital or other movement of the laser cutters can be completed by mechanical, hydraulic or electromechanical systems known in the art.
For example, cutters can be mounted on stepper motors that are powered by batteries, the BOP, surface electrical cables or both.
Stepper motors can additionally have controllers associated with them, whose controllers can be configured to control stepper motors to perform specific movements that correspond to specific cutting steps.
Cam-operated systems can be used to move the cutters through a cutting motion or cycle.
The cams can be driven by electric motors, hydraulic motors, hydraulic pistons or combinations of the preceding ones, to preferably provide support systems to move the cutters in case a half reason fails.
A gear box, rack gear assembly or combinations of the same can be used to provide cutter movement, in conjunction with an electric motor, hydraulic motor or piston assembly.
The control system can be integral to the motif cutter, such as a stepper motor control combination, it can be part of the BOP, such as being contained with the other control system in the BOP, or it can be in the 5 or combinations of precedents.
The use of the term "complete" cut, and such similar terms, includes breaking the tubular into two sections, that is, a cut that occurs across the entire wall and around the entire circumference of the tubular, as well as cuts in the which enough material is removed from the tubular to sufficiently weaken the tubular to ensure that the shear drawers are in sealing engagement.
Depending on the particular configuration of the SLM, the laser-assisted BOP set, and the intended use of the BOP, a complete cut could be, for example: breaking the tubular into two separate sessions; 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 not extending through the wall of the tubular; a number of perforations that runs completely through the tubular wall; a number of cracks created in the wall, but not extending through the wall of the tubular; a number of slits that follow completely through the tubular wall; the material removed by the thrown patterns revealed in this specification; or, other terms of material removal and combinations of the foregoing.
It is preferable that the complete cut is done in less than a minute, and it is more preferable that the complete cut is done in 30 seconds or less.
The rate of orbital motion 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 be compatible with the particular tubular or tubular types, which will be present at the BOP during a particular drilling operation.
The greater the number of laser cutters in a rotating laser distribution assembly, the lower the rate of orbital motion can be to complete a cut in the same amount of time.
Besides that,
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 allow for faster tubular cutting, and thus allows for faster orbit rates, less laser cutters, 5 less time to complete a cut or combinations thereof.
The laser cutters used in the examples and illustrations of the modalities of the present inventions can be any device suitable for the distribution of high power laser energy.
In this way, any configuration of optical elements to culminate and focus the laser beam can be employed.
An additional consideration, however, is the management of the optical effects of fluids and materials that can be located within the annular space between the tubular and the internal BOP cavity wall.
Such drilling fluids could include, for example, water, sea water, salt water, brine, drilling mud, nitrogen, inert gas, diesel, fog, foam or hydrocarbons.
They may be likely to be present in such drilling fluid well drilling fluid, for example, debris, which must be removed from the wellhole advance or other downhole operations or created by same Two-phase fluids and three-phase fluids may be present, which would be mixtures of two or three different types of material.
These drilling fluids can interfere with the laser beam's ability to cut through 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 a flow can further increase its non-transmission capacity.
The non-transmission capacity and partial transmission capacity of these fluids can result from several phenomena, including without limitation, absorption, refraction and dispersion.
In addition, the non-transmission capacity and partial transmission capacity can be, and will probably be dependent on, the laser beam wavelength.
In a 47.625 cm (18 3/4 ") BOP, that is, the cavity has a diameter of approximately 47.625 cm (18 3/4) depending on the configuration of the laser cutters and the size of the tubular in a cavity, the laser beam could be required to pass through more than 15.24 cm (6 ") of drilling fluids.
In other configurations, laser cutters can be positioned in great or very close proximity to the tubular to be cut and moved in such a way that this great proximity is maintained.
In these configurations, the distance for the laser beam to travel between the laser cutters and the tubular to be cut can be kept within 5.08cm (2 "), less than about 5.08cm (2") , less than about 2.54cm (1 ") and less than about 1.27cm (1/2"), and kept within bands of less than about 7.62cm (3 ") at less than about 1.27cm (1/2 "), and less than about 5.08cm (2") less than about 1/2 ". In particular, for these configurations and modalities in which the laser has a relatively long travel distance, for example, greater than about 2.54 cm (1 ") or 5.08 cm (2") (although this distance could be more or less depending on the laser power, wavelength and type of drilling fluid, as well as other factors) it is advantageous to minimize the damaging effects of such well bore fluids and to substantially guarantee or guarantee that such fluids will 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.
To that end, mechanical, pressure and jet systems can be used to reduce, minimize or substantially eliminate the effect of drilling fluids on the laser beam.
For example, mechanical devices such as packers and drawers, including the annular preventer, can be used to isolate the area where the laser cutting is to be performed and the drilling fluid removed from that isolation area, by way of example, by inserting an inert gas or an optically transmissible fluid, 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 mechanical snorkel similar to a device or tube, which is filled with an opti- cally transmissive fluid (gas or liquid) can be extended between the area between the laser cutter and the tubular to be cut or otherwise. mode placed in it 5.
In this way, the laser beam is transmitted through the snorkel or tube to the tubular.
A high pressure gas jet can be used with the laser cutter and laser beam.
The high pressure gas jet can be used to clear a path or partial path for 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 small amount of oxygen required, and the rapid rate at which it would be consumed by burning the tubular through the laser-metal-oxygen interaction, if it does not present a fire hazard or risk to the drilling rig, surface equipment, personal or marine components.
The use of oxygen, air or the use of many high-powered laser beams, for example, larger than about 1 kW, could create and maintain a plasma bubble or the gas bubble in the cutting area, which could am partially or completely displacing the drilling fluid along the laser beam path.
A high pressure laser liquid jet that has a single liquid stream can be used with the laser cutter and laser beam.
The liquid used for the jet must be transmissive or at least substantially transmissive to the laser beam.
In this type of jet beam laser combination, the laser beam can be coaxial to the jet.
This configuration, however, has the disadvantage and problem of the fact that the fluid jet does not act as a waveguide.
An additional 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 means to transmit the beam.
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 guided by optics in the core jet and transmitted by the core jet, which functions as the waveguide.
A single annular jet may involve the nucleus or a plurality of nested annular jets may be employed.
As such, the fluid stream of compound has a core stream.
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 external annular jets work to protect the internal core jet from the drilling fluid present in the annular space between the cavity and tubular BOP wall.
The core stream and the first annular stream must be made of fluids that have different refractive indices.
In the situation where the compound jet has only one core and an annular jet that surrounds the core, the refractive index of the fluid that makes up the core must 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 composite fluid stream to act as a waveguide that keeps the laser beam contained within the core stream and transmits the laser beam in the core stream.
Furthermore, in this configuration, the laser beam does not significantly leave, if at all, the core jet 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 usage environment.
Thus, by way of example the pressure can vary from about 20.68 Mpa (3,000 psi), to about 27.57 Mpa (4,000 psi) to about 206.84 Mpa (30,000 psi), preferably about 482.63 Mpa (70,000 psi), at higher pressures.
The core jet and annular jet (s) can be of the same pressure or different pressures, the core jet can be of higher pressure or the annular jets can be of higher pressure.
Preferably the core jet has a higher pressure than the annular jet.
For example, in a multiple jet configuration, the core jet can be 482.63 Mpa (70,000 psi), the second annular jet (which is positioned adjacent to the core and the third annular jet) could be 413.68
Mpa (60,000 psi) and the third annular jet (external, which is positioned adjacent to the second annular jet and is in contact with the working environment) could be 344.73 Mpa (50,000 psi). The speed of the jets can be the same or different.
In this way, the speed of the core jet 5 may be greater than the speed of the annular jet, the speed of the annular jet may be greater than the speed of the core jet and the speeds of multiple annular jets may be different or the same.
The speeds of the core jet and annular jet can be selected so that the core jet does not come into contact with the drilling fluid or such contact is minimized.
Jet speeds can range from relatively slow to very fast and preferably range from about 1 ms (meters / second) to about 50 m / s, about 200 m / s, about 300 m / s more 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 that is 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.
When selecting fluids to form the jets and determining the amount of difference in the refractive indices for fluids, the laser beam wavelength and the laser beam power are factors that must be considered.
Thus, for example, for a high-powered laser beam that has a wavelength in the range of 1080 nm (nanometer), the core 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. Thus, the core jet for this configuration would have an NA (numerical aperture) of about 0.95 to about 0.12, respectively.
In addition, details, descriptions, and examples of such compound fluid laser jets 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 entire disclosure of which is incorporated into this document as a reference.
It should be noted that said incorporation by way of reference to this document does not provide any right to practice or use the inventions of said application or any patents that may result from it and does not grant or originate any licenses under them. 5 Laser cutters have a discharge end from which the laser beam is propagated.
Laser cutters also have a beam path.
The beam path is defined by the path 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.
Preferably, the beam path (s) can be configured to provide a complete cut in the area where the mechanical forces for the shear drawers, the stress to which the tubular may be subjected or both, are the largest.
In this way, the likelihood that unwanted material can be left at the drawer interface to obstruct or inhibit the drawer seal is reduced or eliminated.
As described in this document, other laser cutter inserts, firing sequences, shear arrangements or combinations thereof, can address this problem of providing greater guarantees that the drawers engage in sealing engagement. .
The angle at which the laser beam comes into contact with the tubular can be determined by the optics inside the laser cutter or it can be determined by the angle or position of the laser cutter itself.
In Figure 13, a schematic representation of a laser cutter 1300 with the beam path 1301 that leaves the cutter at various angles is shown.
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 vertical geometric axis of the BOP cavity (dotted line) 1311. As seen in the enlarged views of Figures 13A and 13B, the angle that the beam path 1301 forms with the vertical geometric axis 1311, and thus, the angle that a laser beam travels along that beam path if it forms with the vertical axis 1311, it can be an acute angle 1305 or an obtuse angle 1306 in relation to the portion of the axis 2311 furthest from the wellhead connection side 1310. A normal or 90 angle can also be be used.
The BOP 1310 wellhead connection side is shown in the Figures as a reference point for the 5 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 geometric axis of BOP, generally corresponds to the angle at which the beam path and the laser beam will reach a tubular that is present in the BOP cavity.
However, the use of a reference point that is based on the BOP to determine the angle is preferred, due to the fact that the tubulars can change or, in the case of joints or a damaged tubular, have a surface that has varying planes that are not parallel to the central geometric axis of the BOP cavity.
Due to the fact that the angle formed between the laser beam and the vertical geometric axis of BOP can vary and be predetermined, the position of the laser cutter or, more specifically, the point at which the laser beam leaves the cutter it does not necessarily have to be normal to the area to be cut.
In this way, 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 would result in an acute angle that is formed between the laser beam and the vertical geometric axis of BOP; the same level as the area to be cut, which would result in an angle of 90 ° that is formed between the laser beam and the vertical geometric axis of BOP; or below the area to be cut, which would result in an obtuse angle that is formed between the laser beam and the vertical geometric axis of the BOP 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 ability to predetermin the angle that the laser beam forms with the vertical geometric axis of BOP provides the ability to have specific predetermined shapes at the end of a broken tubular.
In this way, if the laser beam comes from above the cutting area, an inward-facing cone can be cut at the upper end of the lower part of the broken tubular.
If the laser beam comes from below the area to be cut, an outward-facing cone can be cut at the upper end of the lower part of the broken tube.
If the laser beam comes from the same level as the cutting area, no cone will be cut at the ends of the broken tubes.
These various end shapes for the broken bottom tubular may be advantageous for attaching various types of fishing tools to the tubular to remove it from the well at some later point in time.
The number of laser cutters used 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 on several factors and the ideal number of cutters for any particular configuration and end use can be determined based on the requirements for end use and the revelations and teachings provided in this specification. .
Examples of laser power, creep and cut rates, based on published data, are shown in Table I.
Table I Type Thickness Power Gas Flow Size Rate (mm) of laser point (micron of (watts) crons) (MW / cc²) cutting Steel 15 5,000 300 7.1 O2 1.8 mild Steel innocuous 15 5,000 300 7.1 N2 1.6 xiable The flexible support cables for laser cutters provide the laser energy and other materials that are necessary to carry out 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 that employs a flowing laser jet,
the composite 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 with the single cable or they could be kept separate.
Additionally, for example, if a laser cutter that employs an oxygen jet hurts used, the cutter would need a high-powered optical fiber and an oxygen line.
These lines could be combined with a single cable or they could be kept separate as multiple cables.
The lines and optical fibers must be covered in flexible protective covers or outer layers to protect them from well-hole fluids, the BOP environment and the movement of laser cutters, while at the same time maintaining sufficient flexibility to accommodate orbital movement. of laser cutters.
Depending on the support cables close to the supply assembly that cross them to decrease flexibility and more rigid means to protect them, they can be used.
For example, the optical fiber can be placed in a metal tube.
The conduit that leaves the feed assembly through adds additional protection to the support cables, during the assembly of the SLM, the BOP assembly, handling of the BOP, handling of the SLM, use of the BOP, and environmental conditions at the bottom of the sea .
It is preferable that the feed-through assemblies, ducts, support cables, laser cutters and other marine components associated with the operation of laser cutters, must be built to meet the pressure requirements for the intended use of the BOP.
Components related to laser cutters, if they do not meet the pressure requirements for a particular use or if redundant protection is desired, can be contained or closed by a structure that meets the requirements.
Thus, if the BOP is rated at 68.94 Mpa (10,000 psi) these components must be built to withstand that pressure.
For uses in deep and ultra deep water, components related to the laser cutter should preferably be able to operate under pressures of 103.42 Mpa (15,000 psi), 137.89 Mpa (20,000 psi) or greater. The materials, fittings, assemblies, useful to meet these pressure requirements are known to those of common skill in marine drilling techniques, related to the Submarine Remote Operated Vehicle ("ROV") technique, and the high power laser technique art. 5 In Figure 14, an example of an SLM modality that could be used in a laser assisted BOP set is shown. In this way, an SLM 1400 is shown which has a body 1401. The body has a cavity 1404, whose cavity has a central geometric axis
1411. The 1401 body also has a 1413 through-feed assembly to manage pressure and allow fiber optic cables and other cables, tubes, wires and means of transport, which may be required for the operation of the laser cutter, the be inserted into body 1401. The body houses a laser distribution assembly 1409. The laser distribution assembly 1409 has eight laser cutters 1440, 1441, 1442, 1443, 1444, 1445, 1446 and 1447. Flexible supports are associated with each of the laser cutters. The flexible support cables are long enough to accommodate the orbit of the laser cutters around the central axis 1411. In this mode, cutters only need to follow through 1/8 of a complete orbit to orbit a cut around the entire circumference of a tubular. The flexible support cables are located in a channel and between the through feeder assembly
1413. Through-feed assembly has pressure rated at the same level as the BOP, and therefore must be able to withstand pressures of 34.47 Mpa (5,000 psi), 68.94 Mpa (10,000 psi), 103.42 Mpa ( 15,000 psi), 137.89 Mpa (20,000 psi) and greater. In the general area of the 1413 through-feed assembly, the support cables change from flexible to semi-flexible and can be additionally included in the conduit 1438 for transport to a high power laser or other sources. A 1470 shield is also provided. This 1470 shield protects laser cutters and the laser distribution assembly from drilling fluids and tubular movement through the BOP cavity. It is preferably positioned so that it is not
tend to the BOP cavity or the movement of tubulars through that cavity or otherwise interfere with them.
It preferably has pressure rated at the same level as the other BOP components.
Upon activation, it can be mechanically or hydraulically removed from the laser beam path, or the laser beam can be launched through it, cutting and removing any shield material that initially obstructs the laser beam.
Upon activation, the laser cutters launch laser beams from outside the BOP cavity into that cavity and towards any tubular that may be in that cavity.
In this way, there are the laser beam trajectories 1480, 1481, 1482, 1483, 1484, 1485, 1486, and 1487, whose trajectories revolve around the central geometric axis 1411 during the 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 completely) around the center of the BOP to obtain circumferential cuts, that is, cuts around the circumference of a tubular (including slit-like cuts that partially extend around the circumference, cuts that extend completely around the circumference, cuts that partially follow through the tubular wall thickness, cut that completely follow through the tubular wall thickness or combinations of the foregoing) can occur as follows.
Upon activation, the laser cutter fires a laser beam towards the tubular to be cut.
In a period of time, after the laser beam was first fired, the cutter starts to move, orbiting around the tubular, and in this way, the laser beam moves around the circumference of the tubular, cutting the tubular material.
The laser beam will stop firing at the point where the cut in the tubular is completed.
At some point before, during or after the firing of the laser beam, shear shears are activated, breaking, displacing or both any tubular material that may still be in its path, and sealing the BOP cavity and the well.
Figure 15 shows an example of an SLM modality, which has fixed laser cutters, for use in a laser-assisted BOP set. In this way, an SLM 1500 is shown that has a body
1501. The body has a cavity 1504, in which the cavity has a central geo-5 metric axis 1511. The body 1501 also has a through feeder assembly 1513 to manage pressure and allow fiber optic cables and others cables, tubes, wires and means of transport, which can be inserted for operation of the laser cutter, to be inserted in the body 1501. The body houses a 1509 laser distribution assembly. The 1509 laser distribution assembly has eight cutters a laser 1540, 1541, 1542, 1543, 1544, 1545, 1546 and 1547. 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 across the 1511 central geometric axis. Support cables 1550, 1551, 1552, 1553, 1554, 1555, 1556 and 1557 are associated with each of the 1540, 1541, 1542, 1543, 1544, 1545, 1546 and 1547 laser cutters respectively. The support cables in this modality do not need to accommodate the orbit of the laser cutters around the central geometric axis 1511, due to the fact that the laser cutters are fixed and do not orbit. In addition, due to the fact that the laser cutters are attached, the support cables 1550, 1551, 1552, 1553, 1554, 1555, 1556 and 1557 can be semi-flexible or grooved and the entire assembly 1509 can be contained within of an epoxy of the protective material. The support cables are located in a channel and enter the 1513 bypass feed assembly. The bypass feed assembly has pressure rated at the same level as the BOP, and therefore must be able to withstand pressures of 34.47 Mpa (5,000 psi), 68.94 Mpa (10,000 psi), 103.42 Mpa (15,000 psi), 137.89 Mpa (20,000 psi) and greater. In the general area of the 1513 through-feed assembly, the support cables change from flexible to semi-flexible, and can be additionally included in the 1538 conduit for transport to a high-power laser or other sources. A shield, such as shield 1470 in Figure. 14, can also be used with these and other modalities, but it is not shown in this figure.
Although eight evenly spaced laser cutters are shown in the example of a laser cutter mode fixed in the Figure. 15, other configurations are contemplated.
Less or more laser cutters can be used.
The cutters can be positioned so that their respective laser beam trajectories are parallel or at least non-crossing within the BOP, instead of radially crossing each other, as would be the case of the modality shown in the Figure. 15. When operating such fixed laser cutter modes, laser cutters would fire laser beams along beam paths.
The beam paths do not move in relation to the BOP.
The laser beams would cut the material from the tubular, substantially weakening it and facilitating the partition and displacement of the tubular through the shear drawer.
Depending on the displacement of the laser beams in the tubular, the spot size of the laser beams in the tubular, and the power of the laser beam in the tubular, cutters could quickly break the tubular in two sessions.
If such a laser partition cut is made above the shearing drawers, the bottom section of the tubular may fall into the well hole, provided there is enough space at the bottom of the well hole, and thus out of work. shear drawers, a blind drawer, or both.
A similar cut, which completely breaks the tubular into two pieces, could be made using the cutting and orbit modes.
Having the laser distribution assemblies and in particular the laser cutters on the extendable arms or pistons the distance of the laser beam path through any drilling fluids can be greatly reduced if not eliminated.
In this way, the firing of the laser beam can be delayed until the laser cutters move close, very close or touch the tube to be cut.
In Figures 16A to 16D an example of an SLM modality that could be used in a laser assisted BOP set is shown.
In this way, an SLM 1600 is shown which has a body 1601. The body has a cavity 1604, in which the cavity has a central geometric axis 1611 and a wall 1641. The BOP cavity also has a vertical geometric axis and in this modality the vertical geometric axis and central geometric axis are the same, which is generally the case for BOPs. (The designation of these geometric axes is based on the BOP configuration and is relative to the BOP structures themselves, not the position of the BOP in relation to the earth's surface. Thus, 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 1611 of cavity 1604 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 hole well. Body 1601 has feedthrough assemblies 1613, 1614 to manage pressure and allow fiber optic cables and other cables, tubes, wires and transportation means, which may be required for the operation of the laser cutter, to be inserted into the body 1601. The body, as seen in Figures 16B-D, houses two laser distribution assemblies 1624, 1625. Body 1601 also contains positioning devices 1620, 1621 that are associated with piston assemblies 1622, 1623 , respectively. Figures 16B to 16D are seen in cross-section of the fashion shown in Figures 16A taken along line B-B of Figure 16A and show the SLM 1600 operating sequences, when cutting the tubular
1612. In Figures 16B to 16D, additional details of the laser distribution assemblies 1624, 1625 of SLM 1600 are also shown. In this embodiment, both laser assemblies 1624, 1625 could have similar components and configurations. However, laser assemblies 1624, 1625 could have different configurations and more or less laser cutters. The 1624 laser distribution assembly has three laser cutters 1626, 1627 and 1628. Flexible support cables are associated with each of the laser cutters. The flexible support cable 1635 is associated with the laser cutter 1626, the flexible support cable 1636 is associated with the laser cutter 1627 and the flexible support cable 1637 is associated with the laser cutter 1628. The support cables flexible are located in the
nal1650 and enter the 1613 through-feed assembly. In the general area of the 1613 through-feed assembly, the support cables can change from flexible to semi-flexible. However, in this modality and similar modalities, the cutters do not move, there is no need for the cutters to be flexible. The cables and can be additionally included in the 1633 conduit for transporting the high power laser or other material sources for the cutting operation. The 1625 laser distribution assembly has three cutters 1631, 1630, and 1629. Flexible support cables are associated with each of the laser cutters. The flexible support cable 1640 is associated with the laser cutter 1631, flexible support cable 1639 is associated with the laser cutter 1630 and the flexible support cable 1638 is associated with the laser cutter
1629. The flexible support cables are located in channel 1651 and fit into the 1614 through-feed assembly. In the general area of the 1614 through-feed assembly, the support cables can change from flexible to semi-flexible. However, in this modality and in similar ways the cutters do not move, there is no need for the cutters to be flexible. The cables can be additionally included in the 1634 conduit for transport to a high-powered laser or other material sources for the cutting operation. Figures 16B to 16D show the activation sequence of positioning pins 1620, 1621 to break a tubular 1612. In this example, the first view (for example, photo capture, provided that the sequence is preferably continuous rather than staggered or in stages) of the sequence is shown in the Figure. 16B. As activated, the six laser cutters 1626, 1627, 1628, 1629, 1630, and 1631 launch or fire laser beams towards the tubular to be cut. In this example, laser cutters are configured so that the beam paths 1660 to 1605, 1661 to 1664, 1662 to 1663 are parallel to the beam paths of the laser cutters on the other side of cavity 1604. The beam paths and thus, the laser beams, although not configured like the spokes of a wheel, are still directed in the cavity 1604, generally towards the central geometric axis 1611, with beam paths 1661, 1664 that cross the central geometric axis 1611. In addition, in this example the beam trajectories are configured to be collinear, however, they could also be staggered.
As such, the bundles are launched from the 5 inside the BOP, from outside the cavity wall 1641, and travel towards the tubular 1612. The laser beams reach the tubular 1612 and begin cutting, that is, remove material from the tubular 1612. Upon activation, the laser cutters start firing their respective laser beams, at about the same time as the positioning drawers 1620, 1621 engage the tubular 1612 and move the tubular 1612 through the laser beams fixed in the direction to the left of cavity 1604 (as shown in the figure) the positioning drawers 1620, 1621 from which the tubular 1612 moves through the laser beams fixed towards the right side of cavity 1604 (as shown in the figure). In this way, the tubule to be cut moves back and forth through the laser beams.
It should be understood that as the number of laser cutters used increases, the amount of tubular movement can be reduced or eliminated.
In addition to finding applications in a set of BOP and risers and in association with them, high-power laser assemblies and cutters have applications in underwater well intervention equipment and procedures and in association with them, including tools and assemblies end of an underwater well, for example, underwater Christmas trees.
Test underwater Christmas trees (as used in this document, underwater Christmas tree should be given its widest possible meaning and include, ending Christmas trees, and other assemblies that perform similar activities) have many applications, and they are fully used in conjunction with a surface vessel to conduct operations such as completion, flow testing, intervention, and other subsea well operations.
Christmas trees are typically connected to a surface vessel by means of a column of tubulars.
In general, during and after the completion of a well, occurrences or situations may arise in which it is necessary to enter, re-enter the well borehole with test equipment, cleaning or other types of equipment or instruments.
This can typically be accomplished by placing a BOP or a lower marine riser package (LRP) and an emergency disconnect package (EDP) in the well.
Thus, typically, when dealing with a well that has a vertical "Christmas tree", which is the assembly of valves, coils, pressure gauges and / or regulators fitted to the wellhead of the completed well to control production, the vertical Christmas tree will be removed and the BOP fixed to the wellhead.
When dealing with horizontal and enhanced horizontal and vertical Christmas trees, the Christmas tree can typically be left in place, remaining safe at the wellhead and the BOP (or LRP / EDP) secure to the Christmas tree.
In general, when the test underwater Christmas tree performs underwater operations, the test underwater Christmas tree is extended into the internal cavity of the BOP and positioned inside it.
The external diameter of the test underwater Christmas tree is slightly smaller than the internal cavity of a BOP.
Thus, for a 18 3/4 inch BOP, a typical underwater test Christmas tree will have an outside diameter of about 18 1/2 inches.
Such an underwater Christmas tree could have an internal diameter or internal cavity, of about 7 1/3 inches.
The test underwater Christmas tree has, in addition to the other external ports and valves, two valves that are designed to control well bore pressures, flows or both and, in particular, to control or manage emergency flow or emergency situations. pressure.
In general, these valves can be a lower ball valve and an upper ball valve or in some assemblies, this upper valve can be a flapper valve.
Typically and preferably, these control valves are independent of each other, and configured to fail in a closed position.
When the Christmas tree is positioned inside a BOP, these valves are usually positioned below the shear shelves.
During operations with an underwater test Christmas tree,
many different types of tubulars and lines can extend through the internal cavity of the christmas tree and into the wellhead and borehole.
Thus, for example, VIT, wire line, smooth line, coil tubing (which has external diameters up to about 5.08 cm (2 inches) or 5 potentially larger) and the joined tube (which has a diameter 2.54 cm (one inch) to 5.08 cm (two inches) or potentially larger) could extend into and through the Christmas tree's internal cavity.
Referring to Figure 17, a section of an underwater test Christmas tree that has laser cutter assemblies is shown.
This 1700 laser undersea Christmas tree section can be used with an existing test underwater Christmas tree, or it can be a component of a new test underwater Christmas tree.
The 1700 test underwater Christmas tree section has an outer wall 1701, an internal wall 1702 that forms an internal cavity 1703. The underwater Christmas tree section 1700 has a flapper valve 1704, which could also be a ball valve, and a 1705 ball valve, the type usually found in conventional underwater test Christmas trees.
The underwater Christmas tree section 1700 has a laser assembly 1710 associated with the flapper valve 1704 and the laser assembly 1711 associated with the ball valve 1705. In view of the limited space potential, that is, about 12 , 70 cm (5 inches) or less between the outer wall and the inner wall of the Christmas tree section, reflective optics can be useful in these laser mounts to provide a longer, rather than radially wider, profile.
Laser assemblies are associated optically, using high power laser cables 1720, 1721, 1722, 1723, with a high power laser, are also potentially associated with other sources of materials and control information by other conduits .
The test laser underwater Christmas tree can be used in conjunction with a non-laser BOP or in conjunction with a laser BOP system or as a part of it.
The configurations of the various components and their arrangement in a laser-assisted BOP set, an SLM and an underwater test laser Christmas tree, provide the capability for many varied sequences of laser cutter firing and activation of drawers and annular preventers.
In this way, the sequence of firing of 5 lasers and activations can be varied depending on the situation present in the well or in the BOP, to fulfill the activation requirements.
In this way, for example, tube drawers could engage a tubular, the metal cutters could break the tubular without breaking it.
In another example, where a casing and tubular in these cases are in the BOP, an SLM could be fired to break the casing, which is then pulled and knocked over, laser drawer shears are then used to break the tubular and seal the BOP cavity.
In yet another example, in a situation where the BOP, for unknown reasons, failed to seal the well, all laser cutters can be fired repeatedly, the removal of any tubular can happen by obstructing the various drawers, allowing the sealing from the well The present inventions provide the ability to quickly provide laser, mechanical laser, mechanical cutting and sealing actions in a BOP to address situations that may appear in offshore drilling.
As such, the scope of the present inventions is not limited to a particular maritime situation or sequence of activities.
The invention can be incorporated in ways other 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 (28)
[1]
1. Set of eruption preventers comprising: a drawer preventer; an annular preventer and a shear laser module. 5
[2]
2. Eruption preventer set according to claim 1, in which the eruption preventer is an underwater eruption preventer and in which the annular preventer, the drawer preventer and the shear laser module have a common cavity, the common cavity having a geometric cavity axis.
[3]
3. A set of eruption preventers according to claim 2, wherein the shear laser module comprises a laser cutter that has a beam path that extends from the laser cutter into the common cavity.
[4]
4. Eruption preventer according to claim 3, in which the shear laser module comprises a laser cutter shield located adjacent to the common cavity, wherein the laser cutter shield protects the laser cutter from conditions present in the common cavity, while not significantly interfering with the movement of tubulars through the common cavity.
[5]
5. Eruption preventer according to claim 1, wherein the drawer preventer is a shear drawer and in which the eruption preventer set comprises: a second annular preventer, a second shear drawer, a first drawer tube, a second tube drawer and a third tube drawer.
[6]
6. Shear laser module for use in a set of eruption preventers, the module comprising: a. a body that has a first connector and a second connector, the first and second connectors being adapted for connection to components in a set of eruption preventers; B. the body that has a cavity to pass the tubulars through it; e, 19515881v1 c. a laser cutter on the body and which has a beam path; d. where the beam path travels through the laser cutter into the cavity and to any tubular that may be in the cavity. 5
[7]
A shear laser module according to claim 6, comprising a laser cutter shield.
[8]
Shear laser module according to claim 6, comprising a second laser cutter.
[9]
The shear laser module according to claim 6, wherein the laser cutter is configured inside the body in order to orbit around the cavity.
[10]
10. Shear laser module according to claim 6, comprising a laser cutter shield located adjacent to the cavity, wherein the laser cutter shield protects the laser cutter from drilling fluids, while not significantly interferes with the movement of tubulars through the cavity.
[11]
A shear laser module according to claim 6, comprising: a support cable optically associated with the laser cutter and a through feed assembly mechanically associated with the support cable.
[12]
A shear laser module according to claim 11, wherein the module is rated at an operating pressure of more than 68.94 MPa (10,000 psi).
[13]
A shear laser module according to claim 6, comprising a second laser cutter, wherein the beam path of the laser cutter constitutes a first beam path, wherein the second laser cutter has a second beam path extending from the second laser cutter into the cavity.
[14]
Shear laser module according to claim 13, wherein the first and second beam paths intersect within the cavity.
[15]
15. Shear laser module according to claim 13, wherein the first and second beam paths are directed to the geometric axis of the cavity
[16]
A shear laser module according to claim 13, wherein the cavity has a geometric axis of the cavity and the first and second beam paths cross the geometric axis of the cavity.
[17]
17. Shear laser module according to claim 13, wherein the first and second beam paths do not intersect within the cavity.
[18]
A shear laser module according to claim 13, wherein the first and second beam paths are substantially parallel.
[19]
19. Shear laser module according to claim 6, wherein the cavity has a geometric axis of the cavity and the beam path forms a normal angle with the geometric axis.
[20]
20. Shear laser module according to claim 6, wherein the cavity has a geometric axis of the cavity and the beam path forms an obtuse angle with the geometric axis.
[21]
A shear laser module according to claim 6, wherein the cavity has a geometric axis of the cavity and the beam path forms an acute angle with the geometric axis.
[22]
22. The shear laser module according to claim 10, wherein the laser cutter is configured to orbit at least partially around the cavity during activation.
[23]
23. Retrofit method of a pre-existing set of eruption preventers ("BOP") with a shear laser module to produce a laser-assisted BOP set, the method comprising: a. evaluate a set of pre-existing BOP; B. determine that the pre-existing BOP set does not meet the requirements for a potential intended use; and c. retrofit the pre-existing BOP set by adding a shear laser module to the pre-existing BOP set; thus, the retrofitted BOP set satisfies the requirements for the intended use. 5
[24]
24. Method of producing a laser-assisted rash preventer ("BOP") set, the method comprising: a. obtain a preventive annulment; B. get a drawer preventer; ç. obtain a shear laser module; d. assemble a BOP set comprising the annular preventer, the drawer preventer and the shear laser module.
[25]
25. Submarine well drilling method using a laser-assisted riser and eruption preventer, the method comprising: a. demote a laser-assisted eruption preventer from a marine drilling rig to the seabed using a riser, where the riser has an internal cavity, and where the laser-assisted eruption preventer comprises a module shear laser that has an internal cavity; B. attach the eruption preventer to a well hole in the seabed, the well hole, the shear laser module cavity and the riser cavity being in fluid and mechanical communication; and, c. in which the shear laser module has the ability to perform laser cutting of a tubular present in the cavity assisted laser eruption preventer.
[26]
26. Underwater Christmas tree comprising: a mechanical valve and a laser cutter.
[27]
27. Underwater Christmas tree according to claim 26, comprising: a. an external wall, configured to be positioned adjacent to an eruption preventer cavity wall;
B. an internal wall, which defines an internal cavity of the underwater Christmas tree; and, c. the inner and outer walls that define an annular area between them; D. wherein the laser cutter is substantially contained within the annular space defined by the inner and outer walls.
[28]
28. Method of conducting the operation of an underwater well using high-powered laser-assisted technology, the method comprising: a. lower an eruption preventer that has an interior cavity, from a marine drilling rig to the bottom of the sea; B. attach the eruption preventer to a well hole in the seabed, the well hole and the interior cavity being in fluid and mechanical communication; ç. positioning inside the inner cavity a test underwater Christmas tree that has an internal cavity and that comprises a laser cutter; and, d. lower tubular or line structures from the marine drilling rig, descending through the internal cavity of the test underwater Christmas tree; and. where the test underwater Christmas tree has the ability to laser cut any tubular or line structure present in the internal cavity of the test underwater cavity tree.

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同族专利:

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公开号 | 公开日

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SG192918A1|2013-09-30|

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WO2012161797A1|2012-11-29|

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CN103492669A|2014-01-01|

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CA2827963A1|2012-11-29|

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US20120217019A1|2012-08-30|

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US8720575B2|2014-05-13|

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US8684088B2|2014-04-01|

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EP2678520A1|2014-01-01|

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EP2678520A4|2018-03-28|

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AU2012259443A1|2013-09-12|

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US20130220626A1|2013-08-29|

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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]|

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2021-01-19| B11B| Dismissal acc. art. 36, par 1 of ipl - no reply within 90 days to fullfil the necessary requirements|

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2021-11-23| B350| Update of information on the portal [chapter 15.35 patent gazette]|

优先权:

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申请号 | 申请日 | 专利标题

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US13/034,183|2011-02-24|

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US13/034,183|US8684088B2|2011-02-24|2011-02-24|Shear laser module and method of retrofitting and use|

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PCT/US2012/026525|WO2012161797A1|2011-02-24|2012-02-24|Shear laser module and method of retrofitting and use|

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