Patent Application
20170191314
The present invention relates to methods, apparatus and systems for delivering advancing boreholes using high power laser energy that is delivered over long distances, while maintaining the power of the laser energy to perform desired tasks. In a particular, the present invention relates to providing high power laser energy to create and advance a borehole in the earth and to perform other tasks in the borehole.
The present invention is useful with and may be employed in conjunction with the systems, apparatus and methods that are disclosed in greater detail in co-pending U.S. patent application Ser. No. 12/544,136, which as issued as U.S. Pat. No. 8,511,401, titled Method and Apparatus for Delivering High Power Laser Energy Over Long Distances, U.S. patent application Ser. No. 12/544,038, titled Apparatus for Advancing a Wellbore using High Power Laser Energy, U.S. patent application Ser. No. 12/544,094, which issued as U.S. Pat. No. 8,424,617, titled Methods and Apparatus for Delivering High Power Laser Energy to a Surface, and US patent application Ser. No. 12/543,868, which issued as U.S. Pat. No. 8,363,085, titled Methods and Apparatus for Removal and Control of Material in Laser Drilling of a Borehole, filed contemporaneously herewith, the disclosures of which are incorporate herein by reference in their entirety.
In general, boreholes have been formed in the earth's surface and the earth, i.e., the ground, to access resources that are located at and below the surface. Such resources would include hydrocarbons, such as oil and natural gas, water, and geothermal energy sources, including hydrothermal wells. Boreholes have also been formed in the ground to study, sample and explore materials and formations that are located below the surface. They have also been formed in the ground to create passageways for the placement of cables and other such items below the surface of the earth.
The term borehole includes any opening that is created in the ground that is substantially longer than it is wide, such as a well, a well bore, a well hole, and other terms commonly used or known in the art to define these types of narrow long passages in the earth. Although boreholes are generally oriented substantially vertically, they may also be oriented on an angle from vertical, to and including horizontal. Thus, using a level line as representing the horizontal orientation, a borehole can range in orientation from 0° i.e., a vertical borehole, to 90°,i.e., a horizontal borehole and greater than 90° e.g., such as a heel and toe. Boreholes may further have segments or sections that have different orientations, they may be arcuate, and they may be of the shapes commonly found when directional drilling is employed. Thus, as used herein unless expressly provided otherwise, the “bottom” of the borehole, the “bottom” surface of the borehole and similar terms refer to the end of the borehole, i.e., that portion of the borehole farthest along the path of the borehole from the borehole's opening, the surface of the earth, or the borehole's beginning.
Advancing a borehole means to increase the length of the borehole. Thus, by advancing a borehole, other than a horizontal one, the depth of the borehole is also increased. Boreholes are generally formed and advanced by using mechanical drilling equipment having a rotating drilling bit. The drilling bit is extending to and into the earth and rotated to create a hole in the earth. In general, to perform the drilling operation a diamond tip tool is used. That tool must be forced against the rock or earth to be cut with a sufficient force to exceed the shear strength of that material. Thus, in conventional drilling activity mechanical forces exceeding the shear strength of the rock or earth must be applied to that material. The material that is cut from the earth is generally known as cuttings, i.e., waste, which may be chips of rock, dust, rock fibers and other types of materials and structures that may be created by the thermal or mechanical interactions with the earth. These cuttings are typically removed from the borehole by the use of fluids, which fluids can be liquids, foams or gases.
In addition to advancing the borehole, other types of activities are performed in or related to forming a borehole, such as, work over and completion activities. These types of activities would include for example the cutting and perforating of casing and the removal of a well plug. Well casing, or casing, refers to the tubulars or other material that are used to line a wellbore. A well plug is a structure, or material that is placed in a borehole to fill and block the borehole. A well plug is intended to prevent or restrict materials from flowing in the borehole.
Typically, perforating, i.e., the perforation activity, involves the use of a perforating tool to create openings, e.g. windows, or a porosity in the casing and borehole to permit the sought after resource to flow into the borehole. Thus, perforating tools may use an explosive charge to create, or drive projectiles into the casing and the sides of the borehole to create such openings or porosities.
The above mentioned conventional ways to form and advance a borehole are referred to as mechanical techniques, or mechanical drilling techniques, because they require a mechanical interaction between the drilling equipment, e.g., the drill bit or perforation tool, and the earth or casing to transmit the force needed to cut the earth or casing.
It has been theorized that lasers could be adapted for use to form and advance a borehole. Thus, it has been theorized that laser energy from a laser source could be used to cut rock and earth through spalling, thermal dissociation, melting, vaporization and combinations of these phenomena. Melting involves the transition of rock and earth from a solid to a liquid state. Vaporization involves the transition of rock and earth from either a solid or liquid state to a gaseous state. Spalling involves the fragmentation of rock from localized heat induced stress effects. Thermal dissociation involves the breaking of chemical bonds at the molecular level.
To date it is believed that no one has succeeded in developing and implementing these laser drilling theories to provide an apparatus, method or system that can advance a borehole through the earth using a laser, or perform perforations in a well using a laser. Moreover, to date it is believed that no one has developed the parameters, and the equipment needed to meet those parameters, for the effective cutting and removal of rock and earth from the bottom of a borehole using a laser, nor has anyone developed the parameters and equipment need to meet those parameters for the effective perforation of a well using a laser. Further is it believed that no one has developed the parameters, equipment or methods need to advance a borehole deep into the earth, to depths exceeding about 300 ft (0.09 km), 500 ft (0.15 km), 1000 ft, (0.30 km), 3,280 ft (1 km), 9,840 ft (3 km) and 16,400 ft (5 km), using a laser. In particular, it is believed that no one has developed parameters, equipments, or methods nor implemented the delivery of high power laser energy, i.e., in excess of 1 kW or more to advance a borehole within the earth.
While mechanical drilling has advanced and is efficient in many types of geological formations, it is believed that a highly efficient means to create boreholes through harder geologic formations, such as basalt and granite has yet to be developed. Thus, the present invention provides solutions to this need by providing parameters, equipment and techniques for using a laser for advancing a borehole in a highly efficient manner through harder rock formations, such as basalt and granite.
The environment and great distances that are present inside of a borehole in the earth can be very harsh and demanding upon optical fibers, optics, and packaging. Thus, there is a need for methods and an apparatus for the deployment of optical fibers, optics, and packaging into a borehole, and in particular very deep boreholes, that will enable these and all associated components to withstand and resist the dirt, pressure and temperature present in the borehole and overcome or mitigate the power losses that occur when transmitting high power laser beams over long distances. The present inventions address these needs by providing a long distance high powered laser beam transmission means.
It has been desirable, but prior to the present invention believed to have never been obtained, to deliver a high power laser beam over a distance within a borehole greater than about 300 ft (0.09 km), about 500 ft (0.15 km), about 1000 ft, (0.30 km), about 3,280 ft (1 km), about 9,8430 ft (3 km) and about 16,400 ft (5 km) down an optical fiber in a borehole, to minimize the optical power losses due to non-linear phenomenon, and to enable the efficient delivery of high power at the end of the optical fiber. Thus, the efficient transmission of high power from point A to point B where the distance between point A and point B within a borehole is greater than about 1,640 ft (0.5 km) has long been desirable, but prior to the present invention is believed to have never been obtainable and specifically believed to have never been obtained in a borehole drilling activity.
A conventional drilling rig, which delivers power from the surface by mechanical means, must create a force on the rock that exceeds the shear strength of the rock being drilled. Although a laser has been shown to effectively spall and chip such hard rocks in the laboratory under laboratory conditions, and it has been theorized that a laser could cut such hard rocks at superior net rates than mechanical drilling, to date it is believed that no one has developed the apparatus systems or methods that would enable the delivery of the laser beam to the bottom of a borehole that is greater than about 1,640 ft (0.5 km) in depth with sufficient power to cut such hard rocks, let alone cut such hard rocks at rates that were equivalent to and faster than conventional mechanical drilling. It is believed that this failure of the art was a fundamental and long standing problem for which the present invention provides a solution.
Thus, the present invention addresses and provides solutions to these and other needs in the drilling arts by providing, among other things: spoiling the coherence of the Stimulated Brillioun Scattering (SBS) phenomenon, e.g. a bandwidth broadened laser source, such as an FM modulated laser or spectral beam combined laser sources, to suppress the SBS, which enables the transmission of high power down a long >1000 ft (0.30 km) optical fiber; the use of a fiber laser, disk laser, or high brightness semiconductor laser for drilling rock with the bandwidth broadened to enable the efficient delivery of the optical power via a >1000 ft (0.30 km) long optical fiber; the use of phased array laser sources with its bandwidth broadened to suppress the Stimulated Brillioun Gain (SBG) for power transmission down fibers that are >1000 ft (0.30 km) in length; a fiber spooling technique that enables the fiber to be powered from the central axis of the spool by a laser beam while the spool is turning; a method for spooling out the fiber without having to use a mechanically moving component; a method for combining multiple fibers into a single jacket capable of withstanding down hole pressures; the use of active and passive fiber sections to overcome the losses along the length of the fiber; the use of a buoyant fiber to support the weight of the fiber, laser head and encasement down a drilling hole; the use of micro lenses, aspherical optics, axicons or diffractive optics to create a predetermined pattern on the rock to achieve higher drilling efficiencies; and the use of a heat engine or tuned photovoltaic cell to reconvert optical power to electrical power after transmitting the power >1000 ft (0.30 km) via an optical fiber.
It is desirable to develop systems and methods that provide for the delivery of high power laser energy to the bottom of a deep borehole to advance that borehole at a cost effective rate, and in particular, to be able to deliver such high power laser energy to drill through rock layer formations including granite, basalt, sandstone, dolomite, sand, salt, limestone, rhyolite, quartzite and shale rock at a cost effective rate. More particularly, it is desirable to develop systems and methods that provide for the ability to deliver such high power laser energy to drill through hard rock layer formations, such as granite and basalt, at a rate that is superior to prior conventional mechanical drilling operations. The present invention, among other things, solves these needs by providing the system, apparatus and methods taught herein.
Thus, there is provided a high power laser drilling system for use in association with a drilling rig, drilling platform, drilling derrick, a snubbing platform, or coiled tubing drilling rig for advancing a borehole, in hard rock, the system comprising: a source of high power laser energy, the laser source capable of providing a laser beam having at least 10 kW of power, at least about 20 kW of power or more; a bottom hole assembly, the bottom hole assembly having an optical assembly, the optical assembly configured to provide a predetermined energy deposition profile to a borehole surface and the optical assembly configured to provide a predetermined laser shot pattern; a means for advancing the bottom hole assembly into and down the borehole; a downhole high power laser transmission cable, the transmission cable having a length of at least about 500 feet, at least about 1000 feet, at least about 3000 feet, at least about 4000 feet or more; the downhole cable in optical communication with the laser source; and, the downhole cable in optical communication with the bottom hole assembly.
There is further provided a high power laser drilling system for use in association with a drilling rig, drilling platform, snubbing platform, drilling derrick, or coiled tubing drilling rig for advancing a borehole, the system comprising: a source of high power laser energy; the laser source capable of providing a laser beam having at least 5 kW, at least about 10 kW, at least about 15 kW and at least about 20 kW or more of power; the laser source comprising at least one laser; a bottom hole assembly; configured to provide a predetermined energy deposition profile of laser energy to a borehole surface; configured to provide a predetermined laser shot pattern; comprising an optical assembly; and, comprising a means to mechanically remove borehole material; a means for advancing the bottom hole assembly into and down the borehole; a source of fluid for use in advancing a borehole; a downhole high power laser transmission cable, the transmission cable having a length of at least about 1000 feet; the downhole cable in optical communication with the laser source; the downhole cable in optical communication with the optical assembly; and, the bottom hole assembly in fluid communication with the fluid source; whereby high power laser energy may be provided to a surface of a borehole at locates within the borehole at least 1000 feet from the borehole opening.
Yet further there is provided a high power laser drilling system for use in association with a drilling rig, drilling platform, drilling derrick, a snubbing platform, or coiled tubing drilling rig for advancing a borehole, the system comprising: a source of high power laser energy; a bottom hole assembly; the bottom hole assembly having an optical assembly; the optical assembly configured to provide an energy deposition profile to a borehole surface; and, the optical assembly configured to provide a laser shot pattern; comprising a means for directing a fluid; a means for advancing the bottom hole assembly into and down the borehole; a source of fluid for use in advancing a borehole; a downhole high power laser transmission cable; the downhole cable in optical communication with the laser source; the downhole cable in optical communication with the bottom hole assembly; and, the means for directing in fluid communications with the fluid source; wherein the system is capable of cutting, spalling, or chipping rock by illuminating a surface of the borehole with laser energy and remove waste material created from said cutting, spalling or chipping, from the borehole and the area of laser illumination by the action of the directing means. Wherein the means for directing may be, one or more of and combinations thereof a fluid amplifier, an outlet port, a gas directing means, a fluid directing means, and an air knife.
Additionally, there is provided a laser bottom hole assembly comprising: a first rotating housing; a second fixed housing; the first housing being rotationally associated with the second housing; a fiber optic cable for transmitting a laser beam, the cable having a proximal end and a distal end, the proximal end adapted to receive a laser beam from a laser source, the distal end optically associated with an optical assembly; at least a portion of the optical assembly fixed to the first rotating housing, whereby the fixed portion rotates with the first housing; a mechanical assembly fixed to the first rotating housing, whereby the assembly rotates with the first housing and is capable of applying mechanical forces to a surface of a borehole upon rotation; and, a fluid path associated with first and second housings, the fluid path having a distal and proximal opening, the distal opening adapted to discharge the fluid toward the surface of the borehole, whereby fluid for removal of waste material is transmitted by the fluid path and discharged from the distal opening toward the borehole surface to remove waste material from the borehole.
There is further provided a laser bottom hole assembly comprising: a first rotating housing; a second fixed housing; the first housing being rotationally associated with the second housing; an optical assembly, the assembly having a first portion and a second portion; a fiber optic cable for transmitting a laser beam, the cable having a proximal end and a distal end, the proximal end adapted to receive a laser beam from a laser source, the distal end optically associated with the optical assembly; the fiber proximal and distal ends fixed to the second housing; the first portion of the optical assembly fixed to the first rotating housing; the second portion of the optical assembly fixed to the second fixed housing, whereby the first portion of the optical assembly rotates with the first housing; a mechanical assembly fixed to the first rotating housing, whereby the assembly rotates with the first housing and is capable of apply mechanical forces to a surface of a borehole upon rotation; and, a fluid path associated with first and second housings, the fluid path having a distal and proximal opening, the distal opening adapted to discharge the fluid toward the surface of the borehole, the distal opening fixed to the first rotating housing, whereby fluid for removal of waste material is transmitted by the fluid path and discharged from the distal opening toward the borehole surface to remove waste material from the borehole; wherein upon rotation of the first housing the optical assembly first portion, the mechanical assembly and proximal fluid opening rotate substantially concurrently.
Additionally there is provided a laser bottom hole assembly comprising: a housing; a means for providing a high power laser beam; an optical assembly, the optical assembly providing an optical path upon which the laser beam travels; and, a an air flow and chamber for creating an area of high pressure along the optical path; and, a an air flow through a housing of the bottom hole assembly with ports that function as an aspiration pumping for the removal of waste material from the area of high pressure.
Furthermore, these systems and assemblies may further have rotating laser optics, a rotating mechanical interaction device, a rotating fluid delivery means, one or all three of these devices rotating together, beam shaping optic, housings, a means for directing a fluid for removal of waste material, a means for keeping a laser path free of debris, a means for reducing the interference of waste material with the laser beam, optics comprising a scanner; a stand-off mechanical device, a conical stand-off device, a mechanical assembly comprises a drill bit, a mechanical assembly comprising a three-cone drill bit, a mechanical assembly comprises a PDC bit, a PDC tool or a PDC cutting tool.
Still further, there is provided a system for creating a borehole in the earth having a high power laser source, a bottom hole assembly and, a fiber optically connecting the laser source with the bottom hole assembly, such that a laser beam from the laser source is transmitted to the bottom hole assembly the bottom hole assembly comprising: a means for providing the laser beam to a bottom surface of the borehole; the providing means comprising beam power deposition optics; wherein, the laser beam as delivered from the bottom hole assembly illuminates the bottom surface of the borehole with a substantially even energy deposition profile.
There is yet further provided a method of advancing a borehole using a laser, the method comprising: advancing a high power laser beam transmission means into a borehole; the borehole having a bottom surface, a top opening, and a length extending between the bottom surface and the top opening of at least about 1000 feet; the transmission means comprising a distal end, a proximal end, and a length extending between the distal and proximal ends, the distal end being advanced down the borehole; the transmission means comprising a means for transmitting high power laser energy; providing a high power laser beam to the proximal end of the transmission means; transmitting substantially all of the power of the laser beam down the length of the transmission means so that the beam exits the distal end; transmitting the laser beam from the distal end to an optical assembly in a laser bottom hole assembly, the laser bottom hole assembly directing the laser beam to the bottom surface of the borehole; and, providing a predetermined energy deposition profile to the bottom of the borehole; whereby the length of the borehole is increased, in part, based upon the interaction of the laser beam with the bottom of the borehole.
Additionally, there is provided a method of removing debris from a borehole during laser drilling of the borehole the method comprising: directing a laser beam comprising a wavelength, and having a power of at least about 10 kW, down a borehole and towards a surface of a borehole; the surface being at least 1000 feet within the borehole; the laser beam illuminating an area of the surface; the laser beam displacing material from the surface in the area of illumination; directing a fluid into the borehole and to the borehole surface; the fluid being substantially transmissive to the laser wavelength; the directed fluid having a first and a second flow path; the fluid flowing in the first flow path removing the displaced material from the area of illumination at a rate sufficient to prevent the displaced material from interfering with the laser illumination of the area of illumination; and, the fluid flowing in the second flow path removing displaced material form borehole. Additionally, the forging method may also have the illumination area rotated, the fluid in the first fluid flow path directed in the direction of the rotation, the fluid in the first fluid flow path directed in a direction opposite of the rotation, a third fluid flow path, the third fluid low path and the first fluid flow path in the direction of rotation, the third fluid low path and the first fluid flow path in a direction opposite to the direction of rotation, the fluid directed directly at the area of illumination, the fluid in the first flow path directed near the area of illumination, and the fluid in the first fluid flow path directed near the area of illumination, which area is ahead of the rotation.
There is yet further provided a method of removing debris from a borehole during laser drilling of the borehole the method comprising: directing a laser beam having at least about 10 kW of power towards a borehole surface; illuminating an area of the borehole surface; displacing material from the area of illumination; providing a fluid; directing the fluid toward a first area within the borehole; directing the fluid toward a second area; the directed fluid removing the displaced material from the area of illumination at a rate sufficient to prevent the displaced material from interfering with the laser illumination; and, the fluid removing displaced material form borehole. This further method may additionally have the first area as the area of illumination, the second area on a sidewall of a bottom hole assembly, the second area near the first area and the second area located on a bottom surface of the borehole, the second area near the first area when the second area is located on a bottom surface of the borehole, a first fluid directed to the area of illumination and a second fluid directed to the second area, the first fluid as nitrogen, the first fluid as a gas, the second fluid as a liquid, and the second fluid as an aqueous liquid.
Yet, further there is provided a method of removing debris from a borehole during laser drilling of the borehole the method comprising: directing a laser beam towards a borehole surface; illuminating an area of the borehole surface; displacing material from the area of illumination; providing a fluid; directing the fluid in a first path toward a first area within the borehole; directing the fluid in a second path toward a second area; amplifying the flow of the fluid in the second path; the directed fluid removing the displaced material from the area of illumination at a rate sufficient to prevent the displaced material from interfering with the laser illumination; and, the amplified fluid removing displaced material form borehole.
Moreover, there is provided a laser bottom hole assembly for drilling a borehole in the earth comprising: a housing; optics for shaping a laser beam; an opening for delivering a laser beam to illuminate the surface of a borehole; a first fluid opening in the housing; a second fluid opening in the housing; and, the second fluid opening comprising a fluid amplifier.
Still further, a high power laser drilling system for advancing a borehole is provided that comprises: a source of high power laser energy, the laser source capable of providing a laser beam; a tubing assembly, the tubing assembly having at least 500 feet of tubing, having a distal end and a proximal; a source of fluid for use in advancing a borehole; the proximal end of the tubing being in fluid communication with the source of fluid, whereby fluid is transported in association with the tubing from the proximal end of the tubing to the distal end of the tubing; the proximal end of the tubing being in optical communication with the laser source, whereby the laser beam can be transported in association with the tubing; the tubing comprising a high power laser transmission cable, the transmission cable having a distal end and a proximal end, the proximal end being in optical communication with the laser source, whereby the laser beam is transmitted by the cable from the proximal end to the distal end of the cable; and, a laser bottom hole assembly in optical and fluid communication with the distal end of the tubing; and, the laser bottom hole assembly comprising; a housing; an optical assembly; and, a fluid directing opening. This system may be supplemented by also having the fluid directing opening as an air knife, the fluid directing opening as a fluid amplifier, the fluid directing opening is an air amplifier, a plurality of fluid directing apparatus, the bottom hole assembly comprising a plurality of fluid directing openings, the housing comprising a first housing and a second housing; the fluid directing opening located in the first housing, and a means for rotating the first housing, such as a motor,
There is yet further provided a high power laser drilling system for advancing a borehole comprising: a source of high power laser energy, the laser source capable of providing a laser beam; a tubing assembly, the tubing assembly having at least 500 feet of tubing, having a distal end and a proximal; a source of fluid for use in advancing a borehole; the proximal end of the tubing being in fluid communication with the source of fluid, whereby fluid is transported in association with the tubing from the proximal end of the tubing to the distal end of the tubing; the proximal end of the tubing being in optical communication with the laser source, whereby the laser beam can be transported in association with the tubing; the tubing comprising a high power laser transmission cable, the transmission cable having a distal end and a proximal end, the proximal end being in optical communication with the laser source, whereby the laser beam is transmitted by the cable from the proximal end to the distal end of the cable; and, a laser bottom hole assembly in optical and fluid communication with the distal end of the tubing; and, a fluid directing means for removal of waste material.
Further such systems may additionally have the fluid directing means located in the laser bottom hole assembly, the laser bottom hole assembly having a means for reducing the interference of waste material with the laser beam, the laser bottom hole assembly with rotating laser optics, and the laser bottom hole assembly with rotating laser optics and rotating fluid directing means.
One of ordinary skill in the art will recognize, based on the teachings set forth in these specifications and drawings, that there are various embodiments and implementations of these teachings to practice the present invention. Accordingly, the embodiments in this summary are not meant to limit these teachings in any way.
In general, the present inventions relate to methods, apparatus and systems for use in laser drilling of a borehole in the earth, and further, relate to equipment, methods and systems for the laser advancing of such boreholes deep into the earth and at highly efficient advancement rates. These highly efficient advancement rates are obtainable because the present invention provides for a means to get high power laser energy to the bottom of the borehole, even when the bottom is at great depths.
Thus, in general, and by way of example, there is provided in
The spool of coiled tubing 1009 is rotated to advance and retract the coiled tubing 1012. Thus, the laser beam transmission means 1008 and the fluid conveyance means 1011 are attached to the spool of coiled tubing 1009 by means of rotating coupling means 1013. The coiled tubing 1012 contains a means to transmit the laser beam along the entire length of the coiled tubing, i.e., “long distance high power laser beam transmission means,” to the bottom hole assembly, 1014. The coiled tubing 1012 also contains a means to convey the fluid along the entire length of the coiled tubing 1012 to the bottom hole assembly 1014.
Additionally, there is provided a support structure 1015, which holds an injector 1016, to facilitate movement of the coiled tubing 1012 in the borehole 1001. Further other support structures may be employed for example such structures could be derrick, crane, mast, tripod, or other similar type of structure or hybrid and combinations of these. As the borehole is advance to greater depths from the surface 1030, the use of a diverter 1017, a blow out preventer (BOP) 1018, and a fluid and/or cutting handling system 1019 may become necessary. The coiled tubing 1012 is passed from the injector 1016 through the diverter 1017, the BOP 1018, a wellhead 1020 and into the borehole 1001.
The fluid is conveyed to the bottom 1021 of the borehole 1001. At that point the fluid exits at or near the bottom hole assembly 1014 and is used, among other things, to carry the cuttings, which are created from advancing a borehole, back up and out of the borehole. Thus, the diverter 1017 directs the fluid as it returns carrying the cuttings to the fluid and/or cuttings handling system 1019 through connector 1022. This handling system 1019 is intended to prevent waste products from escaping into the environment and separates and cleans waste products and either vents the cleaned fluid to the air, if permissible environmentally and economically, as would be the case if the fluid was nitrogen, or returns the cleaned fluid to the source of fluid 1010, or otherwise contains the used fluid for later treatment and/or disposal.
The BOP 1018 serves to provide multiple levels of emergency shut off and/or containment of the borehole should a high-pressure event occur in the borehole, such as a potential blow-out of the well. The BOP is affixed to the wellhead 1020. The wellhead in turn may be attached to casing. For the purposes of simplification the structural components of a borehole such as casing, hangers, and cement are not shown. It is understood that these components may be used and will vary based upon the depth, type, and geology of the borehole, as well as, other factors.
The downhole end 1023 of the coiled tubing 1012 is connected to the bottom hole assembly 1014. The bottom hole assembly 1014 contains optics for delivering the laser beam 1024 to its intended target, in the case of
Thus, in general this system operates to create and/or advance a borehole by having the laser create laser energy in the form of a laser beam. The laser beam is then transmitted from the laser through the spool and into the coiled tubing. At which point, the laser beam is then transmitted to the bottom hole assembly where it is directed toward the surfaces of the earth and/or borehole. Upon contacting the surface of the earth and/or borehole the laser beam has sufficient power to cut, or otherwise effect, the rock and earth creating and/or advancing the borehole. The laser beam at the point of contact has sufficient power and is directed to the rock and earth in such a manner that it is capable of borehole creation that is comparable to or superior to a conventional mechanical drilling operation. Depending upon the type of earth and rock and the properties of the laser beam this cutting occurs through spelling, thermal dissociation, melting, vaporization and combinations of these phenomena.
Although not being bound by the present theory, it is presently believed that the laser material interaction entails the interaction of the laser and a fluid or media to clear the area of laser illumination. Thus the laser illumination creates a surface event and the fluid impinging on the surface rapidly transports the debris, i.e. cuttings and waste, out of the illumination region. The fluid is further believed to remove heat either on the macro or micro scale from the area of illumination, the area of post-illumination, as well as the borehole, or other media being cut, such as in the case of perforation.
The fluid then carries the cuttings up and out of the borehole. As the borehole is advanced the coiled tubing is unspooled and lowered further into the borehole. In this way the appropriate distance between the bottom hole assembly and the bottom of the borehole can be maintained. If the bottom hole assembly needs to be removed from the borehole, for example to case the well, the spool is wound up, resulting in the coiled tubing being pulled from the borehole. Additionally, the laser beam may be directed by the bottom hole assembly or other laser directing tool that is placed down the borehole to perform operations such as perforating, controlled perforating, cutting of casing, and removal of plugs. This system may be mounted on readily mobile trailers or trucks, because its size and weight are substantially less than conventional mechanical rigs.
For systems of the general type illustrated in
For example,
For example,
The laser source may be a low order mode source (M2<2) so it can be focused into an optical fiber with a mode diameter of <100 microns. Optical fibers with small mode field diameters ranging from 50 microns to 6 microns have the lowest transmission losses. However, this should be balanced by the onset of non-linear phenomenon and the physical damage of the face of the optical fiber requiring that the fiber diameter be as large as possible while the transmission losses have to be as small as possible.
Thus, the laser source should have total power of at least about 1 kW, from about 1 kW to about 20 kW, from about 10 kW to about 20 kW, at least about 10 kW, and preferably about 20 or more kW. Moreover, combinations of various lasers may be used to provide the above total power ranges. Further, the laser source should have beam parameters in mm millirad as large as is feasible with respect to bendability and manufacturing substantial lengths of the fiber, thus the beam parameters may be less than about 100 mm millirad, from single mode to about 50 mm millirad, less than about 50 mm millirad, less than about 15 mm millirad, and most preferably about 12 mm millirad. Further, the laser source should have at least a 10% electrical optical efficiency, at least about 50% optical efficiency, at least about 70% optical efficiency, whereby it is understood that greater optical efficiency, all other factors being equal, is preferred, and preferably at least about 25%. The laser source can be run in either pulsed or continuous wave (CW) mode. The laser source is preferably capable of being fiber coupled.
For advancing boreholes in geologies containing hard rock formations such as granite and basalt it is preferred to use the IPG 20000 YB having the following specifications set forth in Table 1 herein.
For cutting casing, removal of plugs and perforation operations the laser may be any of the above referenced lasers, and it may further be any smaller lasers that would be only used for workover and completion downhole activities.
In addition to the configuration of
Fiber lasers of the type useful in the present invention are generally built around dual-core fibers. The inner core may be composed of rare-earth elements; ytterbium, erbium, thulium, holmium or a combination. The optical gain medium emits wavelengths of 1064 nm, 1360 nm, 1455 nm, and 1550 nm, and can be diffraction limited. An optical diode may be coupled into the outer core (generally referred to as the inner cladding) to pump the rare earth ion in the inner core. The outer core can be a multi-mode waveguide. The inner core serves two purposes: to guide the high power laser; and, to provide gain to the high power laser via the excited rare earth ions. The outer cladding of the outer core may be a low index polymer to reduce losses and protect the fiber. Typical pumped laser diodes emit in the range of about 915-980 nm (generally—940 nm). Fiber lasers are manufactured from IPG Photonics or Southhampton Photonics. High power fibers were demonstrated to produce 50 kW by IPG Photonics when multiplexed.
In use, one or more laser beams generated or illuminated by the one or more lasers may spall, vaporize or melt material, such as rock. The laser beam may be pulsed by one or a plurality of waveforms or it may be continuous. The laser beam may generally induce thermal stress in a rock formation due to characteristics of the material, such as rock including, for example, the thermal conductivity. The laser beam may also induce mechanical stress via superheated steam explosions of moisture in the subsurface of the rock formation. Mechanical stress may also be induced by thermal decompositions and sublimation of part of the in situ mineral of the material. Thermal and/or mechanical stress at or below a laser-material interface may promote spallation of the material, such as rock. Likewise, the laser may be used to effect well casings, cement or other bodies of material as desired. A laser beam may generally act on a surface at a location where the laser beam contacts the surface, which may be referred to as a region of laser illumination. The region of laser illumination may have any preselected shape and intensity distribution that is required to accomplish the desired outcome, the laser illumination region may also be referred to as a laser beam spot. Boreholes of any depth and/or diameter may be formed, such as by spalling multiple points or layers. Thus, by way of example, consecutive points may be targeted or a strategic pattern of points may be targeted to enhance laser/rock interaction. The position or orientation of the laser or laser beam may be moved or directed so as to intelligently act across a desired area such that the laser/material interactions are most efficient at causing rock removal.
One or more lasers may further be positioned downhole, i.e., down the borehole. Thus, depending upon the specific requirements and operation parameters, the laser may be located at any depth within the borehole. For example, the laser may be maintained relatively close to the surface, it may be positioned deep within the borehole, it may be maintained at a constant depth within the borehole or it may be positioned incrementally deeper as the borehole deepens. Thus, by way of further example, the laser may be maintained at a certain distance from the material, such as rock to be acted upon. When the laser is deployed downhole, the laser may generally be shaped and/or sized to fit in the borehole. Some lasers may be better suited than others for use downhole. For example, the size of some lasers may deem them unsuitable for use downhole, however, such lasers may be engineered or modified for use downhole. Similarly, the power or cooling of a laser may be modified for use downhole.
Systems and methods may generally include one or more features to protect the laser. This become important because of the harsh environments, both for surface units and downhole units. Thus, In accordance with one or more embodiments, a borehole drilling system may include a cooling system. The cooling system may generally function to cool the laser. For example, the cooling system may cool a downhole laser, for example to a temperature below the ambient temperature or to an operating temperature of the laser. Further, the laser may be cooled using sorption cooling to the operating temperature of the infrared diode laser, for example, about 20° C. to about 100° C. For a fiber laser its operating temperature may be between about 20° C. to about 50° C. A liquid at a lower temperature may be used for cooling when a temperature higher than the operating diode laser temperature is reached to cool the laser.
Heat may also be sent uphole, i.e., out of the borehole and to the surface, by a liquid heat transfer agent. The liquid transfer agent may then be cooled by mixing with a lower temperature liquid uphole. One or multiple heat spreading fans may be attached to the laser diode to spread heat away from the infrared diode laser. Fluids may also be used as a coolant, while an external coolant may also be used.
In downhole applications the laser may be protected from downhole pressure and environment by being encased in an appropriate material. Such materials may include steel, titanium, diamond, tungsten carbide and the like. The fiber head for an infrared diode laser or fiber laser may have an infrared transmissive window. Such transmissive windows may be made of a material that can withstand the downhole environment, while retaining transmissive qualities. One such material may be sapphire or other material with similar qualities. One or more infrared diode lasers or fiber lasers may be entirely encased by sapphire. By way of example, an infrared diode laser or fiber laser may be made of diamond, tungsten carbide, steel, and titanium other than the part where the laser beam is emitted.
In the downhole environment it is further provided by way of example that the infrared diode laser or fiber laser is not in contact with the borehole while drilling. For example, a downhole laser may be spaced from a wall of the borehole.
The chiller, which is used to cool the laser, in the systems of the general type illustrated in
For systems of the general type illustrated in
There are two basic spool approaches, the first is to use a spool which is simply a wheel with conduit coiled around the outside of the wheel. For example, this coiled conduit may be a hollow tube, it may be an optical fiber, it may be a bundle of optical fibers, it may be an armored optical fiber, it may be other types of optically transmitting cables or it may be a hollow tube that contains the aforementioned optically transmitting cables.
The spool in this configuration has a hollow central axis where the optical power is transmitted to the input end of the optical fiber. The beam will be launched down the center of the spool, the spool rides on precision bearings in either a horizontal or vertical orientation to prevent any tilt of the spool as the fiber is spooled out. It is optimal for the axis of the spool to maintain an angular tolerance of about +/−10 micro-radians, which is preferably obtained by having the optical axis isolated and/or independent from the spool axis of rotation. The beam when launched into the fiber is launched by a lens which is rotating with the fiber at the Fourier Transform plane of the launch lens, which is insensitive to movement in the position of the lens with respect the laser beam, but sensitive to the tilt of the incoming laser beam. The beam, which is launched in the fiber, is launched by a lens that is stationary with respect to the fiber at the Fourier Transform plane of the launch lens, which is insensitive to movement of the fiber with respect to the launch lens.
A second approach is to use a stationary spool similar to a creel and rotate the laser head as the fiber spools out to keep the fiber from twisting as it is extracted from the spool. If the fiber can be designed to accept a reasonable amount of twist along its length, then this would be the preferred method. Using the second approach if the fiber could be pre-twisted around the spool then as the fiber is extracted from the spool, the fiber straightens out and there is no need for the fiber and the drill head to be rotated as the fiber is played out. There will be a series of tensioners that will suspend the fiber down the hole, or if the hole is filled with water to extract the debris from the bottom of the hole, then the fiber can be encased in a buoyant casing that will support the weight of the fiber and its casing the entire length of the hole. In the situation where the bottom hole assembly does not rotate and the fiber is twisted and placed under twisting strain, there will be the further benefit of reducing SBS as taught herein.
For systems of the general type illustrated in
Preferably, the Spool will have a standard type 2⅞″ hollow steel pipe, i.e., the coiled tubing. As discussed in further herein, the coiled tubing will have in it at least one optical fiber for transmitting the laser beam to the bottom hole assembly. In addition to the optical fiber the coiled tubing may also carry other cables for other downhole purposes or to transmit material or information back up the borehole to the surface. The coiled tubing may also carry the fluid or a conduit for carrying the fluid. To protect and support the optical fibers and other cables that are carried in the coiled tubing stabilizers may be employed.
The spool may have QBH fibers and a collimator. Vibration isolation means are desirable in the construction of the spool, and in particular for the fiber slip ring, thus for example the spool's outer plate mounts to the spool support using a Delrin plate, while the inner plate floats on the spool and pins rotate the assembly. The fiber slip ring is the stationary fiber, which communicates power across the rotating spool hub to the rotating fiber.
When using a spool the mechanical axis of the spool is used to transmit optical power from the input end of the optical fiber to the distal end. This calls for a precision optical bearing system (the fiber slip ring) to maintain a stable alignment between the external fiber providing the optical power and the optical fiber mounted on the spool. The laser can be mounted inside of the spool, or as shown in
There is further provided rotating coupling means to connect the coiled tubing, which is rotating, to the laser beam transmission means 1008, and the fluid conveyance means 1011, which are not rotating. As illustrated by way of example in
The optical rotating coupling means 2002 is connected to a hollow precision ground axle 2004 with bearing surfaces 2005, 2006. The laser transmission means 2008 is optically coupled to the hollow axle 2004 by optical rotating coupling means 2002, which permits the laser beam to be transmitted from the laser transmission means 2008 into the hollow axle 2004. The optical rotating coupling means for example may be made up of a QBH connector, a precision collimator, and a rotation stage, for example a Precitec collimator through a Newport rotation stage to another Precitec collimator and to a QBH collimator. To the extent that excessive heat builds up in the optical rotating coupling cooling should be applied to maintain the temperature at a desired level.
The hollow axle 2004 then transmits the laser beam to an opening 2007 in the hollow axle 2004, which opening contains an optical coupler 2010 that optically connects the hollow axle 2004 to the long distance high power laser beam transmission means 2025 that is located inside of the coiled tubing 2012. Thus, in this way the laser transmission means 2008, the hollow axle 2004 and the long distance high power laser beam transmission means 2025 are rotatably optically connected, so that the laser beam can be transmitted from the laser to the long distance high power laser beam transmission means 2025.
A further illustration of an optical connection for a rotation spool is provided in
In addition to using a rotating spool of coiled tubing, as illustrated in
The source of fluid may be either a gas, a liquid, a foam, or system having multiple capabilities. The fluid may serve many purposes in the advancement of the borehole. Thus, the fluid is primarily used for the removal of cuttings from the bottom of the borehole, for example as is commonly referred to as drilling fluid or drilling mud, and to keep the area between the end of the laser optics in the bottom hole assembly and the bottom of the borehole sufficiently clear of cuttings so as to not interfere with the path and power of the laser beam. It also may function to cool the laser optics and the bottom hole assembly, as well as, in the case of an incompressible fluid, or a compressible fluid under pressure. The fluid further provides a means to create hydrostatic pressure in the well bore to prevent influx of gases and fluids.
Thus, in selecting the type of fluid, as well as the fluid delivery system, consideration should be given to, among other things, the laser wavelength, the optics assembly, the geological conditions of the borehole, the depth of the borehole, and the rate of cuttings removal that is needed to remove the cuttings created by the laser's advancement of the borehole. It is highly desirable that the rate of removal of cuttings by the fluid not be a limiting factor to the systems rate of advancing a borehole. For example fluids that may be employed with the present invention include conventional drilling muds, water (provided they are not in the optical path of the laser), and fluids that are transmissive to the laser, such as halocarbons, (halocarbon are low molecular weight polymers of chlorotrifluoroethylene (PCTFE)), oils and N2. Preferably these fluids can be employed and preferred and should be delivered at rates from a couple to several hundred CFM at a pressure ranging from atmospheric to several hundred psi. If combinations of these fluids are used flow rates should be employed to balance the objects of maintaining the trasmissiveness of the optical path and removal of debris.
Preferably the long distance high powered laser beam transmission means is an optical fiber or plurality of optical fibers in an armored casing to conduct optical power from about 1 kW to about 20 kW, from about 10 kW to about 20 kW, at least about 10 kW, and preferably about 20 or more kW average power down into a borehole for the purpose of sensing the lithology, testing the lithology, boring through the lithology and other similar applications relating in general to the creation, advancement and testing of boreholes in the earth. Preferably the armored optical fiber comprises a 0.64 cm (¼″) stainless steel tube that has 1, 2, 1 to 10, at least 2, more than 2, at least about 50, at least about 100, and most preferably between 2 to 15 optical fibers in it. Preferably these will be about 500 micron core diameter baseline step index fibers
At present it is believed that Industrial lasers use high power optical fibers armored with steel coiled around the fiber and a polymer jacket surrounding the steel jacket to prevent unwanted dust and dirt from entering the optical fiber environment. The optical fibers are coated with a thin coating of metal or a thin wire is run along with the fiber to detect a fiber break. A fiber break can be dangerous because it can result in the rupture of the armor jacket and would pose a danger to an operator. However, this type of fiber protection is designed for ambient conditions and will not withstand the harsh environment of the borehole.
Fiber optic sensors for the oil and gas industry are deployed both unarmored and armored. At present it is believed that the currently available unarmored approaches are unacceptable for the high power applications contemplated by this application. The current manifestations of the armored approach are similarly inadequate, as they do not take into consideration the method for conducting high optical power and the method for detecting a break in the optical fiber, both of which are important for a reliable and safe system. The current method for armoring an optical fiber is to encase it in a stainless steel tube, coat the fiber with carbon to prevent hydrogen migration, and finally fill the tube with a gelatin that both cushions the fiber and absorbs hydrogen from the environment. However this packaging has been performed with only small diameter core optical fibers (50 microns) and with very low power levels <1 Watt optical power.
Thus, to provide for a high power optical fiber that is useful in the harsh environment of a borehole, there is provided a novel armored fiber and method. Thus, it is provided to encase a large core optical fiber having a diameter equal to or greater than 50 microns, equal to or greater than 75 microns and most preferably equal to or greater than 100 microns, or a plurality of optical fibers into a metal tube, where each fiber may have a carbon coating, as well as a polymer, and may include Teflon coating to cushion the fibers when rubbing against each other during deployment. Thus the fiber, or bundle of fibers, can have a diameter of from about greater than or equal to 150 microns to about 700 microns, 700 microns to about 1.5 mm, or greater than 1.5 mm.
The carbon coating can range in thicknesses from 10 microns to >600 microns. The polymer or Teflon coating can range in thickness from 10 microns to >600 microns and preferred types of such coating are acrylate, silicone, polyimide, PFA and others. The carbon coating can be adjacent the fiber, with the polymer or Teflon coating being applied to it. Polymer or Teflon coatings are applied last to reduce binding of the fibers during deployment.
In some non-limiting embodiments, fiber optics may send up to 10 kW per a fiber, up to 20 kW per a fiber, up to and greater than 50 kw per fiber. The fibers may transmit any desired wavelength or combination of wavelengths. In some embodiments, the range of wavelengths the fiber can transmit may preferably be between about 800 nm and 2100 nm. The fiber can be connected by a connector to another fiber to maintain the proper fixed distance between one fiber and neighboring fibers. For example, fibers can be connected such that the beam spot from neighboring optical fibers when irradiating the material, such as a rock surface are under 2″ and non-overlapping to the particular optical fiber. The fiber may have any desired core size. In some embodiments, the core size may range from about 50 microns to 1 mm or greater. The fiber can be single mode or multimode. If multimode, the numerical aperture of some embodiments may range from 0.1 to 0.6. A lower numerical aperture may be preferred for beam quality, and a higher numerical aperture may be easier to transmit higher powers with lower interface losses. In some embodiments, a fiber laser emitted light at wavelengths comprised of 1060 nm to 1080 nm, 1530 nm to 1600 nm, 1800 nm to 2100 nm, diode lasers from 800 nm to 2100 nm, C02 Laser at 10,600 nm, or Nd:YAG Laser emitting at 1064 nm can couple to the optical fibers. In some embodiments, the fiber can have a low water content. The fiber can be jacketed, such as with polyimide, acrylate, carbon polyamide, and carbon/dual acrylate or other material. If requiring high temperatures, a polyimide or a derivative material may be used to operate at temperatures over 300 degrees Celsius. The fibers can be a hollow core photonic crystal or solid core photonic crystal. In some embodiments, using hollow core photonic crystal fibers at wavelengths of 1500 nm or higher may minimize absorption losses.
The use of the plurality of optical fibers can be bundled into a number of configurations to improve power density. The optical fibers forming a bundle may range from two at hundreds of watts to kilowatt powers in each fiber to millions at milliwatts or microwatts of power. In some embodiments, the plurality of optical fibers may be bundled and spliced at powers below 2.5 kW to step down the power. Power can be spliced to increase the power densities through a bundle, such as preferably up to 10 kW, more preferably up to 20 kW, and even more preferably up to or greater than 50 kW. The step down and increase of power allows the beam spot to increase or decrease power density and beam spot sizes through the fiber optics. In most examples, splicing the power to increase total power output may be beneficial so that power delivered through fibers does not reach past the critical power thresholds for fiber optics.
Thus, by way of example there is provided the following configurations set forth in Table 3 herein.
A thin wire may also be packaged, for example in the ¼″ stainless tubing, along with the optical fibers to test the fiber for continuity. Alternatively a metal coating of sufficient thickness is applied to allow the fiber continuity to be monitored. These approaches, however, become problematic as the fiber exceeds 1 km in length, and do not provide a practical method for testing and monitoring.
The configurations in Table 3 can be of lengths equal to or greater than 1 m, equal to or greater than 1 km, equal to or greater than 2 km, equal to or greater than 3 km, equal to or greater than 4 km and equal to or greater than 5 km. These configuration can be used to transmit there through power levels from about 0.5 kW to about 10 kW, from greater than or equal to 1 kW, greater than or equal to 2 kW, greater than or equal to 5 kW, greater than or equal to 8 kW, greater than or equal to 10 kW and preferable at least about 20 kW.
In transmitting power over long distances, such as down a borehole or through a cable that is at least 1 km, there are three sources of power losses in an optical fiber, Raleigh Scattering, Raman Scattering and Brillioun Scattering. The first, Raleigh Scattering is the intrinsic losses of the fiber due to the impurities in the fiber. The second, Raman Scattering can result in Stimulated Raman Scattering in a Stokes or Anti-Stokes wave off of the vibrating molecules of the fiber. Raman Scattering occurs preferentially in the forward direction and results in a wavelength shift of up to +25 nm from the original wavelength of the source. The third mechanism, Brillioun Scattering, is the scattering of the forward propagating pump off of the acoustic waves in the fiber created by the high electric fields of the original source light (pump). This third mechanism is highly problematic and may create great difficulties in transmitting high powers over long distances. The Brillioun Scattering can give rise to Stimulated Brillioun Scattering (SBS) where the pump light is preferentially scattered backwards in the fiber with a frequency shift of approximately 1 to about 20 GHz from the original source frequency. This Stimulated Brillioun effect can be sufficiently strong to backscatter substantially all of the incident pump light if given the right conditions. Therefore it is desirable to suppress this non-linear phenomenon. There are essentially four primary variables that determine the threshold for SBS: the length of the gain medium (the fiber); the linewidth of the source laser; the natural Brillioun linewidth of the fiber the pump light is propagating in; and, the mode field diameter of the fiber. Under typical conditions and for typical fibers, the length of the fiber is inversely proportional to the power threshold, so the longer the fiber, the lower the threshold. The power threshold is defined as the power at which a high percentage of incident pump radiation will be scattered such that a positive feedback takes place whereby acoustic waves are generated by the scattering process. These acoustic waves then act as a grating to incite further SBS. Once the power threshold is passed, exponential growth of scattered light occurs and the ability to transmit higher power is greatly reduced. This exponential growth continues with an exponential reduction in power until such point whereby any additional power input will not be transmitted forward which point is defined herein as the maximum transmission power. Thus, the maximum transmission power is dependent upon the SBS threshold, but once reached, the maximum transmission power will not increase with increasing power input.
Thus, as provided herein, novel and unique means for suppressing nonlinear scattering phenomena, such as the SBS and Stimulated Raman Scattering phenomena, means for increasing power threshold, and means for increasing the maximum transmission power are set forth for use in transmitting high power laser energy over great distances for, among other things, the advancement of boreholes.
The mode field diameter needs to be as large as practical without causing undue attenuation of the propagating source laser. Large core single mode fibers are currently available with mode diameters up to 30 microns, however bending losses are typically high and propagation losses are higher than desired. Small core step index fibers, with mode field diameters of 50 microns are of interest because of the low intrinsic losses, the significantly reduced launch fluence and the decreased SBS gain because the fiber is not polarization preserving, it also has a multi-mode propagation constant and a large mode field diameter. All of these factors effectively increase the SBS power threshold. Consequently, a larger core fiber with low Raleigh Scattering losses is a potential solution for transmitting high powers over great distances, preferably where the mode field diameter is 50 microns or greater in diameter.
The next consideration is the natural Brillioun linewidth of the fiber. As the Brillioun linewidth increases, the scattering gain factor decreases. The Brillioun linewidth can be broadened by varying the temperature along the length of the fiber, modulating the strain on the fiber and inducing acoustic vibrations in the fiber. Varying the temperature along the fiber results in a change in the index of refraction of the fiber and the background (kT) vibration of the atoms in the fiber effectively broadening the Brillioun spectrum. In down borehole application the temperature along the fiber will vary naturally as a result of the geothermal energy that the fiber will be exposed to as the depths ranges expressed herein. The net result will be a suppression of the SBS gain. Applying a thermal gradient along the length of the fiber could be a means to suppress SBS by increasing the Brillioun linewidth of the fiber. For example, such means could include using a thin film heating element or variable insulation along the length of the fiber to control the actual temperature at each point along the fiber. Applied thermal gradients and temperature distributions can be, but are not limited to, linear, step-graded, and periodic functions along the length of the fiber.
Modulating the strain for the suppression of nonlinear scattering phenomena, on the fiber can be achieved, but those means are not limited to anchoring the fiber in its jacket in such a way that the fiber is strained. By stretching each segment between support elements selectively, then the Brillioun spectrum will either red shift or blue shift from the natural center frequency effectively broadening the spectrum and decreasing the gain. If the fiber is allowed to hang freely from a tensioner, then the strain will vary from the top of the hole to the bottom of the hole, effectively broadening the Brillioun gain spectrum and suppressing SBS. Means for applying strain to the fiber include, but are not limited to, twisting the fiber, stretching the fiber, applying external pressure to the fiber, and bending the fiber. Thus, for example, as discussed above, twisting the fiber can occur through the use of a creel. Moreover, twisting of the fiber may occur through use of downhole stabilizers designed to provide rotational movement. Stretching the fiber can be achieved, for example as described above, by using support elements along the length of the fiber. Downhole pressures may provide a pressure gradient along the length of the fiber thus inducing strain.
Acoustic modulation of the fiber can alter the Brillioun linewidth. By placing acoustic generators, such as piezo crystals along the length of the fiber and modulating them at a predetermined frequency, the Brillioun spectrum can be broadened effectively decreasing the SBS gain. For example, crystals, speakers, mechanical vibrators, or any other mechanism for inducing acoustic vibrations into the fiber may be used to effectively suppress the SBS gain. Additionally, acoustic radiation can be created by the escape of compressed air through predefined holes, creating a whistle effect.
The interaction of the source linewidth and the Brillioun linewidth in part defines the gain function. Varying the linewidth of the source can suppress the gain function and thus suppress nonlinear phenomena such as SBS. The source linewidth can be varied, for example, by FM modulation or closely spaced wavelength combined sources, an example of which is illustrated in
Additionally, a spectral beam combination of laser sources which may be used to suppress Stimulated Brillioun Scattering. Thus the spaced wavelength beams, the spacing as described herein, can suppress the Stimulated Brillioun Scattering through the interference in the resulting acoustic waves, which will tend to broaden the Stimulated Brillioun Spectrum and thus resulting in lower Stimulated Brillioun Gain. Additionally, by utilizing multiple colors the total maximum transmission power can be increased by limiting SBS phenomena within each color. An example of such a laser system is illustrated in
Raman scattering can be suppressed by the inclusion of a wavelength-selective filter in the optical path. This filter can be a reflective, transmissive, or absorptive filter. Moreover, an optical fiber connector can include a Raman rejection filter. Additionally a Raman rejection filter could be integral to the fiber. These filters may be, but are not limited to, a bulk filter, such as a dichroic filter or a transmissive grating filter, such as a Bragg grating filter, or a reflective grating filter, such as a ruled grating. For any backward propagating Raman energy, as well as, a means to introduce pump energy to an active fiber amplifier integrated into the overall fiber path, is contemplated, which, by way of example, could include a method for integrating a rejection filter with a coupler to suppress Raman Radiation, which suppresses the Raman Gain. Further, Brillioun scattering can be suppressed by filtering as well. Faraday isolators, for example, could be integrated into the system. A Bragg Grating reflector tuned to the Brillioun Scattering frequency could also be integrated into the coupler to suppress the Brillioun radiation.
To overcome power loss in the fiber as a function of distance, active amplification of the laser signal can be used. An active fiber amplifier can provide gain along the optical fiber to offset the losses in the fiber. For example, by combining active fiber sections with passive fiber sections, where sufficient pump light is provided to the active, i.e., amplified section, the losses in the passive section will be offset. Thus, there is provided a means to integrate signal amplification into the system. In
A further method is to use dense wavelength beam combination of multiple laser sources to create an effective linewidth that is many times the natural linewidth of the individual laser effectively suppressing the SBS gain. Here multiple lasers each operating at a predetermined wavelength and at a predetermined wavelength spacing are superimposed on each other, for example by a grating. The grating can be transmissive or reflective.
The optical fiber or fiber bundle can be encased in an environmental shield to enable it to survive at high pressures and temperatures. The cable could be similar in construction to the submarine cables that are laid across the ocean floor and maybe buoyant if the hole is filled with water. The cable may consist of one or many optical fibers in the cable, depending on the power handling capability of the fiber and the power required to achieve economic drilling rates. It being understood that in the field several km of optical fiber will have to be delivered down the borehole. The fiber cables maybe made in varying lengths such that shorter lengths are used for shallower depths so higher power levels can be delivered and consequently higher drilling rates can be achieved. This method requires the fibers to be changed out when transitioning to depths beyond the length of the fiber cable. Alternatively a series of connectors could be employed if the connectors could be made with low enough loss to allow connecting and reconnecting the fiber(s) with minimal losses.
Thus, there is provided in Tables 4 and 5 herein power transmissions for exemplary optical cable configurations.
The optical fibers are preferably placed inside the coiled tubing for advancement into and removal from the borehole. In this manner the coiled tubing would be the primary load bearing and support structure as the tubing is lowered into the well. It can readily be appreciated that in wells of great depth the tubing will be bearing a significant amount of weight because of its length. To protect and secure the optical fibers, including the optical fiber bundle contained in the, for example, ¼″ stainless steel tubing, inside the coiled tubing stabilization devices are desirable. Thus, at various intervals along the length of the coiled tubing supports can be located inside the coiled tubing that fix or hold the optical fiber in place relative to the coiled tubing. These supports, however, should not interfere with, or otherwise obstruct, the flow of fluid, if fluid is being transmitted through the coiled tubing. An example of a commercially available stabilization system is the ELECTROCOIL System. These support structures, as described above, may be used to provide strain to the fiber for the suppression of nonlinear phenomena.
Although it is preferable to place the optical fibers within the tubing, the fibers may also be associated with the tubing by, for example, being run parallel to the tubing, and being affixed thereto, by being run parallel to the tubing and being slidably affixed thereto, or by being placed in a second tubing that is associated or not associated with the first tubing. In this way, it should be appreciated that various combinations of tubulars may be employed to optimize the delivery of laser energy, fluids, and other cabling and devices into the borehole. Moreover, the optical fiber may be segmented and employed with conventional strands of drilling pipe and thus be readily adapted for use with a conventional mechanical drilling rig outfitted with connectable tubular drill pipe.
During drilling operations, and in particular during deep drilling operations, e.g., depths of greater than 1 km, it may be desirable to monitor the conditions at the bottom of the borehole, as well as, monitor the conditions along and in the long distance high powered laser beam transmission means. Thus, there is further provided the use of an optical pulse, train of pulses, or continuous signal, that are continuously monitored that reflect from the distal end of the fiber and are used to determine the continuity of the fiber. Further, there is provided for the use of the fluorescence from the illuminated surface as a means to determine the continuity of the optical fiber. A high power laser will sufficiently heat the rock material to the point of emitting light. This emitted light can be monitored continuously as a means to determine the continuity of the optical fiber. This method is faster than the method of transmitting a pulse through the fiber because the light only has to propagate along the fiber in one direction. Additionally there is provided the use of a separate fiber to send a probe signal to the distal end of the armored fiber bundle at a wavelength different than the high power signal and by monitoring the return signal on the high power optical fiber, the integrity of the fiber can be determined.
These monitoring signals may transmit at wavelengths substantially different from the high power signal such that a wavelength selective filter may be placed in the beam path uphole or downhole to direct the monitoring signals into equipment for analysis. For example, this selective filter may be placed in the creel or spool described herein.
To facilitate such monitoring an Optical Spectrum Analyzer or Optical Time Domain Reflectometer or combinations thereof may be used. An AnaritsuMS9710C Optical Spectrum Analyzer having: a wavelength range of 600 nm-1.7 microns; a noise floor of 90 dBm @ 10 Hz, −40 dBm @ 1 MHz; a 70 dB dynamic range at 1 nm resolution; and a maximum sweep width: 1200 nm and an Anaritsu CMA 4500 OTDR may be used.
The efficiency of the laser's cutting action can also be determined by monitoring the ratio of emitted light to the reflected light. Materials undergoing melting, spallation, thermal dissociation, or vaporization will reflect and absorb different ratios of light. The ratio of emitted to reflected light may vary by material further allowing analysis of material type by this method. Thus, by monitoring the ratio of emitted to reflected light material type, cutting efficiency, or both may be determined. This monitoring may be performed uphole, downhole, or a combination thereof.
Moreover, for a variety of purposes such as powering downhole monitoring equipment, electrical power generation may take place in the borehole including at or near the bottom of the borehole. This power generation may take place using equipment known to those skilled in the art, including generators driven by drilling muds or other downhole fluids, means to convert optical to electrical power, and means to convert thermal to electrical power.
The bottom hole assembly contains the laser optics, the delivery means for the fluid and other equipment. In general the bottom hole assembly contains the output end, also referred to as the distal end, of the long distance high power laser beam transmission means and preferably the optics for directing the laser beam to the earth or rock to be removed for advancing the borehole, or the other structure intended to be cut.
The present systems and in particular the bottom hole assembly, may include one or more optical manipulators. An optical manipulator may generally control a laser beam, such as by directing or positioning the laser beam to spall material, such as rock. In some configurations, an optical manipulator may strategically guide a laser beam to spall material, such as rock. For example, spatial distance from a borehole wall or rock may be controlled, as well as the impact angle. In some configurations, one or more steerable optical manipulators may control the direction and spatial width of the one or more laser beams by one or more reflective mirrors or crystal reflectors. In other configurations, the optical manipulator can be steered by an electro-optic switch, electroactive polymers, galvonometers, piezoelectrics, and/or rotary/linear motors. In at least one configuration, an infrared diode laser or fiber laser optical head may generally rotate about a vertical axis to increase aperture contact length. Various programmable values such as specific energy, specific power, pulse rate, duration and the like maybe implemented as a function of time. Thus, where to apply energy may be strategically determined, programmed and executed so as to enhance a rate of penetration and/or laser/rock interaction, to enhance the overall efficiency of borehole advancement, and to enhance the overall efficiency of borehole completion, including reducing the number of steps on the critical path for borehole completion. One or more algorithms may be used to control the optical manipulator.
Thus, by way of example, as illustrated in
In use, the high energy laser beam, for example greater than 10 kW, would travel down the fibers 9002, exit the ends of the fibers 9003 and travel through the sealed chamber and pupil plane 9004 into the optics 9006, where it would be shaped and focused into an elliptical spot. The laser beam would then strike the bottom of the borehole spalling, melting, thermally dissociating, and/or vaporizing the rock and earth struck and thus advance the borehole. The lower part 9001 would be rotating and this rotation would cause the elliptical laser spot to rotate around the bottom of the borehole. This rotation would also cause the rollers 9008, 9009 to physically dislodge any material that was crystallized by the laser or otherwise sufficiently fixed to not be able to be removed by the flow of the fluid alone. The cuttings would be cleared from the laser path by the laminar flow of the fluid, as well as, by the action of the rollers 9008, 9009 and the cuttings would then be carried up the borehole by the action of the fluid from the air amplifier 9005, as well as, the laminar flow opening 9007.
In general, the LBHA may contain an outer housing that is capable of withstanding the conditions of a downhole environment, a source of a high power laser beam, and optics for the shaping and directing a laser beam on the desired surfaces of the borehole, casing, or formation. The high power laser beam may be greater than about 1 kW, from about 2 kW to about 20 kW, greater than about 5 kW, from about 5 kW to about 10 kW, preferably at least about 10 kW, at least about 15 kW, and at least about 20 kW. The assembly may further contain or be associated with a system for delivering and directing fluid to the desired location in the borehole, a system for reducing or controlling or managing debris in the laser beam path to the material surface, a means to control or manage the temperature of the optics, a means to control or manage the pressure surrounding the optics, and other components of the assembly, and monitoring and measuring equipment and apparatus, as well as, other types of downhole equipment that are used in conventional mechanical drilling operations. Further, the LBHA may incorporate a means to enable the optics to shape and propagate the beam which for example would include a means to control the index of refraction of the environment through which the laser is propagating. Thus, as used herein the terms control and manage are understood to be used in their broadest sense and would include active and passive measures as well as design choices and materials choices.
The LBHA should be construed to withstand the conditions found in boreholes including boreholes having depths of about 1,640 ft (0.5 km) or more, about 3,280 ft (1 km) or more, about 9,830 ft (3 km) or more, about 16,400 ft (5 km) or more, and up to and including about 22,970 ft (7 km) or more. While drilling, i.e. advancement of the borehole, is taking place the desired location in the borehole may have dust, drilling fluid, and/or cuttings present. Thus, the LBHA should be constructed of materials that can withstand these pressures, temperatures, flows, and conditions, and protect the laser optics that are contained in the LBHA. Further, the LBHA should be designed and engineered to withstand the downhole temperatures, pressures, and flows and conditions while managing the adverse effects of the conditions on the operation of the laser optics and the delivery of the laser beam.
The LBHA should also be constructed to handle and deliver high power laser energy at these depths and under the extreme conditions present in these deep downhole environments. Thus, the LBHA and its laser optics should be capable of handling and delivering laser beams having energies of 1 kW or more, 5 kW or more, 10 kW or more and 20 kW or more. This assembly and optics should also be capable of delivering such laser beams at depths of about 1,640 ft (0.5 km) or more, about 3,280 ft (1 km) or more, about 9,830 ft (3 km) or more, about 16,400 ft (5 km) or more, and up to and including about 22,970 ft (7 km) or more.
The LBHA should also be able to operate in these extreme downhole environments for extended periods of time. The lowering and raising of a bottom hole assembly has been referred to as tripping in and tripping out. While the bottom hole assembling is being tripped in or out the borehole is not being advanced. Thus, reducing the number of times that the bottom hole assembly needs to be tripped in and out will reduce the critical path for advancing the borehole, i.e., drilling the well, and thus will reduce the cost of such drilling. (As used herein the critical path referrers to the least number of steps that must be performed in serial to complete the well.) This cost savings equates to an increase in the drilling rate efficiency. Thus, reducing the number of times that the bottom hole assembly needs to be removed from the borehole directly corresponds to reductions in the time it takes to drill the well and the cost for such drilling. Moreover, since most drilling activities are based upon day rates for drilling rigs, reducing the number of days to complete a borehole will provided a substantial commercial benefit. Thus, the LBHA and its laser optics should be capable of handling and delivering laser beams having energies of 1 kW or more, 5 kW or more, 10 kW or more and 20 kW or more at depths of about 1,640 ft (0.5 km) or more, about 3,280 ft (1 km) or more, about 9,830 ft (3 km) or more, about 16,400 ft (5 km) or more, and up to and including about 22,970 ft (7 km) or more, for at least about ½ hr or more, at least about 1 hr or more, at least about 2 hours or more, at least about 5 hours or more, and at least about 10 hours or more, and preferably longer than any other limiting factor in the advancement of a borehole. In this way using the LBHA of the present invention could reduce tripping activities to only those that are related to casing and completion activities, greatly reducing the cost for drilling the well.
Thus, in general the cutting removal system may be typical of that used in an oil drilling system. These would include by way of example a shale shaker. Further, desanders and desilters and then centrifuges may be employed. The purpose of this equipment is to remove the cuttings so that the fluid can be recirculated and reused. If the fluid, i.e., circulating medium is gas, than a water misting systems may also be employed.
There is provided in
It is presently believed that the ratio of the flow rates between the first and the second flow paths should be from about 100% for the first flow path, 1:1, 1:10, to 1:100. Further, the use of fluid amplifiers are exemplary and it should be understood that a LBHA, or laser drilling in general, may be employed without such amplifiers. Moreover, fluid jets, air knives, or similar fluid directing means many be used in association with the LBHA, in conjunction with amplifiers or in lieu of amplifiers. A further example of a use of amplifiers would be to position the amplifier locations where the diameter of the borehole changes or the area of the annulus formed by the tubing and borehole change, such as the connection between the LBHA and the tubing. Further, any number of amplifiers, jets or air knifes, or similar fluid directing devices may be used, thus no such devices may be used, a pair of such devices may be used, and a plurality of such devices may be use and combination of these devices may be used. The cuttings or waste that is created by the laser (and the laser-mechanical means interaction) have terminal velocities that must be overcome by the flow of the fluid up the borehole to remove them from the borehole. Thus for example if cuttings have terminal velocities of for sandstone waste from about 4 m/sec. to about 7 m/sec., granite waste from about 3.5 m/sec. to 7 m/sec., basalt waste from about 3 m/sec. to 8 m/sec., and for limestone waste less than 1 m/sec these terminal velocities would have to be overcome.
In
There is provided in
The illustrative outlet port of
There is provided in
To further illustrate the advantages, uses, operating parameters and applications of the present invention, by way of example and without limitation, the following suggested exemplary studies are proposed.
Test exposure times of 0.05 s, 0.1 s, 0.2 s, 0.5 s and 1 s will be used for granite and limestone. Power density will be varied by changing the beam spot diameter (circular) and elliptical area of 12.5 mm×0.5 mm with a time-average power of 0.5 kW, 1.6 kW, 3 kW, 5 kW will be used. In addition to continuous wave beam, pulsed power will also be tested for spallation zones.
The ability to chip a rectangular block of material, such as rock will be demonstrated in accordance with the systems and methods disclosed herein. The setup is presented in the table below, and the end of the block of rock will be used as a ledge. Blocks of granite, sandstone, limestone, and shale (if possible) will each be spalled at an angle at the end of the block (chipping rock around a ledge). The beam spot will then be moved consecutively to other parts of the newly created ledge from the chipped rock to break apart a top surface of the ledge to the end of the block. Chipping approximately 1″×1″×1″ sized rock particles will be the goal. Applied SP and SE will be selected based on previously recorded spallation data and information gleaned from Experiments 1 and 2 presented above. ROP to chip the rock will be determined, and the ability to chip rock to desired specifications will be demonstrated.
Multiple beam chipping will be demonstrated. Spalling overlap in material, such as rock resulting from two spaced apart laser beams will be tested. Two laser beams will be run at distances of 0.2″, 0.5″, 1″, 1.5″ away from each other, as outlined in the experimental setup below. Granite, sandstone, limestone, and shale will each be used. Rock fractures will be tested by spalling at the determined spalling zone parameters for each material. Purge gas will be accounted for. Rock fractures will overlap to chip away pieces of rock. The goal will be to yield rock chips of the desired 1″×1″×1″ size. Chipping rock from two beams at a spaced distance will determine optimal particle sizes that can be chipped effectively, providing information about particle sizes to spall and ROP for optimization.
Spelling multiple points with multiple beams will be performed to demonstrate the ability to chip material, such as rock in a pattern. Various patterns will be evaluated on different types of rock using the parameters below. Patterns utilizing a linear spot approximately 1 cm×15.24 cm, an elliptical spot with major axis approximately 15.24 cm and minor axis approximately 1 cm, a single circular spot having a diameter of 1 cm, an array of spots having a diameter of 1 cm with the spacing between the spots being approximately equal to the spot diameter, the array having 4 spots spaced in a square, spaced along a line. The laser beam will be delivered to the rock surface in a shot sequence pattern wherein the laser is fired until spallation occurs and then the laser is directed to the next shot in the pattern and then fired until spallation occurs with this process being repeated. In the movement of the linear and elliptical patterns the spots are in effect rotated about their central axis. In the pattern comprising the array of spots the spots may be rotated about their central axis, and rotated about an axis point as in the hands of a clock moving around a face.
From the foregoing examples and detailed teaching it can be seen that in general one or more laser beams may spall, chip, vaporize, or melt the material, such as rock in a pattern using an optical manipulator. Thus, the rock may be patterned by spalling to form rock fractures surrounding a segment of the rock to chip that piece of rock. The laser beam spot size may spall, vaporize, or melt the rock at one angle when interacting with rock at high power. Further, the optical manipulator system may control two or more laser beams to converge at an angle so as to meet close to a point near a targeted piece of rock. Spallation may then form rock fractures overlapping and surrounding the target rock to chip the target rock and enable removal of larger rock pieces, such as incrementally. Thus, the laser energy may chip a piece of rock up to 1″ depth and 1″ width or greater. Of course, larger or smaller rock pieces may be chipped depending on factors such as the type of rock formation, and the strategic determination of the most efficient technique.
There is provided by way of examples illustrative and simplified plans of potential drilling scenarios using the laser drilling systems and apparatus of the present invention.
Moreover, one or more laser beams may form a ledge out of material, such as rock by spalling the rock in a pattern. One or more laser beams may spall rock at an angle to the ledge forming rock fractures surrounding the ledge to chip the piece of rock surrounding the ledge. Two or more beams may chip the rock to create a ledge. The laser beams can spall the rock at an angle to the ledge forming rock fractures surrounding the ledge to further chip the rock. Multiple rocks can be chipped simultaneously by more than one laser beams after one or more rock ledges are created to chip the piece of rock around the ledge or without a ledge by converging two beams near a point by spalling; further a technique known as kerfing may be employed.
In accordance with the teaching of the invention, a fiber laser or liquid crystal laser may be optically pumped in a range from 750 nm to 2100 nm wavelength by an infrared laser diode. A fiber laser or liquid crystal laser may be supported or extend from the infrared laser diode downhole connected by an optical fiber transmitting from infrared diode laser to fiber laser or liquid crystal laser at the infrared diode laser wavelength. The fiber cable may be composed of a material such as silica, PMMA/perfluirnated polymers, hollow core photonic crystals, or solid core photonic crystals that are in single-mode or multimode. Thus, the optical fiber may be encased by a coiled tubing or reside in a rigid drill-string. On the other hand, the light may be transmitted from the infrared diode range from the surface to the fiber laser or liquid crystal laser downhole. One or more infrared diode lasers may be on the surface.
A laser may be conveyed into the wellbore by a conduit made of coiled tubing or rigid drill-string. A power cable may be provided. A circulation system may also be provided. The circulation system may have a rigid or flexible tubing to send a liquid or gas downhole. A second tube may be used to raise the rock cuttings up to the surface. A pipe may send or convey gas or liquid in the conduit to another pipe, tube or conduit. The gas or liquid may create an air knife by removing material, such as rock debris from the laser head. A nozzle, such as a Laval nozzle may be included. For example, a Laval-type nozzle may be attached to the optical head to provide pressurized gas or liquid. The pressurized gas or liquid may be transmissive to the working wavelength of the infrared diode laser or fiber laser light to force drilling muds away from the laser path. Additional tubing in the conduit may send a lower temperature liquid downhole than ambient temperature at a depth to cool the laser in the conduit. One or more liquid pumps may be used to return cuttings and debris to the surface by applying pressure uphole drawing incompressible fluid to the surface.
The drilling mud in the well may be transmissive to visible, near-IR range, and mid-IR wavelengths so that the laser beam has a clear optical path to the rock without being absorbed by the drilling mud.
Further, spectroscopic sample data may be detected and analyzed. Analysis may be conducted simultaneously while drilling from the heat of the rock being emitted. Spectroscopic samples may be collected by laser-induced breakdown derivative spectroscopy. Pulsed power may be supplied to the laser-rock impingement point by the infrared diode laser. The light may be analyzed by a single wavelength detector attached to the infrared diode laser. For example, Raman-shifted light may be measured by a Raman spectrometer. Further, for example, a tunable diode laser using a few-mode fiber Bragg grating may be implemented to analyze the band of frequencies of the fluid sample by using ytterbium, thulium, neodymium, dysprosium, praseodymium, or erbium as the active medium. In some embodiments, a chemometric equation, or least mean square fit may be used to analyze the Raman spectra. Temperature, specific heat, and thermal diffusivity may be determined. In at least one embodiment, data may be analyzed by a neural network. The neural network may be updated real-time while drilling. Updating the diode laser power output from the neural network data may optimize drilling performance through rock formation type.
An apparatus to geo-navigate the well for logging may be included or associated with the drilling system. For example, a magnemometer, 3-axis accelerometer, and/or gyroscope may be provided. As discussed with respect to the laser, the geo-navigation device may be encased, such as with steel, titanium, diamond, or tungsten carbide. The geo-navigation device may be encased together with the laser or independently. In some embodiments, data from the geo-navigation device may direct the directional movement of the apparatus downhole from a digital signal processor.
A high power optical fiber bundle may, by way of example, hang from an infrared diode laser or fiber laser downhole. The fiber may generally be coupled with the diode laser to transmit power from the laser to the rock formation. In at least one embodiment, the infrared diode laser may be fiber coupled at a wavelength range between 800 nm to 1000 nm. In some embodiments, the fiber optical head may not be in contact with the borehole. The optical cable may be a hollow core photonic crystal fiber, silica fiber, or plastic optical fibers including PMMA/perfluorinated polymers that are in single or multimode. In some embodiments, the optical fiber may be encased by a coiled or rigid tubing. The optical fiber may be attached to a conduit with a first tube to apply gas or liquid to circulate the cuttings. A second tube may supply gas or liquid to, for example, a Laval nozzle jet to clear debris from the laser head. In some embodiments, the ends of the optical fibers are encased in a head composed of a steerable optical manipulator and mirrors or crystal reflector. The encasing of the head may be composed of sapphire or a related material. An optical manipulator may be provided to rotate the optical fiber head. In some embodiments, the infrared diode laser may be fully encased by steel, titanium, diamond, or tungsten carbide residing above the optical fibers in the borehole. In other embodiments, it may be partially encased.
Single or multiple fiber optical cables may be tuned to wavelengths of the near-IR, mid-IR, and far-IR received from the infrared diode laser inducement of the material, such as rock for derivative spectroscopy sampling. A second optical head powered by the infrared diode laser above the optical head drilling may case the formation liner. The second optical head may extend from the infrared diode laser with light being transmitted through a fiber optic. In some configurations, the fiber optic may be protected by coiled tubing. The infrared diode laser optical head may perforate the steel and concrete casing. In at least one embodiment, a second infrared diode laser above the first infrared diode laser may case the formation liner while drilling.
In accordance with one or more configurations, a fiber laser or infrared diode laser downhole may transmit coherent light down a hollow tube without the light coming in contact with the tube when placed downhole. The hollow tube may be composed of any material. In some configurations, the hollow tube may be composed of steel, titanium or silica. A mirror or reflective crystal may be placed at the end of the hollow tube to direct collimated light to the material, such as a rock surface being drilled. In some embodiments, the optical manipulator can be steered by an electro-optic switch, electroactive polymers, galvonometers, piezoelectrics, or rotary/linear motors. A circulation system may be used to raise cuttings. One or more liquid pumps may be used to return cuttings to the surface by applying pressure uphole, drawing incompressible fluid to the surface. In some configurations, the optical fiber may be attached to a conduit with two tubes, one to apply gas or liquid to circulate the cuttings and one to supply gas or liquid to a Laval nozzle jet to clear debris from the laser head.
In a further embodiment of the present inventions there is provided a drilling rig for making a borehole in the earth to a depth of from about 1 km to about 5 km or greater, the rig comprising an armored fiber optic delivery bundle, consisting of from 1 to a plurality of coated optical fibers, having a length that is equal to or greater than the depth of the borehole, and having a means to coil and uncoil the bundle while maintaining an optical connection with a laser source. In yet a further embodiment of the present invention there is provided the method of uncoiling the bundle and delivering the laser beam to a point in the borehole and in particular a point at or near the bottom of the borehole. There is further provided a method of advancing the borehole, to depths in excess of 1 km, 2 km, up to and including 5 km, in part by delivering the laser beam to the borehole through armored fiber optic delivery bundle.
The novel and innovative armored bundles and associated coiling and uncoiling apparatus and methods of the present invention, which bundles may be a single or plurality of fibers as set forth herein, may be used with conventional drilling rigs and apparatus for drilling, completion and related and associated operations. The apparatus and methods of the present invention may be used with drilling rigs and equipment such as in exploration and field development activities. Thus, they may be used with, by way of example and without limitation, land based rigs, mobile land based rigs, fixed tower rigs, barge rigs, drill ships, jack-up platforms, and semi-submersible rigs. They may be used in operations for advancing the well bore, finishing the well bore and work over activities, including perforating the production casing. They may further be used in window cutting and pipe cutting and in any application where the delivery of the laser beam to a location, apparatus or component that is located deep in the well bore may be beneficial or useful.
Thus, by way of example, an LBHA is illustrated in
The upper part 1400 may be connected to the lower end of the coiled tubing, drill pipe, or other means to lower and retrieve the LBHA 14100 from the borehole. Further, it may be connected to stabilizers, drill collars, or other types of downhole assemblies (not shown in the figure), which in turn are connected to the lower end of the coiled tubing, drill pipe, or other means to lower and retrieve the LBHA 14100 from the borehole. The upper part 1400 further contains, is connect to, or otherwise optically associated with the means 1402 that transmitted the high power laser beam down the borehole so that the beam exits the lower end 1403 of the means 1402 and ultimately exits the LBHA 14100 to strike the intended surface of the borehole. The beam path of the high power laser beam is shown by arrow 1415. In
The upper part 1400 further is attached to, connected to or otherwise associated with a means to provide rotational movement 1410. Such means, for example, would be a downhole motor, an electric motor or a mud motor. The motor may be connected by way of an axle, drive shaft, drive train, gear, or other such means to transfer rotational motion 1411, to the lower part 1401 of the LBHA 14100. It is understood, as shown in the drawings for purposes of illustrating the underlying apparatus, that a housing or protective cowling may be placed over the drive means or otherwise associated with it and the motor to protect it form debris and harsh down hole conditions. In this manner the motor would enable the lower part 1401 of the LBHA 14100 to rotate. An example of a mud motor is the CAVO 1.7″ diameter mud motor. This motor is about 7 ft long and has the following specifications: 7 horsepower @ 110 ft-lbs full torque; motor speed 0-700 rpm; motor can run on mud, air, N2, mist, or foam; 180 SCFM, 500-800 psig drop; support equipment extends length to 12 ft; 10:1 gear ratio provides 0-70 rpm capability; and has the capability to rotate the lower part 1401 of the LBHA through potential stall conditions.
The upper part 1400 of the LBHA 14100 is joined to the lower part 1401 with a sealed chamber 1404 that is transparent to the laser beam and forms a pupil plane 1420 to permit unobstructed transmission of the laser beam to the beam shaping optics 1406 in the lower part 1401. The lower part 1401 is designed to rotate. The sealed chamber 1404 is in fluid communication with the lower chamber 1401 through port 1414. Port 1414 may be a one way valve that permits clean transmissive fluid and preferably gas to flow from the upper part 1400 to the lower part 1401, but does not permit reverse flow, or if may be another type of pressure and/or flow regulating value that meets the particular requirements of desired flow and distribution of fluid in the downhole environment. Thus, for example there is provided in
The lower part 1401 has a means for receiving rotational force from the motor 1410, which in the example of the figure is a gear 1412 located around the lower part housing 1419 and a drive gear 1413 located at the lower end of the axle 1411. Other means for transferring rotational power may be employed or the motor may be positioned directly on the lower part. It being understood that an equivalent apparatus may be employed which provide for the rotation of the portion of the LBHA to facilitate rotation or movement of the laser beam spot while that he same time not providing undue rotation, or twisting forces, to the optical fiber or other means transmitting the high power laser beam down the hole to the LBHA. In his way laser beam spot can be rotated around the bottom of the borehole. The lower part 1401 has a laminar flow outlet 1407 for the fluid to exit the LBHA 14100, and two hardened rollers 1408, 1409 at its lower end. Although a laminar flow is contemplated in this example, it should be understood that non-laminar flows, and turbulent flows may also be employed.
The two hardened rollers may be made of a stainless steel or a steel with a hard face coating such as tungsten carbide, chromium-cobalt-nickel alloy, or other similar materials. They may also contain a means for mechanically cutting rock that has been thermally degraded by the laser. They may range in length, i.e., from about 1 in to about 4 in and preferably are about 2-3 in and may be as large as or larger than 6 inches. Moreover in LBHAs for drilling larger diameter boreholes they may be in the range of 10-20 inches in diameter or greater.
Thus,
In use the high energy laser beam, for example greater than 15 kW, would enter the LBHA 14100, travel down fiber 1402, exit the end of the fiber 1403 and travel through the sealed chamber 1404 and pupil plane 1420 into the optics 1406, where it would be shaped and focused into a spot, the optics 1406 would further rotate the spot. The laser beam would then illuminate, in a potentially rotating manner, the bottom of the borehole spelling, chipping, melting, and/or vaporizing the rock and earth illuminated and thus advance the borehole. The lower part would be rotating and this rotation would further cause the rollers 1408, 1409 to physically dislodge any material that was effected by the laser or otherwise sufficiently fixed to not be able to be removed by the flow of the drilling fluid alone.
The cuttings would be cleared from the laser path by the flow of the fluid along the path 1417, as well as, by the action of the rollers 1408, 1409 and the cuttings would then be carried up the borehole by the action of the drilling fluid from the air amplifiers 1405, as well as, the laminar flow opening 1407.
It is understood that the configuration of the LBHA is
The optics 1406 should be selected to avoid or at least minimize the loss of power as the laser beam travels through them. The optics should further be designed to handle the extreme conditions present in the downhole environment, at least to the extent that those conditions are not mitigated by the housing 1419. The optics may provide laser beam spots of differing power distributions and shapes as set forth herein above. The optics may further provide a sign spot or multiple spots as set forth herein above.
Drilling may be conducted in a dry environment or a wet environment. An important factor is that the path from the laser to the rock surface should be kept as clear as practical of debris and dust particles or other material that would interfere with the delivery of the laser beam to the rock surface. The use of high brightness lasers provides another advantage at the process head, where long standoff distances from the last optic to the work piece are important to keeping the high pressure optical window clean and intact through the drilling process. The beam can either be positioned statically or moved mechanically, opto-mechanically, electro-optically, electromechanically, or any combination of the above to illuminate the earth region of interest.
In general, and by way of further example, the LBHA may comprise a housing, which may by way of example, be made up of sub-housings. These sub-housings may be integral, they may be separable, they may be removably fixedly connected, they may be rotatable, or there may be any combination of one or more of these types of relationships between the sub-housings. The LBHA may be connected to the lower end of the coiled tubing, drill pipe, or other means to lower and retrieve the LBHA from the borehole. Further, it may be connected to stabilizers, drill collars, or other types of downhole assemblies, which in turn are connected to the lower end of the coiled tubing, drill pipe, or other means to lower and retrieve the bottom hole assembly from the borehole. The LBHA has associated therewith a means that transmitted the high power energy from down the borehole.
The LBHA may also have associated with, or in, it means to handle and deliver drilling fluids. These means may be associated with some or all of the sub-housings. There are further provided mechanical scraping means, e.g. a PDC bit, to remove and/or direct material in the borehole, although other types of known bits and/or mechanical drilling heads by also be employed in conjunction with the laser beam. These scrapers or bits may be mechanically interacted with the surface or parts of the borehole to loosen, remove, scrap or manipulate such borehole material as needed. These scrapers may be from less than about 1 in to about 20 in. In use the high energy laser beam, for example greater than 15 kW, would travel down the fibers through optics and then out the lower end of the LBHA to illuminate the intended part of the borehole, or structure contained therein, spalling, melting and/or vaporizing the material so illuminated and thus advance the borehole or otherwise facilitating the removal of the material so illuminated.
In
Accordingly, the profiles of the beam interaction with the borehole to obtain a maximum amount of stress in the borehole in an efficient manner, and thus, increase the rate of advancement of the borehole can be obtained. Thus, for example if an elliptical spot is rotated about its center point for a beam that is either uniform or Gaussian the energy deposition profile is illustrated in
Thus, it is desirable to modify the beam deposition profile to obtain a substantially even and uniform deposition profile upon rotation of the beam. An example of such a preferred beam deposition profile is provided in
To obtain this preferable beam energy profile there are provided examples of optical assemblies that may be used with a LBHA. Thus, an example is illustrated in
A further example is illustrated in
A further example is illustrated in
A further example is illustrated in
There is further provided shot patterns for illuminating a borehole surface with a plurality of spots in a multi-rotating pattern. Accordingly in
There is illustrated in
There is further illustrated in
In accordance with one or more aspects, one or more fiber optic distal fiber ends may be arranged in a pattern. The multiplexed beam shape may comprise a cross, an x shape, a viewfinder, a rectangle, a hexagon, lines in an array, or a related shape where lines, squares, and cylinders are connected or spaced at different distances.
In accordance with one or more aspects, one or more refractive lenses, diffractive elements, transmissive gratings, and/or reflective lenses may be added to focus, scan, and/or change the beam spot pattern from the beam spots emitting from the fiber optics that are positioned in a pattern. One or more refractive lenses, diffractive elements, transmissive gratings, and/or reflective lenses may be added to focus, scan, and/or change the one or more continuous beam shapes from the light emitted from the beam shaping optics. A collimator may be positioned after the beam spot shaper lens in the transversing optical path plane. The collimator may be an aspheric lens, spherical lens system composed of a convex lens, thick convex lens, negative meniscus, and bi-convex lens, gradient refractive lens with an aspheric profile and achromatic doublets. The collimator may be made of the said materials, fused silica, ZnSe, SF glass, or a related material. The collimator may be coated to reduce or enhance reflectivity or transmission. Said optical elements may be cooled by a purging liquid or gas.
It is readily understood in the art that the terms lens and optic(al) elements, as used herein is used in its broadest terms and thus may also refer to any optical elements with power, such as reflective, transmissive or refractive elements,
In some aspects, the refractive positive lens may be a microlens. The microlens can be steered in the light propagating plane to increase/decrease the focal length as well as perpendicular to the light propagating plane to translate the beam. The microlens may receive incident light to focus to multiple foci from one or more optical fibers, optical fiber bundle pairs, fiber lasers, diode lasers; and receive and send light from one or more collimators, positive refractive lenses, negative refractive lenses, one or more mirrors, diffractive and reflective optical beam expanders, and prisms.
In some aspects, a diffractive optical element beam splitter could be used in conjunction with a refractive lens. The diffractive optical element beam splitter may form double beam spots or a pattern of beam spots comprising the shapes and patterns set forth above.
There is additionally provided a system and method for creating a borehole in the earth wherein the system and method employ means for providing the laser beam to the bottom surface in a predetermined energy deposition profile, including having the laser beam as delivered from the bottom hole assembly illuminating the bottom surface of the borehole with a predetermined energy deposition profile, illuminating the bottom surface with an any one of or combination of: a predetermined energy deposition profile biased toward the outside area of the borehole surface; a predetermined energy deposition profile biased toward the inside area of the borehole surface; a predetermined energy deposition profile comprising at least two concentric areas having different energy deposition profiles; a predetermined energy deposition profile provided by a scattered laser shot pattern; a predetermined energy deposition profile based upon the mechanical stresses applied by a mechanical removal means; a predetermined energy deposition profile having at least two areas of differing energy and the energies in the areas correspond inversely to the mechanical forces applied by a mechanical means.
There is yet further provided a method of advancing a borehole using a laser, the method comprising: advancing a high power laser beam transmission means into a borehole; the borehole having a bottom surface, a top opening, and a length extending between the bottom surface and the top opening of at least about 1000 feet; the transmission means comprising a distal end, a proximal end, and a length extending between the distal and proximal ends, the distal end being advanced down the borehole; the transmission means comprising a means for transmitting high power laser energy; providing a high power laser beam to the proximal end of the transmission means; transmitting substantially all of the power of the laser beam down the length of the transmission means so that the beam exits the distal end; transmitting the laser beam from the distal end to an optical assembly in a laser bottom hole assembly, the laser bottom hole assembly directing the laser beam to the bottom surface of the borehole; and, providing a predetermined energy deposition profile to the bottom of the borehole; whereby the length of the borehole is increased, in part, based upon the interaction of the laser beam with the bottom of the borehole.
Moreover there is provided a method of advancing a borehole using a laser, wherein the laser beam is directed to the bottom surface of the borehole in a substantially uniform energy deposition profile and thereby the length of the borehole is increased, in part, based upon the interaction of the laser beam with the bottom of the borehole.
In accordance with one or more aspects, a method for laser drilling using an optical pattern to chip rock formations is disclosed. The method may comprise irradiating the rock to spall, melt, or vaporize with one or more lasing beam spots, beam spot patterns and beam shapes at non-overlapping distances and timing patterns to induce overlapping thermal rock fractures that cause rock chipping of rock fragments. Single or multiple beam spots and beam patterns and shapes may be formed by refractive and reflective optics or fiber optics. The optical pattern, the pattern's timing, and spatial distance between non-overlapping beam spots and beam shapes may be controlled by the rock type thermal absorption at specific wavelength, relaxation time to position the optics, and interference from rock removal.
In some aspects, the lasing beam spot's power is either not reduced, reduced moderately, or fully during relaxation time when repositioning the beam spot on the rock surface. To chip the rock formation, two lasing beam spots may scan the rock surface and be separated by a fixed position of less than 2″ and non-overlapping in some aspects. Each of the two beam spots may have a beam spot area in the range between 0.1 cm2 and 25 cm2. The relaxation times when moving the two lasing beam spots to their next subsequent lasing locations on the rock surface may range between 0.05 ms and 2 s. When moving the two lasing beam spots to their next position, their power may either be not reduced, reduced moderately, or fully during relaxation time.
In accordance with one or more aspects, a beam spot pattern may comprise three or more beam spots in a grid pattern, a rectangular grid pattern, a hexagonal grid pattern, lines in an array pattern, a circular pattern, a triangular grid pattern, a cross grid pattern, a star grid pattern, a swivel grid pattern, a viewfinder grid pattern or a related geometrically shaped pattern. In some aspects, each lasing beam spot in the beam spot pattern has an area in the range of 0.1 cm2 and 25 cm2. To chip the rock formation all the neighboring lasing beam spots to each lasing beam spot in the beam spot pattern may be less than a fixed position of 2″ and non-overlapping in one or more aspects.
In some aspects, more than one beam spot pattern to chip the rock surface may be used. The relaxation times when positioning one or more beam spot patterns to their next subsequent lasing location may range between 0.05 ms and 2 s. The power of one or more beam spot patterns may either be not reduced, reduced moderately, or fully during relaxation time. A beam shape may be a continuous optical beam spot forming a geometrical shape that comprises of, a cross shape, hexagonal shape, a spiral shape, a circular shape, a triangular shape, a star shape, a line shape, a rectangular shape, or a related continuous beam spot shape.
In some aspects, positioning one line either linear or non-linear to one or more neighboring lines either linear or non-linear at a fixed distance less than 2″ and non-overlapping may be used to chip the rock formation. Lasing the rock surface with two or more beam shapes may be used to chip the rock formation. The relaxation times when moving the one or more beam spot shapes to their next subsequent lasing location may range between 0.05 ms and 2 s.
In accordance with one or more aspects, the one or more continuous beam shapes powers are either not reduced, reduced moderately, or fully during relaxation time. The rock surface may be irradiated by one or more lasing beam spot patterns together with one or more beam spot shapes, or one or two beam spots with one or more beam spot patterns. In some aspects, the maximum diameter and circumference of one or more beam shapes and beam spot patterns is the size of the borehole being chipped when drilling the rock formation to well completion.
In accordance with one or more aspects, rock fractures may be created to promote chipping away of rock segments for efficient borehole drilling. In some aspects, beam spots, shapes, and patterns may be used to create the rock fractures so as to enable multiple rock segments to be chipped away. The rock fractures may be strategically patterned. In at least some aspects, drilling rock formations may comprise applying one or more non-overlapping beam spots, shapes, or patterns to create the rock fractures. Selection of one or more beam spots, shapes, and patterns may generally be based on the intended application or desired operating parameters. Average power, specific power, timing pattern, beam spot size, exposure time, associated specific energy, and optical generator elements may be considerations when selecting one or more beam spots, a shape, or a pattern. The material to be drilled, such as rock formation type, may also influence the one or more beam spot, a shape, or a pattern selected to chip the rock formation. For example, shale will absorb light and convert to heat at different rates than sandstone.
In accordance with one or more aspects, rock may be patterned with one or more beam spots. In at least one embodiment, beam spots may be considered one or more beam spots moving from one location to the next subsequent location lasing the rock surface in a timing pattern. Beam spots may be spaced apart at any desired distance. In some non-limiting aspects, the fixed position between one beam spot and neighboring beam spots may be non-overlapping. In at least one non-limiting embodiment, the distance between neighboring beam spots may be less than 2″.
In accordance with one or more aspects, rock may be patterned with one or more beam shapes. In some aspects, beam shapes may be continuous optical shapes forming one or more geometric patterns. A pattern may comprise the geometric shapes of a line, cross, viewfinder, swivel, star, rectangle, hexagon, circular, ellipse, squiggly line, or any other desired shape or pattern. Elements of a beam shape may be spaced apart at any desired distance. In some non-limiting aspects, the fixed position between each line linear or non-linear and the neighboring lines linear or non-linear are in a fixed position may be less than 2″ and non-overlapping.
In accordance with one or more aspects, rock may be patterned with a beam pattern. Beam patterns may comprise a grid or array of beam spots that may comprise the geometric patterns of line, cross, viewfinder, swivel, star, rectangle, hexagon, circular, ellipse, squiggly line. Beam spots of a beam pattern may be spaced apart at any desired distance. In some non-limiting aspects, the fixed position between each beam spot and the neighboring beam spots in the beam spot pattern may be less than 2″ and non-overlapping.
In accordance with one or more aspects, the beam spot being scanned may have any desired area. For example, in some non-limiting aspects the area may be in a range between about 0.1 cm2 and about 25 cm2. The beam line, either linear or non-linear, may have any desired specific diameter and any specific and predetermined power distribution. For example, the specific diameter of some non-limiting aspects may be in a range between about 0.05 cm2 and about 25 cm2. In some non-limiting aspects, the maximum length of a line, either linear or non-linear, may generally be the diameter of a borehole to be drilled. Any desired wavelength may be used. In some aspects, for example, the wavelength of one or more beam spots, a shape, or pattern, may range from 800 nm to 2000 nm. Combinations of one or more beam spots, shapes, and patterns are possible and may be implemented.
In accordance with one or more aspects, the timing patterns and location to chip the rock may vary based on known rock chipping speeds and/or rock removal systems. In one embodiment, relaxation scanning times when positioning one or more beam spot patterns to their next subsequent lasing location may range between 0.05 ms and 2 s. In another embodiment, a camera using fiber optics or spectroscopy techniques can image the rock height to determine the peak rock areas to be chipped. The timing pattern can be calibrated to then chip the highest peaks of the rock surface to lowest or peaks above a defined height using signal processing, software recognition, and numeric control to the optical lens system. In another embodiment, timing patterns can be defined by a rock removal system. For example, if the fluid sweeps from the left side the rock formation to the right side to clear the optical head and raise the cuttings, the timing should be chipping the rock from left to right to avoid rock removal interference to the one or more beam spots, shape, or pattern lasing the rock formation or vice-a-versa. For another example, if the rocks are cleared by a jet nozzle of a gas or liquid, the rock at the center should be chipped first and the direction of rock chipping should move then away from the center. In some aspects, the speed of rock removal will define the relaxation times.
In accordance with one or more aspects, the rock surface may be affected by the gas or fluids used to clear the head and raise the cuttings downhole. In one embodiment, heat from the optical elements and losses from the fiber optics downhole or diode laser can be used to increase the temperature of the borehole. This could lower the required temperature to induce spallation making it easier to spall rocks.
In another embodiment, a liquid may saturate the chipping location, in this situation the liquid would be turned to steam and expand rapidly, this rapid expansion would thus create thermal shocks improving the growth of fractures in the rock. In another embodiment, an organic, volatile components, minerals or other materials subject to rapid and differential heating from the laser energy, may expand rapidly, this rapid expansion would thus create thermal shocks improving the growth of fractures in the rock. In another embodiment, the fluids of higher index of refraction may be sandwiched between two streams of liquid with lower index of refraction. The fluids used to clear the rock can act as a wavelength to guide the light. A gas may be used with a particular index of refraction lower than a fluid or another gas.
By way of example and to further illustrate the teachings of the present inventions, the thermal shocks can range from lasing powers between one and another beam spot, shape, or pattern. In some non-limiting aspects, the thermal shocks may reach 10 kW/cm2 of continuous lasing power density. In some non-limiting aspects, the thermal shocks may reach up to 10 MW/cm2 of pulsed lasing power density, for instance, at 10 nanoseconds per pulse. In some aspects, two or more beam spots, shapes, and patterns may have different power levels to thermally shock the rock. In this way, a temperature gradient may be formed between lasing of the rock surface.
By way of example and to further demonstrate the present teachings of the inventions, there are provided examples of optical heads, i.e., optical assemblies, and beam shot patterns, i.e., illumination patterns, that may be utilized with, as a part of, or provided by an LBHA.
By way of example and to further demonstrate the present teachings,
By way of example and to further demonstrate the present teachings,
By way of example and to further demonstrate the present teachings,
By way of example and to further demonstrate the present teachings,
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By way of example and to further demonstrate the present teachings,
It is understood that the rails in these examples for providing z-direction movement are provided by way of illustration and that z-direction movement, i.e. movement toward or away from the bottom of the borehole may be obtained by other means, for example winding and unwinding the spool or raising and lowering the drill string that is used to advance the LBHA into or remove the LBHA from the borehole.
By way of example and to further demonstrate the present teachings,
By way of example and to further demonstrate the present teachings,
By way of example and to further demonstrate the present teachings,
By way of example and to further demonstrate the present teachings,
The tools that are useful with high power laser systems many generally be laser cutters, laser cleaners, laser monitors, laser welders and laser delivery assemblies that may have been adapted for a special use or uses. Configurations of optical elements for culminating and focusing the laser beam can be employed with these tools to provide the desired beam properties for a particular application or tool configuration. A further consideration, however, is the management of the optical effects of fluids or debris that may be located within the beam path between laser tool and the work surface.
It is advantageous to minimize the detrimental effects of such fluids and materials and to substantially ensure, or ensure, that such fluids do not interfere with the transmission of the laser beam, or that sufficient laser power is used to overcome any losses that may occur from transmitting the laser beam through such fluids. To this end, mechanical, pressure and jet type systems may be utilized to reduce, minimize or substantially eliminate the effect of these fluids on the laser beam.
For example, mechanical devices may be used to isolate the area where the laser operation is to be performed and the fluid removed from this area of isolation, by way of example, through the insertion of an inert gas, or an optically transmissive fluid, such as water, an oil, kerosene, or diesel fuel. The use of a fluid in this configuration has the added advantage that it is essentially incompressible.
Preferably, if an optically transmissive, or substantially transmissive fluid is employed the fluid will be flowing, and in particular flowing at the work surface. In this manner the overheating of the fluid, and in particular over heating at the work surface, from the laser energy passing through it or for the cutting activity, may be avoided.
Moreover, a mechanical snorkel like device, or tube, which is filled with an optically transmissive fluid (gas or liquid) may be extended between or otherwise placed in the area between the laser tool and the work surface or area.
A jet of high-pressure gas may be used with the laser beam. The high-pressure gas jet may be used to clear a path, or partial path for the laser beam. The gas may be inert, or it may be air, oxygen, or other type of gas that accelerates the laser cutting.
The use of oxygen, air, or the use of very high power laser beams, e.g., greater than about 1 kW, could create and maintain a plasma bubble, a vapor bubble, or a gas bubble in the laser illumination area, which could partially or completely displace the fluid in the path of the laser beam. If such a bubble is utilized, preferably the size of the bubble should be maintained as small as possible, which will avoid, or minimize the loss of power density.
A high-pressure laser liquid jet, having a single liquid stream, may be used with the laser beam. The liquid used for the jet should be transmissive, or at least substantially transmissive, to the laser beam. In this type of jet laser beam combination the laser beam may be coaxial with the jet. This configuration, however, has the disadvantage and problem that the fluid jet does not act as a wave-guide. A further disadvantage and problem with this single jet configuration is that the jet must provide both the force to keep the drilling fluid away from the laser beam and be the medium for transmitting the beam.
A compound fluid laser jet may be used as a laser tool. The compound fluid jet has an inner core jet that is surrounded by annular outer jets. The laser beam is directed by optics into the core jet and transmitted by the core jet, which functions as a waveguide. A single annular jet can surround the core, or a plurality of nested annular jets can be employed. As such, the compound fluid jet has a core jet. This core jet is surrounded by a first annular jet. This first annular jet can also be surrounded by a second annular jet; and the second annular jet can be surrounded by a third annular jet, which can be surrounded by additional annular jets. The outer annular jets function to protect the inner core jet from the drill fluid present in the annulus between the laser cutter and the structure to be cut. The core jet and the first annular jet should be made from fluids that have different indices of refraction. Further examples of such cutters, tools, jets, compound jets and related uses are disclosed and taught in the following U.S. patent applications: Ser. No. 13/210,581, Ser. No. 13/222,931, Ser. No. 13/211,729 and Ser. No. 61/514,391, the entire disclosures of each of which are incorporated herein by reference.
The systems and methods of the present inventions are, in part, directed to the cleaning, resurfacing, removal, and clearing away of unwanted materials, e.g., build-ups, deposits, corrosion, or substances, in, on, or around structures, e.g. the work piece, or work surface area. Such unwanted materials would include by way of example rust, corrosion, corrosion by products, degraded or old paint, degraded or old coatings, paint, coatings, waxes, hydrates, microbes, residual materials, biofilms, tars, sludges, and slimes. The present inventions enable the ability to have laser energy of sufficient power and characteristics to be transported over great lengths and delivered to remote and difficult to access locations. An example of a preferred application for the present inventions would be in field of “flow assurance,” (a broad term that has been recently used in the oil and natural gas industries to cover the assurance that hydrocarbons can be brought out of the earth and delivered to a customer, or end user) they would also find many applications and uses in other fields as illustrated by the following examples and embodiments. Moreover, the present inventions would have uses and applications beyond oil, gas, geothermal and flow assurance, and would be applicable to the, cleaning, resurfacing, removal and clearing away of unwanted materials in any location that is far removed from a laser source, or difficult to access by conventional technology as well as assembling and monitoring structures in such locations.
The parameters of the laser energy delivered to a substrate having an unwanted material should be selected to provide for the efficient removal, or degradation of the unwanted material, while minimizing any harm to the substrate. The laser delivery parameters will vary based upon, for example, such factors as: the desired duty cycle; the surface area of the substrate to be cleaned; the composition of the substrate; the thickness of the substrate; the opacity of the unwanted material; the composition of the unwanted material; the absorptivity and/or reflectivity of the unwanted material for a particular laser wavelength; the absorptivity and/or reflectivity of the wanted material for a particular laser wavelength; the geometry of the laser beam; the laser power; the removal speed (linear or area); as well as, other factors that may be relevant to a particular application. Although continuous wave and pulsed delivery lasers may be useful in addressing the issue of unwanted materials in or on structures such as for example pipelines, or in or on other substrates, pulsed laser have been shown to be particularly beneficial in some applications and situation. Without limitation to the present teachings and inventions set forth in this specification, the following US patents set forth parameters and methods for the delivery of laser energy to a substrate to remove unwanted materials from the substrate: U.S. Pat. Nos. 5,986,234; RE33,777, 4,756,765, 4,368,080, 4,063,063, 5,637,245, 5,643,472, 4,737,628, the entire disclosures of each of which are incorporated herein by reference.
Thus, for example, the laser tool may be a laser monitoring tool for illuminating a surface of a work piece to detect surface anomalies, cracks, corrosion, etc. In this type of laser monitoring tool, the laser beam may be scanned as a spot, or other shape, along the surface of the work area, in a pattern, or it may be directed to a surface in a continuous line that impacts some or all of the inner circumference of the inner wall of the work piece. The light reflect by and/or absorbed by the surface would then be analyzed to determine if any anomalies were present, identify their location and potentially characterize them. A laser radar type of system may be used for this application, a laser topographic system may be used for this application, as well as, other known laser scanning, measuring and analyzing techniques.
The laser tool may be a laser cutter, such as the cutters discussed herein, that is used to remove unwanted material from a surface, cut a hole through, or otherwise remove a section of materials, such as milling a window in a well casing, or weld a joint between two sections of a structure, or repair a grout line between two section of structure by for example activating a heat activated grout material. The laser tool may be a laser illumination tool that provides sufficient high power laser energy to an area of the surface to kill or remove microbes and microbial related materials such as a biofilm. This type of laser illumination tool may also be used to clear and remove other materials, such as waxes, from an interior surface of for example a tank, a pipeline or a well.
In general, when dealing with cleaning activities, and by way of example, the power of the laser energy that is directed to a surface of the workpiece should preferably be such that the foreign substance, e.g., a biofilm, wax, etc., is removed or sterilized, by heating, spalling, cutting, melting, vaporizing, ablating etc., as a result of the laser beam impinging upon the foreign substance, but the underlying structure or surface is not damaged or adversely affected by the laser beam. In determining this power, the power of the laser beam, the area of surface that the laser beam illuminates, and the time that the laser beam is illuminating that surface area are factors to be balanced.
Combinations of laser tools, e.g., a cutter, an illuminator, a measurement tool, and non-laser tools, may be utilized in a single assembly, or they may be used in separate assemblies that are used sequentially or in parallel activities.
In addition to directly affecting, e.g., cutting, cleaning, welding, etc., a work piece or sight, e.g., a tubular, borehole, etc., the high power laser systems can be used to transmit high power laser energy to a remote tool or location for conversion of this energy into electrical energy, for use in operating motors, sensors, cameras, or other devices associated with the tool. In this manner, for example and by way of illustration, a single optical fiber, or one or more fibers, preferably shielded, have the ability to provide all of the energy needed to operate the remote tool, both for activities to affect the work surface, e.g., cutting drilling etc. and for other activities, e.g., cameras, motors, etc. The optical fibers of the present invention are substantially lighter and smaller diameter than convention electrical power transmission cables; which provides a potential weight and size advantage to such high power laser tools and assemblies over conventional non-laser technologies.
Photo voltaic (PV) devices, thermoelectric or mechanical devices may be used to convert the laser energy into electrical energy. Thus, as energy is transmitted down the high power optical fiber in the form high power laser energy, i.e., high power light having a very narrow wavelength distribution it can be converted to electrical, and/or mechanical energy. A photo-electric conversion device is used for this purpose and is located within, or associated with a tool, assembly or system. Examples of such PV devices and conversion systems are disclosed and taught in U.S. patent application Ser. No. 13/347,445 and in PCT patent application PCT/US12/20789, the entire disclosure of each of which are incorporated herein by reference. A thermoelectric convertor operates by generating electrical current from a temperature gradient using a Peltier effect.
In the use of high power laser energy an effect known as carbon gettering may occur, which results in carbon deposits being formed on optical surfaces and other areas where the high power beam is transmitted. Such carbon deposits can quickly cover optics, windows or other surfaces in a laser system or laser tool, causing hot spots and failures. Such carbon deposits are more readily formed in environments or under conditions in which there is a carbon source but little or no oxygen, such as for example doing workover, completion or drilling activities in a well, and in particular if the beam is being propagated and/or the work is being done with a nitrogen blanket or in nitrogen. The problems associated with carbon gettering are driven by fluence and typically are seen when fluences exceed about 100,000 w/cm2, thus, although these problems can be see with as low as about a 1 W laser, they can become more pronounced as laser power is increased, and in particular, when laser powers of greater than 20 kW, greater than 30 kW, and greater are used. Thus, high power laser systems, and in particular at locations where the beam is being transmitted, such as at an optical slip ring, or at laser tool, such as for example a laser-mechanical drill bit, a laser cutter, a laser milling tool, or a laser pipe cutting tool, may employ an anti-carbon gettering system and methods. An anti-carbon gettering system would include for example a means to provide a source of oxygen, such as by providing gas flow having oxygen to those areas where carbon deposit formation can occur. Pure oxygen, however, is not required, and for example a flow of breathable air, i.e., about 20% oxygen, may be utilized depending upon the air flow and the amount of carbon present in the system Thus, anti-carbon gettering gas flows may be less than about 50% oxygen, less than about 30% oxygen, and less than about 20% oxygen, and for use in a sealed system, the oxygen content may be less than 1% and as low as a few ppm (parts per million). This anti-carbon gettering system can be incorporated into the laser system, or it can be a separate system that is brought to the work site when needed. Depending on the integrity of the optical system, ranging from hermetic sealed system to an unsealed system the amount of oxygen required is proportional to the exposure to the carbon source, such as hydrocarbons. A hermetic sealed system will require an initial fill containing some portion of oxygen to react with any carbon left inside the system due to the assembly processes. A sealed system, depending on the operating time for the system, may also only require a pre-fill of a gas with oxygen content. An unsealed system however will require a continuous purge or flow of a gas with some oxygen content. For example, in a sealed system the oxygen content may need to be only a few ppm, in a flowing gas system the oxygen content many only need to be a percent or so, depending on the application, the components of the laser system, and the operating conditions and environments for the laser system. Generally, the gettering process arises from hydrocarbon cracking present in the high power laser beam. Thus, if the beam path is kept relatively clean, e.g., free from hydrocarbons, then only trace amounts of hydrocarbon and cracked hydrocarbon will be present, requiring only an impurity level, e.g., a trace amount, or very low ppm, of oxygen to remove the deposits. The mechanism for preventing the gettering depositions is the oxidation of the carbon, e.g., converting the carbon into CO2 which cannot be cracked again by the the laser beam. The CO2 will not deposit on or otherwise adversely effect the optics and components of the system.
Jointed drill pipe and jointed tubulars are used in many drilling applications. Thus, this example provides an embodiment of a device for use with or as a part of a high power laser drilling system, and in particular a high power laser drilling workover and completion system for using high power laser tools, such as laser-mechanical drill bits, with jointed tubulars. A tubular assembly contains a high power optical fiber wound inside of the tubular, preferably in a helix. The outer diameter of this tubular-fiber assembly would be no greater than the largest outer diameter of any component of the drill string, tools, or bottom hole assembly that the tubular-fiber assembly was intended to be used with. The high power optical fibers of the present invention can be very thin, generally several hundreds of a micron to a few thousands of microns. Thus, a substantial length of fiber may be helixed inside of a single piece tubular, having the length of a standard piece of drill pipe, which is about from 31 ft to about 46 ft. Moreover, many drilling rigs can handle three or four connected pieces of drill pipe, e.g. a triple or quad, and thus can handle pipe lengths of over 120 ft. Accordingly, tubular-fiber assemblies are provided with lengths of about 30 ft or greater, of about 60 ft or greater, about 90 ft or greater, of about 100 ft or greater and of about 120 ft or greater. The length of the tubular may be as long as is permitted by the particular derrick and drilling assembly, e.g., distance of travel from rotary table, or drill floor up into the derrick, for the top drive, or other tubular handling equipment.
A single tubular-fiber assembly can be placed in the drill string, at or near the bottom of the drill string, for example just above the bottom hole assembly (“BHA”), or may even be include in or as a part of the BHA. Further, one or more tubular-fiber assemblies may be placed, e.g., staggered, along the length of a very long drill string, such as would be encountered when dealing with bore holes having depths of greater than 10,000 ft, greater than 20,000 ft, greater than 30,000 ft and greater.
One end of the fiber in the tubular-fiber assembly many be attached to a connector, for a “plug-and-play” type high power laser system, or the fiber may be directly attached to a tool when the tool is attached to the tubular-fiber assembly. The other end of the fiber may have a connector, or be connected to, for example the end of another fiber in a tubular-fiber assembly, a high power laser, or in the case where the drill string will be rotated, such as with a BHA and a laser-mechanical bit, an optical slip ring may be associated with the top drive or other source of rotation for the drill pipe, or an optical slip ring assembly may be contained within or near to the tubular-fiber assembly. In this way either the entire length of the fiber within the drill string can rotate with the string, or the fiber within the drill string does not rotate above the location of the optical slip ring device and rotates with the drill string below the slip ring.
In operation as the drill string, tubular-fiber assembly and tool are tripped-in the fiber can be pulled from the interior of the drill string and run through the next section of drill pipe, or, and preferably, once the intend depth for the string has been reached a fishing tool can be sent down attached to the fiber end, or connector, and pull the fiber to the rig floor where it will be optically connected to the high power laser. (Tripping-in is the process of running or advancing a drill sting into a borehole to the depth where drilling or other activates are to occur. Tripping-out is the process of removing the drill string form the borehole. To trip-in or -out, pieces of drill string are added or removed from a drill string to lengthen or shorten the string is as it is advanced into or pulled out of a borehole.) In tripping-out, the fiber can be automatically disconnected from the tubular-fiber assembly and recovered first, or it can be re-helixed by fixing a section of the fiber and using the turning of the drill string and/or a re-helixing assembly, to helix the fiber in the tubular-fiber assembly.
The use of high power laser energy in drilling, cutting, machining and milling related activities has the potential to perform such activities with greatly reduced noise and/or vibration levels, when compared to conventional non-laser technologies used to accomplish these activities. This ability to greatly reduce noise and vibration provides, among many benefits, the ability to perform real-time and/or simultaneous monitoring, measuring, data collection and other observations of the activity, the conditions for the activity, and the surrounding environment and area of the work site, with out interference from the noise and vibration that would accompany conventional non-laser technology. In addition to greatly improving the ability to monitor, measure, data collect and observe, the reduction in noise and vibration may further provide the ability for real-time and/or simultaneous monitoring, measuring, data collection and other observations that were previously thought to be impossible.
The reduction in noise and vibration has the further advantage of permitting activity in areas or situation where such noise could prove to be against zoning ordinances, rules or environmental considerations.
One such utilization for this benefit of noise and vibration reduction that the present high power laser systems provide is in the area of logging while drill (“LWD”) and measuring while drilling (MWD) and combination thereof (LWD/MWD). When using laser-mechanical drilling processes, such as disclosed and taught in the following U.S. patent applications and patent application Publications: US 2010/0044106; US 2010/0044103; Ser. No. 61/446,041; Ser. No. 61/446,042, reductions in the weight-on-bit (WOB), in the order of many magnitudes, needed to advance a borehole through hard and ultra-hard rock have been observed. This reduction in WOB can result in greatly reduced noise and vibration levels. For example and preferably, this reduction in WOB permits the use of a motor, or other means to supply rotational movement to the bit, such as an electric motor, that still further reduces vibrations. For example, this system and method provides the ability for greatly enhancing logging, measuring and monitoring systems, by advancing a borehole with a laser bottom hole assembly in association with a logging, measuring and monitoring system. The borehole is advanced by utilizing at least about 50 kW of laser power and utilizing less than about 2,000 lbs, less than about 1,000 lbs, and more preferably less than about 500 lbs WOB. In this manner the noise and vibrations from advancing the bore hole are at a low level at least two times lower, at least about 5 times lower, and at least about 10 times lower, than a level that interferes with the logging measuring, and monitoring systems, which level is typically set based upon, configured in view of, conventional mechanical drilling technologies, vibrations, noise, etc. Thus, providing for enhanced and more accurate MWD, LWD and MDW/LWD.
Additionally, the high power laser may be used in LWD providing the ability to measure the formation (rock and fluid) with the laser energy to determine petrophysical, geological, and fluid identification in the pores.
The use of high power laser energy and/or high power laser energy in conjunction with mechanical removal of material, including laser-affected material for the borehole, provides the ability to perform laser-assisted case while drilling and laser-assisted directional casing while drilling. The potential for reduced vibrations, reduced WOB, and smoother borehole surfaces (without the need for reaming) provide additional benefits, among others, for this high power down hole laser application.
Thus, for example, a down hole assembly having a down hole motor, e.g., electric motor, turbine, or positive displace motor, a MWD system, a rotary steerable system and a laser-mechanical bit that is optically connected to a high power laser on the surface may be employed. This down hole assembly would further have a casing shoe, a means to device to attach the casing to the motor and an under reamer to conform the hole side to the casing being used. The under-reamer may be a laser-mechanical under-reamer, or may not be needed if the laser beam profile at the bit is such that the laser-mechanical bit provides a sufficient borehole diameter and smoothness.
Thus, there is provided a laser directional drilling while casing assembly. The assembly associated with a casing string, having a casing shoe. A casing motor assembly connects, fixes the down hole power section to the casing. The down hole power section has a motor a stabilized assembly, a laser-reamer (under reamer in the embodiment shown in the figure) a RSS 1208, a MWD 1209, a laser-mechanical bit, an optics package, and a high power optical fiber cable. In operation the embodiment of the casing would be rotated at an RPM of about 10 to 30, and the mud motor would be rotated at an RPM of about 100 to 600. Preferably, about greater than 50 kW and more preferably about greater than 80 kW of laser power would be available to the bottom of the borehole. Greater and lesser laser powers are also contemplated. The WOB may be preferably below 1000 lbs and more preferably below 500 lbs.
Packer and other such devices may become lodge in a borehole against the casing or an uncased borehole surface. It may take a considerable amount of time, effort and money to dislodge a packer that has become stuck. There is provided a high power laser tool, has one or more high power laser cutters that is lowered to the stuck packer. The high power laser tool then cuts the outer area of the packer, e.g., the area adjacent to the casing, or other sections of the packer, weakening the packer and/or grip that the packer has on casing freeing the packer or enabling the packer to be freed with substantially less force than would be required with out the packer having been cut by the laser. The laser cutter, which preferably cold be along the lines of a laser kerfing assembly to direct the laser energy along the outer edges, e.g., the gauge area of the borehole. The laser cutter may further be a series of laser cutters that are rotate by the tool, or by a down hole motor.
The laser and laser-mechanical drilling process provide boreholes having sidewalls that are very smooth. Borehole sidewall smoothness, for example in hard rock, such as, granite and basalt may have slight, to little, to no visually observable rugosity. Further the sidewall smoothness may have a surface roughness of less 0.05″. These wall properties are obtainable without reaming. Thus, there is provided a method to obtain smooth borehole surfaces without the need of any subsequent processing of the borehole, by using a high power laser mechanical drilling system.
Hydrates form at low-temperature, high-pressure in the presence hydrocarbons and water. Hydrate formation can plug flow lines, equipment and other structures and devices used in deepwater offshore hydrocarbon exploration and production. The kinetics of hydrate formation is dependent upon, among other things the nature of the crude oil being produced. Thus, the rate of hydrate formation may be very different from well to well, or as other factors change on a single well. To address, mitigate and manage hydrate related problems there is provided a method of positioning a high power laser tool, for example a laser cutter or a laser illuminator in the areas where hydrate formation is likely, where flow assurance is critical, where hydrate formation has been detected or observed and combinations thereof. The laser tool is connected to a high power laser, preferably on the surface, by way of a high power laser cable. The high power laser energy is then delivered to abate the hydrate formation, for example by heating the structure, by maintaining the structure at a certain level, preferably above a temperature at which hydrate formation can occur, by directly heating, cutting or ablating the hydrate, and combinations of the foregoing.
A preferred wavelength for treating and managing hydrate formation would be about 1.5 μm or greater, more preferably from about 1.5 μm to about 2 μm, which is a wavelength range, as taught in the co-pending high power laser transmission specification, that can be transmitted down the fiber over great lengths without substantial power losses, and is also a wavelength range that is preferentially absorbed by the hydrate.
In this embodiment of a high power laser system, there is provided the use of high power laser energy and the use of high power laser optical cables for intelligent completion and sensor systems for wells, e.g., smart wells, including gas, oil and geothermal wells. These systems use a high power optical cable and high power lasers, to transmit and provide down hole power (either optical and/or opt-electrical), data, control information, and combinations thereof, from the surface to system's components, such as for example optical sensors. As addressed in the specification above, when a single fiber is being used for both power and data transmission the wavelengths, pulse rates, plus widths, and other parameters of the laser beams need to be addressed to maximize fiber performance, avoid interferences and maintain the suppression of non-linear effects. In this manner the size and complexity of conventional, i.e., non-high power laser cables, used to power and operate such systems can be minimized and/or avoided. Such high power laser smart well systems may have or include equipment for down hole flow control, hydrate formation control, the management of multi-lateral completions, controlling commingled production, controlling down hole water separation, controlling down hole gas separation, equipment for down hole gas re-injection, and pressure control, among other things.
Thus, a high power laser smart well system may preferably provide one, several or all of these features: automatic surface interaction with sub-surface equipment; continuous monitoring of sub-surface conditions; automatic flow control; real-time control loops; and extensive down hole communications and data transmission. These and potentially other features are provided through the utilization of the high power optical fibers provided in this specification.
These high power laser smart wells also provide the benefit of monitoring, evaluating and characterizing the formation, preferably in real-time and continuously, for such characteristics as fluid-gas contact zones, gas-water coning, saturation, structure, pressure and temperature, to name a few. In this manner these systems provide the ability to quickly and consistently optimize reservoir drainage and production. Although the benefits of such high power laser systems may be realized to a greater or lesser extent in many, if not most, wells, these systems may be particularly beneficial if utilized in marginal wells, highly deviated wells, horizontal wells, deepwater wells and high volume wells.
In this embodiment of a high power laser system, there is provided the use of high power laser energy and the use of high power laser optical cables for powering, controlling and/or monitoring artificial lift systems and, in particular, artificial lift pumps, such as, for example, progressive cavity pumps, electric submersible pumps, and hydraulic pumps.
In this embodiment of a high power laser system, there is provided the use of high power laser energy and the use of high power laser optical cables for powering, controlling and/or monitoring equipment and components that make up a subsea production field. Such equipment and components would include, for example, subsea trees, controls, manifolds, and tie-ins. There is further provided a high power optical fiber network, which forms a part of the subsea field.
In this embodiment of a high power laser system, there is provided the use of high power laser energy and the use of high power laser optical cables for powering, controlling and/or monitoring a seismic monitoring system, and in particular the sensor used in such system and the data and information obtained from those sensors.
In this embodiment of a high power laser system, there is provided the use of high power laser energy and the use of high power laser optical cables for powering, controlling and/or monitoring equipment and components that make up a heating system for the production and recovery of heavy oil.
In this embodiment of a high power laser system, there is provided the use of high power laser energy and the use of high power laser optical cables for powering, controlling and/or monitoring down hole tractors and similar types of down hole equipment. Further the down hole tractor may be equipped with a laser cutting, laser illumination, laser drilling and/or laser-mechanical drilling tool.
Flow assurance is the method and related practices and procedures to ensure an uninterrupted flow of hydrocarbons from the well, to a storage facility and to the end recipient. In this embodiment of a high power laser system, there is provided the use of high power laser energy, the use of high power laser optical cables for powering, controlling and/or monitoring equipment and components, and/or the use of remote high power laser tools, to provide a high power laser flow assurance system.
In this embodiment of a high power laser system, there is provided the use of high power laser energy, the use of high power laser optical cables for powering, controlling and/or monitoring equipment and components, and/or the use of remote high power laser tools, to provide a system for removing paint. This system would provide the added advantage that it would eliminate the waste, noise and other environmental issues, with conventional abrasive, mechanical or chemical paint removal techniques. This system would also provide the ability to remove paint, or other coatings, from areas that are remote, distant or otherwise difficult to access.
In this embodiment of a high power laser system, there is provided the use of high power laser energy, the use of high power laser optical cables for powering, controlling and/or monitoring equipment and components, and/or the use of remote high power laser tools, to provide a system for removing or controlling, corroded material, corrosion, or mitigating unwanted biologics that coat, cover or adversely affect a structure or surface. This system would provide the added advantage that it would eliminate the waste, noise and other environmental issues, with conventional abrasive, mechanical or chemical paint removal techniques.
The high power systems may be used to provide controlled perforations, including perforations having predetermined shape for the oil, gas and geothermal stimulation and production. Additionally, such controlled cuts or perforations may be used for stimulation and/or recovery of hydrocarbons from coal bed methane and oil shale formations.
From the foregoing examples, there are contemplated several illustrative embodiments. For example, there is provided a method of providing an high power optical connection between a high power laser source and a high power laser tool located at a remote location, the method including: advancing a tubular-fiber assembly associated with a laser tool to a predetermined location removed from a source of high power laser beam, the tubular-fiber assembly containing a high power optical fiber having a proximal end and a distal end in optical association with a high power laser tool; withdrawing the proximal end of the optical fiber from the tubular-fiber assembly and there by withdrawing at least a portion of the optical fiber from the tubular-fiber assembly, while maintaining the distal end in optical association with the high power laser tool; and, optically associating the proximal end of the cable with the source of the high power laser beam; whereby a high power laser beam is transmitted from the laser source to the high power laser tool. Yet further, there are provided methods that may also include: where the tubular-fiber assembly has a length of about 30 feet to about 120 feet, and comprises at least about 1,000 feet of high power optical fiber; and where the remote location is within a borehole and the remote location is at least about 5,000 feet from the high power laser source. Still further there is provided a method of enhancing logging, measuring and monitoring system, the method including advancing a borehole with a laser bottom hole assembly in association with a logging, measuring and monitoring system, and utilizing at least about 50 kW of laser power and utilizing less than about 2,000 lbs WOB, whereby noise and vibrations from advancing the bore hole are at a low level at least two times lower than a level that interferes with the logging measuring, and monitoring systems. Yet further, there are provided methods that may also include: where the logging, measuring and monitoring system is a LWD system; where the logging, measuring and monitoring system is a MWD system; and where the logging, measuring and monitoring system is a LWD/MWD system. Moreover, there is provided a method of casing while drilling including lowering a laser bottom hole assembly having a means for providing rotation, a laser under reamer, a laser-mechanical bit and an optics package to the bottom of a borehole, advancing the bore hole by rotating the means to rotate and delivering a high power laser beam to surfaces of the borehole from the laser under reamer and laser-mechanical bit while being rotated by the rotating means. Furthermore, there is provided a method of dislodging a stuck packer or tool from a borehole including positioning a high power laser cutting tool adjacent an obstruction in a borehole, the high power laser tool in optical association with a source of high power laser energy, directing a high power laser beam, from the high power laser t to cut the obstruction thereby permitting its removal. Still further, there is provided a method of providing electrical power to an intelligent completion and sensor system of a well including: providing a photovoltaic device in a location in the well, electrically associating the photovoltaic device with the system, optically associating the photovoltaic device with a source for a high power laser beam, whereby high power laser energy is provided to the photovoltaic to provide electrical energy to the system. Additionally, there is provided a method of providing electrical power to an artificial lift pump system in a well including: providing a photovoltaic device in a location in the well, electrically associating the photovoltaic device with the system, optically associating the photovoltaic device with a source for a high power laser beam, whereby high power laser energy is provided to the photovoltaic to provide electrical energy to the system. Yet still further, there is provided a method of providing electrical power to a subsea completion system for a well including: providing a photovoltaic device in a location in the well, electrically associating the photovoltaic device with the system, optically associating the photovoltaic device with a source for a high power laser beam, whereby high power laser energy is provided to the photovoltaic to provide electrical energy to the system. Moreover, there is provided a method of providing electrical power to a seismic sensing system including: providing a photovoltaic device in a location associated with the formation to be monitored by the system, electrically associating the photovoltaic device with the system, optically associating the photovoltaic device with a source for a high power laser beam, whereby high power laser energy is provided to the photovoltaic to provide electrical energy to the system.
The foregoing examples are illustrative only and are not meant to, and do not limit the many and varied applications that are available for the high power laser systems of the present inventions. These systems provide the ability to deliver many kW of power, e.g, greater than 10 kW, greater than 50 kW, greater than 100 kW and, over great distances, e.g., greater than 1 km, greater than 5 km, greater than 10 kM. through light weight, high power optical cables. Further, these systems provide the capability to transmit and receive data and control information over the same lightweight optical cable. Thus, these systems will find application in, for example, uses where high power energy is needed in a remote location for the processing of material, control and/or powering of equipment and/or the transmission and retrieval of information and data.
The inventions may be embodied in other forms than those specifically disclosed herein without departing from their spirit or essential characteristics. The described embodiments are to be considered in all respects only as illustrative and not restrictive.
This application is: (i) a continuation-in-part of U.S. patent application Ser. No. 14/330,980 filed Jul. 14, 2014, which is a divisional application of U.S. patent application Ser. No. 12/543,986 filed Aug. 19, 2009, which claims the benefit of priority of provisional applications: Ser. No. 61/090,384 filed Aug. 20, 2008, Ser. No. 61/102,730 filed Oct. 3, 2008; Ser. No. 61/106,472 filed Oct. 17, 2008; and, Ser. No. 61/153,271 filed Feb. 17, 2009; and, (ii) a continuation-in-part of U.S. patent application Ser. No. 13/403,741 filed Feb. 23, 2012, which claims, under 35 U.S.C. §119(e)(1) the benefit of the filing date of Feb. 24, 2011 of provisional application Ser. No. 61/446,312; claims, under 35 U.S.C. §119(e)(1) the benefit of the filing date of Feb. 24, 2011 of provisional application Ser. No. 61/446,041; claims, under 35 U.S.C. §119(e)(1) the benefit of the filing date of Feb. 24, 2011 of provisional application Ser. No. 61/446,412; claims, under 35 U.S.C. §119(e)(1) the benefit of the filing date of Feb. 24, 2011 of provisional application Ser. No. 61/446,407; the disclosures of each of which are incorporated herein by reference.
This invention was made with Government support under Award DE-AR0000044 awarded by the Office of ARPA-E U.S. Department of Energy. The Government has certain rights in this invention.
| Number | Date | Country | |
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| 61153271 | Feb 2009 | US | |
| 61106472 | Oct 2008 | US | |
| 61102730 | Oct 2008 | US | |
| 61090384 | Aug 2008 | US | |
| 61446041 | Feb 2011 | US | |
| 61446412 | Feb 2011 | US | |
| 61446407 | Feb 2011 | US | |
| 61446312 | Feb 2011 | US | |
| 61605401 | Mar 2012 | US |
| Number | Date | Country | |
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| Parent | 12543986 | Aug 2009 | US |
| Child | 14330980 | US | |
| Parent | 13782942 | Mar 2013 | US |
| Child | 14997072 | US |
| Number | Date | Country | |
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| Parent | 14330980 | Jul 2014 | US |
| Child | 15445238 | US | |
| Parent | 13403741 | Feb 2012 | US |
| Child | 12543986 | US | |
| Parent | 14997072 | Jan 2016 | US |
| Child | 13403741 | US |
