Method and system for advancement of a borehole using a high power laser.

(54) Title: METHOD AND SYSTEM FOR ADVANCING A DRILLING HOLE USING A HIGH POWER LASER.

(54) Title: METHOD AND SYSTEM FOR ADVANCEMENT OF A BOREHOLE USING A HIGH POWER LASER.

(57) Summary

A system, apparatus and method for laser drilling a well hole in the ground is provided; In addition, a means is provided in the system for supplying high power laser energy down to a deep hole drilling, while maintaining high power to advance said depth of drilling wells in the ground and at highly efficient advance rates, a downhole laser assembly, and fluid direction techniques and assemblies to remove displaced material from the drill hole.

(57) Abstract

There is provided a system, apparatus and methods for the laser drilling of a borehole in the earth. There is further provided with in the systems a means for delivering high power laser energy down a deep borehole, while maintaining the high power to advance such boreholes deep into the earth and at highly efficient advancement rafes, a laser bottom hole assembly, and fluid directing techniques and assemblies for removing the displaced material from the borehole.

METHOD AND SYSTEM FOR ADVANCING A DRILLING HOLE USING A HIGH POWER LASER

BACKGROUND OF THE INVENTION

This application claims the priority benefit of provisional applications: serial number 61 / 090,384 that was filed on August 20, 2008, titled System and Methods for Borehole Drilling; serial number 61 / 102,730 filed on October 3, 2008, titled Systems and 10 Methods to Optically Pattern Rock to Chip Rock Formations; serial number 61 / 106,472 filed on October 17, 2008, titled Transmission of High Optical Power Levels via Optical Fibers for Applications such as Rock Drilling and Power Transmission; and serial number 61 / 153,271 filed on February 17, 2009, entitled "Method and Apparatus for an Armored High 15 Power Optical Fiber for Providing Boreholes in the Earth," the disclosures of which are incorporated herein by reference.

The present invention relates to methods, apparatus and systems for supplying well drilling advance using high potential laser energy which is supplied over long distances, while maintaining the power of the laser energy to perform the desired tasks. In particular, the present invention relates to providing high power laser energy to create and advance a drill hole on the ground and perform other tasks on the drill hole.

The present invention is useful with and can be used in conjunction with the systems, apparatus, and methods described in greater detail in US Co-pending Patent Application Serial No. 12 / 544,136, entitled Method and Apparatus for Delivering High Power. Laser Energy Over Long Distances, US Patent Application Serial No. 12 / 544,038, entitled Apparatus for Advancing to Wellbore using High Power Laser Energy, US Patent Application No. Serial No. 12 / 544,094, entitled Methods and Apparatus for Delivering High Power Laser Energy to a Surface, and US Patent Application Serial No. 12 / 543,968, entitled Methods and Apparatus for Removal and Control of Material in Laser Drilling of a Borehole, presented contemporaneously therewith, the descriptions of which are incorporated herein by reference in their entirety.

In general, drill holes have been formed on the surface of the earth and the earth, that is, the ground, to access resources that are located on and below the surface. Such resources could include hydrocarbons, such as oil and natural gas, water, and geothermal energy sources, including hydrothermal wells. Drill holes have also been formed in the ground to study, sample, and explore materials and formations that are located below the surface. These have also been formed in the ground to create passages for the laying of cables and other similar items below the surface of the ground.

The term drill hole includes any opening that is created in the ground that is substantially longer than its width, such as a well, a bore hole, a well hole, and other terms commonly used or known in the art to define these types of long narrow passages in the ground. Although drill holes are generally substantially vertically oriented, they can also be oriented at angles from vertical, to and including horizontal. Therefore, using a level line as representing the horizontal orientation, a drill hole can vary in orientation from 0^or, ie, a vertical drill hole, up to 90 °, ie, a horizontal drill hole greater than 90, for example, such as a slow pitch. Drill holes may additionally have segments or sections that have different orientations, these may be arched, and may have other shapes that are commonly found when steering drilling is employed. Accordingly, as used herein, unless expressly provided otherwise, the “bottom” of the drill hole, the “bottom” surface of the drill hole, and the like refers to the end of the hole. Drill, that is, that portion of the drill hole furthest along the path of the drill hole from the opening of the drill hole, the surface of the ground, or the start of the drill hole.

To advance a well drilling medium is to increase the length of the drill hole. Accordingly, by advancing a wellbore, that different from the horizontal, the depth of the wellbore is also increased. Drill holes are generally formed and advanced using mechanical drilling equipment that has a rotary drill bit. The drill bit extends into and into the ground and is rotated to create a hole in the ground. In general, a diamond-tipped tool is used to perform the drilling operation. That tool must be forced against the rock or earth to be cut with sufficient force to exceed the cutting force of that material. Therefore, in conventional drilling activity, mechanical forces that exceed the shear force of the rock or earth must be applied. Material that is cut from the ground is generally known as cuttings, meaning waste, which can be bits of rock, dust, rock fibers, and other types of materials and structures that can be created by thermal or mechanical interactions with the earth. These cuts are normally removed from the drill hole through the use of fluids. Fluid showers can be liquids, foams or gases.

In addition to advancing the drill hole, other activities in or related to drill hole formation are performed, such as working and completing activities. These types of activities could include, for example, cutting and drilling the cover and removing a well plug. The well cover, or cover refers to the tubulars or other materials that are used to apply a coating to a drill hole. A well plug is a structure, or material, that is placed in a drill hole to fill and block the drill hole. A well plug is intended to prevent or restrict materials from flowing into the drill hole.

Typically drilling, i.e. drilling activity, involves the use of a drilling tool to create openings, for example windows or a porosity in the casing and the drill hole to allow searching after the resource flows inside the drill hole. Accordingly, the drill sides of the drill hole to create such openings or porosities.

The above mentioned conventional ways to form and advance a drill hole are referred to as mechanical techniques or mechanical drilling techniques, because they require a mechanical interaction between the drilling equipment, for example the drill bit or the drilling tool , and the ground or coating to transmit the force necessary to cut the ground or coating.

It has been theorized that lasers could be adapted to be used to form and advance a drill hole. Consequently, it has been theorized that the laser energy from a laser source could be used to cut rock and earth through chipping, thermal dissociation, melting, vaporization, and combinations of these phenomena. Foundry involves the transition of rock and earth from a solid to a liquid state. Vaporization involves the transition of rock and earth from any solid or liquid state to a gaseous state. Chipping involves rock fragmentation from localized heat induced stress effects. Thermal dissociation involves the breakdown of chemical bonds at the molecular level.

To date, no one is considered to have been successful in developing and implementing these laser beam drilling theories to provide an apparatus, method, and system that can advance a drill hole through the ground using a laser, or drill in a well using a laser beam. Additionally, to date it is considered that no one has developed the parameters and equipment necessary to comply with those parameters, for the effective cutting and removal of rocks and earth from the bottom of a drilling well using a laser beam, nor has anyone Developed the parameters and equipment necessary to meet those parameters for effective drilling of a well using a laser beam. Additionally, no one is deemed to have developed the parameters, equipment, or methods necessary to advance a drill hole deep into the ground to depths exceeding approximately 300 feet (0.09 km), 500 feet (0.15 km), 1000 feet (0.30 km), 3,280 feet (1 km), 9,840 feet (3 km) and 16,400 feet (5 km), using a laser beam. In particular, it is considered that no one has developed the parameters, equipment or methods has not implemented the high power laser power supply, that is, it exceeds 1 kW or more to advance a drilling well within the ground.

Although mechanical drilling has advanced and is efficient in many types of geological formations, it is considered that a highly efficient means of creating drill holes through harder geological formations such as basalt and granite has yet to be developed. Accordingly, the present invention provides solutions to this need by providing parameters, equipment, and techniques for using a laser beam to advance a wellbore in a highly efficient manner through harder rock formations, such as basalt and granite.

The environment and long distances that are present within a drilling well in the ground can be very harsh and demanding on fiber optics, optics and packaging. Accordingly, there is a need for methods and apparatus for the deployment of optical fibers, optics and packaging within a drill hole, and in particular, very deep drill holes, which will allow these and all associated components to support and They resist the dirt, pressure and temperature present in the drill hole and overcome or mitigate the power losses that occur when transmitting high power laser beams over long distances. The present invention addresses these needs by providing a means of transmitting high-power laser beam over long distances.

It has been desirable, although the present invention considers that it has never been obtained, to supply a high power laser beam over a distance within the drill hole greater than about 300 feet (0.09 km), from about 500 feet (0.15 km), approximately 1,000 feet (0.30 km), approximately 3,280 feet (1 km), approximately 9.8430 (3 km), and approximately 16,400 feet (5 km) under an optical fiber in a drill hole, to minimize optical power losses due to non-linear phenomenon. Accordingly, efficient transmission of high power from point A to point B where the distance from point A to point B within a drill hole is greater than approximately 1,640 feet (0.5 km) has long been desired. , although prior to the present invention it is considered to have never been obtained and is specifically considered to have never been obtained in a drilling well activity.

Conventional drilling equipment, which supplies power from the surface through mechanical means, must create a force on the rock that exceeds the cutting force of the rock being drilled. Although a laser beam has been shown to effectively fragment and chip such hard rocks in the laboratory under laboratory conditions, and it has been theorized that a laser beam could cut hard rocks at net rates higher than mechanical drilling, to date it has been has considered that no one has developed the devices, systems or methods that could allow the laser beam to be delivered to the bottom of a drill hole that is greater than approximately 1,640 feet (0.5 km) in depth with sufficient power to cut such hard rocks, allowing such hard rocks to be cut at rates that they were equivalent to and faster than conventional mechanical drilling. This technical failure is considered to be a fundamental and long-standing problem for which the present invention provides a solution.

Therefore, the present invention is oriented to and provides solutions to these and other needs in drilling techniques, among other things: deteriorating the coherence of the Stimulated Brillioun Scattering phenomenon (SBS), for example, a wide bandwidth laser source, such as an FM modulated laser beam or a spectral beam from combined laser sources, to suppress SBS, allowing high power transmission down a long optical fiber> 1000 feet (0.30 km); the use of a high-brightness semiconductor laser, laser disk, or laser beam fiber to drill rock with widened bandwidth to allow efficient delivery of high power by means of a long optical fiber> 1000 ft (0.30 km); using phased array laser sources with their bandwidth widened to suppress Stimulated Brillioun Gain (SBG) for power transmission under fibers that are> 1000 feet (0.30 km) in length; a technique for winding the fiber that allows the fiber to be fed from the central axis of the coil by a laser beam while the coil is spinning; a method of winding the fiber without having to use a mechanically mobile component; a method of combining multiple fibers into a single jacket with the ability to withstand downward pressures from the hole; the use of a floating fiber to support the weight of the fiber, a laser head, and the packaging down a drill hole; the use of micro-lenses, spherical optics, axicons or diffraction optics to create a previously determined pattern on the rock to achieve superior drilling efficiencies; and the use of a heat engine or a photovoltaic cell match to convert optical power back into electrical power after transmitting the power> 1000 feet (0.30 km) using an optical fiber.

BRIEF DESCRIPTION OF THE INVENTION

It is desirable to develop systems and methods that provide the supply of high power laser energy to the bottom of a deep drilling well to advance that drilling well at a cost effective rate, and in particular to have the ability to supply such laser energy High powered to drill through rock layer formations including granite, basalt, sandstone, dolomite, sand, salt, limestone, rhyolite, quartzite and rock shale at a cost effective index. More particularly, it is desirable to develop systems and methods that provide the ability to supply such high power laser energy to drill through hard rock bed formations, such as granite and basalt, at a rate that is superior to drilling operations. conventional mechanics. The present invention, among other things, meets these needs by providing the system, apparatus, and methods taught in the present disclosure.

Accordingly, a high power laser drilling system is provided for use in association with a drill rig, drill rig, scrap rig, or coiled-pipe drill rig to advance a rock drill hole. lasts, the system includes: a high power laser power source, the laser source having the ability to provide a laser beam having at least 10 kW of power, at least about 20 kW of power or more; a downhole assembly, the downhole assembly having an optical assembly, the optical assembly configured to provide a predetermined energy deposition profile to a drill hole surface, and the optical assembly configured to provide a firing pattern previously determined laser; a means of advancing the downhole assembly into and down the drill hole; a high power laser transmission cable down the well, the transmission cable having a length of at least about 154.2 meters, at least about 304.8 meters, at least about 914.4 meters, at least about 1,219.2 meters or more ; the downhole cable in optical communication with the laser source; and the downhole cable in optical communication with the downhole assembly.

Additionally, a high power laser drilling system is provided for use in association with a drill rig, drilling rig, scrap rig, drill rig, or coiled pipe drill rig to advance a drill hole, the system It comprises: a high power laser energy source; 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 comprises at least one laser beam; a downhole assembly; configured to provide a predetermined energy deposition profile of laser energy to a surface of the drill hole; configured to provide a predetermined laser firing pattern; comprising an optical assembly; and, which comprises a means for mechanically removing the drill hole material; a means of advancing the downhole assembly into and down the drill hole; a fluid source to use to drive a drill hole; a downhole high power laser transmission cable, the transmission cable having a length of at least approximately 304.8 meters; the downhole cable in optical communication with the laser source; downhole cable in optical communication with the optical assembly; and, the downhole assembly in fluid communication with the fluid source; whereby high power laser energy can be supplied to a surface of a drill hole that is located within the drill hole at least 304.8 meters from the drill hole opening.

Still further provided is a high power laser drill system for use in association with a drill rig, drilling rig, derrick, a scrap rig or a coiled pipe drill rig to advance a drill hole, The system comprises: a high power laser energy source; a downhole assembly; the downhole assembly having an optical assembly; the optical assembly configured to provide an energy deposition profile to a surface of the drill hole; and, the optical assembly configured to provide a laser firing pattern; comprising a means for directing a fluid; a means of advancing the downhole assembly into and down the drilling well, a source of fluid to use when advancing the drilling well; a downhole high power laser transmission cable; the downhole cable in optical communication with the laser source; downhole cable in optical communication with the downhole assembly; and, the means for directing fluid communications with the fluid source; where the system has the ability to cut, chip, or rock bite by illuminating a surface of the drill hole with laser energy and removing the waste material created from said cut, chipped or pitted, from the drill hole and the laser lighting area by the action of the steering means. Wherein the directing means may be, one or more of and combinations of a fluid amplifier, an outlet port, a gas directing means, a fluid directing means and an air knife.

Additionally, a downhole laser assembly is provided comprising: a first rotatable housing; a second fixed housing; the first housing being rotatably 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 rotatable housing, whereby the fixed portion rotates with the first housing; a mechanical 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 has the ability to apply mechanical forces to a surface of a drill hole from rotation; and, a fluid path associated with the first and second housing, the fluid path having a proximal and distal opening, the distal opening adapted to discharge fluid to the surface of the drill hole, whereby the fluid for removal of waste material is transmitted by the fluid path and is discharged from the distal opening to the surface of the drill hole to remove the waste material from the drill hole.

Additionally, a downhole laser assembly is provided comprising: a first rotatable housing; a second fixed housing; the first housing being rotatably 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 proximal and distal fiber ends fixed to the second housing; the first portion of the optical assembly fixed to the first rotatable housing; the second portion of the optical assembly fixes 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 has the ability to apply mechanical forces to a surface of a drill hole from rotation; and, a fluid path associated with the first and second housings, the fluid path having a proximal and a distal opening, the distal opening adapted to discharge fluid to the surface of the drill hole, the distal opening fixed to the first rotating housing , through which, the waste material removal fluid is transmitted by the fluid path and discharged from the distal opening to the surface of the drill hole to remove the waste material from the drill hole: where from the rotation of the first housing, the first portion of the optical assembly, the mechanical assembly, and the next large fluid opening substantially simultaneously.

Additionally, a downhole laser assembly is provided comprising: a housing; a means of providing a high power laser beam; an optical assembly, the optical assembly providing an optical path on which the laser beam moves; and, an air and chamber flow to create a high pressure area along the optical path; and an air flow through a downhole assembly housing with posts that function as a suction pump for removal of waste material from the high pressure area.

Additionally, these systems and assemblies may additionally have rotating laser optics, a rotating mechanical interaction device, a rotating fluid supply means, one or all three of these devices rotating together, the beam forming optics, the housings, a means to direct a fluid for removal of waste material, a means of maintaining a debris-free laser path, a means of reducing interference of waste material with the laser beam, optics comprising a digital scanner; a remote mechanical device, a remote conical device, a mechanical assembly comprising a drill bit, a mechanical assembly comprising a three-cone drill bit, a mechanical assembly comprising a PDC bit, a PDC tool, or a tool cutting

PDC.

Still further, a system is provided for creating an onshore drill hole that has a high power laser source, a downhole assembly, and a fiber that optically connects the laser source to the downhole assembly. , such that a laser beam from the laser source is transmitted to the downhole assembly, the downhole assembly comprises: a means for providing the laser beam to a surface of the bottom of the drill hole; the supply means comprise laser power deposition optics; wherein the laser beam as supplied from the downhole assembly illuminates the bottom surface of the drill hole with a substantially uniform energy deposition profile.

Still further provided is a method of advancing a drill hole using a laser, the method comprising: advancing a high power laser beam transmission medium within a drill hole; the drill hole having a bottom surface, a top opening, and a length extending between the bottom surface and the top opening of at least approximately 304.8 meters; the transmission means comprise a distal end, a proximal end, and a length extending between the distal and proximal ends, the distal end being advanced down the drill hole; the transmission means comprise a means for transmitting high power laser energy; providing a high power laser beam to the proximal end of the transmission medium; transmitting substantially all the power of the laser beam down the length of the transmission medium such that the beam exits the distal end; transmitting the laser beam from the distal end to an optical assembly in a downhole laser assembly, the downhole laser assembly directing the laser beam to the bottom surface of the drill hole; and, provide a previously determined energy deposition profile to the bottom of the drilling well; whereby the length of the drill hole is increased, in part based on the interaction of the laser beam with the bottom of the drill hole.

Additionally, a method is provided for removing debris from a drill hole during laser drilling of the drill hole, the method comprising: directing a laser beam comprising a wavelength, and having a power of at least about 10 kW, below a drill hole and toward a drill hole surface; the surface being at least 304.8 meters inside the drill hole; the laser beam illuminating an area of ​​the surface; the laser beam displacing the surface material in the lighting area; directing a fluid into the drill hole and to the surface of the drill hole; the fluid being substantially transmitter at 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 illumination area at a rate sufficient to prevent the displaced material from interfering with the laser illumination of the illumination area; and, the fluid flowing in the second flow path removing the displaced material from the drill hole. Additionally, the above method may also have the illumination area rotated, the fluid in the first flow path directed in the direction of rotation, the fluid in the first fluid flow path directed in an opposite direction of rotation, a third fluid flow path, third fluid flow path, and first fluid flow path in a direction opposite to the direction of rotation, the fluid directed directly into the illumination area, the fluid in the first directed flow path near the illumination area, and the fluid in the first directed fluid flow path near the illumination area, the area of ​​which is ahead of rotation .

Still further providing a method for removing debris from a drill hole during laser drilling of the drill hole, the method comprises: directing a laser beam having at least about 10 kW of power towards a surface of the drill hole; illuminating an area of ​​the surface of the drill hole; shift material from lighting area; provide a fluid; direct fluid into a first area within the drill hole; direct the fluid into a second area; the directed fluid removing the displaced material from the illumination area at a rate sufficient to prevent the displaced material from interfering with the laser illumination; and, the fluid that removes the displaced material forms the drill hole. This method may additionally have the first area as the lighting area, the second area on a side wall of a downhole assembly, the second area near the first area, and the second area located on a downhole surface. drilling, the second area near the first area when the second area is located on a bottom surface of the drill hole, a first fluid directed to the lighting area 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.

Still further provided is a method of removing debris from a drill hole during laser drilling of the drill hole, the method comprising: directing a laser beam towards a surface of the drill hole; illuminate a surface area of ​​the drill hole; move the material from the lighting area; provide a fluid; directing the fluid in a first path to a first area within the drill hole; direct the fluid in a second path to a second area; amplify fluid flow in the second path; the directed fluid removing the displaced material from the illumination area at a rate sufficient to prevent the displaced material from interfering with the laser illumination; and the amplified fluid by removing the displaced material from the drill hole.

In addition, a downhole laser assembly is provided for drilling a drill hole in the ground, comprising: a housing; optics to form a laser beam; an opening to supply a laser beam to illuminate the surface of a drill hole;

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 drill hole is provided comprising: a high power laser energy source, the laser source with the ability to provide a laser beam, a pipeline assembly, the assembly of pipe that has at least 154.2 meters of pipe, that has a distal end and a proximal end; a fluid source to use when advancing a drill hole; the proximal end of the pipe being in fluid communication with the source of the fluid, whereby the fluid is transported in association with the pipe from the proximal end of the pipe to the distal end of the pipe; the distal end of the pipe being in optical communication with the laser source, whereby the laser beam can be transported in association with the pipe; The pipeline comprises a high power laser transmission cable, the transmission cable having a distal end and a proximal end, the distal end being in optical communication with the laser source, whereby the laser beam is transmitted by the cable from the end close to the distal end of the cable; and, a downhole laser assembly in fluid and optical communication with the distal end of the pipeline; and, the downhole laser assembly comprising; accommodation; an optical assembly; and, an opening to direct the fluid. This system can also be supplemented by having the fluid directing opening as an air knife, the fluid directing the opening as a fluid amplifier, the fluid directing opening is an air amplifier, a plurality of fluid directing apparatuses , the downhole assembly comprises a plurality of openings for directing the fluid, the housing comprises 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.

Also provided is a high power laser drilling system for advancing a drilling well comprising: a high power laser power source, the laser source with the ability to provide a laser beam; a pipeline assembly, the pipeline assembly having at least 152.4 meters of pipeline, having a distal end and a proximal end; a source of fluid to use when advancing the drill hole; the proximal end of the pipe being in fluid communication with the fluid source, whereby the fluid is transported in association with the pipe from the proximal end of the pipe to the distal end of the pipe; the proximal end of the pipe being in optical communication with the laser source, whereby the laser beam can be transported in association with the pipe; the pipeline 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 end close to the distal end of the cable; and, a downhole laser assembly in fluid and optical communication with the distal end of the pipeline; and a fluid directing means for removal of waste material.

In addition, such systems may additionally have the fluid directing means located in the downhole laser assembly, the downhole laser assembly having a means of reducing interference of the waste material with the laser beam, the downhole with rotating laser optics downhole laser assembly with rotating laser optics and means that direct the rotating fluid.

A person skilled in the art will recognize, based on the teachings established in these specifications and drawings, that there are various modalities and implementations of these teachings to practice the present invention. Therefore, the modalities in this brief description are not intended to limit these teachings in any way.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a cross-sectional view of the ground, a drill hole, and an example of a system of the present invention for advancing a drill hole.

Figure 2 is a view of a coil.

Figures 3A and 3B are views of a pot.

Figure 4 is a schematic diagram for a laser beam configuration.

Figure 5 is a schematic diagram for a laser beam configuration.

Figure 6 is a perspective section of a coil and a rotating optical coupler.

Figure 7 is a schematic diagram of a laser fiber amplifier.

Figure 8 is a perspective section of a downhole assembly.

Figure 9 is a cross sectional view of a portion of an LBHA.

Figure 10 is a cross sectional view of a portion of an LBHA.

Figure 11 is an LBHA

Figure 12 is a perspective view of a fluid outlet.

Figure 13 is a perspective view of an air knife fluid outlet.

Figure 14A is a perspective view of an LBHA.

Figure 14B is a cross-sectional view of the LBHA of Figure 14A taken along BB.

Figures 15A and 15B are a graphical representation of an example of a laser beam basalt illumination.

Figures 16A and 16B illustrate the energy deposition profile of an elliptical pot that is rotated about its center point for a ray that is either uniform or Gaussian.

Figure 17A shows the energy deposition profile without rotation.

Figure 17B shows the substantially equal and uniform energy deposition profile from the rotation of the beam that provides the energy deposition profile of Figure 17A.

Figures 18A to 18D illustrate an optical assembly.

Figure 19 illustrates an optical assembly.

Figure 20 illustrates an optical assembly.

Figures 21A to 21B illustrate an optical assembly.

Figure 22 illustrates a multiple rotation laser firing pattern.

Figure 23 illustrates an elliptical shaped shot

Figure 24 illustrates a point with a rectangular shape.

Figure 25 illustrates a multiple shot trigger pattern.

Figure 26 illuminates a firing pattern.

Figures 27 to 36 illustrate LBHAs.

DETAILED DESCRIPTION OF THE PREFERRED MODALITIES

In general, the present invention relates to methods, apparatus and systems for use in laser drilling of a drilling well in the ground, and additionally to equipment, methods and systems for laser advancement of such deep drilling wells within of the land and highly efficient rates of progress. These highly efficient rates of advance can be obtained because the present invention provides a means of obtaining high power laser energy down to the bottom of the drill hole, even when the bottom is at great depth.

Accordingly, in general, and by way of example, a high efficiency laser drilling system 1000 is provided in Figure 1 to create a drilling well 1001 in the ground 1002. As used in the present description, the term "earth" must receive its widest possible meaning (unless expressly stated otherwise) and could include, without limitation, earth, all natural materials, such as rock, and artificial materials, such as concrete, that are or may be found in the earth, including without limitation rock layer formations, such as granite, basalt, sandstone, dolomite, sand, salt, limestone, rhyolite, quartzite and shale stone.

Fig. 1 provides a cutaway perspective view showing the surface of the earth 1030 and a section of the earth below the surface 1002. In general and by way of example, an electrical power source 1003 is provided, which provides power. electrical using 1004 and 1005 cables to a 1006 laser and a 1007 cooler for the 1006 laser. The laser provides a laser beam, that is, laser energy, which can be carried by a laser beam transmission means 1008 to a coil of wound pipe 1009. A fluid source 1010 is provided. The fluid is carried by the means of fluid transport 1011 to coil of wound pipe 1009.

Coiled tubing coil 1009 is rotated to advance and retract coil tubing 1012. Accordingly, laser beam transmission medium 1008 and fluid transport medium 1011 are attached to coiled tubing coil 1009 by means of the rotating coupling means 1013. Coiled tubing 1012 contains a means of transmitting the laser beam along the full length of the coiled tubing, ie, "high-power laser beam transmission means over long distances" to the downhole assembly, 1014 Coiled tubing 1012 also contains a means of transporting fluid along the entire length of coiled tubing 1012 to the bottom assembly of well 1014.

Additionally, a support structure 1015, which supports an injector 1016, is provided to facilitate movement of the coiled tubing 1012 in drill hole 1001. Additionally, other support structures may be employed, for example, such structures could be a loading mast, crane, mast, tripod, or other similar type of frame or hybrid and combinations thereof. As the drill hole advances to greater depths from the surface 1030, the use of a diverter 1017, a burst blocker (BOP) 1018, and a fluid handling and / or cut system 1019, may become necessary. Coiled tubing 1012 passes from injector 1016 through diverter 1017, BOP 1018, a wellhead 1020, and into borehole 1001.

Fluid is transported to bottom 1021 of drilling well 1001. At that point the fluid exits at or near the bottom assembly of well 1014 and is used, among other things, to transport the cuts, which are created by advancing the well drill, back and out of the drill hole. Accordingly, diverter 1017 directs fluid as it returns by transporting fluid cuts and / or handling system cuts 1019 through connector 1022. This management system 1019 aims to prevent waste products from escaping into the environment and separates and cleans waste products and any vents are flushed from fluid to air, if environmentally and economically permissible, as might be the case if the fluid is nitrogen, or returns the clean fluid to fluid source 1010, or otherwise contains the fluid used for post treatment and / or disposal.

BOP 1018 serves to provide multiple levels of emergency shutdown and / or containment of the drill hole a high pressure event could occur in the drill hole, such as a potential well blowout. The BOP is attached to the wellhead 1020. The wellhead, in turn, can be attached to the liner. For the sake of simplicity, the structural components of a drill hole such as a casing, hanging supports, and cement are not shown. It should be understood that these components can be used and will vary based on the depth, type, and geology of the drill hole, as well as other factors.

The bottom end of the well 1023 of the coiled tubing 1012 connects to the bottom assembly of the well 1014. The bottom of the well assembly 1014 contains optics to supply the laser beam 1024 to its intended object, in the case of Figure 1, the bottom 1021 of drilling well 1001. The bottom assembly of well 1014, for example, also contains means for supplying the fluid.

Accordingly, in general, this system operates to create and / or advance a drill hole that has the laser-creating laser energy in the form of a laser beam. The laser beam is then transmitted from the laser through the coil and into the wound pipe. At which point, the laser beam is then transmitted to the downhole assembly where it is directed towards the ground and / or drilling well surfaces. Upon contact with the surface of the earth and / or the drill hole, the laser beam has sufficient power to cut, or otherwise effect, the rock and earth to create and / or advance the drill hole. The laser beam at the point of contact has sufficient power and is aimed at rock and soil so that it has the ability to create the drill hole that can be compared to or be superior to a conventional mechanical drilling operation. Depending on the type of soil and rock and the properties of the laser beam, this cut occurs through fragmentation, thermal dissociation, casting, vaporization, and combinations of these phenomena.

Although we are not tied to the present theory, interaction with laser material is currently considered to involve the interaction of the laser and a fluid or medium to clear the area of ​​laser illumination. Consequently, laser illumination creates a surface event, and the impact of fluid on the surface quickly transports debris, ie cuts and waste, out of the illumination region. The fluid is additionally considered to remove heat, either on a macro or micro scale, from the lighting area, the post-lighting area, as well as the drill hole, or other media being cut, such as in the case of drilling.

The fluid then transports the cuts up and out of the drill hole. As the drill hole is advanced, the coiled tubing is unwound and further lowered into the drill hole. In this way, the proper distance can be maintained between the downhole assembly and the bottom of the drill hole. If the downhole assembly needs to be removed from the drill hole, for example the well cover, the coil is wound, resulting in the wound pipe being pulled out of the drill hole. Additionally, the laser beam can be directed through the downhole assembly or other laser targeting tool that is placed under the drill hole to perform operations such as drilling, controlled drilling, liner cutting, and plug removal. This system can be mounted on trailers or trucks that can be easily moved, because the size and weight are substantially less than conventional mechanical cranes.

For the systems of the general type illustrated in Figure 1, which have the laser located outside the drill hole, the laser can be any high-energy laser that has the ability to provide enough energy to perform the desired functions, such as driving the drill hole within and through the earth and rock considered present in the geology corresponding to the drill hole. The laser source of choice is a single-mode laser or low-order multi-mode laser with an M² low to facilitate launching into a small-core fiber optic, i.e. about 50 sights. However, larger core fibers are preferred. Examples of a laser source include fiber laser, chemical laser, disc laser, thin block laser, high-light diode laser, as well as the combination of spectral beam from these laser sources or a phased array laser. coherence of these sources to increase the brightness of the individual laser source.

For example, Figure 4 illustrates a combination of spectral beam from laser sources to allow high power transmission under a fiber by assigning a predetermined amount of power per color, limited by the Stimulated Brillioun Scattering (SBS) phenomenon. Accordingly, a first laser source 4001 is provided in FIG. 4 having a first wavelength of "x", where x is less than 1 meter. A second laser 4002 is provided having a second wavelength of x + Ó1 microns, where Ó1 is a predetermined change in wavelength, the change of which could be positive or negative. A third laser 4003 is provided having a third wavelength of χ + δ1 + δ2 microns and a fourth laser 4004 having a wavelength of χ + δ1 + δ2 + δ3 microns. The laser beams are combined by a beam combining device 4005 and transmitted by fiber optic 4006. The combined beam has a spectrum shown in 4007.

For example, Figure 5 illustrates a group of frequency modulated phase lasers. Accordingly, a master oscillator is provided that can be frequency modulated, directly or indirectly, which is then used for injection gate lasers or amplifiers to create a higher power composite beam that can be achieved by any individual laser. Accordingly, laser beams 5001, 5002, 5003 and 5004 are provided, which have the same wavelength. The lasers are combined by a beam combining device 5005 and transmitted by an optical fiber 5006. Lasers 5001, 5002, 5003 and 5004 are associated with a master oscillator 5008 that is FM modulated. The combined ray having a spectrum shown in 5007, where δ is the frequency excursion of the FM modulation. Such lasers are described in US Patent No. 5,694,408, the disclosure of which is incorporated herein by reference in its entirety.

The laser source can be a low order mode source (m²<2) so that it can focus within 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 could be balanced by initiating the nonlinear phenomenon and physical damage to the fiber optic face that requires the fiber diameter to be as long as possible while transmission losses have to be as small as possible. possible.

Accordingly, the laser source should have the 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. Furthermore, combinations of various laser beams can be used to provide the above total power ranges. Additionally, the laser source must have beam parameters in mm millirad, as large as feasible with respect to its ability to bend and substantial fiber fabrication lengths, therefore beam parameters may be less than about 100 mm millirad , from the single mode to about 50 mm millirad, less than about 50 mm millirad, less than about 15 mm millirad, and more preferably about 12 mm millirad. Additionally, the laser source will have at least 10% efficient electrical optics, and at least approximately 50% optical efficiency, at least approximately 70% optical efficiency, by which it should be understood that the highest optical efficiency, all other factors being equal, at least about 25% is preferred, and preferably. The laser source can be operated in wave mode, either pulse or continuous (CW).

The laser source preferably has the ability to be fiber coupled.

To advance drill holes in geologies containing hard rock formations such as granite and basalt, it is preferred to use the YB IPG 20000 which has the following specifications set forth in Table 1 below.

TABLE 1

Optical characteristics

<td>characteristics</td><td>Test conditions</td><td>Symbol</td><td>Min.</td><td>Kind</td><td>Max</td><td>Unit</td>

<td>Operation mode</td><td></td><td></td><td colspan="3">CW, QCW</td><td></td>

<td>Polarization</td><td></td><td></td><td colspan="3">Random</td><td></td>

<td>Nominal output power</td><td></td><td>P NOM</td><td> 20000 *</td><td></td><td></td><td>W</td>

<td>Output power adjustment range</td><td></td><td></td><td> 10</td><td></td><td> 100</td><td> %</td>

<td>Emission wavelength</td><td>Pout = 20 kW</td><td></td><td> 1070</td><td></td><td> 1080</td><td>nm</td>

<td>Broadcast line width</td><td>Pout = 20 kW</td><td></td><td></td><td> 3</td><td> 6</td><td>Nm</td>

<td>ON / OFF time switching DO</td><td>P_0UT = 20 kW</td><td></td><td></td><td> 80</td><td> 100</td><td>Msec</td>

<td>output power modulation index</td><td>P_0UT= 20 kW</td><td></td><td></td><td></td><td> 5.0</td><td>kHz</td>

<td>Output power stability</td><td>For 8 hours T_AGUA = Const</td><td></td><td></td><td> 1.0</td><td> 2.0</td><td> %</td>

<td>Diameter of the feed fiber core</td><td></td><td></td><td colspan="3"> 200</td><td></td>

<td>Product feed fiber lightning parameter</td><td>200 pm</td><td>BPP</td><td></td><td> 12</td><td> 14</td><td>mm * mr ad</td>

<td>Fiber length</td><td></td><td>L</td><td></td><td> 10</td><td></td><td>m</td>

<td>Fiber Cable Bending Radius: Effortless With effort</td><td></td><td>R</td><td> 100 200</td><td></td><td></td><td>mm</td>

<td>Output termination</td><td></td><td></td><td>PAIGH (QBF</td><td colspan="2">_C-8 compatible connector)</td><td></td>

<td>Direction laser wavelength</td><td></td><td></td><td> 640</td><td></td><td> 680</td><td>nm</td>

<td>Steering laser output power</td><td></td><td></td><td> 0.5</td><td></td><td> 1</td><td>mW</td>

• Tested output power at the connector at a distance of no more than 50 meters from the laser

<td>Parameters</td><td>Test conditions</td><td>Min.</td><td>Tip.</td><td>Max.</td><td>Unit</td>

<td>Operating voltage (3 phases)</td><td></td><td>440V</td><td> 480</td><td> 520</td><td>VAC</td>

<td>Frequency</td><td></td><td colspan="3"> 50/60</td><td>Hz</td>

<td>Power consumption</td><td>Pout = 20 kW</td><td></td><td> 75</td><td> 80</td><td>kW</td>

<td>Operating temperature range</td><td></td><td> +15</td><td></td><td> +40</td><td>° C</td>

<td>Humidity: Without conditioner With integrated conditioner</td><td>T &lt;25 ° C T &lt;40 ° C</td><td></td><td></td><td> 90 95</td><td> %</td>

<td>Storage temperature</td><td>Without water</td><td> -40</td><td></td><td> +75</td><td>° C</td>

<td>Dimensions, HxWxd</td><td>NEMA-12; IP-55</td><td colspan="3">1490x 1480x 810</td><td>mm</td>

<td>Weight</td><td></td><td colspan="3"> | 1200 |</td><td>kg</td>

<td>Pipeline</td><td></td><td colspan="3">NPT threaded stainless steel and / or plastic tubing</td><td></td>

For deck cutting, plug removal and drilling operations, the laser can be any of the lasers referenced above, and can additionally be any minor lasers that could only be used to work and complete bottom activities from the well.

In addition to the configuration of Figure 1, and the above preferred examples of lasers for use with the present invention, other laser configurations for use in a high efficiency laser drilling system are contemplated. Accordingly, laser selection can generally be based on the intended application or desired operating parameters. Average power, specific power, irradiance, operating wavelength, pumping source, beam spot size, exposure time, and associated specific energy may be considerations in selecting a laser. The material to be drilled, such as a rock formation time, can also influence laser selection. For example, the type of rock may be related to the type of resource you are looking for. Hard rocks, such as limestone and granite, can generally be associated with hydrothermal sources, while sandstone and shale can generally be associated with sources of gas or oil. Accordingly, by way of example, the laser may be a solid-state laser, it may be a gas, chemical, die laser, or metal vapor, or it may be a semiconductor laser. Additionally, the laser can produce a kilowatt level laser beam, and can be a pulse laser. The laser may additionally be an Nd: YAG laser, a CO2 laser, a diode laser, such as an infrared diode laser, or a fiber laser, such as a ytterbium mixed multi-shielded fiber laser. The infrared fiber laser emits light in the wavelength ranges from 800 to 1600 nm. The fiber laser is mixed with an active gain medium comprising rare earth elements, such as holmium, erbium, ytterbium, neodymium, dysprosium, praseodymium, tulium, and combinations thereof. Combinations of one or more types of lasers can be implemented.

Fiber laser beams of the type useful in the present invention are generally constructed around dual core fibers. The inner core may be composed of rare earth elements; ytterbium, erbium, tulium, holmium or a combination. The optical gain medium emits wavelengths of 1064nm, 1360nm, 1455nm and 1550nm, and may be of limited diffraction. An optical diode can be coupled within the outer core (generally referred to as the inner liner) to pump the rare earth ions into 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 through the excited rare earth ions. The outer shell of the outer core can be a low index polymer to reduce losses and protect the fiber. Typical pumped laser diodes emit in the range of about 915-980nm (generally - 940nm). Fiber laser beams are manufactured by IPG photonics or Southhampton Photonics. High power fibers were shown 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 can chip, 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 can generally induce thermal stress in a rock formation due to the characteristics of the material, such as rock, including, for example, thermal conductivity. The laser beam can also induce mechanical stress by blasting superheated steam from moisture at the subsurface of the rock formation. Mechanical stress can also be induced by decomposition and thermal sublimation of part of the mineral in situ from the material. Thermal and / or mechanical stress at or below a laser-material interface can promote splintering of the material, such as rock. Likewise, the laser can be used to make coatings for wells, cement or other material bodies, as desired. A laser beam can generally act on a surface at a location where the laser beam makes contact with the surface, which can be referred to as a region of laser illumination. The laser illumination region can have any previously selected shape and intensity distribution that is required to achieve the desired output, the laser illumination region can also be referred to as a laser beam spot. Drill holes of any depth and / or diameter can be formed, such as multiple chipping points or layers. Accordingly, by way of example, consecutive points may be targeted or a strategic pattern of points may be targeted to improve laser / rock interaction. The position or orientation of the laser or laser beam can be moved or directed so that it intelligently acts through a desired area, so that laser / material interactions are more efficient in causing rock removal.

One or more lasers can additionally be placed at the bottom of the well, that is, at the bottom of the drill hole. Therefore, depending on the specific requirements and operating parameters, the laser beams can be located at any depth within the drill hole. For example, the laser can be kept relatively close to the surface, it can be placed deep within the drill hole, it can be kept at a constant depth within the drill hole, or it can be incrementally placed deeper as more drill hole deep. Therefore, by way of further example, the laser can be kept at a certain distance from the material, such as rock to be acted upon. When the laser is deployed down the hole, the laser can generally be shaped and / or sized to fit within the drill hole. Some lasers may be better suited than others for downhole use. For example, the size of some lasers may be considered unsuitable for downhole use, however such lasers may be designed or modified for downhole use. Similarly, the power or cooling of a laser can be modified to be used at the bottom of the well.

Systems and methods can generally include one or more features to protect the laser. This becomes important due to harsh environments, for both surface units and downhole units. Accordingly, in accordance with one or more embodiments, a drill hole drilling system may include a cooling system. The cooling system can generally work to cool the laser. For example, the cooling system may cool a downhole laser, for example, to a temperature below ambient temperature or to a laser operating temperature. Additionally, the laser can be cooled using absorption cooling to the operating temperature of the infrared diode laser, for example, from about 20 ° C to about 100 ° C. For a fiber laser, its operating temperature can be between about 20 ° C to about 50 ° C. A liquid at a lower temperature can be used to cool when a temperature higher than the operating diode laser temperature is reached, to cool the laser.

Heat can also be sent up the well, that is, out of the drill hole and to the surface, using a liquid heat transfer agent. The liquid transfer agent can then be cooled by mixing with a liquid at the top of the well at a lower temperature. One or multiple heat dispersing fans can be attached to the laser diode to spread heat away from the infrared diode laser. Fluids can also be used as a coolant, although an external coolant can also be used.

In downhole applications, the laser can be protected from downhole pressure and the environment by being covered in a suitable material. Such materials can include steel, titanium, diamond, tungsten carbide, and the like. The fiber head for an infrared diode laser or fiber laser may have an infrared transmission window.

Said transmission windows can be made of a material that can withstand the environment of the downhole, while retaining the transmission qualities. One such material may be sapphire or another material with similar qualities. One or more infrared diode laser or fiber laser can be completely covered by sapphire. As an example, an infrared diode laser or fiber laser can be made of diamond, tungsten carbide, 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 or fiber laser is not in contact with the drilling well during drilling. For example, a downhole laser can be detached from a wall of the drill hole.

The cooler, which is used to cool the laser, in systems of the general type illustrated in Figure 1, is chosen to have a cooling capacity dependent on the size of the laser, the efficiency of the laser, the operating temperature, and the environmental location, and preferably the cooler can be selected to operate on all of these parameters. Preferably, an example of a cooler that is useful for a 20 kW laser will have the following specifications set forth in Table 2 of this description.

TABLE 2

<td>Cooler</td><td>PC400.01-NZ-DIS</td>

<td></td><td></td>

<td>Technical data for 60 Hz operation:</td><td></td>

<td>IPG laser type</td><td></td>

<td>Net cooling capacity</td><td>YLR-15000, YLR-20000</td>

<td>Refrigerant</td><td>60.0 kW</td>

<td>Required air flow</td><td>R407C</td>

<td>Installation</td><td>26100 m^or/ h</td>

<td>Number of compressors</td><td>Outdoor installation</td>

<td>Number of fans</td><td> 2</td>

<td>Number of pumps</td><td> 3</td>

<td></td><td> 2</td>

<td>Operation limits</td><td></td>

<td>Designated operating temperature</td><td>33 ° C (92 ° F)</td>

<td>Minimum operating temperature</td><td>(-) 20 ° C (-4 ° F)</td>

<td>Maximum operating temperature</td><td>39 ° C (102 ° F)</td>

<td>Minimum storage temperature (with empty water tank)</td><td>(-) 40 ° C (-40 F)</td>

<td>Maximum storage temperature</td><td>70 ° C (158 ° F)</td>

<td>Regular volume of tank water</td><td>240 liters (63.50 gallons)</td>

<td>DI volume of tank water</td><td>25 liters (6.61 gallons)</td>

<td></td><td></td>

<td>Electrical data for 60 Hz operation:</td><td></td>

<td>Power consumption designed without heater</td><td>29.0 kW</td>

<td>Power consumption designed with heater</td><td>33.5 kW</td>

<td>Maximum power consumption</td><td>41.0 kW</td>

<td>Maximum current</td><td>60.5 A</td>

<td>Maximum fusion</td><td>80.0A</td>

<td>Initial current</td><td>141.0A</td>

<td>Connection voltage</td><td>460 V / 3 Ph / PE</td>

<td>Frequency</td><td>60 Hz</td>

<td>Connection voltage tolerance</td><td> +/- 10%</td>

<td>Dimensions, weights and sound level</td><td></td>

<td>Empty tank weight</td><td>900 KG (1984 Ibs)</td>

<td>Sound level at a distance of 5 m</td><td>68 dB (A)</td>

<td>Width</td><td>2120 mm (83 1/2 inches)</td>

<td>Depth</td><td>860 mm (33 7/8 inches)</td>

<td>Height</td><td>1977 mm (77 7/8 inch)</td>

<td></td><td></td>

<td>Water circuit tap</td><td></td>

<td>Cooling capacity</td><td>56.0 kW</td>

<td>Outlet water temperature</td><td>21 ° C (70 ° F)</td>

<td>Water inlet temperature</td><td>26 ° C (79 ° F)</td>

<td>Temperature stability</td><td>+/- 1.0 K</td>

<td>Water flow vs free water pressure available</td><td>135 l / min at 3.0 bar (35.71 GPM at 44 PSI)</td>

<td>Water flow vs. free water pressure available</td><td>90 l / min at 1.5 bar (23.81 GPM at 21 PSI)</td>

<td></td><td></td>

<td>Deionized water circuit</td><td></td>

<td>Cooling capacity</td><td>4.0 kW</td>

<td>Outlet water temperature</td><td>26 ° C (79 ° F)</td>

<td>Water inlet temperature</td><td>31 ° C (88 ° F)</td>

<td>Temperature stability</td><td>+/- 1.0 K</td>

<td>Water flow vs free water pressure available</td><td>20 l / min at 1.5 bar (5.28 GPM at 21 PSI)</td>

<td>Water flow vs. free water pressure available</td><td>15 l / min at 4.0 bar (3.96 GPM at 58 PSI)</td>

<td></td><td></td>

<td>Options (included)</td><td></td>

<td>Bifrequent version: 400 V / 3 Ph / 50 Hz 460 V / 3 Ph 60 Hz</td><td></td>

For the systems of the general type illustrated in Figure 1, the laser beam is transmitted to the coil of wound pipe by means of a laser beam transmission means. Said transmission medium may be commercially available industrial hardened fiber optic cabling of QBH connectors at each end.

There are two basic coil treatments, the first is to use a coil which is simply a wheel with a duct wound around the outside of the wheel. For example, this coiled conduit may be a hollow tube, this may be an optical fiber, this may be a bundle of optical fibers, this may be a fiber optic shield, this may be other types of transmission cables in optical form, or It may be a hollow tube containing the optical transmission cables mentioned above.

The coil 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 coil, the coil drives over the precision bearings in either a horizontal or vertical orientation to avoid any tilting of the coil as the fiber is wound. This is optimal for the axis of the coil to maintain the angular tolerance of approximately +/- 10 micro-radians, which is preferably obtained by having the optical axis isolated and / or independent of the axis of coil rotation. The beam, when thrown into the fiber, is launched by a lens, which is rotating with the fiber in the plane of the Fourier Transform of the launch lens, which is insensitive to movement in the position of the lenses with relative to the laser beam, although sensitive to the inclination of the incoming laser beam. The beam, which is launched into the fiber, is launched by a lens that is stationary with respect to the fiber in the plane of the Fourier Transform of the launch lens, which is insensitive to the movement of the fiber with respect to the launch lens.

A second treatment is to use a stationary cage-like coil and rotate the laser head as the fiber is wound up to prevent the fiber from twisting as it is removed from the coil. If the fiber can be designed to accept a reasonable amount of twist along its length, then this may be the preferred method. Using the second treatment, if the fiber could be previously twisted around the coil then as the fiber is pulled out of the coil the fiber straightens out and there is no need for the fiber and the drill head to be rotated as the fiber is removed. There will be a series of turnbuckles that will suspend the fiber down the well, or if the well is filled with water to remove debris from the bottom of the well, then the fiber can be coated in a floating liner that will support the weight of the fiber and its casing over the full length of the well. In the situation where the downhole assembly does not rotate and the fiber is spirally twisted and placed under spiral twisting stress, there will be an additional benefit in reducing SBS as taught in the present disclosure.

For the systems of the general type illustrated in Figure 1, the coil of coil tubing may contain the following example lengths of coil tubing: from 1 km (3,280 ft) to 9 km (29,528 ft); 2 km (6,561 ft) to 5 km (16,404 ft); at least approximately 5 km (16,404 ft); and from approximately 5 km (16,404 ft) to at least approximately 9 km (29,528 ft). The coil can be any standard type of coil using 2,875 steel pipe. For example, commercial coils typically include 4-7 km steel pipe 7.30 centimeters (2 7/8 inches). The pipe is available in commercial sizes ranging from 2.54 centimeters to 7.30 centimeters.

Preferably, the coil will have a 7.30 centimeter standard type hollow steel pipe, i.e. the coiled pipe. As further discussed in the present disclosure, the coiled tubing will have at least one optical fiber inside to transmit the laser beam to the downhole assembly. In addition to fiber optics, coiled tubing can also carry other cables for other purposes at the bottom of the hole or to transmit material or information back to the top of the drill hole to the surface. The coiled tubing can also carry fluid or a conduit to transport fluid. It can be used to protect and support optical fibers and other cables that can be transported in wound pipe stabilizers.

The coil can have QBH fibers and a collimator. Vibration isolation means is desirable in coil construction, and in particular for the fiber slip ring, therefore, for example, the coil outer plate is mounted to the coil holder using a Delrin plate, although the inner plate floats on the coil and the pins rotate the assembly. The fiber slip ring is the stationary fiber, which communicates power through the rotating coil hub to the rotating fiber.

When a coil is used, the mechanical axis of the coil is used to transmit optical power from the input end of the optical fiber to the distant end. This requires a precision optical support system (the fiber slip ring) to maintain a stable alignment between the external fiber that provides the optical power and the optical fiber mounted on the coil. The laser can be mounted inside the coil, or as shown in figure 1, it can be mounted external to the coil or if multiple laser beams are used, both internal and external locations can be used. The internally mounted laser can be a laser probe, used for analysis and monitoring of the system and methods performed by the system. Additionally, the detection and monitoring equipment may be located within or otherwise fixed to the rotating elements of the coil.

Additionally rotatable coupling means are provided to connect the wound tubing, which is rotating, for the laser beam transmission medium 1008, and fluid transport means 1011, which are not rotating. As illustrated by way of example in Figure 2, a coil of wound pipe 2009 has rotating coupling means 2013. One of said coupling means has an optical rotary coupling means 2002 and the other has a fluid rotatable coupling means 2003. The optical rotary coupling means 2002 may have the same structure as the fluid rotatable coupling means 2003, or these can be separated. Accordingly, preferably, two separate coupling means are employed. Additional rotating coupling means can also be added to handle other cables, such as, for example, cables for downhole probes.

The 2002 optical rotary coupling means connects to a 2004 hollow precision grounding shaft with bearing surfaces 2005, 2006. The 2008 laser transmission means is optically coupled to the 2004 hollow shaft by the optical rotary coupling means 2002, which allows the laser beam to be transmitted from the laser transmission medium 2008 into the hollow shaft 2004. The optical rotary coupling means, for example, may be integrated with 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 collimator. QBH. To the extent that excessive heat accumulates in the optical rotary coupling, cooling must be applied to maintain the temperature at a desired level.

The hollow shaft 2004 then transmits the laser beam to an opening 2007 in the hollow shaft 2004, the opening of which contains an optical coupler 202010 that optically connects the hollow shaft 2004 to the 2025 long distance high power laser beam transmission medium. which is located inside the 2012 wound pipe. Accordingly, in this way, the laser transmission medium 2008, the hollow shaft 2004 and the long-range high-power laser beam transmission medium 2025 are rotatably connected optically, so that the laser beam can transmit from the laser to the 2025 long distance high power laser beam transmission medium.

A further illustration of an optical connection for a rotating coil is provided in Figure 6, where a coil 6000 and a bracket 6001 for coil 6000 are illustrated. Coil 6000 is rotatably mounted to bracket 6001 by the bracket brackets. 6002 charging cable. One 6003 optical input cable. which transmits a laser beam from a laser source (not shown in this figure) to an optical coupler 6005. The laser beam exits connector 6005 and passes through optics 6009 and 6010 into optical coupler 6006, which is optically connected to an optical output cable 6004. Optical coupler 6005 is mounted to the coil by a bracket. which preferably does not support load 6008, while coupler 6006 is mounted to the coil by device 6007 in a manner that allows its rotation with the coil. Thus, as the coil is rotated, the weight of the coil and coiled tubing is supported by the load bearing brackets 6002, while the rotating optical coupling assembly allows the laser beam to be transmitted from the cable 6003 which does not rotate cable 6004, which rotates with the coil.

In addition to using a rotating coil of wound tubing, as illustrated in Figures 1 and 2, other means for extending and recovering the high-energy laser beam transmission medium over a long distance is a stationary coil or cage. As illustrated by way of example, in Figures 3A and 3B, a cage 3009 is provided which is stationary, and which contains winding within the long range high energy laser beam transmission medium 3025. That medium is connected to the laser beam transmission medium 3008, which is connected to the laser (not shown in this figure). In this way, the laser beam can be transmitted within the high-power laser beam transmission medium over a long distance and that medium can be deployed down a drill hole. Similarly, the high-power, long-range laser beam transmission medium may be contained within the coiled tubing above the cage. Accordingly, the long-range medium could be a shielded optical cable of the type provided in the present disclosure. During the use of the cage, you must take into consideration the fact that the optical cable will be twisted when it is unfolded. To make sense of this consideration, the downhole assembly, or just the laser drill head, can be rotated slowly to keep the cable without twisting, the optical cable can be pre-twisted, and the optical cable can be designed to tolerate the crooked.

The fluid source can be either a gas, a liquid, a foam, or a system that has multiple capabilities. The fluid can serve many purposes in advancing the drill hole. Accordingly, the fluid is primarily used for the removal of cuts from the bottom of the drill hole, for example, as it is commonly referred to as a drilling fluid or drilling mud, and to maintain the area between the end of the laser optics. at the downhole and downhole assembly, sufficiently clear of cuts so that it does not interfere with the path and power of the laser beam. It can also function to cool down the laser optics and downhole assembly, as well as in the case of a compressible fluid, or a compressible fluid under tension. The fluid additionally provides a means to create hydrostatic pressure in the well to avoid the influx of gases and fluids.

Therefore, in selecting the type of fluid, as well as the fluid delivery system, consideration should be given to, among other things, the laser wavelength, and cut removal rate that is necessary to remove cuts created by the advancement of the laser in the drill hole. It is highly desirable that the rate of cut removal through the fluid is not a limiting factor for the advance rate systems of a drilling well. For example, fluids that can be employed with the present invention include conventional drilling muds, water (as long as these are not in the optical path of the laser), and fluids that are highly transmissive to the laser, such as halogenated hydrocarbon, (halogenated hydrocarbons are low molecular weight polymers of chlorotrifluoroethylene (PCTFE)), oils and N2. Preferably these fluids can be employed and preferred and should be supplied at rates ranging from a couple to several hundred CFMs at a pressure ranging from atmospheric pressure to several hundred psi. If combinations of these fluids are used, flow rates should be used to balance objects to maintain optical path transmission and debris removal capabilities.

Preferably, the long-range high-power laser beam transmission medium is an optical fiber or plurality of optical fibers in a shielded jacket to drive 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 approximately 20 or more kW of average power down into the drill hole for the purpose of detecting lithology, testing lithology, drilling through lithology, and other similar applications generally related to creation, advancement and testing of drilling holes in the ground. Preferably, the shielded optical fiber comprises a 0.64 cm (1/4 ”) stainless steel tube having 1, 2, 1 to 10, at least 2, more than 2, at least about 50, at least approximately 100, and more preferably between 2 to 15 optical fibers inside. Preferably these will have approximately a core diameter baseline of 500 microns of fiber index pitch.

Today, industrial lasers are considered to use high-power fiber optics shielded with steel wound around the fiber and a polymeric sheath surrounding the steel sheath to prevent unwanted dust and dirt from entering the fiber optic environment . The optical fibers are covered with a thin metal sheath or a thin cable which is moved along with the fiber to detect a fiber break. A fiber break can be dangerous because it can result in a break in the shield and could expose an operator to danger. However, this type of protection fiber is designed for ambient conditions and will not withstand the harsh environment of the drill hole.

Fiber optic sensors for the oil and gas industry are deployed, both unshielded and shielded. Currently available unshielded methods are considered unacceptable for the high power applications contemplated by the present application. The current manifestations of the shielded method are equally inadequate, as they do not take into account the method of conducting high optical power and the method of detecting a break in the optical fiber, both of which are important to a reliable and safe system. The current method for shielding an optical fiber is to coat it in a stainless steel tube, cover the fiber with carbon to avoid hydrogen migration, and finally fill the tube with a jelly that both cushions the fiber and absorbs hydrogen from the environment. However, this packaging has been made only with small diameter core fiber optics (50 microns) and with very low power levels &lt;1 Watt of optical power.

Accordingly, to provide a high power optical fiber that is useful in the rough environment of a drill hole, a novel shielded fiber and method is provided. Accordingly, there is provided, to cover a large core optical fiber having a diameter equal to or greater than 50 microns, equal to or greater than 75 microns and more preferably equal to or greater than 100 microns, or a plurality of optical fibers within a metal tube, where each fiber can have a carbon coating, as well as a polymer, and can include Teflon coating to pad the fibers when they rub against each other during deployment. Accordingly, the fiber, or set 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 vary in thickness from 10 microns to&gt; 600 microns. The polymer or Teflon coating can vary in thickness from 10 microns to&gt; 600 microns and the preferred types of such coating are acrylate, silicone, polyimide, PFA and others. The carbon coating can be adjacent to the fiber, with the polymeric or Teflon coating being applied thereto. Polymeric or Teflon coatings are applied at the end to reduce fiber clumping during deployment.

In some non-limiting modes, optical fibers can send up to 10 kW per fiber, up to 20 kW per fiber, up to or more than 50 kW per fiber. The fibers can transmit any desired wavelength or combination of wavelengths. In some embodiments, the range of wavelengths that the fiber can transmit can preferably be between about 800nm ​​and 2,100nm. The fiber can be connected via a connector to another fiber to maintain the proper fixed distance between one fiber and the surrounding fibers. For example, the fibers can be connected such that the ray point of the surrounding optical fibers when irradiating the material, such as a rock surface, is 5.08 centimeters below and does not overlap the particular optical fiber. The fiber can have any desired core size. In some modalities, the size of the nucleus can vary from approximately 50 microns to 1 mm or greater. The fiber can be single-mode or multi-mode. If it is multi-mode, the numerical aperture of some modes can vary 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 less interface losses. In some embodiments, a fiber laser emitted light at wavelengths from 1060nm to 1080nm, 1530nm to 1600nm, 1800nm ​​to 2100nm, diode lasers from 800nm ​​to 2100nm, CO2 lasers to 10,600. nm, or Nd YAG lasers emitting at 1064 can be coupled to the optical fibers. In some embodiments, the fiber may have a low water content. The fiber may be covered, such as with polyimide, acrylate, carbon polyamide, carbon / dual acrylate, or other material. If high temperatures are required, a polyimide or a derived material can be used to operate at temperatures above 300 degrees Celsius. The fibers can be a hollow core photonic crystal or a solid core photonic crystal. In some embodiments, the use of hollow core photonic crystal fibers at wavelengths of 1500nm or greater can minimize absorption losses.

The use of the plurality of optical fibers can be bundled together in a number of configurations to improve power density. The optical fibers that make up a set can vary from two in hundreds of watts to kilowatt powers in each fiber up to millions in milliwatts or microwatts of power. In some embodiments, the plurality of optical fibers can be bundled together and spliced ​​to powers below 2.5 kW to stagger the power. The power can be spliced ​​to increase the power densities across an array, such as preferably up to 10 kW, more preferably up to 20 kW, and even more preferably up to or greater than 50 kW. Staging and power increase allows the beam spot to increase or decrease the power density and beam spot sizes across the optical fibers. In most of the examples, splicing the power to increase the total power output can be beneficial so that the power delivered through the fibers does not reach the critical power thresholds for the optical fibers.

Accordingly, by way of example, the following configurations provided in Table 3 of the present disclosure are provided.

TABLE 3

<td>Assembly diameter</td><td>Number of fibers in the set</td>

<td>100 micras</td><td> 1</td>

<td>200 micras - 1 mm</td><td>2 to 100</td>

<td>100 micras - 1 mm</td><td> 1</td>

A thin cable can also be packed, for example, in the 0.635 centimeter steel pipe, along with the optical fibers to test the continuity of the fiber. Alternatively / a metallic coating of sufficient thickness is applied to allow fiber continuity to be monitored. These methods, however, become problematic since the fiber exceeds a length of 1 km, and do not provide a practical method for testing and monitoring.

The configurations in Table 3 may 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 settings can be used to transmit 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 preferably at least about 20 kW.

During power transmission over long distances, such as at the bottom of a drill hole or through a cable that is at least 1 km, there are three sources of power loss in an optical fiber, Raleigh Scattering, Scattering Raman and Brillioun Scattering. The first, Raleigh Scattering is the intrinsic loss of the fiber that is due to impurities in the fiber. The second, Raman scattering can result in Stokes or anti-Stokes stimulated Raman scattering outside of the fiber vibration molecules. Raman scattering occurs preferably in the forward direction and results in a change in wavelength of up to + 25 nm from the original wavelength of the source. The third mechanism, the Brillioun Scattering, is the dispersion of the forward propagation pump by 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 can create greater difficulties in transmitting high powers over long distances. Brillioun Scattering can give rise to Stimulated Brillioun Scattering (SBS) where the light pump is preferably scattered backward into the fiber with a frequency change of about 1 to about 20 GHz from the frequency of original source. This effect of Stimulated Brillioun can be strong enough to scatter back substantially all incident pump light if the correct conditions are determined. Therefore, it is desirable to suppress this nonlinear phenomenon. Essentially there are four primary variables that determine the threshold for SBS: the length of the gain medium (the fiber); the linear width of the laser source; the linear width of the natural fiber Brillioun in which the pump light is propagating; 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 that 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, so that positive feedback occurs, whereby sound waves are generated by scattering procedures. These sound waves then act as a lattice to incite additional SBS. Once the power threshold is passed, the exponential growth of stray light occurs and the ability to transmit higher power is greatly reduced. This exponential growth continues with an exponential reduction in power up to that point whereby any additional power input will not be transmitted forward, the point of which is defined in the present description as the maximum transmission power. Accordingly, the maximum transmit power depends on the SBS threshold, although once reached, the maximum transmit power will not increase with increasing power input.

Accordingly, as provided in the present disclosure, the novel and unique means of suppressing the nonlinear scattering phenomenon, such as SBS and Stimulated Raman Scattering phenomenon, the means for increased power threshold, and the means To increase the maximum transmission power they are established to be used in the transmission of high power laser energy over long distances for, among other things, the advancement of drilling wells.

The mode field diameter needs to be as large as it is practical, without causing undue attenuation of the propagation source laser. Large core single mode fibers are currently available with mode diameters up to 30 microns, however, turning losses are typically high and propagation losses are larger than desired. Small core pitch index fibers, with 50 micron mode field diameters, are of interest, due to low intrinsic losses, significantly reduced launch creep, and decreased SBS gain because the fiber is not while retaining polarization, it also has a multimode propagation constant and a large mode field diameter. All of these factors effectively increase the SBS power threshold. Consequently, a larger core fiber with Raleigh dispersion losses is a potential solution for transmitting high powers over large distances, preferably where the mode field diameter is 50 microns or greater in diameter.

The next consideration is the natural Brillioun line width of the fiber. As the Brillioun line width increases, the dispersion gain factor decreases. The Brillioun line width can be widened by varying the temperature along the length of the fiber, modulating the tension on the fiber and inducing acoustic vibrations in the fiber. Varying the temperature across the fiber results in a change in the fiber's refractive index and the background vibration (kT) of the atoms in the fiber that significantly broaden the Brillioun spectrum. In the downhole application, the temperature along the fiber will naturally vary as a result of the geothermal energy to which the fiber will be exposed at the depth ranges expressed in the present description. The net result will be a suppression of the SBS profit. Applying a thermal gradient along the length of the fiber could be a means of suppressing SBS by increasing the Brillioun linear width of the fiber. For example, such means could include the use of 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. The applied thermal gradients and temperature distributions can be, but are not limited to, linear, staggered, and periodic functions along the length of the fiber.

Modulating the tension for the suppression of the non-linear dispersion phenomenon on the fiber can be achieved, although this means is not limited to anchoring the fiber in its cover, so that the fiber is tensioned. By effectively stretching each segment between the support elements, then the Brillioun spectrum will be either a red shift or a blue shift from the natural center frequency, effectively widening the spectrum and lowering the gain. If the fiber is allowed to hang freely from a turnbuckle, then the tension will vary from the top of the well to the bottom of the well, effectively widening the Brillioun gain spectrum and suppressing the SBS. Means for applying tension to the fiber include, without limitation, twisting the fiber, stretching the fiber, applying external pressure to the fiber, and bending the fiber. Accordingly, for example, as discussed above, fiber twisting can occur through the use of a cage. In addition, fiber twisting can occur through the use of downhole stabilizers, designed to provide rotary motion. The stretching of the fiber can be achieved, for example, as described above using support elements along the length of the fiber. Downhole pressures can provide a pressure gradient across the length of the fiber, thereby inducing stress.

Acoustic modulation of the fiber can alter the linear width of Brillioun. 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 widened, effectively lowering the SBS gain. For example, crystals, transducers, mechanical vibrators, or any other mechanism to induce acoustic vibrations within the fiber, can be used to effectively suppress SBS gain. Additionally, acoustic radiation can be created by the escape of compressed air through previously defined holes, creating a hissing effect.

The interaction of the font linear width and the Brillioun linear width in part defines the gain function. By varying the line width of the source the gain function can be suppressed and consequently the non-linear phenomenon, such as SBS, can be suppressed. The linear width of the source can be varied, for example, by FM modulation or combined sources of the closely spaced wavelength, an example of which is illustrated in Figure 5. Therefore, a fiber laser can be FM modulated directly by a number of means, one method is simply stretching the fiber with a piezo-electric element, which induces a rate of change in the fiber medium, resulting in a change in the length of the laser cavity, which produces a change in the natural frequency of the fiber laser. This FM modulation scheme can achieve very wide band modulation of the fiber laser with relatively slow mechanical and electrical components. A more direct method for FM modulation of these laser sources may be to pass the beam through a nonlinear crystal, such as lithium niobate, which operates in a phase modulation mode, and modulates the phase at the desired frequency to suppress profit.

Additionally, a combination of laser source spectral beam, which can be used to suppress Stimulated Brillioun Scattering. Therefore, separate wavelength rays, separation as described in this description, can suppress Stimulated Brillioun Scattering through interference with the resulting sound waves, which tend to widen the Stimulated Brillioun Spectrum, and thus results in a lower Stimulated Brillioun gain. Additionally, by using multiple colors, the total maximum transmit power can be increased by limiting the SBS phenomenon within each color. An example of such a laser system is illustrated in Figure 4.

Raman scattering can be suppressed by including a selective wavelength filter in the optical path. This filter can be reflective, transmitter, or an absorbent filter. Additionally, a fiber optic connector can include a Raman rejection filter. Additionally, a Raman rejection filter could be integral to the fiber. These filters can be, but are not limited to, a volume filter, such as a dichroic filter or a transmitting lattice filter, such as a Bragg lattice filter, or a reflective lattice filter, such as a patterned grid. For any backward propagating Raman energy, as well as a means of introducing pump energy to an integrated active fiber amplifier within the overall fiber path, is contemplated, which, by way of example, could include a method to integrate a reject filter with a coupler to suppress Raman radiation, which suppresses Raman gain. Additionally, the Brillioun dispersion can also be suppressed by filtration. Faraday isolators, for example, could be integrated into the system. A Bragg lattice reflector tuned to the Brillioun scattering frequency could also be integrated into the coupler to suppress Brillioun radiation.

To overcome the power loss in the fiber as a function of distance, active amplification of the digital signal can be used. An active fiber amplifier can provide gain along the optical fiber to compensate for losses in the fiber. For example, by combining active fiber sections with passive fiber sections, where sufficient pumping light is provided to the active, i.e. the amplified section, the losses in the passive section will be compensated. Accordingly, a means is provided to integrate signal amplification into the system. In Fig. 7, an example of such a medium having a first passive fiber section 8000 was illustrated with, for example, -1 dB loss, a pump source 8001 optically associated with fiber amplifier 8002, the which can be inserted into the outer shield, to provide, for example, a +1 dB gain of propagation signal power. The fiber amplifier 8002 is optically connected to a coupler 8003, which can be freely detached or fused, which is optically connected to a passive section 8004. This configuration can be repeated numerous times, for varying lengths, losses power, and downhole conditions. Additionally, the fiber amplifier could act as the supply fiber for the entire transmission length. The pumping source may be above the well, downhole, or combinations of wellhead and downhole for various drill hole configurations.

An additional method is to use a combination of dense wavelength beam from multiple laser sources to create an effective linear width that is many times the natural linear width of the individual laser that effectively suppresses SBS gain. Here, multiple lasers, each operating at a predetermined wavelength and a predetermined wavelength spacing, are superimposed on each other, for example, by a grid. The grid can be transmitting or reflective.

The fiber optic or fiber bundle can be coated in an environmental protection to enable it to survive high pressures and temperatures. The cable could be similar in construction to submarine cables that reside through the seabed and can be buoyant if the well is filled with water. The cable may consist of one or many optical fibers in the cable, depending on the power handling capacity of the fiber and the power required to achieve economical puncture rates. It should be understood that in the field, several km of fiber optics will have to be supplied down into the drill hole. Fiber cables can be manufactured in variable lengths, so that shorter lengths are used for shallower depths so that higher power levels can be supplied and consequently, higher perforation rates can be achieved. This method requires that the fibers be changed 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 a low enough loss to allow connection and reconnection of the fibers with minimal losses.

Accordingly, power transmissions are provided in Tables 4 and 5 of the present description for the example optical cable configurations.

TABLE 4

<td>Power input</td><td>Fiber length (s)</td><td>Diameter of the set</td><td># of fibers in the set</td><td>Power output</td>

<td>20 kW</td><td>5 km</td><td>500 micras</td><td> 1</td><td>15 kW</td>

<td>20 kW</td><td>7 km</td><td>500 micras</td><td> 1</td><td>13 kW</td>

<td>20 kW</td><td>5 km</td><td>200 microns 1mm</td><td>2 to 100</td><td>15 kW</td>

<td>20 kW</td><td>7 km</td><td>200 microns 1mm</td><td>2 to 100</td><td>13 kW</td>

<td>20 kW</td><td>5 km</td><td>100-200 micras</td><td> 1</td><td>10 kW</td>

<td>20 kW</td><td>7 km</td><td>100-200 micras</td><td> 1</td><td>8 kW</td>

TABLE 5 (with active amplification)

<td>Power input</td><td>Fiber length (s)</td><td>Diameter of the set</td><td># of fibers in the set</td><td>Power output</td>

<td>20 kW</td><td>5 km</td><td>500 micras</td><td> 1</td><td>17 kW</td>

<td>20 kW</td><td>7 km</td><td>500 micras</td><td> 1</td><td>15 kW</td>

<td>20 kW</td><td>5 km</td><td>200 microns 1mm</td><td>2 to 100</td><td>20 kW</td>

<td>20 kW</td><td>7 km</td><td>200 microns 1mm</td><td>2 to 100</td><td>18 kW</td>

<td>20 kW</td><td>5 km</td><td>100-200 micras</td><td> 1</td><td>15 kW</td>

<td>20 kW</td><td>7 km</td><td>100-200 micras</td><td> 1</td><td>13 kW</td>

The optical fibers are preferably placed inside the wound pipe to be advanced inside and removed from the drill hole. In this way, the coiled tubing could be the primary load bearing and support the structure as the tubing is lowered into the well. It can easily be seen that in deep wells the pipe will support a significant amount of weight due to its length. To protect and secure the optical fibers, include the set of optical fiber contained in, for example, 0.635 centimeter stainless steel pipe, inside the winding pipe, stabilization devices are desirable. Accordingly, at various intervals along the length of the wound pipe, the supports can be located within the wound pipe that fixes or holds the optical fiber in place relative to the wound pipe. These supports, however, must not interfere with, or otherwise obstruct, the flow of fluid if the 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, can be used to provide a tension for the fiber to suppress the nonlinear phenomenon.

Although it is preferable to place the optical fibers within the pipe, the fibers may also be associated with the pipe, for example, by running parallel to the pipe, and by being attached to it, by running parallel to the pipe and fixed in such a way that You can slide to it, or when being placed on a second pipe that is associated or not associated with the first pipe. In this way, it will be appreciated that various combinations of tubulars can be employed to optimize the supply of laser energy, fluids, and other wiring and devices within the drill hole. Additionally, the fiber optic can be segmented and used with conventional drill pipe parts and therefore easily adapted for use with conventional mechanical drill equipment equipped with connectable tubular drill pipe.

During drilling operations, and in particular during deep drilling operations, for example, depths greater than 1 km, it may be desirable to monitor downhole conditions, as well as to monitor conditions throughout and in the medium of high-energy laser transmission over long distance. Accordingly, there is further provided the use of an optical pulse, pulse train, or continuous signal that are continuously monitored that are reflected from the distal end of the fiber and are used to determine the continuity of the fiber. Additionally, the use of fluorescence from the illuminated surface is provided as a means of determining the continuity of the optical fiber. A high power laser will sufficiently heat the rock material to the point of light emission. This emitted light can be continuously monitored as a means of determining 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, the use of a separate fiber is provided to send a probe signal to the distal end of the shielded fiber array at a different wavelength from the high power signal and monitoring the return signal on the high power fiber optic, fiber integrity can be determined.

These monitoring signals can be transmitted at wavelengths substantially different from the high power signal, so that a selective wavelength filter can be placed in the beam path at the top of the well or the bottom of the well to direct monitoring signals within the equipment for analysis. For example, this selective filter can be placed in the cage or the coil described in the present description.

To facilitate such monitoring, an Optical Spectrum Analyzer or an 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 base of 90 dBm @ 10 Hz, -40 dBm @ 1 MHz; a dynamic range of 70 dB at a resolution of 1 nm; and a maximum sweep depth: 1200 nm and an Anaritsu CMA 4500 OTDR can be used.

The efficiency of the laser cutting action can also be determined by monitoring the ratio of light emitted to reflected light. Materials that undergo melting, chipping, thermal dissociation, or vaporization reflect and absorb different proportions of light. The ratio of light emitted to reflected can be varied by the material which additionally allows material type analysis by this method. Therefore, by monitoring the ratio of light emitted to reflected of the type of material, the cutting efficiency, or both, can be determined. This monitoring can be done at the top of the well, at the bottom of the well, or a combination of these.

Additionally, for a variety of purposes, such as powering downhole monitoring equipment, electrical power generation may occur in the drill hole including at or near the bottom of the drill hole. This generation of power can occur using equipment known to those of skill in the art, including generators driven by drilling mud or other downhole fluids, means of converting optical power to electrical, and means of converting power. thermal in electrical.

The downhole assembly contains the laser optics, the fluid supply medium, and other equipment. In general, the downhole assembly contains the outlet end, also referred to as the distal end, of the high power laser beam transmission medium over long distances and preferably the optics to direct the laser beam to the ground or rock at be removed to advance the drill hole, or other structure to be cut.

The present systems, and in particular the downhole assembly, may include one or more optical manipulators. An optical manipulator can generally control a laser beam, such as directing or positioning the laser beam to chip the material, such as rock. For example, the spatial distance from a wall of the drill hole or rock can be controlled, as well as the angle of impact. In some configurations, one or more drivable optical manipulators can control the direction and spatial width of the one or more laser beams by one or more reflective mirrors or reflective crystals. In other configurations, the optical manipulator can be driven by an electro-optical switch, electroactive polymers, galvanometers, piezoelectrics, and / or rotary / linear motors. In at least one configuration, an infrared diode laser or fiber laser optical head can generally rotate about a vertical axis to increase the opening contact length. Various values ​​that can be programmed, such as specific energy, specific power, pulse rate, duration and the like can be implemented as a function of time. Therefore, where the energy is applied can be strategically determined, programmed and executed in a way that improves a penetration index and / or laser / rock interaction, to improve the general efficiency of the advancement of the drilling well, and to improve the overall drilling well completion efficiency, including reducing the number of steps in the critical path to complete the drilling well. One or more algorithms can be used to control the optical manipulator.

Accordingly, by way of example, the downhole assembly comprising an upper part 9000 and a lower part 9001 is illustrated in Figure 8. The upper part 9000 may be connected to the lower end of the wound pipe, drill pipe or other means to lower and retrieve the downhole assembly from the drill hole. Additionally, it can 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 wound pipe, the drill pipe and other means. to lower and retrieve the downhole assembly from the drill hole. The upper part 9000 additionally contains the medium 9002 which transmitted the high power energy down the drill hole and the lower end 9003 of the medium. In Figure 8, this medium is shown as a set of four optical cables. Top 9000 can also have 9005 air amplification nozzles that discharge up to 100% of the fluid, for example N₂. The upper part 9000 is attached to the lower part 9001 with a sealed chamber 9004 that is transparent to the laser beam and forms a pupil plane for the optics that make up the 9006 beam on the lower 9001. The lower part 9001 may be designed to rotate and thus, for example, an elliptical shaped laser beam spot can be rotated around the bottom of the drill hole. The bottom 9001 has a laminar flow outlet 9007 for the fluid and two hardened rollers 9008, 9009 at its lower end, although non-laminar flows and turbulent flows can be used.

During use, the high energy laser beam, for example, greater than 10 kW, could travel down the 9002 fibers, exit the ends of the 9003 fibers, and travel through the sealed chamber and the 9004 pupil plane within of optics 9006, where it could be shaped and focused on an elliptical point. The laser beam could then strike the bottom of the drill hole by chipping, melting, thermally dissociating and / or vaporizing the rock and striking the rock and thereby advancing the drill hole. Bottom 9001 could be rotatable, and this rotation could cause the elliptical laser spot to rotate around the bottom of the drill hole. This rotation could also cause rollers 9008, 9009 to physically displace any material that was crystallized by the laser or otherwise fixed sufficiently to not have the ability to be removed by fluid flow alone. The cuts could be removed from the laser path by the laminar flow of the fluid, as well as by the action of the rollers 9008, 9009 and the cuts could then be transported up the drill hole by the action of the fluid from the amplifier of air 9005, as well as laminar flow opening 9007.

In general, the LBHA may contain an outer housing that has the ability to withstand the conditions of a downhole environment, a source of a high power laser beam, or optics for shaping and directing a laser beam onto desired surfaces. of the drilling, casing or formation well. The high power laser beam can 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 additionally contain or be associated with a system for supplying and directing the fluid to the desired location in the drill hole, a system for reducing or controlling or handling debris in the path of the laser beam to the material surface, a medium 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 used in conventional mechanical drilling operations. Additionally, the LBHA may incorporate a means to allow the optics to shape and propagate the beam, which, for example, could include a means to control the refractive index of the environment through which the laser propagates. Accordingly, as used in the present disclosure, thermal control and handling elements are understood to be used in their broadest sense and could include active and passive measures, as well as design choices and material choices.

The LBHA must be formed to withstand the conditions encountered in drill holes that include drill holes that have depths of approximately 1,640 feet (0.5 km) or more, approximately 3,280 feet (1 km) or more, approximately 9,830 feet (3 km) or more, approximately 16,400 feet (5 km) or more, and up to and including approximately 22,970 feet (7 km) or more. Although drilling, i.e. drilling well advancement is occurring at the desired location in the drilling hole, dust, drilling fluid and / or cuts may be present. Therefore, the LBHA must be constructed of materials that can withstand these pressures, temperatures, flows, and conditions, and protect the laser optics that are contained in the LBHA. Additionally, the LBHA must be designed and built to withstand downhole temperatures, pressures and flows, and conditions while managing the adverse effects of conditions on the operation of the laser optics and the supply of the laser beam.

The LBHA must also be built to handle and supply high power laser energy at these depths and under the extreme conditions present in these deep downhole environments. Accordingly, the LBHA and its laser optics must be capable of handling and supplying lasers having energies of 1 kW or more, 5 kW or more, 10 kW or more, and 20 kW or more. This assembly and optics must also have the ability to supply such lasers at depths of approximately 1,640 feet (0.5 km) or more, approximately 3,280 feet (1 km) or more, approximately 9,830 feet (3 km) or more, approximately 16,400 feet (5 km) or more, and up to and including approximately 22,970 feet (7 km) or more.

The LBHA must also have the ability to operate in these extreme downhole environments for extended periods of time. The descent and elevation of a downhole assembly has been termed an inbound trip and an outbound trip. Although the downhole assembly has an inlet and outlet travel to the drill hole it is not being advanced. Accordingly, by reducing the number of times the downhole assembly needs to travel inward and outward, it will reduce the critical path to advance the drill hole, i.e., drilling the well, and therefore reduce the cost of such drilling. (As used in this description, the critical path refers to the minimum number of steps that must be performed in series to complete the well.) These cost savings are equal to an increase in the efficiency of the drilling index. Therefore, reducing the number of times the downhole assembly needs to be removed from the drill hole directly corresponds to the reductions in the time it takes to drill the hole and the cost of drilling. Additionally, since most drilling activities are based on daily rates for drill rigs, reducing the number of days to complete a drill hole will provide a substantial business benefit. Accordingly, the LBHA and its laser optics must be capable of handling and supplying lasers having energies of 1 kW or more, 5 kW or more, 10 kW or more, and 20 kW or more at depths of approximately 1,640 feet ( 0.5 km) or more, approximately 3,280 feet (1 km) or more, approximately 9,830 feet (3 km) or more, approximately 16,400 feet (5 km) or more, and up to and including approximately 22,970 feet (7 km) or more, for at least about 1/2 hour or more, at least about 1 hour 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 greater than any other limiting factor in the progress of a drilling well. In this way, using the LBHA of the present invention, unique travel activities could be reduced to those related to the liner and activities to complete it, greatly reducing the cost for well drilling.

Therefore, in general, the cut removal system can be typical of that used in an oil drilling system. This could include, by way of example, a shale shaker. Additionally, you can use sand centrifuges and sediment centrifuges and then centrifuges. The purpose of this kit is to remove the cuts so that the fluid can be circulated again and used again. If the fluid, ie the circulation medium is gas, then a water vaporization system can also be employed.

Figure 9 provides an illustration of an example of an LBHA configuration with two fluid outlet ports shown in the figure. This example employs the use of fluid amplifiers, and in particular, for this illustration, the air amplifier techniques for removing material from the drill hole. Accordingly, a section of an LBHA 9101 is provided, having a first exit port 9103, and a second exit port 9105. The second outlet port as configured provides a means of amplifying air, or a means of fluid amplification. The first 9103 output port also provides an opening for the laser beam and laser path. A first fluid flow path 9107 and a second fluid flow path 9109 are provided. Additionally, there is a boundary layer 9111 associated with the second fluid flow path 9109. The distance between the first outlet 9103 and the bottom of drill hole 9112 is shown by distance y, and the distance between the second outlet port 9105 and the side wall of drill hole 9114 is shown by distance x. having the curvature of the upper side 9115 of the second port 9105 is important to provide the fluid flow to curve around and move up the drill hole. Additionally, having the angle 9116 formed by the angled surface 9117 of the underside 9119, is similarly important in having the boundary layer 9111 associated with the fluid flow 9109. Accordingly, the second flow path 9109 is responsible in a manner main to move the waste material up and out of the drill hole. The first flow path 9117 is primarily responsible for keeping the optical path optically open to debris and reducing debris in that path and additionally responsible for moving waste material from the area below the LBHA to its sides and a point where it can be transported out of the drill hole via second flow 9105.

The ratio of flow rates between the first and second flow paths is currently considered to be approximately 100% for the first flow path, 1: 1, 1:10, to 1: 100. Additionally, the use of fluid amplifiers is exemplary and it should be understood that an LBHA, or laser drilling in general, can be used without such amplifiers. Additionally, fluid jets, air knives, or general fluid direction means can be used in association with the LBHA, in conjunction with amplifiers, or in place of amplifiers. A further example of an use of amplifiers could be to place the locations of the amplifier where the diameter of the drill hole changes or the area of ​​the ring formed by the pipe and the change of the drill hole, such as the connection between the LBHA and the pipe . Additionally, any number of amplifiers, air jets or blades, or similar fluid direction devices can be used, therefore said devices cannot be used, a pair of said devices can be used, and a plurality of said devices can be used. you can use, and you can use the combination of these devices. Cuts or debris that are created by the laser (and the interaction of mechanical laser media) have terminal velocities that must be overcome by the flow of fluid up the drill hole to remove them from the drill hole. Therefore, for example, if the cuts 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, waste of basalt from about 3 m / sec to 8 msec., and for limestone waste less than 1 m / sec, these terminal speeds may have to be exceeded.

An example of an LBHA is provided in Figure 10. Accordingly, a portion of an LBHA 100 is shown, having a first port 103 and a second port 105. In this configuration, the second port 105, compared to the example configuration in Figure 3, moves downward to the LBHA fund. The second port is provided for a flow path 109 that can be seen to have two paths; an essentially horizontal path 113 and a vertical path 111. There is also a flow path 107, which is primarily to keep the laser path optically clear of debris. Flow paths 113 and 107 combine to become part of path 111.

In Figure 12, an example of a rotary outlet port is provided that may be part of or be associated with an LBHA, or be employed in laser drilling. Accordingly, a port 1201 is provided having an opening 1203. The port rotates in the direction of arrows 1205. The fluid is then ejected from the port in two different angularly directed flow paths. Both flow paths have are in the direction of rotation. Accordingly, a first flow path 1207 and a second flow path 1209 are provided. The first flow path has an angle "a with respect to and relative to the outlet rotation. The second flow path has an angle "b" with respect to and relative to the rotation of the outlet. In this way, the fluid can act as a blade or propeller and aid in material removal.

The illustrative outlet port of Figure 12 may be configured to provide flows 1207 and 1209 to be in the opposite direction of rotation, the outlet may be configured to provide flow 1207 in the direction of rotation and flow 1209 in one direction. opposite of rotation. Additionally, the outlet can be configured to provide the flow angles a and b, which are the same or different, whose flow angles can vary from 90 ° to almost 0^or, and can be within the ranges from about 80 ° to 10 °, about 70 ° to 20 °, about 60 ° to 30 °, and about 50 ° to 40 °, including variations of these where “a” is a different angle and / or direction than "b".

In Figure 13, an example of an air knife configuration that is associated with an LBHA is provided. Accordingly, an air knife 1301 is provided which is associated with an LBHA 1313. In this way, the air knife and its related fluid flow can be directed in a predetermined manner, both with respect to angle and location of the flow. Additionally, in the additional air knives, other fluid directing and supplying devices can be employed, such as fluid jets.

To further illustrate the advantages, uses, operating parameters and applications of the present invention, by way of example and without limitation, the following suggested example studies are proposed.

EXAMPLE 1

Test exposure times of 0.05 s, 0.1 s, 0.2 s, and 0.5 s and 1 s will be used for granite and limestone. The power density will be varied by changing the diameter of the ray point (circular) and the elliptical area of ​​12.5 mm x 0.5 mm will be used with an average power-time of 0.5 kW, 1.6 kW, 3 kW, 5 kW. In addition to the continuous wave beam, pulse power will also be tested for chipping areas.

<td colspan="2">Experimental setup</td>

<td>Fiber laser</td><td>IPG Photonics 5kW Multi-Shielded Fiber Laser Mixed With Ytterbium</td>

<td>Dolomite / Barre granite</td><td>30.48 cm x 30.48 cm x 12.7 cm oy 12.7 cm x 12.7 cm x 12.7 cm</td>

<td>Rock size</td><td></td>

<td>Limestone</td><td>30.48 cm x 30.48 cm x 12.7 cm oy 12.7 cm x 12.7 cm x 12.7 cm</td>

<td>Beam spot size (or diameter)</td><td>0.3585, 0.0625 ”(12.5mm, 0.5mm), 0.1 ",</td>

<td>Exposure times</td><td>0.05s, 0.1s, 0.2s, 0.5s, 1s</td>

<td>Time - average power</td><td>0.25 kW, 0.5 kW, 1.6 kW, 3 kW, 5 kW</td>

<td>Pulse</td><td>0.5 J / pulse at 20 J / pulse at 40 to 600 1 / s</td>

EXAMPLE 2

<td colspan="2">The general parameters of Example 1 will be repeated using the experimental configuration of sandstone and shale</td>

<td>Fiber laser</td><td>IPG Photonics 5kW Multi-Shielded Fiber Laser Mixed With Ytterbium</td>

<td>Gray (or yellow) berea sandstone</td><td>30.48 cm x 30.48 cm x 12.7 cm and 12.7 cm x 12.7 cm x 12.7 cm</td>

<td>Shale</td><td>30.48 cm x 30.48 cm x 12.7 cm and 12.7 cm x 12.7 cm x 12.7 cm</td>

<td>Lightning type</td><td>CW / collimated</td>

<td></td><td></td>

<td>Beam spot size (or diameter)</td><td>0.0625 "(12.5mm, 0.5mm), 0.1",</td>

<td>Power</td><td>0.25 kW, 0.5 kW, 1.6 kW, 3 kW, 5 kW</td>

<td>Exposure times</td><td>1 s, 0.5 s, 0.1 s</td>

<td></td><td></td>

EXAMPLE 3

The ability to chip a rectangular block of material, such as a rock, will be demonstrated in accordance with the systems and methods of the present description. The configuration is presented in the table below, and the end of the rock block will be used as a flange. The granite, sandstone, limestone and shale blocks (if possible) will each be chipped at an angle to the end of the block (chipping the rock around the ledge). The beam point will then move consecutively to other parts of the newly created rim of the chipped rock to separate an upper surface of the rim at the end of the block. The objective will be to chop rock particles of approximately 2.54 cm x 2.54 cm x 2.54 cm. The applied SP and SE will be selected based on the chipping data previously recorded and the information collected from Experiments 1 and 2 presented above. Rock Chipping ROP, rock chipping ability to desired specifications will be determined and demonstrated.

<td colspan="2">Experimental setup</td>

<td>Permanent:</td><td></td>

<td>Fiber laser</td><td>IPG Photonics 5kV \ Z Multiple Shielding Fiber Laser Mixed With Ytterbium</td>

<td>Dolomite / granite bar Rock size</td><td>30.48 cm x 30.48 cm x 30.48 cm and 30.48 cm x 30.48 cm x 60.96 cm</td>

<td>Limestone</td><td>30.48 cm x 30.48 cm x 30.48 cm and 30.48 cm x 30.48 cm x 60.96 cm</td>

<td>Gray (or yellow) berea sandstone</td><td>30.48 cm x 30.48 cm x 30.48 cm and 30.48 cm x 30.48 cm x 60.96 cm</td>

<td>Shale</td><td>30.48 cm x 30.48 cm x 12.7 cm and 12.7 cm x 12.7 cm x 12.7 cm</td>

<td>Lightning type</td><td>CW / collimated and pulsed in chipping areas</td>

<td>Specific power</td><td>Chipping Zones (920 W / cm2 at ~ 2.6 kJ / cc for sandstone and 4kW / cm2 at ~ 0.52 kJ / cc for limestone</td>

<td>Lightning size</td><td>12.5mm x 0.5mm</td>

<td>Exposure times</td><td>See Experiments 1 and 2</td>

<td>Purge</td><td>189 l / min nitrogen flow</td>

EXAMPLE 4

Multi-ray chopping will be demonstrated. Overlapping chipping in the material, such as rock, will be tested as a result of two separate laser beams. Two laser beams will be used at two distances of 0.508 cm,

1.27 cm, and 3.81 cm apart, as outlined in the experimental setup below. Each of granite, sandstone, limestone and shale will be used. Rock fractures will be tested by chipping on the chipping zone parameters, determined for each material. The purge gas will be determined. Rock fractures overlap with separate pitted pieces of rock. The objective will be to produce pieces of rock of the desired size 2.54 cm x 2.54 cm x 2.54 cm. The rock will be minced from two rays at a separate distance that will determine the optimal particle sizes that can be effectively mined, providing information on the particle sizes to chip and ROP for optimization.

<td colspan="2">Experimental setup</td>

<td></td><td></td>

<td>Fiber laser</td><td>IPG Photonics 5kW Multi-Shielded Fiber Laser Mixed With Ytterbium</td>

<td>Dolomite / granite bar Rock size</td><td>12.5 cm x 12.5 cm x 12.5 cm</td>

<td>Limestone</td><td>12.5 cm x 12.5 cm x 12.5 cm</td>

<td>Gray (or yellow) berea sandstone</td><td>12.5 cm x 12.5 cm x 12.5 cm</td>

<td>Shale</td><td>12.5 cm x 12.5 cm x 12.5 cm</td>

<td>Lightning type</td><td>CW / collimated or pulsed in chipping areas</td>

<td>Specific power</td><td>Chipping zones (920 W / cm2 at ~ 2.6 kJ / cc for sandstone and 4kW / cm2 at - 0.52 kJ / cc for limestone</td>

<td>Lightning size</td><td>12.5mm x 0.5mm</td>

<td>Exposure times</td><td>See Experiments 1 and 2</td>

<td>Purge</td><td>189 l / min nitrogen flow</td>

<td></td><td></td>

<td>Distance between two laser beams</td><td>0.508 cm, 1.27 cm, and 3.81 cm</td>

EXAMPLE 5

Multi-point chipping with multiple rays will be performed to demonstrate the ability to tear material, such as rock, into a pattern. Various patterns on different types of rock will be evaluated using the parameters below. Patterns using a linear point of approximately 1 cm x 15.24 cm, an elliptical point with a main axis of approximately 15.24 cm and a minor axis of approximately 1 cm, a single circular point having a diameter of 1 cm, a set of points that have a diameter of 1 cm with the separation between the points being approximately equal to the diameter of points, the set has 4 points separated in a square, separated along a line. The laser beam will be delivered to the rock surface in a firing sequence pattern, where the laser is fired until chipping occurs and then the laser is directed to the next shot in the pattern and then fired until chipping, repeating this procedure. In the motion of linear and elliptical patterns, the points are indeed rotated around their central axes. In the pattern that comprises the set of points, the points can rotate around their central axis, and rotate around an axis point like in the hands of a clock that moves around a dial.

<td colspan="2">Experimental setup</td>

<td></td><td></td>

<td>Fiber laser</td><td>IPG Photonics 5kW Multi-Shielded Fiber Laser Mixed With Ytterbium</td>

<td>Dolomite / granite bar Rock size</td><td>30.48 cm x 30.48 cm x 30.48 cm and 30.48 cm x 13.48 cm x 12.7 cm</td>

<td>Limestone</td><td>30.48 cm x 30.48 cm x 30.48 cm and 30.48 cm x 13.48 cm x 12.7 cm</td>

<td>Gray (or yellow) berea sandstone</td><td>30.48 cm x 30.48 cm x 30.48 cm and 30.48 cm x 13.48 cm x 12.7 cm</td>

<td>Shale</td><td>30.48 cm x 30.48 cm x 30.48 cm and 30.48 cm x 13.48 cm x 12.7 cm</td>

<td>Lightning type</td><td>CW / collimated or pulsed in chipping areas</td>

<td>Specific power</td><td>Chipping Zones {920 W / cm2 at ~ 2.6 kJ / cc for sandstone and 4kW / cm2 at ~ 0.52 kJ / cc for limestone)</td>

<td>Lightning size</td><td>12.5mm x 0.5mm</td>

<td>Exposure times</td><td>See Experiments 1 and 2</td>

<td>Purge</td><td>189 l / min nitrogen flow</td>

From the examples above and the teachings detailed therein, it can be seen that in general one or more lasers can chip, chop, vaporize, or melt material, such as rock, in a pattern that uses an optical manipulator. Consequently, the rock can be cut into a pattern by chipping to form rock fractures that surround a segment of the rock to bite that piece of rock. The spot size of the laser beam can chip, vaporize, or melt rock at an angle when interacting with rock at high power. Additionally, the optical manipulator system can control two or more laser beams to converge at an angle, so that it is close to a point near a selected piece of rock as a target. Chipping can then form rock fractures that overlap and surround the target rock to pit the target rock and allow removal of larger pieces of rock, incrementally. Consequently, laser energy can bite a piece of rock up to 2.54 cm deep and 2.54 cm wide or larger. Of course, larger or smaller pieces of rock can be pitted depending on factors such as the type of rock formation and the strategic determination of the most efficient technique.

Illustrative examples and simplified drawings of potential drilling scenarios are provided using the laser drilling systems and apparatus of the present invention.

DRILLING PLAN EXAMPLE 1

<td></td><td>Depth</td><td>Rock type</td><td>Drilling Type / Downhole Laser Power</td>

<td>44.45 cm well drilling</td><td>Surface - 914.4 meters</td><td>Sand and shale</td><td>Conventional mechanical drilling</td>

<td>Run a 33.97 centimeter liners</td><td>Length 914.4 meters</td><td></td><td></td>

<td>31.11 cm well drilling</td><td>914.4 meters - 2,438 meters</td><td>basalt</td><td>40 kW (minimum)</td>

<td>Run a 24.44 centimeter liner</td><td>Lenght of 2,438 meters</td><td></td><td></td>

<td>21.59 cm well drilling</td><td>2,438 meters - 3,352.8 meters</td><td>Limestone</td><td>Conventional mechanical drilling</td>

<td>Run a 17.78-centimeter liner</td><td>Lenght of 3,352.8 meters</td><td></td><td></td>

<td>Drilling a 15.87-centimeter well</td><td>3,352.8 meters - 4,267.2 meters</td><td>Sandstone</td><td>Conventional mechanical drilling</td>

<td>Run a 12.7 centimeter liner</td><td>Lenght of 914.4 meters</td><td></td><td></td>

EXAMPLE 2 OF DRILLING PLAN

<td></td><td>Depth</td><td>Rock type</td><td>Drilling Type / Downhole Laser Power</td>

<td>44.45 cm well drilling</td><td>Surface 154.2meters</td><td>Sand and shale</td><td>Conventional mechanical drilling</td>

<td>Run a 33.97 centimeter liners</td><td>Length 154.2 meters</td><td></td><td></td>

<td>31.11 cm well drilling</td><td>154.2 meters - 1,219.2 meters</td><td>granite</td><td>40 kW (minimum)</td>

<td>Run a 24.44 centimeter liner</td><td>Lenght of 1,219.2 meters</td><td></td><td></td>

<td>21.59 cm well drilling</td><td>1,219.2 meters - 3,352.8 meters</td><td>basalt</td><td>20 kW (minimum)</td>

<td>Run a 17.78-centimeter liner</td><td>Lenght of 3,352.8 meters</td><td></td><td></td>

<td>Drilling a 15.87-centimeter well</td><td>3,352.8 meters - 4,267.2 meters</td><td>Sandstone</td><td>Conventional mechanical drilling</td>

<td>Run a 12.7 centimeter liner</td><td>Lenght of 914.4 meters</td><td></td><td></td>

Also, one or more laser beams can form a rim out of the material, such as rock, chipping the rock in a pattern. One or more laser beams can chip the rock at an angle to the flange that forms rock fractures surrounding the flange to bite the piece of rock surrounding the flange. Two or more rays can sting the rock to create a rim. Laser beams can chip the rock at an angle to the rim that forms rock fractures surrounding the rim to further pit the rock. Multiple rocks can be chipped simultaneously by more than one laser beam after one or more rock ridges are created to chip the piece of rock around the rim or without a rim by merging two rays close to a point by chipping: additionally , a technique known as kerfing or cutting can be used.

In accordance with the teachings of the present invention, a fiber laser or liquid crystal laser can be optically pumped in a range from 750nm to 2100nm wavelength by an infrared laser diode. A fiber laser or liquid crystal laser can be supported or extended from the downhole infrared laser diode connected by an optical fiber that transmits from the infrared diode laser to the fiber laser or liquid crystal laser at the wavelength of infrared diode laser. The fiber cable can be composed of a material such as silica, PMMA / perfluorinated polymers, hollow-core photonic crystals, or solid-core photonic crystals that are in single or multiple modes. Consequently, the optical fiber can be covered by a coiled tubing or reside on a rigid drill string. Furthermore, light can be transmitted from the infrared diode range from the surface to the fiber laser or liquid crystal laser at the bottom of the well. One or more infrared diode lasers may be on the surface.

A laser can be transported into the well using an elaborate wound pipe conduit or a rigid drill string. A power cable can be provided. A circulation system can also be provided. The circulation system can have a rigid or flexible pipe to send a liquid or gas to the bottom of the well. A second pipe can be used to bring the rock cuts up to the surface. A pipeline can send or transport gas or liquid in the conduit to another pipeline, pipe or conduit. The gas or liquid can create an air knife that removes material, such as rock debris from the laser head. A mouthpiece, such as a Laval mouthpiece may be included. For example, a Laval type nozzle can be attached to the optical head to provide pressurized gas or liquid. The pressurized liquid or gas can be transmitters at the working wavelength of the infrared diode laser or fiber laser light to force the drilling mud away from the laser path. The additional pipe in the conduit can send a liquid at a lower temperature to the bottom of the well than ambient temperature at a depth to cool the laser in the conduit. One or more liquid pumps can be used to return cuttings and debris to the surface, applying upward pressure from the well that draws the non-compressible fluid to the surface.

The drilling mud in the well can be transmitting up to the wavelengths of the visible range, close to IR, and average IR, so that the laser beam has a clear optical path for the rock without being absorbed by the drilling mud.

Additionally, the spectroscopic sample data can be detected and analyzed. Analysis can be conducted simultaneously while drilling from rock heat is being emitted. Spectroscopic samples can be collected using * laser-induced failure derived spectroscopy. Pulse power can be supplied to the rock-laser impact point using the infrared diode laser. Light can be analyzed using a unique wavelength detector attached to the infrared diode laser. For example, alternate Raman light can be measured using a Raman spectrometer. Additionally, for example, a diode laser that can be tuned using a few mode fiber Bragg grid can be implemented to analyze the frequency band of the fluid sample using ytterbium, tulium, neodymium, dysprosium, praseodymium, or erbium as the active medium. In some modalities, the chemometric equation, or the least squares mean fit can be used to analyze the Raman spectrum. The temperature, specific heat, and theoretical diffusion can be determined. In at least one modality, the data can be analyzed by a neural network. The neural network can be updated in real time while drilling is in progress. Updating the diode laser power output from neural network data can optimize drilling performance through the rock formation type.

An apparatus for geo-navigating the well for logging may be included or associated with the drilling system. For example, a magnemometer, 3-axis accelerometer and / or gyroscope can be provided. As raised with respect to the laser, the geonavigation device may be coated, such as with steel, titanium, diamond, or tungsten carbide. The geo-navigation device can be coated together with the laser or independently. In some embodiments, data from the geo-navigation device may direct the downhole movement of the apparatus from a digital signal processor.

A set of high power fiber optics may, for example, hang from an infrared diode laser or downhole fiber laser to transmit power from the laser to the rock formation. In at least one embodiment, the infrared diode laser can be fiber coupled at a wavelength range between 800nm ​​to 1000nm. In some embodiments, the fiber optic head may not be in contact with the drill hole. 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 mode or multiple modes. In some embodiments, the optical fiber can be covered by a coiled or rigid pipe. The optical fiber can be attached to a conduit with a first tube to apply gas or liquid to circulate the cuts. A second tube can supply gas or liquid to, for example, a Laval jet nozzle to clear debris from the laser head. In some embodiments, the ends of the optical fibers are covered in a head composed of a directional optical manipulator and mirrors or a glass reflector. The head covering may be composed of sapphire or a related material. An optical manipulator can be provided to rotate the fiber optic head. In some embodiments, the infrared diode laser can be completely coated by steel, titanium, diamond, or tungsten carbide that resides on the optical fibers in the drill hole. In other modalities, it can be partially covered.

Single or multiple fiber optic cables can be tuned to wavelengths close to IR, medium IR or far from IR, received from the material's infrared diode laser induction, such as rock for derivative spectroscopy sampling. A second optical head powered by the infrared diode laser on the optical drill head can cover the formation liner. The second optical head can be extended from the infrared diode laser with the light being transmitted through an optical fiber. In some configurations, the optical fiber can be protected by the wound pipe. The infrared diode laser optical head can pierce the steel and concrete coating. In at least one embodiment, a second infrared diode laser on top of the first infrared diode laser can cover the formation liner while drilling.

According to one or more configurations, a fiber laser or an infrared diode laser can transmit coherent light down a hollow tube without the light coming into contact with the tube when it is placed at the bottom of the well. The hollow tube can be made of any material. In some configurations, the hollow tube may be made of steel, titanium, or silica. A mirror or reflective glass can be placed at the end of the hollow tube to direct collimated light to the material, such as a rock surface that is being drilled. In some embodiments, the optical manipulator can be operated by an electro-optical switch, electroactive polymers. Galvonometers, piezo-electric or rotary / linear motors. A circulation system can be used to raise the cuts. One or more liquid pumps can be used to return cuttings to the surface by applying pressure to the top of the wellbore, withdrawing the fluid that cannot be compressed to the surface. In some configurations, the fiber optic can be attached to a conduit with two tubes, one to apply gas or liquid to circulate the cuts and one to supply grease or liquid to a Laval jet nozzle to clear debris from the laser head.

In a further embodiment of the present invention, a drilling rig is provided to make a drill hole in the ground at a depth of from about 1 km to about 5 km or greater, the kit comprises an assembly carrying a shielded optical fiber, 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 drill hole, and it has a means for winding and unwinding the assembly while maintaining an optical connection with a laser source. In still a further embodiment of the present invention, a method is provided for unlocking the assembly and supplying the laser beam to a point in the drill hole, and in particular, to a point at or near the bottom of the drill hole. Additionally, a method is provided to advance the drill hole to depths that

100 they exceed 1 km, 2 km up to and including 5 km, in part by supplying the laser beam to the drill hole through the shielded fiber optic supply assembly.

The novel and innovative armored assemblies and associated winding and unwinding apparatus and methods of the present invention, the assemblies of which may be a single fiber or a plurality of fibers as set forth in the present disclosure, may be used with the equipment and apparatus. drilling to drill, complete and related and associated operations. The apparatus and methods of the present invention can be used with drilling apparatus and equipment, such as field exploration and development activities. Accordingly, these can be used with, by way of example and without limitation, land-based equipment, mobile land-based equipment, fixed tower equipment, barge equipment, drilling vessels, survey rigs, and semi-submersible equipment. These can be used in operations to advance the well, complete the well, and work activities, including drilling the production deck. These can additionally be used in window cutting and pipe cutting and in any application where supplying the laser beam to a location, apparatus or components that is located deep in the well. Where they can be beneficial or useful.

Accordingly, by way of example, an LBHA is illustrated in Figures 14A and 14B, which are collectively referred to as the

101 Figure 14. An LBHA 14100 will be provided, which has a top 1400 and a bottom 1401. Top 1400 has a housing 1418 and bottom 1401 has a housing 1419. The LBHA 14100, Top 1400, Bottom 1401, and in particular Housings 1418, 1419 must be constructed of materials and structurally designed to withstand the extreme conditions of the deep downhole environment and protect any components that are contained within them.

Top 1400 may be connected to the bottom end of wound pipe, drill pipe, or other means to lower and retrieve LBHA 14100 from the drill hole. Additionally, it can 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 wound pipe, drill pipe, or other means for lowering and retrieving LBHA 14100 from the drill hole. Top 1400 additionally contains, is connected to, or is optically associated with media 1402 which is transmitted to the low power laser beam at the bottom of the drill hole so that the beam exits the end bottom 1403 of medium 1402 and ultimately exits LBHA 14100 to hit the intended surface of the drill hole. The beam path of the high power laser beam is shown by arrow 1415. In Figure 14, medium 1402 is shown as an optical fiber

102 only. Top 1400 may also have amplification nozzles 1405 that discharge drilling fluid, for example, N₂, among other things to assist in the removal of cuttings up the drill hole.

Top 1400 is additionally attached to, connected to, or otherwise associated with a means for providing rotational motion 1410. Such means, for example, could be a downhole motor, an electric motor, or a mud motor. The motor may be connected by means of a shaft, drive shaft, drive train, gear, or other such means to transfer rotational motion 1411, to the bottom 1401 of the LBHA 14100. It should be understood, as shown in the drawings for illustrative purposes, the underlying apparatus, that a protective motor housing or cover may be placed on or otherwise associated with the driving means and the motor to protect it from debris and conditions. rough at the bottom of the well. In this way, the engine could allow the bottom 1401 of the LBHA 14100 to rotate. An example of a mud motor is the CAVO mud motor with a diameter of 1.7 ”(4.31 cm). This engine is approximately 2.13 meters long and has the following specifications: 7 horsepower @ 15.20 kgf.m of full torque; engine speed 0-700 rpm; the motor can run in mud, air, N₂, steam or foam; 180 SCFM, 35.15 kg / cm² manometric-56.24 kg / cm² drop manometers; the support team extends to a length of 3.65 meters; 10: 1 gear ratio provides 0-70 rpm capacity; and has

103 the ability to rotate the bottom 1401 of the LBHA through potential jam conditions.

The upper part 1400 of the LBHA 14100 is attached to the lower part 1401 with a sealed chamber 1404 which is transparent to the laser beam and forms a pupil plane 1420 to allow unobstructed transmission of the laser beam to the beam shaping optic 1406 in the bottom 1401. Bottom 1401 is designed to rotate. Sealed chamber 1404 is in fluid communication with lower chamber 1401 through port 1414. Port 1414 may be a one-way valve that allows clean fluid transmission and preferably gas to flow from top 1400 to bottom 1401, although it does not allow reverse flow, or it may be another type of valve. pressure and / or flow regulation that meets the particular flow and flow distribution requirements desired in the downhole environment. Accordingly, for example, there is provided in FIG. 14, a first fluid flow path, shown by arrows 1416, and a second fluid flow path, shown by arrows 1417. In the example of FIG. 14, the second fluid flow path is a laminar flow, although other flows including turbulent flows can be employed.

Bottom part 1401 has a means for receiving rotary force from motor 1410, which, in the example of the figure is a gear 1412 located around the bottom housing 1419 and a drive gear 1413 located at the bottom end of the shaft 1411. It can

104 use other means to transfer rotary power or the motor can be placed directly on the bottom. It should be understood that an equivalent apparatus may be employed, which is provided for rotation of the LBHA portion to facilitate rotation or movement of the laser beam spot, while at the same time not providing undue rotation, or twisting forces. , to the fiber optic or other means that transmit the high power laser beam down the well to the LBHA. In this way, the laser beam spot can be rotated around the bottom of the drill hole. Bottom 1401 has laminar flow outlet 1407 for fluid to exit LBHA 14100, and two hardened rollers 1408, 1409 at its bottom end. Although laminar flow is contemplated in this example, it should be understood that non-laminar flows and turbulent flows can also be employed.

The two hardened rollers can be made of 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. These can vary in length, that is, from about 2.54 centimeters to about 10.16 centimeters and are preferably approximately 5.08 to 7.62 cm and can be as large as or greater than 15.24 cm. Additionally, in LBHAs for drill holes with a diameter of

105 Major perforation, these may be within the range of 25.4 to 50.8 inches in diameter or larger.

Accordingly, Figure 14 provides a high power laser beam path 1415 entering LBHA 14100, traveling through laser dot shaping optics 1406, and then exiting LBHA to strike its intended target on the surface of a drilling well. Additionally, although not required, the optics that make up the beam spot can also provide a rotating element to the spot, and if so, could be considered to be the spinning beam and the shaping point optics.

During use, the high energy laser beam, for example, greater than 15 kW could enter the LBHA 14100, travel under the 1402 fiber, exit through the end of the 1403 fiber and travel through the sealed chamber 1404 and the plane Pupil 1420 within optics 1406, where it could be shaped and focused within a point, optics 1406 could further rotate the point. The laser beam could then illuminate, in a potentially rotating shape, the bottom of the drill hole that splinters, chops, melts, and / or vaporizes the illuminated rock and earth and consequently advances the drill hole. The lower part could be rotatable and its rotation could additionally cause the rollers 1408, 1409 to physically displace any material that was made by the laser or otherwise fix enough to not have the ability to be removed by the flow of the fluid. drilling alone.

106

The cuts could be cleared from the laser path by fluid flow along path 1417, as well as by the action of rollers 1408, 1409, and the cuts could be hauled up the drill hole by the action of the drilling fluid from the 1405 air amplifiers, as well as the laminar flow opening 1407.

It should be understood that the LBHA configuration of Figure 14 is an example, and that other configurations of its components are available to achieve the same results. Consequently, the motor can be located at the bottom instead of the top, the motor can be located at the top although it only rotates the optics at the bottom and not in the housing. The optics may additionally be located both at the bottom and at the top, the optics for rotation of which is being placed on that part that rotates. The motor may be located at the bottom although it only rotates the optics and the rollers. In this last configuration, the upper and lower parts could be the same, that is, it could be only one part of the LBHA. Therefore, for example, the inner portion of the LBHA can rotate, while the outer portion is stationary or vice versa, likewise, the upper and / or lower portions can rotate or various combinations of rotating or non-rotating components can be used to provide a means for the laser beam spot to be moved around the bottom of the drill hole.

107

Optic 1406 should be selected to avoid or at least minimize power loss as the laser beam travels through it. The optics may additionally be designed to handle the extreme conditions present in the downhole environment, at least to the extent that those conditions are not mitigated by housing 1419. The optics can provide laser beam spots of different power shapes and distributions such as those set forth herein above. The optics may additionally provide a signal point or multiple points as established in the present description above.

Drilling can be conducted in a dry or wet environment. An important factor is that the path from the laser to the rock surface must be kept as clear as practical of debris and dust particles or other material that could interfere with the delivery of the laser beam to the rock surface. The use of high luminosity lasers provides another advantage at the head of the procedure, where long separation distances from the last optic to the workpiece are important to keep the high pressure optic window clear and intact through the procedure. drilling. The beam can be placed either statically or mechanically, optomechanically, electro-optically, electromechanically, or any combination of the above to illuminate the region of the earth of interest.

In general, and as an additional example, the LBHA can

108 comprise a housing, which may, by way of example, be made up of sub-housings. These sub-housings can be integral, can be separated, can be fixedly removable connected, can be rotatable, or can be any combination of one or more of these types of relationships between the sub-housings. The LBHA can be connected to the lower end of the wound pipe, drill pipe, or other means to lower and retrieve the LBHA from the drill hole. Additionally, it can be connected to stabilizers, drill collars, or other types of downhole assemblies, which in turn are connected to the lower end of wound pipe, drill pipe, or other means to lower and retrieve the assembly. from the bottom of the wellbore. The LBHA has associated with it a medium that transmitted the high power energy from the bottom of the drill hole.

LBHA can also be associated with, or in, which means it handles and supplies drilling fluids. These media may be associated with some or all of the sub-housings. Additionally, mechanical scraping means, for example a PDC bit, are provided to remove and / or direct the material in the drill hole, although other types of known bits and / or mechanical drill heads may also be used in conjunction with the laser beam. These scrapers or bits can be mechanically interacted with the surface or parts of the drill hole to loosen, remove, scrape or manipulate said material from the hole

109 drill as needed. These scrapers can be from less than approximately 2.54 cm to approximately 50.8 centimeters. In use, the high energy laser beam, for example, greater than 15 kW, could travel under the fibers through the optics and then exit through the lower end of the LBHA to illuminate the intended portion of the drill hole, or the structure contained therein, splintering, melting and / or vaporizing the material thus illuminated, and in this way advance the drill hole or otherwise facilitate the removal of the material thus illuminated.

In Figures 15A and 15B, a graphical representation of an example of a laser beam - drill hole surface interaction is provided. Accordingly, a laser beam 1500, a beam illumination area 1501, that is, a spot (as used in the present disclosure unless expressly provided otherwise, the term "spot" is not limited to a circle), on a wall or bottom of drill hole 1502. Additionally, Figure 1B provides a more detailed representation of the interaction and a corresponding graph 1510 that categorizes the effort created in the lighting area. Graph 1510 provides the von Mises stress on Om 10⁸N / m² where, cross hatching and shading correspond to the effort that was created in the illuminated area during an illumination period of 30 milliseconds, under downhole conditions of 140.61 kg / cm² and a temperature of 65.55 ° C, with lightning having a creep of 2 kW / cm². Under these conditions, the compression force of basalt is

110 about 2.6 x 10⁸ N / m², and the cohesion force is approximately 0.66 x 10⁸ N / m². Accordingly, a first relatively high stress area 1505 is shown, from approximately 4,722 to 5,211 x 10⁸ N / m², a second area 1506 of stress relative to or exceeding basalt compression stress under downhole conditions, from approximately 2,766 to 3,255 x 10⁸ N / m², a third area 1507 of relative stress approximately equal to the basalt compression stress under downhole conditions, from approximately 2,276 to 2,766 x 10⁸ N / m², a fourth area 1508 of relative lower stress that is below the basalt compression stress under downhole conditions, still greater than the cohesion force from about 2,276 to 2,766 x 10⁸ N / m², and a fifth area 1509 of relative stress that is at or about basalt cohesion strength under downhole conditions, from about 0.320 to about 0.899 x 10⁸ N / m².

Consequently, the beam interaction profiles with the drill hole to obtain a maximum amount of effort in the drill hole in an efficient way, and therefore, the increase in the advancement rate of the drill hole is obtained. Therefore, for example, if an elliptical point is rotated about its center point for a ray that is both uniform and Gaussian, the energy deposition profile is illustrated in Figures 16A and 16B. Where the area of ​​the drill hole from the beam center point is shown as the x and y axes 1601 and 1602 and

111 the amount of energy deposited is shown on the z axis 1603. From this, it is observed that inefficiencies are present in the energy deposition to the drilling well with the external sections of the drilling well 1605 and 1606 being the limiting factor in the rate of progress.

Accordingly, it is desirable to modify the beam deposition profile to obtain a substantially constant and uniform deposition profile from the rotation of the beam. An example of such a preferred beam deposition profile is provided in Figures 17A and 17B, where Figure 17A shows the energy deposition profile without rotation, and Figure 17B shows the energy deposition profile when the 17A beam is rotated through a rotation, ie 360 ​​degrees; which has x and y axes 1701 and 1702 and energy on the z axis 1703. The energy deposition distribution could be considered substantially uniform.

To obtain this preferable beam energy profile, examples of optical assemblies that can be used with an LBHA are provided. Accordingly, an example was illustrated in Figures 18A to 18D, which have x and y axes 1801 and 1802 and z axis 1803, where a laser beam 1805 is provided having a plurality of beams 1807. The 1805 laser beam enters an 1820 optical assembly, which has a 1809 culmination lens, which has an 1811 input curvature and an 1813 output curvature. Additionally, an 1815 axicon lens and an 1817 window are provided. The Example optical assembly 1 could provide a desired beam intensity profile from an input beam having a distribution

112 substantially Gaussian, Gaussian, or super-Gaussian to apply the beam point to a surface of the 1830 drill hole.

A further example was illustrated in Figure 19 and has an optical assembly 1920 to provide the desired beam intensity profile of Figure 17A and energy deposition of Figure 17B to a surface of the drill hole from a laser beam having a uniform distribution. Accordingly, a 1905 laser beam having a uniform profile and 1907 rays entering a spherical lens 1913 are provided in this example, colliding the laser output from the bottom end of the fiber shaft, the beam leaving Then 1913 and enters a 1915 toroidal lens, which has power on the x axis to form the minor axis of the elliptical ray. The beam then leaves 1915 and enters a pair of 1917 spherical toroidal lenses, which have the power on the axis and to map the intensity profiles of the axis and which form the pupil plane for the image plane. The beam then leaves the 1917 lenses and enters a flat 1919 window, which protects the optics from the outside environment.

A further example is illustrated in Figure 20, which provides an additional optical assembly to provide predetermined lightning energy profiles. Accordingly, there is provided a laser beam 205 having beams 207, which enter collimation lenses 209, lenses that form the shape of point 211, which is preferably an ellipse, and a micro-optical assembly 213. Micro-optical assembly 213 may be a micro-prism assembly, or a set of

113 micro-lenses. Additionally, the micro-optical assembly can be specifically designed to provide a predetermined energy deposition profile, such as the profile in Figures 17A and 17B.

A further example is illustrated in Figure 21, which provides an optical assembly to provide a predetermined beam pattern. Accordingly, a laser beam 2105 is provided, which exits the bottom end of the fiber well 2140, having beams 2107, which enter collimation lenses 2109, a diffraction optic 2111, which could be a micro- optics, or a correction optics for a micro optics, which provides the pattern 2120, which may, but not necessarily, pass through the remaining lenses 2113, which provide the pattern 2121.

Additionally, trigger patterns are provided to illuminate a surface of the drill hole, with a plurality of dots in a multiple rotation pattern. Accordingly, in Figure 22 a first pair of dots 2203, 2205 are provided, which illuminate the lower surface 2201 of the peroration well. The first pair of points rotates about a first axis of rotation 2202 in the direction of rotation shown by arrow 2204 (the opposite direction of rotation is also contemplated in the present disclosure). A second para of dots 2207, 2209 are provided, which illuminate the bottom surface 2201 of the drill hole. The second pair of shots rotates around axis 2206 in the direction of rotation shown by arrow 2208 (the opposite direction of

114 rotation is also contemplated in the present description). The distance between the points in each pair of points can be the same or different. The first and second axes of rotation simultaneously rotate around the center of drill hole 2212 in a direction of rotation, shown by arrows 2212, which is preferably in rotation counter to the direction of rotation 2208, 2204. Accordingly, preferably although not necessarily, if 2208 and 2204 are clockwise, then 2212 should be counterclockwise. This firing pattern provides a substantially uniform energy deposition.

In Fig. 23, an elliptical firing pattern of the general type set forth with respect to the previous illustrated examples is illustrated having a center 2301, a major axis 2302, a minor axis 2303 and rotated about the center. In this way, the main axis of the point could generally correspond to the diameter of the drill hole, which varies from any of the known or contemplated diameters, such as approximately 76.2, 50.8, 44.45, 33.97, 31.15, 24.44, 21.59, 17.78 and 15.87. centimeters.

In FIG. 24, a rectangular shaped dot 2401 is illustrated further which could be rotated around the center of the drill hole. In FIG. 25, a pattern 2501 is illustrated having a plurality of individual shots 2502 that can be rotated, analyzed, or moved relative to the drill hole to provide the deposition profile of

115 desired energy. Additionally, Figure 26 illustrates a square shot 2601 that is analyzed 2601 in a scan pattern along the bottom of the drill hole, additionally a circle, square, or other. Shooting way can be explored.

According to one or more aspects, one of the fiber ends distal to the optical fiber can be arranged in a pattern. The multiplexed beam shape can comprise a cross, an x ​​shape, a staff, a rectangle, a hexagon, lines in an array, or a related shape where the lines, squares, and cylinders are connected or separated at different distances.

According to one or more aspects, one or more reflective lenses, diffraction elements, transmission grids and / or reflective lenses can be added to focus, explore and / or change the ray point pattern from the ray points emitting from the fiber optics that are arranged in a pattern. One or more reflective lenses, diffraction elements, transmission grids, and / or reflection lenses can 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 can be placed after the lens shapes the ray point in the transverse optical path plane. The collimator may be on a spherical lens, a spherical lens system composed of a convex lens, coarse convex lenses, negative menisci, and bi-convex lenses, gradient refraction lenses with a spherical profile and achromatic pairs. The

116 collimator can be made from such fused silica materials, ZnSe, SF glass or a related material. The collimator can be coated to reduce or improve the ability to reflect or transmit. Said optical elements can be cooled by means of a liquid or purge gas.

It will be readily understood in the art that the terms lens and optical elements, as used in the present disclosure, are used in their broadest terms and can therefore also refer to any powered optical elements, such as reflective elements, transmitters, or refractors. .

In some respects, positive refractive lenses can be micro-lenses. The micro-lenses can be directed in the plane of light propagation to increase / decrease the focal length, as well as perpendicular to the plane of light propagation to translate the beam. The micro-lenses can receive the incident light to focus on multiple focuses from one or more optical fibers, fiber optic array pairs, fiber laser, diode laser; and receiving and sending light from one or more collimators, positive refractive lenses, negative refractive lenses, one or more mirrors, reflective optical beam expansion devices, and prisms.

In some aspects, a diffraction optical element beam separator could be used in conjunction with a refractive lens. The diffraction optical element beam separator can form double beam spots or a beam spot pattern comprising the shapes and patterns set forth above.

117

Additionally, a system and method for creating a drill hole in the ground is provided, where the system and method employ means to provide the laser beam to the bottom surface at a previously determined energy deposition profile, including that which has three laser beams supplied from the downhole assembly illuminating the bottom surface of the drill hole with a predetermined energy deposition profile, illuminating the underside with any one or combination of: a predetermined energy deposition profile deviated to the outside surface area of ​​the drill hole; a previously determined energy deposition profile deviated towards the interior surface area of ​​the drill hole; 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 firing pattern; a previously determined energy deposition profile based on the mechanical stresses applied by means of a mechanical removal means; a predetermined energy deposition profile having at least two different energy areas and the energies in the areas correspond inversely to the mechanical forces applied by a mechanical means.

Additionally, a method is provided for advancing a drilling well using a laser, the method comprising: making

118 advancing a high power laser beam transmission medium in a drill hole; the drill hole has a bottom surface, a top opening, and a length extending between the bottom surface and the top opening of at least approximately 304.8 meters; the transmission means comprise a distal end, a proximal end, and a length extending between the distal and proximal ends, the distal end being advanced down the drill hole; the transmission means comprise a means for transmitting high power laser energy; providing a high power laser beam to the proximal end of the transmission medium; transmitting substantially all the power of the laser beam down the length of the transmission means such that the beam leaves the distal end; transmitting the laser beam from the distal end to an optical assembly in a bottom assembly of the laser well, the bottom assembly of the laser well directing the laser beam to the bottom surface of the drill hole; and providing a predetermined energy deposition profile to the bottom of the drill hole; whereby the length of the drill hole is increased, in part, based on the interaction of the laser beam with the bottom of the drill hole.

Additionally, a method is provided for advancing a drill hole using a laser, where the laser beam is directed to the bottom surface of the drill hole in a substantially uniform energy deposition profile and thus, the length of the Well of

119 Drilling is increased, in part, based on the interaction of the laser beam with the bottom of the drill hole.

According to one or more aspects, a method for laser drilling is described that uses an optical pattern to bite rock formations. The method may comprise irradiating the rock to chip, melt, or vaporize it with one or more laser beam spots, beam spot patterns, and beam shapes at non-overlapping distances and time patterns to induce thermal rock fractures that They overlap causing rock bite of rock fragments. Single or multiple beam patterns and beam patterns and shapes can be formed by refraction and reflection optics or fiber optics. The optical pattern, the pattern time, and the spatial distance between the non-overlapping ray points and the ray forms, can be controlled by thermal absorption of the rock type at a specific wavelength, relaxation time to place the Optics and interference of rock removal.

In some respects, the power of the laser beam points is either not reduced, moderately reduced or completely reduced during the relaxation time when the beam point is again placed on the rock surface. To bite the rock formation, the two laser beam points can scan the rock surface to separate by a fixed position of less than 5.08 centimeters and which does not overlap in some respects. Each of the two ray points can have a ray point area in the interval between 0.1 cm² and 25 cm². Relaxation times when you

120 move the two laser beam points to their next subsequent laser locations on the rock surface, can range from 0.05 ms to 2 s. When the two laser beam points are moved to their next position, their power may either not be reduced, moderately reduced, or completely reduced during the relaxation time.

According to one or more aspects, the ray spot pattern can comprise three or more ray points in a grid pattern, a rectangular grid pattern, a hexagonal grid pattern, lines in an assembly pattern, a circular pattern , a triangular grid pattern, a cross grid pattern, a star grid pattern, a ball joint grid pattern, a crosshair grid pattern, or a geometrically related grid pattern. In some respects, each laser beam spot in the beam spot pattern has an area within the range of 0.1 cm² and 25 cm². To chip the rock formation all the laser beam points surrounding each laser beam point in the beam point pattern may be less than a fixed position of 5.08 centimeters and does not overlap in one or more respects.

In some respects, more than one ray spot pattern can be used to chip the rock surface. The relaxation times when one or more beam spot patterns are placed for their next subsequent laser location can range from 0.05 ms to 2 s. The power of one or more beam spot patterns can be either reduced, moderately reduced, or completely during the relaxation time. A beam shape can be a continuous optical beam spot that forms a

121 geometric shape comprising a cross shape, hexagonal shape, spiral shape, circular shape, triangle shape, star shape, line shape, rectangular shape, or related continuous lightning dot shape.

In some respects, placing a line either linear or non-linear to one or more surrounding lines either linear or non-linear at a fixed distance less than 5.08 cm and not overlapping, can be used to chop rock formation. Aiming a laser at the rock surface with two or more beam shapes can be used to bite the rock formation. The relaxation times when you move the one or more beam spot shapes to their next subsequent laser location can range from 0.05 ms to 2 s.

According to one or more aspects, the one or more powers of continuous lightning forms are either not reduced, moderately reduced, or completely during the relaxation time. The rock surface can be irradiated by one or more laser beam spot patterns together with one or more beam spot shapes, or one or two beam points with one or more beam spot patterns. In some respects, the maximum diameter and girth of one or more ray shapes and ray spot patterns is the size of the drill hole that is being pitted when drilling the formation to complete the hole.

According to one or more aspects, rock fractures can be created to promote pitting away from the rock segments for efficient drilling of the drill hole. In some

122 Aspects, ray points, shapes, and patterns can be used to create rock fractures in ways that allow multiple rock segments to be pitted. Rock fractures can have strategically designed patterns. In at least some respects, rock formation drilling may comprise the application of one or more non-overlapping ray points, shapes, or patterns to create the rock fractures. The selection of one or more beam points, shapes and patterns can generally be based on the intended application or the desired operating parameters. Average power, specific power, time pattern, ray point size, exposure time, associated specific energy, and elements of the optical generator may be considerations when selecting one or more ray points, a shape or pattern. The material to be drilled, such as a type of rock formation, can also influence the one or more ray points, a shape or a selected pattern to chip the rock formation. For example, the shale will absorb light and convert it to heat at different rates than sandstone.

According to one or more aspects, the rock may have a pattern with one or more ray points. In at least one embodiment, the beam points can be considered one or more beam points moving from one location to the next subsequent location that the laser receives on the rock surface in a time pattern. The beam points can be separated at any desired distance. In some aspects

123 non-limiting, the fixed position between a beam point and the surrounding beam points may be non-overlapping. In at least one non-limiting embodiment, the distance between the surrounding beam points may be less than 5.08 cm.

According to one or more aspects, the rock may have a pattern with one or more lightning forms. In some respects, the beam shapes can be continuous optical shapes that form one or more geometric patterns. A pattern may comprise the geometric shapes of a line, cross, crosshair, head, star, rectangle, hexagon, circular, ellipse, scribbled line, or any other desired shape or pattern. The elements of a ray shape can be separated at any desired distance. In some non-limiting aspects, the fixed position between each linear or non-linear line and the surrounding linear or non-linear lines that are in a fixed position, may be less than 5.08 cm and not overlap.

According to one or more aspects, the rock may have a lightning pattern. Lightning patterns can comprise a grid or ray dot arrangement that can comprise the geometric patterns of a line, cross, crosshair, kneecap, star, rectangle, hexagon, circular, ellipse, scribbled line. The beam points of a beam pattern can be separated by any desired distance. In some non-limiting aspects, the fixed position between each ray point and the surrounding ray points in the ray point pattern may be less than 5.08 cm and not overlap.

124

According to one or more aspects, the ray point being scanned can have any desired area. For example, in some non-limiting aspects, the area may be within a range of about 0.1 cm² and about 25 cm². The beam line, either linear or non-linear, can have any specific desired diameter and any specific and predetermined power distribution. For example, the specific diameter of some non-limiting aspects may be in a range between approximately 0.05 cm² and about 25 cm². In some non-limiting aspects, the maximum length of a line, either linear or non-linear, can generally be the diameter of a drill hole to be drilled. Any desired wavelength can be used. In some respects, for example, the wavelength of one or more ray points, a shape or pattern, can vary from 800nm ​​to 2000nm. Combinations of one or more beam points, shapes, and patterns are possible and can be implemented.

According to one or more aspects, the time and location patterns for rock chipping may vary based on known rock chopping speeds and / or rock removal systems. In one embodiment, the relaxation scan times when one or more beam spot patterns are placed at their next next subsequent laser location can range from 0.05 ms to 2 s. In another embodiment, a camera using fiber optics or spectroscopy techniques can design the image of the height of the rock to determine the areas of rock.

125 beak to be chopped. The time pattern can then be calibrated to peck the highest peaks on the rock surface to the lowest or peaks above a defined height using signal processing, software recognition, and numerical control for the optical lens system. For example, if the fluid is swept from the left side of the rock formation to the right side to clear the optic head and push the cuts up, the schedule will be to rock the rock from left to right to avoid rock removal interference to the one or more laser beam, shape, or pattern points on the rock formation or vice versa. For another example, if the rocks are cleared by a jet nozzle of a gas or liquid, the rock in the center will be chipped first and the rock's chopping direction will then move away from the center. In some respects, the rate of rock removal will define relaxation times.

According to one or more aspects, the rock surface can be affected by the gas or fluids used to clear the mouth and raise the cuts from the bottom of the well. In one embodiment, heat from the optical elements and losses from the downhole optical fibers or laser diode can be used to increase the temperature of the drill hole. This could lower the temperature required to induce chipping that facilitates chipping of rocks. In another embodiment, a liquid can saturate the pitting location, in this situation, the liquid could be converted to vapor and expand rapidly, this rapid expansion could thus create thermal impacts that enhance the growth of

126 fractures in the rock. In another embodiment, organic, volatile, mineral, or other materials subject to rapid and differential heating of laser energy can expand rapidly, this rapid expansion could thus create thermal impacts that enhance the growth of fractures in the rock. In another embodiment, higher refractive index fluids can be sandwiched between two liquid streams with a lower refractive index. The fluids used to clear the rock can act as a wavelength to guide light. A gas with a particular refractive index lower than a fluid or other gas can be used.

By way of example and to further illustrate the teachings of the present invention, thermal impacts can vary from laser powers between one and the other beam point, shape or pattern. In some non-limiting aspects, thermal impacts can reach 10 kW / cm² continuous laser power density. In some non-limiting aspects, thermal impacts can reach up to 10 MW / cm² of laser power density in pulses, for example, at 10 nanoseconds per pulse. In some respects, two or more beam points, shapes, and patterns may have different power levels to thermally impact the rock. In this way, a temperature gradient can form between the laser effect of the rock surface.

By way of example and to further demonstrate the present teachings of the present invention, examples of optical heads are provided, i.e., optical assemblies, and beam firing patterns,

127 that is, lighting patterns, which can be used with, as part of, or provided by an LBHA. Figure 27 illustrates pitting a rock formation using a laser beam pattern. An optical beam-shaped laser pattern 2701 that forms a checkerboard of lines 2702 radiates the surface of rock 2703 from a rock 2704. The distance between the beam point shapes does not overlap due to the stress and heat absorption that causes natural rock fractures to overlap inducing pitting of the rock segments. These 2705 rock segments may detach or explode from the rock formation.

By way of example and to further demonstrate the present teachings, Figure 28 illustrates the removal of rock segments by sweeping the flow of liquid or gas 2801 when a rock formation 2802 is pitted. The rock segments are pitted using a 1606 pattern of non-overlapping lines of dotted shapes 2803, 2804, 2805. The 2807 optical head, optically associated with a fiber optic assembly, the 2807 optical head having an optical element system irradiates the rock surface 2808. A left to right sweep with a flow of gas or liquid 2801 raises 2809 rock fragments pitted by thermal impacts to the surface.

By way of example and to further demonstrate the present teachings, Figure 29 illustrates the removal of rock segments by the directed liquid or gas flow from the optical head when a 2901 rock formation is being bitten. The rock segments are

128 pitted using a 2902 pattern of non-overlapping beam dot lines 2903, 2904, 2905. Optical head 2907 with an optical element system radiates the rock surface 2908. Debris from rock segment 2909 is swept from a nozzle 2915 that flows a gas or liquid 2911 from the center of the rock formation and away. Optical head 2907 is shown attached to a 2920 rotary motor and optical fiber 2924 separated in a pattern. The optical head also has 2928 rails for x-axis movement if needed for focus. Refractive optics and reflection optics form the ray path.

By way of example and to further demonstrate the present teachings, FIG. 30 illustrates optical mirrors that scan a point or shape of laser beam to bite a rock formation in the XY plane. Accordingly, with respect to a coating 3023 in a drill hole, a first rotary motor 3001, a plurality of optical fibers in a pattern 3003, a gimbal 3005, a second rotary motor 3007 and a third rotary motor 3010 are shown . The second rotary motor 3007 having a step motor 3011 and a mirror 3015 associated therewith. The third rotary motor 3010 having a step motor 3013 and a mirror 3017 associated therewith. Optical elements 3019 are optically associated with optical fibers 3003 and have the ability to provide a laser beam along optical path 3021. As the gimbal rotates around the z axis and repositions the mirrors in the XY plane. The

129 Mirrors are attached to a step motor to rotate the step motors and mirrors in the XY plane. In this embodiment, the optical fibers are separated in a pattern that forms three beam points manipulated by optical elements that scan the rock formation at a separate distance and that do not overlap to cause rock bite. Other fiber optic patterns, shapes, or a diode laser can be used.

By way of example and to further demonstrate the present teachings, Figure 31 illustrates a beam splitting lens to form a multi-ray approach to bite a rock formation. Fibers 3101 are shown in a pattern / rail 3105 to provide movement in the z direction shown by arrow 3103, a fiber connector 3107, an optical head 3109, having a beam expansion device 3119, which comprises a DOE / ROE 3115, a 3117 positive lens, a 3113 collimator, a 3111 beam expansion device. This assembly has the ability to deliver one or more laser beams, such as dots 3131 in a pattern, along optical paths 3129 to a rock formation 3123 that has a surface 3125. The optical fibers are separated a far distance by a pattern. An optical element system composed of a beam expansion device and a collimator feeds a diffraction optical element attached to a positive lens to focus multiple beam points at multiple focus. The distance between the points does not overlap and will cause pitting. In this figure, the rails move in

130 the z axis to focus the optical path. The fibers are connected by a connector. Also, an optical element can be attached to each optical fiber, as shown in this figure, to more than one optical fiber.

By way of example and to further demonstrate the present teachings, Figure 32 illustrates the use of a lens to shape the beam spot, to shape a pattern to bite a rock formation. A set of optical fibers 3201 is provided, an optical head 3209. The optical head having a rail 3203 to facilitate movement in the z direction, shown by arrow 3205, a fiber connector 3702, an optical assembly 3201 to form the laser beam that is transmitted by the fibers 3201. The optical head has the ability to transmit a laser beam along optical path 3213 to illuminate a surface 3219 with a laser beam firing pattern 3221 that has separate lines, albeit intersecting in a grid-like pattern. The optical fibers are separated a distance in a pattern connected by a connector. The optical fibers emit a ray point to a ray point shaping lens attached to the optical fiber. The beam spot shaping lens forms a line in this figure that overlaps to form a three-line laser pattern on the rock surface. The cables in the fiber optic bundle are attached to rails that move on the z axis to focus the beam points.

As an example and to further demonstrate the present teachings, Figure 33 illustrates the use of an F-theta objective to focus a laser beam pattern on a rock formation to produce the

131 chopped. An optical head 3301 is provided, a first motor to provide rotation 3303, a plurality of optical fibers 3305, a connector 3307, which places the fibers in a predetermined pattern 3309. The laser beam exits the fibers and travels along of optical path 3311 through F-theta 3315 and illuminates the rock surface 3313 in trigger pattern 3310. Additionally rails 3317 are shown to provide movement in the z direction. The optical fibers connected by the connectors in a pattern are rotated on the x axis by a gimbal attached to the optical coating head. The beam path is then again focused by an F-theta target on the rock formation. The beam points are at a separate and non-overlapping distance to induce rock bite in the rock formation. A rail is attached to the optical fibers and the F-theta objective moves on the z axis to focus the beam spot size.

It should be understood that the rails in these examples to provide movement in the z direction are provided by way of illustration and that movement in the z direction, i.e. movement to or away from the bottom of the drill hole can be obtained by other means, for example, coil winding and unwinding, or up and down the drill string that is used to advance the LBHA into or remove the LBHA from the drill hole.

By way of example and to further demonstrate the present teachings, Figure 34 illustrates mechanical fiber control

132 optics attached to the optics that make up the beam to cause rock bite. An assembly of a plurality of fibers 3401 of the first motor 3405 is provided to provide rotational motion of a power cable 3403, the optical head 3406, and the rails 3407. Additionally, a second motor 3409, a 3413 fiber connector and a 3421 lens for each fiber to form the beam. The laser beams exit the fibers and travel along the optical paths 3415 and illuminate the rock surface 3419 in a plurality of single line shaped firing patterns 3417. The optical fibers are connected by the connectors in a pattern and They are attached to a rotating gimbal motor around the z axis. The rails are attached to the motor that moves on the z axis. The rails are structurally attached to the optical head coating and a support rail. A power cable powers the motors. In this figure, the optical fibers emit a ray point to a lens to form the ray point that forms three non-overlapping lines towards the rock formation to induce pitting.

By way of example and to further demonstrate the present teachings, Figure 35 illustrates the use of a plurality of optical fibers to form a line shaped beam. A 3511 optical assembly is provided having a laser power source 3501, a power cable 3503, a first rotation motor 3505, which is mounted as a gimbal, a second motor 3507, and 3517 rails for directional movement. z. A plurality of fiber bundles are also provided.

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3521, with each set containing a plurality of individual fibers 3523. The sets 3521 are held in a predetermined position by connector 3525. Each set 3521 is optically associated with a beam that makes up the optics 3509. The laser beams leave the optics that make up beam 3509 and travel along optical path 3515 to illuminate surface 3519. Engines 3507, 3505 provide the ability to move the plurality of beam points in a plurality of previously determined and desired patterns on surface 3519, which may be the surface of the drill hole, such as the bottom surface, the surface side, or lining in the drill hole. A plurality of optical fibers, are connected by connectors in a pattern and are attached to a rotating gimbal motor about the z axis. The rails are attached to the motor that moves on the z axis. The rails are structurally attached to the optical head coating and a support rail. A power cable powers the motors. In this figure, the plurality of optical fibers emits a beam point to a beam point shaping lens that forms the three lines that do not overlap with rock formation. Lightning forms induce rock bite.

By way of example and to further demonstrate the present teachings, FIG. 36 illustrates the use of a plurality of optical fibers to form a multi-ray point approach that is rotated about an axis. A 3601 laser source, a first 3603 motor, which is gimbal mounted, a second 3605 motor, and a means for

134 movement in the z direction 3607. A plurality of fiber assemblies 3613 and a connector 3609 are further provided to position the plurality of assemblies 3613, the laser beam exits the fibers and illuminates a surface in a divergent and transverse laser firing pattern. The optical fibers are connected by connectors at an angle that is rotated by a motor attached to a gimbal that is attached to a second motor that moves on the z axis on the rails. The motors are powered by a power cable. The rails are attached to the head of the optical coating and support the lightning rail. In this figure, a collimator sends the beam spot originating from the plurality of optical fibers to a beam splitter. The beam separator is a diffraction optical element that is attached to the positive refractive lens. The beam splitter forms a multiple beam point approach to the rock formation at non-overlapping distances to bite the rock formation. The focus is repositioned on the z axis using the rails.

By way of example and to further demonstrate the present teachings, Figure 11 illustrates scanning of the rock surface with a ray pattern and XY scanning system. An optical path 1101 is provided for a laser beam, a scanner 1103, a diffraction optic 1105, and a collimator optic 1107. A fiber optic emits a beam spot that is expanded by a beam expansion unit and is focused by a collimator on a refractive optical element. The refractive optical element is placed in front of a

135 XY scanner to form a ray spot pattern or shape. The XY scanner consisting of two mirrors controlled by 1109 galvanometer mirrors irradiates the rock surface 1113 to induce pitting.

From the above description, a person skilled in the art can easily discern the essential characteristics of the present invention, and without departing from the spirit and scope thereof, can make various changes and / or modifications of the present invention to adapt it to various uses and conditions.

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