RO121145B1 - Method and equipment for perforating and treating multiple intervals of one or more subterranean formations intersected by a wellbore - Google Patents

Abstract

The invention relates to a method and equipment for perforating and treating multiple intervals of one or more subterranean formations intersected by a wellbore, which are used for the stimulation of multiple formation intervals without the necessity of removing the equipment from the wellbore between steps, meant to increase the production of oil and gas. According to the invention, the method for perforating and treating multiple intervals of one or more subterranean formations intersected by a wellbore consists in :deploying a bottom hole assembly (BHA), using a deployment means within the above mentioned wellbore, said bottomhole assembly (BHA) being provided with a perforating device and a sealing mechanism, followed by positioning said bottomhole assembly within said wellbore so that the low end of the assembly is below the lowest target zone, perforating then the previously established interval and displacing the above mentioned sealing mechanism, so as to establish a hydraulic seal of the target zone in said wellbore. Finally, a treatment fluid is pumped into the wellbore in the perforations created by said perforating device, without removing the equipment from the wellbore. According to the invention, the perforating and treating equipment used for applying said method is provided with a bottomhole assembly (27, BHA) having at least one perforating device (134, 144 and 154) for successively perforating multiple intervals and at least one sealing mechanism (120), capable of establishing a hydraulic sealing so that the treatment intervals should be treated separately.

Description

The invention relates to a method and equipment for drilling and treating multiple intervals, from one or more underground formations, intersected by a wellbore, used to stimulate intervals of multiple formations, without the need to extract the equipment. from the borehole, between steps or floors, designed to increase the production of oil and gas, from these.

if an underground hydrocarbon deposit formation does not have sufficient permeability or flow capacity, for hydrocarbons to flow to the surface, in economical quantities or at optimum flow rates, hydraulic fracturing / cracking or chemical stimulation is often used, acid, usually, to increase the flow capacity. A well hole, which penetrates an underground formation, consists of a metal pipe, the pipe column, cemented in the initial well hole. The holes are placed to penetrate the tubing column and the cement coating, which surrounds the tubing column, to allow hydrocarbons to flow into the wellbore and, if necessary, to allow treatment fluids to flow through the wellbore, into the wellbore. formation.

Hydraulic fracturing consists of injecting fluids, usually non-Newtonian, viscous gels or emulsions, that dilute, in a formation at pressures and flows so high, that the rock of the deposit, the rock of the store, deteriorates and forms a fracture, in a way Typical, vertical, flat, or fracture network, which resembles a crack, which extends through a wooden hub when a breakdown occurs in it. A granular support material, for example, sand, ceramic balls or other materials, is injected with the last part of the fracture fluid, to keep the fracture / fractures open, after the pressure is triggered. The increased flow capacity from the deposit results from an easier flow path, remaining between the granules of supporting material, inside the fracture / fractures. In the chemical stimulation treatments, the flow capacity is improved, by dissolving some materials in the mentioned formation or otherwise modifying the properties of the formation.

The application of hydraulic fracturing, as described above, is a routine part of operations in the oil industry, when applied to target areas, individually, with a total vertical thickness of about 60 m, to the underground formation. When there are stratified or multiple deposits, which need to be hydraulically fractured, or a very thick crude oil bearing formation, over 60 m, then alternative treatment methods are needed to obtain the treatment of the entire target area. In the petroleum industry terminology, methods of improvement, in the field of treatments, are commonly known as deviation methods.

When areas carrying multiple hydrocarbons are stimulated by hydraulic fracturing or chemical stimulation treatments, then the economic and technical benefits are obtained by injecting multiple treatment stages, which can be derived or separated, by various means, including mechanical devices, for example, bridge plugs, packs, sealing systems, probe sole valves, sliding sleeves, baffle / stopper combinations, ball sealing layers, macroparticles, for example, sand, ceramic material, support material, salts, paraffins, resins and other compounds; or by fluid systems, alternatives, for example, viscous fluids, gelled fluids, foams, or other chemically formulated fluids; or using limited input methods. These methods and devices for blocking fluid flow, in or out of a set of perforations, are referred to herein as diverting agents.

In the mechanical point stopper, for example, the deepest interval is first perforated and the fracture is stimulated, then the interval is typically isolated, by means of a cable stopper, and the procedure is repeated in the next interval. . Assuming ten target perforation intervals, treatment in this manner, of 300 m formation, would require ten operations over a period of ten days to two

RO 121145 Β1 weeks, but not only multiple fracture treatments, but also current operations of multiple 1 piercing and bridge stopper. At the end of the treatment procedure, a drill hole cleaning operation will be required to remove the bridge plugs and to put the probe into 3 production. The main advantage of using bridge plugs or other mechanical deflectors is the certainty that the entire target area is subject to treatment. 5 The main disadvantages are the high cost of the treatment, caused by multiple steps in the well hole and outside it, and the risk of complications, which result from 7 such a large number of operations in the well. For example, a bridge stopper can get stuck in the pipe column and the cement must be milled, with high costs. Another 9 disadvantage is that the operation required for cleaning and clearing the well may deteriorate some fractured intervals successfully. 11

An alternative to using bridge plugs is the filling of the portion of the well drill, associated with the newly fractured interval, with fracture sand, commonly referred to as the Pine Island method. The sand column in the well hole effectively blocks / clogs the already fractured interval and allows the next interval to be independently perforated and fractured. The main advantage is to eliminate the problems and risks associated with the deck plugs. The disadvantages are that the sand plug does not provide perfect hydraulic sealing and that it can be easily removed from the wellbore at the end of all fracture stimulations. If the fluid production of the probe is not strong enough, 19 to transport the sand from the wellbore, then the probe may still need to be cleaned / cleared with an intervention facility or assembly of flexible tubes. As before May 21, additional operations at the well hole increase costs, mechanical risks and risks of damage at fractured intervals. 2. 3

Another method of deviation involves the use of materials in the form of macroparticles, solid, granular substances, which are introduced into the treatment fluid, to aid the diversion. When the fluid is pumped and the macroparticles enter the perforations, a temporary block is formed in the area that accepts the fluid, if a sufficiently high concentration of 27 particles is carried out in the flow. Then, the flow restriction lowers the fluid to the other areas. After treatment, the macroparticles are removed by the fluids 29 of the formed formation or by the injected washing fluid, either through the transport of fluid or by dissolution. Typically, the 31 macroparticle diversion materials available, include benzoic acid, naphthalene, sodium chloride, resin materials, paraffins and polymers. Alternatively, as abatement agents, in the form of 33 macroparticles, sand, support material and ceramic materials could be used. Other special macroparticles may be designed to form and precipitate during treatment.

Another method of deviation involves the use of viscous fluids, viscous gels or 37 foams, as diverting agents. This method involves pumping the transverse deflection fluid and / or in the perforated range. These fluid systems are formulated to temporarily obstruct, decrease the viscosity or relative permeability of the formation, and are also designed so that, at the desired time, the fluid system breaks, degrades or dissolves, with or without the addition of chemicals or other additives to trigger such breakage or dissolution, so that the flow can be restored to 43 or from perforations. These fluid systems can be used for diversion, to chemical matrix stimulation treatments or fracture treatments. Some diversion agents and / or 45 ball sealing agents are sometimes incorporated into these fluid systems, in an effort to intensify the deflection. 47

Another possible process is a limited entry deviation, in which the entire target area of the formation to be treated is perforated with a very small number of 49

EN 121145 Β1 perforations, generally of small diameter, so that the loss of pressure, transversely on those perforations, during pumping, promotes an internal pressure, high, in the well hole. The internal pressure of the borehole is set to be high enough to cause all perforated intervals to fracture simultaneously. If the pressure were too low, then only the weakest parts of the formation would fracture. The main advantage of the diversion with limited entry is that there are no obstructions inside the pipe column, such as bridge or sand plugs, which subsequently give rise to problems. The disadvantage is that often, the limited-entry fracture does not work well for thick intervals because, as a result, the resulting fracture is too narrow, the supporting agent cannot be pumped remotely, in the narrow fracture, and remains in the borehole. probe, and the pressure, initially high, in the wellbore, cannot last. When sanding material is pumped, the diameters of the perforations are often rapidly eroded to larger dimensions, which reduce the internal pressure in the wellbore. The net result may be that not all of the target area is stimulated. An additional concern is the possibility that the potential for flow capacity in the wellbore is limited by the small number of perforations.

Some of the problems that arise from the failure to stimulate the entire target area or from the use of mechanical methods, which require drill hole operations and multiple drill hole inputs, which discuss higher risk and higher costs, as described above, they can be relieved by the use of perforated, concentrated, limited intervals, deflected by means of ball-sealing agents. The area to be treated could be divided into subzones with perforations located approximately at the center of each of those subzones or the subzones could be chosen based on an analysis of the formation, at the desired fracture sites of the layer. The fracture floors would then be pumped with diversion agent, with the help of ball-deflecting agents, at the end of each floor. Specifically, a global formation of 300 m could be divided into ten subzones, of about 30 m each. At the center of each 30 m subzone, ten perforations could be executed, with a density of three perforations / meter of pipe column. A fracturing floor would then be pumped with fluid loaded with support material or with several sealing agents, in the form of balls, at least one, for each open bore, in a single set or bore interval. The procedure should be repeated until all the perforations in the perforation set have been fractured. Such a process is described in more detail in US Patent No. 5,890,536, granted April 6, 1999.

All areas to be treated in a particular work, in which ball-shaped sealing materials are used as a deflecting agent, were perforated before pumping the treatment fluids, and the ball-shaped sealing materials were used to divert treatment fluids, from areas already destroyed or taking the highest flow of fluid, compared to other areas that take less fluid or not at all, before releasing ball-shaped sealing materials. Theoretically, the treatment and sealing were carried out zone by zone, depending on the relative permeabilities or pressures, but problems with the balls that were deposited prematurely, on one or more perforations, outside the targeted range, and with two or more frequently appeared. many areas, which were subjected to treatment simultaneously. Moreover, this method assumes that each perforation interval or subzone is destroyed or fractured at a quite different pressure, so that only one set of perforations will enter each treatment stage.

The main advantages of ball sealing deflection are low cost and low risk of mechanical problems. Costs are low because, typically, the process can be completed in a continuous operation, usually, even within a few hours of a single day. Only the materials are left in the wellbore

EN 121145 Β1 ball-shaped seal, either to flow out of the hydrocarbons produced or 1 to fall to the bottom of the well, in an area known as the drive rod hole.

The main disadvantage is the inability to be sure that only one set of perforations will be broken once, so that at the end of each step, the correct number of ball sealing materials will be dropped. In fact, the optimal benefit of process 5 depends on the fact that a fracture stage enters the formation only through a set of perforations, and all other open perforations remain unaffected, during that 7 stage of treatment. Other disadvantages are the lack of certainty that all perforated intervals will be treated as well as the order in which these intervals are treated, while the work is in progress. When the order of the area treatment is not known or ordered, it is not possible to be certain that each individual zone 11 is treated or that an individual stimulation treatment step is optimally designed for the target area. In some cases, the treatment may not be controllable, 13 so that individual areas may be treated with single treatment steps. To overcome some of these disadvantages, which may occur during stimulation treatments, 15 when multiple areas are perforated prior to pumping treatment fluids, an alternative mechanical diversion method has been developed, which involves the use of a 17 stimulation system. with flexible tube, to stimulate sequentially, multiple intervals, with separate treatment.

As for the ball-shaped sealant deflection, all intervals 19 that need to be treated are perforated before applying the stimulation treatment. Then, the flexible tube is inserted into the probe hole, with a double-pacer 21-way deflection tool attached at the end. This deflection tool, when positioned and operated optimally, transversely on the perforations, allows to obtain a hydraulic insulation above and below the deflection tool 23. After the deflection tool is located and actuated to isolate the deepest set of perforations, the stimulation fluid is pumped down inside the flexible tube 25 and it exits through the flow holes, placed in the deflection tool, between the sealing elements. , upper and lower. At the end of the first treatment step, the sealing elements 27, contained in the deflection tool, are deactivated or uncoupled, and the flexible tubing is pulled up to place the deflection tool, transversely, on the second set, the deepest, 29 of perforations, and the process continues, until all targeted intervals are stimulated or the process fails due to functional disturbances. 31

This method and elastic tubing stimulation device are used to hydraulically fracture, multiple areas of the probes, with depths up to about 8000 feet. However, 33 various technical obstacles, including loss of pressure through friction, damage to sealing elements, depth adjustment, operating speed and potential erosion of flexible tubing 35, currently limit the displacement to deeper wells.

Excessive pressure loss occurs when stimulation fluids are pumped, 37 in particular, fluids loaded with supporting material and / or with high viscosity, at high flow rates, over longer lengths of flexible tubing. Depending on the length and diameter of the flexible tubing 39, the fluid viscosity and the maximum permissible working pressures of the surface machinery, the pumping rates could be limited to a few barrels per minute, which, depending on the characteristics of the underground formation, are specific. , may not allow the placement of supporting material, during hydraulic fracturing treatments, or the effective dissolution of 43 materials of the formation, to acid stimulation treatments.

The erosion of the flexible tube could also be a problem, when pumping fluid loaded with support material inside the flexible tubing at high speed, including the portion of the flexible tube, which remains wound on the surface drum. 47

RO 121145 Β1

Erosion concerns are exacerbated when the fluid loaded with support material collapses with a continuous bending, associated with the flexible tubing part, placed on the surface drum.

Most sealing elements, for example, cuff sealing technology, commonly used in flexible tubing stimulation operations, described above, may be subject to sealing problems or sealing damage, in deeper probes, when seals are exploited after a large number of perforations at higher probe temperatures, associated with deeper probes. As the gaskets operate in contact with the tube wall or at a short distance from it, the inner, coarse, pipe surfaces, and / or bore holes may damage the sealing elements. The gaskets currently available in double pacer deflection tools are also constructed of elastomers, which may not withstand the higher temperatures associated with deeper probes.

The operating speed of existing systems, provided with cuff fittings, is generally of the order of 15 to 30 feet per minute, when working at the bottom of the well, reaching 30 to 60 feet per minute, when they reach the top of the well. drill hole.

For example, at a lower operating speed, it would take about 13 hours to reach a depth of 12000 feet before starting stimulation. Due to the safety leaks in the environment, at night operations, this low speed could result in a need for several days to complete a stimulation work. If certain problems are encountered, during the work, the execution of descending and ascending maneuvers, in the wellbore, could be very expensive, due to the total time of the operation, associated with the low operating speeds.

Controlling the depth of the system with a flexible tube and double-pack type deflection tool can become more difficult as the depth increases, for example, placing the tool at the correct depth to successfully perform the stimulation operation can be difficult. This problem can be solved by firing the perforations before directing the flexible tubing system into the wellbore. The drilling operation uses a different depth measuring device, usually a column connection detector system, than is generally used in the flexible tubing system.

In addition, the flexible tubing method described above requires that all perforations be placed in the wellbore, in a separate drilling operation, before pumping the stimulation work. The presence of multiple sets of open perforations, above the deflection tool, can cause difficulties. For example, if the fracture of the supporting material in the current area would increase vertically and / or a poor quality cement would be present behind the tubing column, then the fracture could intersect the set of perforations above the deflection tool, for example, a material the support could be unloaded back into the probe hole at the top of the deflection tool and could prevent the tool from moving further. Also, it may be difficult to perform circular operations if multiple sets of perforations are opened above the deflection tool. For example, if the circulating pressures exceed the breaking pressures, associated with open perforations above the deflection tool, then the circulation may not be maintained with unintentionally lost circulating fluid at the formation.

A similar type of stimulation operation can also be performed, using a combined tubing, extraction / injection pipes and an intervention facility, rather than a flexible tubing system. The use of a deflection tool, carried out on a joint tubing, may also allow a larger diameter tubing to reduce frictional pressure losses and allow for increased pump flows. Also, concerns about erosion and integrity of tubing can be reduced compared to flexible tubing,

EN 121145 Β1 because a bonded tubing pipe with greater wall thickness can be used, and 1 the jointed tubing would not be exposed to plastic deformation when operating in the wellbore. However, the use of this method would probably increase the time and cost, associated with 3 respective operations, due to the lower operating speeds of the pipe, than those possible with flexible tubing. 5

To overcome some of the limitations associated with termination operations, which require descending and ascending maneuvers of the equipment, in the wellbore, to drill 7 and stimulate some underground formations, methods have been proposed on a single maneuver of the gasket. drilling with a hole, to allow the simulation of the fracturing of the areas in connection with the drilling, specifically, these methods propose operations that can minimize the number of operations required at the wellbore and the time required to complete these operations, 11 thereby reducing the cost of treatment of the stimulation. These methods include the following:

- maintaining a cement-sand milk in the well hole, during drilling with 13 over-balanced pressure;

- reversing the sand from a tiling / cementing spoon, simultaneously detonating 15 drilling loads, and

- incorporation of sand in an explosion-proof container. 17

All these methods allow only minimal fracture penetration, which surrounds the wellbore and are not adaptable to the needs of multi-stage hydraulic fracturing, as described here.

Accordingly, an improved method and apparatus is needed for the individual treatment of each of the multiple ranges of an underground formation penetrated by a wellbore, while maintaining the economic benefits of treatment 23 over several. steps. There is also a need for a method and equipment that can economically reduce the risks inherent in stimulation treatment options, currently available for hydrocarbon formations with multiple or stratified deposits, or with a thickness that exceeds about 60 m, while ensuring 27 that the placement of the optimal treatment is performed with a mechanical deflection agent, able to precisely direct the treatment steps to the desired place. 29

The method of drilling and treatment of multiple intervals, from one or more underground formations, intersected by a borehole, and the equipment used to implement the method, according to the invention, provides the treatment of multiple intervals of one or more underground formations, intersected by the borehole, in that it comprises:

a - carrying a heavy rod assembly, using a means of conducting inside said drill hole 35, said heavy rod assembly being provided with a drilling device and a sealing mechanism, mounted one after the other 37 and whose displacement 37 is performed simultaneously;

b - positioning the heavy rod assembly, within the respective borehole, 39 so that the lower end of the assembly is below the target area, the lowest, using a depth control device; 41 c - drilling of the previously established interval;

d - displacing the sealing mechanism, said, so as to establish a hydraulic sealing of the target area, in the respective borehole;

e - pumping a treatment fluid into said well hole and into the perforations 45 created by said drilling device, without removing the drilling device from the well hole; 47 f - decoupling the sealing mechanism, mentioned; and

EN 121145 Β1 g - repetition of phases b to laf, for at least an additional interval of those one or more underground formations, mentioned.

The means for carrying out said heavy rod assembly is chosen from a metal cable, a guide cable or another cable.

The middle is a tubing gasket.

The sealing mechanism is actuated so as to establish a hydraulic seal below said perforated range.

Said tubing gasket is chosen from a flexible tubing to a joined tubing.

The heavy rod assembly is positioned inside said drill hole, using a depth control device, which may be a pipe column connection detector or a surface metering system.

Said drilling device, is a drilling rifle, with selective trigger, containing multiple sets, of one or more drilling loads, with molded load; each of the aforementioned sets, of one or more loads, with molded load, being controlled by an electrical or optical signal, transmitted by a cable in the probe hole.

Said drilling device is a hydraulic jet cutting device, which uses pumped fluid, downstream of said tubing gasket, to establish hydraulic communication path between said drill hole and one or more intervals of one or more many underground formations.

Said treatment fluid is pumped down the annular gap between the tubing gasket and the wellbore.

The treatment fluid is also pumped down the tubing gasket, mentioned, through the flow holes, provided in the assembly of heavy rods and through the aforementioned perforations.

A second treatment fluid is pumped down the tubing gasket, mentioned, through flow holes, from said assembly of heavy rods and into said perforations.

The second treatment fluid mentioned is nitrogen.

The sealing mechanism is a retractable packer.

The treatment fluid is chosen from an acidic solution, an organic solvent or a suspension of the supporting material and a carrier fluid.

Before the release of said sealing mechanism, at least one deflecting agent is deployed in the respective borehole to block the further flow of the treatment fluid into said perforations.

The deflection agent, carried out in said probe hole, is chosen from macroparticles, gels, viscous fluids, foams or ball-sealing agents.

The sealing mechanism, mentioned, is driven by hydraulic pressure, transmitted from the surface, through a spherical connecting element.

The drilling device, mentioned, is driven by hydraulic pressure, transmitted from the surface, through a spherical connecting element.

The drilling device, mentioned, is actuated by hydraulic pressure, transmitted from the surface, through said drill hole.

The drilling device, mentioned, is driven by a hydraulic pressure, transmitted from the surface, through said tubing gasket.

The heavy rod assembly is repositioned inside the borehole, prior to activating said sealing mechanism.

RO 121145 Β1

The method according to the invention, in one embodiment, comprises: 1 a - carrying a heavy rod assembly inside said drill hole, said heavy rod assembly being provided with a drilling device, 3 a sealing mechanism and at least one means pressure equalization;

b - drilling the interval established within the underground formation, previously established, through the use of said drilling device 5;

c - conducting the sealing mechanism, said, so as to establish a 7 hydraulic sealing of the target area, in the respective borehole;

d - pumping a treatment fluid into said drill hole and into the perforations 9 created by the respective drilling device, without removing the drilling device from the drill hole; 11 e - establishing a pressure communication between the portions above and below the sealing mechanism, mentioned, by at least one means of equalizing the pressure 13;

f - decoupling the sealing mechanism, mentioned; and 15 g - the repetition of phases (b) to (f), for at least an additional interval of those one or more underground formations, mentioned.17

The method of drilling and treatment of multiple intervals, from one or more underground formations, intersected by a borehole, in another embodiment, comprises: 19 a - unfolding of an assembly of heavy rods, using a means of deployment in the interior of said drill hole, said heavy rod assembly having at least one drilling device and at least one sealing mechanism, said drilling device being positioned under said sealing mechanism; 23 b - drilling a target range from the underground formations, using at least one drilling device, mentioned; 25 c - conducting said sealing mechanism, so as to establish a hydraulic sealing of the target area, in the respective drill hole; 27 d - pumping a treatment fluid into said drill hole and into the perforations created by the respective drilling device, without removing the drilling device from the 29 drill hole;

e - decoupling the sealing mechanism, mentioned; and31 f - repetition of phases (b) to (e), for at least an additional range of those underground formations, mentioned.33

The drilling device, mentioned, is devoid of the flow channel of the washing fluid.35

The heavy rod assembly is repositioned in said drill hole and said sealing mechanism is actuated to establish a hydraulic seal 37 below said interval.

The method according to the invention, in another embodiment, comprises: 39 a - conducting a heavy rod assembly (BHA), within said drill hole, said heavy rod assembly (BHA) being provided with a 41 drilling device and a sealing mechanism, said drilling mechanism, being positioned underneath the respective sealing mechanism; 43 b - piercing the deepest target range of the underground formations;

c- pumping a treatment fluid into the wellbore and into the perforations created in the 45th deepest target range, by the drilling device, without removing the respective drilling device from the wellbore; 47

EN 121145 gr1 d - positioning the heavy rod assembly (BHA) in the wellbore and using said drilling device to drill the next target interval, successively higher at the surface, between the underground formations;

e - repositioning the heavy rod assembly (BHA) in the well hole and actuating said sealing mechanism to hydraulically isolate the perforations created in the next target range, successively located further afield, from the perforated target range, the deepest;

f - pumping a treatment fluid into said drill hole and into the perforations created in the next target range, successively located on the surface, by the drilling device, without removing said drilling device from said drill hole;

g - decoupling the sealing mechanism; and h - the repetition of phases (d) to (g), for at least one additional interval, located successively further on the surface, of the underground formations, in which the perforations created in at least one of the respective target intervals, successively further on the surface, are hydraulically insulated from the perforated intervals below.

The drilling and treatment equipment of multiple intervals, from one or more underground formations, intersected by a well hole, used for the implementation of the method according to the invention, is provided with:

a - an assembly of heavy rods, adapted to be deployed in the borehole, by means of a conducting means, chosen from a metal wire, a guide wire or another cable, the rod assembly having at least one drilling device, for successive drilling of multiple intervals and at least one sealing mechanism;

b - the sealing mechanism is capable of establishing a hydraulic seal in the respective borehole and, further, capable of being disengaged, so as to release said hydraulic sealing, to allow the assembly of heavy rods (27, BHA) to move in a different position, within the wellbore, thereby allowing each of the said multiple treatment intervals to be treated separately from the other treatment intervals.

The equipment according to the invention, in one embodiment, is provided with:

a - a set of heavy rods, having at least one drilling device, for successive drilling of said multiple intervals, at least one sealing mechanism and at least one displacement device;

b - the displacement device is capable of positioning the respective assembly of different heavy rods in said drill hole; and c - the sealing device is able to establish a seal in the respective borehole and subsequently capable of disengaging said hydraulic sealing to allow the said heavy rod assembly to move in a different position, inside probe holes, thereby allowing each of the multiple treatment intervals to be treated separately, from the other intervals subjected to the treatment.

The equipment according to the invention, in another embodiment, has as a means of carrying out a tubing gasket.

Said tubing gasket is a flexible tubing or a joined tubing.

The deployment means is chosen from a metal cable, a guide cable or another cable.

The equipment according to the invention comprises a depth control means for positioning the heavy rod assembly in the wellbore, which may be a pipe column connection detector or a surface measuring system.

The sealing mechanism is a retractable packer.

RO 121145 Β1

The drilling device is a selective trigger drilling rifle, 1 containing multiple sets, consisting of one or more molded load drilling loads; each of these sets, of one or more 3-hole loads, with the shaped load, being controlled and activated by an electrical signal, transmitted through a cable line, carried out in the borehole. 5

The sealing mechanism, mentioned, is driven by hydraulic pressure, transmitted from the surface, through the borehole.7

The drilling device is actuated by hydraulic pressure, transmitted from the surface, through the tubing gasket.9

The drilling device is a jet cutting device, which uses a fluid pumped down the tubing gasket, to establish a hydraulic communication path between 11 wells and one or more intervals of those underground formations.

The equipment according to the invention, in another embodiment, is provided with: 13 a - an assembly of heavy rods, adapted to be deployed in said drill hole, by means of a deployment means, the respective assembly of heavy rods 15 having the at least one drilling device, for the successive drilling of said multiple intervals, and at least one means of equalizing pressure; 17 b - the sealing mechanism, mentioned, is capable of establishing a hydraulic seal in the respective borehole, and the pressure equalization means being able to establish a pressure communication between the portions of the borehole, located above and below the borehole mechanism. sealing, and further, the sealing mechanism is capable of loosening the hydraulic sealing, to allow the assembly of heavy rods to move in a different position, within the borehole, thereby allowing 23 such intervals. of multiple treatment, mentioned, to be treated separately, of the other treatment intervals. 25

The equipment according to the invention, in another embodiment, is provided with:

a - an assembly of heavy rods, adapted to be deployed in said well 27, with the aid of a deployment means, said assembly of heavy rods having at least one drilling device, for the successive drilling of said multiples, 29, and at least one sealing device, the perforating device being positioned below the sealing mechanism; and 31 b - the sealing mechanism is capable of establishing a hydraulic seal in the respective borehole and subsequently capable of releasing said hydraulic sealing, 33 to allow the heavy rod assembly to move into position. different, within the borehole, thereby allowing each of the said multiple treatment intervals to be treated separately from the other treatment intervals.

Said drilling device is devoid of a fluid flowing channel of 37 washes.

By applying the invention, the following advantages are obtained: 39

- the heavy rod assembly, including the sealing mechanism and the drilling device, must not be removed from the wellbore, prior to treatment with 41 treatment fluid and between treatment of multiple formation areas or intervals;

- each step of the treatment is diverted using a mechanical diversion agent, 43 so that a precise control of the deviation process of the treatment is obtained and each zone can be optimally stimulated. As a result, there are significant cost savings of 45, associated with reducing the time required to drill and perform the treatment at multiple intervals, within the wellbore. In addition, there are production improvements, 47 associated with the use of a mechanical diversion agent, to ensure a diversion of

EN 121145 precis1 treatment, precisely ordered, when a multi-formation interval is stimulated, inside a borehole;

- it provides economic advantages over the existing methods and equipment, because they allow the drilling and stimulation of multiple zones, with a single entrance in the wellbore and the subsequent withdrawal of the heavy rod assembly, which ensures a double functionality, as a mechanical diversion agent, as well as a drilling device;

- economically reducing the risks inherent in the stimulation treatment options, currently available, for hydrocarbon formations with multiple or stratified deposits, or with a thickness exceeding about 60 m, while ensuring the optimal treatment placement it is executed with a mechanical diversion agent, able to direct the treatment steps to the desired place;

- the possibility to economically place, in production, multiple drill holes, from a single place of launching the treatments.

Further examples of embodiments of the invention are given in connection with FIG. 1 ... 10, which represents:

FIG. 1, a view and section through a possible, representative configuration of a borehole, with peripheral equipment that could be used to support the BHA heavy rod assembly used in the present invention, and which also illustrates boreholes, for the storage of heavy rod assemblies, representative, with surface fastening feathers that can be used for the storage of heavy, spare or eventual rod assemblies;

FIG. 2A, section through a borehole, equipped, according to the invention, in a first embodiment of the assembly of heavy rods, deployed, using a flexible tubing in a borehole, not perforated, and positioned at the depth site which must be perforated by the first set of selective trigger drilling loads. Fig. 2A further illustrates that the heavy rod assembly consists of a drilling device, a packer, sealing system, expandable, removable, an axial, removable sliding device and ancillary components;

FIG. 2B, section through a drill hole equipped with a heavy rod assembly, flexible tubing, after the first set of drilling loads has been selectively detonated, resulting in drilling holes through the operating column and the cement shell / ring and in the first area of the formation, so that a hydraulic communication is established between the wellbore and the first zone of the formation;

FIG. 20, section through a drill hole, equipped with an assembly of heavy rods, flexible tubing, after the assembly of heavy rods was repositioned and the first area of the formation stimulated with the first step of the fracture treatment with support, hydraulically, with multiple steps, where the first step was pumped to the probe sole, in the annular space, existing between the flexible tubing and the operating column. in FIG. 2C, the sealing mechanism is shown in the deactivated position, for illustration purposes only, since it is admitted that there are no perforations other than those associated with the first zone and, as such, no isolation is required for the treatment of the first zone;

FIG. 3A, section through a drill hole, equipped with a heavy rod assembly, flexible tubing, after the heavy rod assembly has been repositioned and the second set of drilling loads has been selectively detonated, resulting in drilling holes through the column. operating and the cement coating / ring, and in the second zone of the formation, so that a hydraulic communication is established between the well hole and the second zone of the formation;

FIG. 3B, section through a borehole, equipped with a heavy rod assembly, flexible tubing, after the heavy rod assembly has been repositioned to a sufficient

EN 121145 Β1 distance, under the deepest perforation of the second set of perforations, to allow 1 a slight upward movement of the BHA heavy rod assembly, in order to fix the sliding, axial, retractable device, in time what is the place of the circulation hole 3 below the perforation, located at the base of the second set of perforations;

FIG. 3C, section through a borehole, equipped with an assembly of heavy rods, 5 a flexible tubing, after the device, mechanical slide, retractable, was actuated to ensure resistance to downward axial movement and create the certainty that the packer , the sealing system 7, removable, expandable, and the mechanical sliding device, releasable, are located between the perforations of the first zone and the second zone; 9

FIG. 3D, section through a borehole, equipped with a set of heavy rods, flexible tubing, after the packer, sealing system, removable, expandable, was actuated to provide a barrier to flow, between the portion of the borehole. located directly above the packer, retractable, expandable, and the portion of the borehole located directly 13 below the packer, expandable;

FIG. 3E, section through a drill hole, equipped with an assembly of heavy rods, 15 flexible tubing, after the second zone of the formation was stimulated with the second stage of fracture treatment, with hydraulic support, in multiple stages, where the second stage of the 17 fracture treatment was pumped down, into the annular space of the borehole, existing between the flexible tubing and the operating column; 19

FIG. 3F, section through a borehole, equipped with an assembly of heavy rods, a flexible tubing and the borehole, after the removable, expandable packer has been deactivated, thus restoring the pressure communication between the borehole portion, located directly above the resealable, expandable packer, and the portion of the borehole, located directly 23 below the packable, expandable packer. The sliding device, mechanical, retractable, is still actuated and continues to prevent the flexible tubing and the assembly of 25 heavy rods moving down the drill hole;

FIG. 4A, section through a drill hole, equipped with a heavy rod assembly, 27 modified, similar to the heavy rod assembly described in fig. 2A to 2C and in FIG. 3A to 3F, but with the addition of a mechanical stopper, which can be mounted with a system of fixing 29 explosive charges, selectively detonable, located under the seal of the wells to be perforated and with a flexible tube, represented in the well hole in fig. 3F, after an operation 31 of stimulation by perforation and fracture was performed, additional. It is noted that in FIG. 4A, only the second and third sets of perforations and fractures are shown. in FIG. 4A, the modified heavy rod assembly 33 is shown suspended by means of flexible tubing, so that the place of the bridge stopper is located above the last perforated interval and below 35 the next interval to be perforated;

FIG. 4B, section through a drill hole, equipped with a set of heavy rods, 37 flexible tubing, after the mechanical stopper with the explosive charges, selectively detonated, was fixed in the well hole and after the assembly of heavy rods had it was repositioned, and 39 the first set of explosive charges, selectively detonated, was detonated, resulting in drilling holes through the operating column and the cement shell / ring and in the fourth area 41 of the formation, so that a hydraulic communication is established , between the wellbore and the fourth area of the formation. 43

FIG. 5, section through a borehole, representing the second embodiment of the invention, wherein the suspension means is a tubing column and after the interval has been perforated, the BHA heavy rod assembly can be moved and the sealing mechanism actuated to establish a hydraulic seal above the perforated range. Then, the treatment fluid may be pumped down the tubing column and into the perforated range;

RO 121145 Β1

FIG. 6, a section through a borehole, representing a third embodiment of the invention, wherein the suspension means is a tubing column, and the BHA heavy rod assembly can also be moved and the sealing mechanism operated to establish a seal. hydraulics above and below the perforated range and where the sealing mechanism consists of two sealing elements, sufficiently spaced apart, to fit the perforated range. In this third embodiment, the treatment fluid may be pumped down the tubing column itself, through a flow port located between the two sealing elements of the sealing mechanism, and in the perforated range;

FIG. 7, section through a borehole, representing a fourth embodiment of the invention. The BHA heavy rod assembly is suspended in the borehole, using a metal cable, guide wire or other cable. The heavy rod assembly will also be moved and the sealing mechanism operated to establish a hydraulic seal below the perforated range to be treated, and the treatment fluid will be pumped down the annular gap between the metal cable, guide cable or other cable.

FIG. 8A, section through a borehole, representing a fifth example of the embodiment of the invention, which uses a central tubing, carried out inside the tubing used as a deployment means, for actuating the sealing mechanism;

Fig. 8B, section through a borehole, representing a fifth embodiment of the invention, which uses a central tubing, carried out inside the tubing used as a deployment means, for actuating the sealing mechanism, which can be releasable;

FIG. 9, a section through a borehole, representing a sixth embodiment of the invention, which uses a displacement means system, attached to the BHA heavy rod assembly, so that the BHA heavy rod assembly can also be displaced. sealing actuated, to establish a hydraulic seal below the perforated range. The treatment fluid can be pumped down the borehole and into the perforated range;

FIG. 10 is a section through a borehole, representing a seventh embodiment of the invention, which uses an abrasive or erosive fluid jet cutting technology for the drilling device. The heavy rod assembly is suspended in the borehole, using a joined tubing, and consists of a mechanical compression set, a resealable packer, an abrasive or erosive fluid jet drilling device, a column coupling detector, mechanically , and auxiliary components. In this embodiment, the perforations are created by pumping an abrasive fluid, around the joint tubing and outside the jet making tool, located on the heavy rod assembly, so that a high-speed abrasive or erosive fluid jet is created, at high pressure, and used to penetrate the operating column and surrounding cement coat / ring, to establish hydraulic communication with the desired formation range. After fixing the pacemaker under the area to be stimulated, the stimulation treatment can be pumped down the annular space, located between the tubing column and the operating column.

The method of drilling and treatment of multiple intervals, from one or more underground formations, intersected by a borehole, according to the invention, includes the phases of conducting the heavy rods inside the borehole, using a means of deployment, where the deployment means may be a tubing gasket, extraction / injection pipes, a cable or a means of displacement at the probe sole.

The drilling and treatment equipment of multiple intervals, from one or more underground formations, intersected by a borehole, for the implementation of the method according to the invention, consists of a deployment means, for example flexible tubing, tubing combined, electrical network, conductors, means of travel, etc., with a

EN 121145 Β1 BHA heavy rod assembly, comprising at least one drilling device and 1 reset mechanism, which can be actuated independently, by one or more signaling means, for example, electronic signals, transmitted by a network of 3 conductors, hydraulic signals, transmitted by tubing, extraction / injection pipes, annular space, central connecting elements, tensile or compression loads, radio transmission, 5 optical fiber transmission, electronic computer systems on board, for heavy fry etc. 7

The drilling device is positioned adjacent to the interval to be drilled and is used to drill the respective interval. The heavy rod assembly is positioned 9 inside the well bore, using the deployment means, and the sealing mechanism is actuated so as to establish a hydraulic seal able to direct the pumped fluid down the well bore to enter the range. perforated. The sealing mechanism is released. 13

The method can then be repeated, without removing the heavy rod assembly

BHA from the wellbore, for at least an additional interval of one or more 15 underground formations.

The deployment means may be a tubing column, including a flexible tubing or a standard joint tubing, a metal cable, a guide wire or another cable.

Preferably, as opposed to a cable or tubing deployment, the deployment means could also be a displacement means system, attached to the BHA heavy rod assembly. The displacement means system can be self-propelled, controlled by electronic computer 21 and can carry signaling on board, so it is not necessary to attach cable or tubing, to control or operate the system of the heavy rod assembly BHA 23 and / or the middle system. moving. Alternatively, the displacement system could be controlled and put into operation by cable connection elements or 25 tubing elements, such a displacement system and the BHA heavy rod assembly being controlled and actuated by signals transmitted to probe sole, using the respective 27 connecting elements. There can be many different variants of the invention, depending on the suspension means and the specific components of the BHA heavy rod assembly. 29 in a first embodiment according to the invention, once an interval has been perforated, the BHA heavy rod assembly may be displaced and the sealing mechanism 31 actuated to establish a hydraulic seal below said perforated interval. The treatment fluid can be pumped down into the annular space between the tubing column and the probe hole 33 and into the perforated range. And a second treatment fluid, for example nitrogen, can be pumped down the tubing column, at the same time as the first treatment fluid is pumped into the annular space between the tubing column and the wellbore.

In the second embodiment, when the suspension means is a 37-tubing column, once an interval has been perforated, the BHA heavy rod assembly can be moved and the sealing mechanism actuated, to establish a hydraulic seal above the 39 perforated interval. . Then, the treatment fluid can be pumped down the tubing column and into the perforated range. 41 in the third embodiment, when the deployment means is a tubing column, the heavy rod assembly can be moved and the sealing mechanism operated, 43 to establish a hydraulic sealing above and below the perforated range, where the sealing mechanism consists of two sealing elements, sufficiently spaced, to form a double packer on the perforated range. In this third embodiment, the treatment fluid can be pumped down the tubing column itself, through a flow hole 47 located between the two sealing elements of the sealing mechanism and in the perforated range. 49

In a fourth embodiment, according to the invention, when the BHA heavy rod assembly is deployed in the drill hole, using a metal cable, guide wire or other cable, the BHA heavy rod assembly could be and the sealing mechanism operated, to establish a hydraulic seal below the interval to be perforated, and the treatment fluid is pumped into the annular space between the metal cable, the guide cable or another cable.

In a fifth embodiment, according to the invention, a central, umbilical, linking means is deployed as an additional means to actuate a component of the BHA heavy rod assembly. In the most general sense, the central connecting means could take the form of a small diameter tubing or a multiple tubing, to ensure hydraulic communication with the components of the BHA heavy rod assembly; and / or the central connecting means could take the form of a cable or multiple cables, to ensure electrical or electro-optical communication with the components of the BHA heavy rod assembly.

In a sixth embodiment, according to the invention, when the deployment means is a displacement means system attached to the BHA heavy rod assembly, said BHA heavy rod assembly may be moved and the sealing mechanism actuated to establish a hydraulic sealing below the perforated range. The treatment fluid can be pumped down the borehole and into the perforated range.

In a seventh embodiment, according to the invention, abrasive fluid jet cutting technology is used for drilling, and the heavy rod assembly is suspended by means of the tubing, so that the BHA heavy rod assembly can also be moved. sealing actuated, to establish a hydraulic seal below the perforated range. The treatment fluid is then pumped down the annular space between the tubing and the wellbore.

The method of drilling and treatment of multiple intervals, from one or more underground formations, intersected by a borehole, according to the invention, involves the suspension of an assembly of heavy rods, in order to drill and treat successively, each of the desired multiple zones. , while pumping the multiple steps of the simultaneous treatment, and to carry out a sealing mechanism, reseatable, mechanically, in order to ensure a controlled deviation of each individual treatment step. For these purposes, it will be understood that the probe hole includes sealed components of the probe, below the ground level and also all equipment above the ground level such as, for example, the probe mouth, coils, eruption prevention equipment and lubrication apparatus.

The drilling and treatment equipment of multiple intervals, from one or more underground formations, intersected by a well bore, according to the invention, consists of a means of deployment, for example, flexible tubing, joint tubing, cable line, system with displacement means, etc., with an assembly of heavy rods, composed of at least one drilling device and a resealable sealing mechanism, which can be operated independently from the surface, by means of one or more means. signaling, for example, electronic signals, transmitted by cable line; hydraulic signals, transmitted by tubing, annular space, central connecting elements; stretching or compression loads; radio transmission, optical fiber transmission, etc. and built for the environment and stress conditions in the wellbore.

In the most general sense, the term heavy rod assembly is used to designate a component column / gasket, consisting of at least one drilling device and a resealable sealing mechanism. Some additional components, which include, but are not limited to these instrumentation parts, shear connections, tools

RO 121145 Β1 wash, connections with circulation ports, connections with flow ports, 1 pressure equalization ports, temperature indicators, manometers, connections for conductor connections, mechanical clamping fuses, releasable, connection detectors 3 column columns, centering connections and / or socket connections may also be placed on the heavy rod assembly to facilitate other anticipated auxiliary operations and measurements, which may be desirable during the stimulation treatment.

In the most general sense, the mechanical sealing mechanism, releasable, performs the function of providing a hydraulic seal, where the hydraulic seal is defined as a sufficient flow restriction or blocking, so that a fluid is forced to be directed 9 toward a place that is different from the place to which it would be directed if the flow restriction were not present. Specifically, this broad definition for hydraulic sealing is meant to include perfect hydraulic sealing so that the entire flow is directed to a different place from where the flow would be directed if the flow restriction were not present; 13 and an imperfect hydraulic seal, so that an appreciable part of the flow is directed to a place different from the place to which the flow would be directed if the flow restriction were not present. Although, in general, it would be preferable to use a mechanical, resealable seal, which provides perfect hydraulic sealing, to achieve optimum stimulation, 17 a sealing mechanism that provides imperfect hydraulic sealing, a treatment could also be used. economical would be to be achieved, even if the stimulation treatment may not be perfectly diverted.

In the first preferred embodiment, a flexible tubing is used as a means of 21 unfolding, and the method according to the invention involves successive perforation and then stimulation of the individual areas, from bottom to top, of the filling interval, with the stimulation fluid 23 pumped down. of the annular space between the operating column and the flexible tubing. As discussed below, this embodiment of new equipment and 25 new methods provides substantial improvements over existing flexible tubing and joint tubing stimulation technology and is applicable to a wide range of hole architectures. of 27 wells and constructions of the stimulation treatment.

Specifically, the first embodiment of the method and equipment involves the deployment system, signaling means, heavy rod assembly, and operations, as described in detail below, where the various components, their orientation, and steps 31 / functional phases are chosen for descriptive purposes only, to correspond to the components and operations that could be used to install fracture stimuli, with 33 hydraulic supports, of multiple intervals.

In the first preferred embodiment for fracture stimulation treatment 35 and hydraulic support, the equipment consists of an assembly of heavy BHA rods, carried out in the borehole by means of a flexible tubing. The heavy rod assembly 37 includes a shear device, a mechanical, resealable mechanism, a column connection detector, circulation ports and other ancillary components, as described in detail below.

Moreover, in this first embodiment, preferably, the drilling device 41 consists of a system of selective fire drilling rifles, using shaped drilling charges, the mechanical sealing mechanism, releasable, 43 consists of - a retractable, extendable pack, a sliding, releasable, mechanical device, to prevent axial downward movement, of the heavy rod assembly, when fixed, 45 and pressure equalization ports, located above and below the retractable, extendable pack . 47

In addition, in the first preferred embodiment, a cable line is placed inside the flexible tubing and used to provide a signaling means for actuating the selective ignition drilling loads and the transmission of electrical signals, associated with the column connection detector, used to measure the depth of the BHA heavy rod assembly.

Referring to FIG. 1, an example of surface equipment, which could be used in the first embodiment, preferably, is an assembly using a very long lubrication apparatus 2, with an injection tube 4 of the elastic tubing, suspended above, in air , with a crane arm 6, attached to a base 8 of the crane. The wellbore typically comprises a surface 78 / anchor column, partially or totally in a cementitious coating / ring 80, and an operating column 82, partially or totally in a coating / ring 84 of cement, where the inner wall of the well is composed of an operating column 82. The depth of the borehole, preferably, extends with a certain distance below the lowest interval to be stimulated, in order to receive the length of the assembly of heavy spindles, which will be attached at one end of an elastic tubing 106. Elastic tubing 106 is inserted into the wellbore, using the injection head 4 of the elastic tubing and the lubrication apparatus 2.

Also, installed on the lubrication apparatus 2, there are some 10 eruption preventers, which can be operated remotely, in case of operating disturbances. The base 8 of the crane, the arm 6 of the crane, the injection head 4 of the elastic tubing, the lubrication apparatus 2, the eruption preventers 10 and the auxiliary control and / or drive components, associated with them, are standard equipment components, well known to the persons of profession in this field, which adapts to methods and procedures for safe installation of the heavy rod assembly, the elastic tubing, in a pressure probe, and subsequently, the removal of the heavy rod assembly, the elastic tubing, from the probe under pressure.

With available equipment, the height at the top of the injection head 4 of the elastic tubing can be approximately 27 m above the ground level, and with a groove 12 of the hydraulic head, where the elastic tubing is bent over, to descend vertically into the well. , it can be approximately 31.5 m above the ground. The arm 6 of the crane and the base 8 of the crane will support the load of the injection head 4, the elastic tubing 106 and any anticipated load requirements for potential instrumentation operations, instrumentation using gelation and traction.

Generally, the lubrication apparatus 2 must be longer than the length of the heavy rod assembly, to allow the heavy rod assembly to be safely deployed in a pressure probe. Depending on the full length requirements and as determined on the basis of careful design calculations, for a specific application, to ensure the stability of the injection head 4 of the flexible tubing and the lubrication apparatus 2, some 14 anchor cables can be attached. , in various places on the injection head 4 of the flexible tubing and the lubrication apparatus 2. The anchor cables 14 must be securely fastened to the ground to prevent unwanted movement of the flexible tubing injection head 4 and lubrication apparatus 2 so that the integrity of the surface components is not compromised to maintain pressure. Depending on the full-length requirements, alternate system suspension systems, injection head / lubrication apparatus, flexible tubing structures or filling-adjusting / intervention installations may also be used.

in FIG. 1 are also shown a few preventive parts from the mouth of the well, which can be used for flow control and hydraulic isolation, during assembly operations, stimulation operations and disassembly operations.

RO 121145 Β1

A crown valve 16 provides a device for isolating the hole portion of 1 well above the crown valve 16, relative to the portion of the well hole, below the crown valve 16. The upper main fracturing valve 18 of the eruption head 3 and the lower main fracturing valve 20 of the eruption head also provide ventilation systems for isolating the borehole pressures above and below their corresponding locations. Depending on the specific site practices and the construction of the stimulation work, it may not be necessary or required all these 7 type valves for insulation.

Some 22 side valves for injection for injection, shown in fig. 1, provides a place 9 for the injection of the stimulation fluids into the wellbore. The pipes from the pumps and the surface tanks, used for the injection of the stimulation fluids, will be attached with 11 fittings and / or couplings suitable for the 22 lateral injection injection valves. The stimulation fluids will then be pumped into the wellbore on this flow path. With the installation 13 of other suitable flow control equipment, fluid may also be produced from the wellbore, using the side valves 22 for the injection injection. It should be noted that the interior of the flexible tubing 106 can also be used as a flow pipe for injection of fluid into the borehole. 17

Some 24 drill holes for the storage of heavy rod assemblies, shown in fig. 1, it provides a storage place for a set of 27 spare heavy rods or 19 for the storage of heavy rod assemblies that were used during the previous interventions. The drill holes 24 for holding heavy rod assemblies may be drilled 21 at shallow depth, so that a heavy rod assembly, which may contain drilling loads, is securely held in place with surface feathers, so that 23 the drilling loads are placed below the ground level, until the heavy rod assembly is ready to be attached to the flexible tubing 106. The drill holes 24 for the 25 heavy rod assembly can be drilled to ensure the placement of cementitious or cemented column seals, or they can be left unattached in the 71-pipe column. The actual number of drill holes 24 for heavy rod assemblies required for a particular operation depends on the total working requirements. The probe holes 24 for keeping the heavy rod assemblies can be located within the range of the arm 6 of the crane, to ensure the rapid change of the heavy rod assemblies 31, during the stimulation operation, without the need to move. physics of the base of the crane in another place.33

Referring to FIG. 2A, the flexible tubing 106 is equipped with a flexible tubing connection 110, which can be connected to a combined shear connection - uncoupling / parts of 35 instrumentation, which contains both a shearing mechanism and a piece of instrumentation and allows the passage of pressurized fluids and a line 102 of cable.37

Combined shear - decoupling / instrumentation connection 112 may be linked to a connection containing a connection 114 with movement holes, which may provide a flow path 39 for washing residues of substances above a removable, extendable, or provide a fluid injection flow path to the probe sole 41, using flexible tubing 106. The connection 114 with circulation ports contains a set of valves, which actuate the opening of the circulation connection 114 and an equalization hole 116 43, superior. The upper equalizing port 116 may be connected to a lower equalizing port 122 by passing the tubing through the retractable, extendable pack 120. Both the opening of the circulation connection 114 and the equalization hole 116, superior, will preferably be opened in the forward position of the drilling gasket, allowing, through 47

EN 121145 Β1 this, a pressure communication between the inner pressure of flexible tubing and the flexible tubing through the pressure in the annular space. In this description, the term march position refers to the situation where all the components in the heavy rod assembly have a configuration that allows for an unobstructed axial movement, up and down the borehole. Equalization hole 122, lower, located beneath the packer 120, retractable, expandable, is always open, and the flow through the equalization holes is controlled by the equalization hole 116, superior. The circulation and equalization holes can be closed simultaneously by placing a slight compression load on the heavy rod assembly. In order to prevent a potential flow in the opposite direction, in the flexible tubing, when the opening of the circulation connection 114 is opened in the reverse position, a surface pressure can be applied to the flexible tubing 106, so that the pressure inside the opening of the circulation connection 114 to overcome the pressure of the drill hole, which exists directly outside the orifice of the connection 114 in circulation. The retractable, extensible pacer 120 can receive pressure communication, through valves, from the inside, with internal pressure of the flexible tubing, placing a slight compression load on the assembly of heavy rods. Some axles, lockable, mechanically actuated, or locking fuses 124 may be located under the retractable, extensible pack 120 to withstand downward movement in the borehole. The grips 124 can be actuated by a continuous mechanism J by a cyclization of the axial load between compression and stretch. A cable line connection 126 is located above a column detector 128 and selective detonation punch system. A connector connection 130 connects the detector 128 column connections with a selective detonation head 152. The drill gun system can be built based on the knowledge of the number, location and thickness of the hydrocarbon carrier sands, within the target areas. The rifle system will consist of a set of 134 rifles, for each area to be subjected to treatment. The first, the lowest set of rifles, will consist of a selective ignition head 132 and a pack of rifles that will be loaded with some piercing charges 136 and a detonating system with selective ignition.

Specifically, a preferred embodiment of the proposed method involves the following phases, where the stimulation work is chosen, for descriptive reasons only, as a fracture stimulation with hydraulic support, on several steps / floors.

- The probe is perforated and the column is cemented transversely over the interval to be completed and, if desired, one or more drill holes, to keep the rod assemblies, are drilled and finished.

- Target areas, within the termination range, are typically identified by a combination of open hole and tubed hole diagrams.

- BHA heavy rod assemblies and drill bit assemblies, to be deployed on each heavy rod assembly, expected to be used during the simulation operation, are designed based on the knowledge of the number, location and thickness of the hydrocarbon bearing sands inside. target areas.

The 4-0 flexible tubing coil is prepared with a preferred heavy rod assembly described above. The flexible tubing coil will also be prepared to contain the cable line that is used to provide a signaling means, intended for the actuation of drilling wells. Preferably, the desired number of suitably configured spare rod assemblies will also be prepared and stored in the borehole / holes for retaining the heavy rod assemblies. The flexible tubing can be preloaded with fluid, either before or after attaching the heavy rod assembly to the flexible tubing.

RO 121145 Β1

- As shown in FIG. 1, the flexible tubing 106, with the assembly of heavy rods, 1 is inserted into the well, through the lubrication apparatus 2, and the injection head 4 of the flexible tubing is suspended, by means of a crane arm 6. 3

- The respective flexible tubing / BHA heavy rod assembly is introduced into the probe, while a correlation of the depth of the BHA heavy rod assembly with the detector 128 5 of column connections, fig. 2A.

The respective flexible tubing / BHA heavy rod assembly is introduced below the 7th lowest target area, in order to be certain that there is sufficient depth of the borehole, below the perforations below, to place the heavy rod assembly below 9 first. set of perforations, during fracturing operations.

As shown in FIG. 2B, the coiled tubing / assembly of heavy rods is then elevated to a position, inside the borehole, so that the first, lowest, set of loads 136 for drilling, contained in the first assembly 134 of the bore system drill guns 13 with selective trigger, to be placed directly transversely on the lowest target area, where a precise depth adjustment must be established, based on the readings obtained 15 from the detector 128 of column connections and the system with counter flexible tubing path, not shown. The action of moving the BHA heavy rod assembly to the 17th position of the first perforated range will pass the continuous, mechanically, non-sliding, continuous J mechanism to the pre-locking position, where a subsequent downward movement will force the feathers 124 of 19, retractable, into the locked position. , thereby preventing further downward movement. It should be noted that an additional cyclic passage of the axial load of the flexible tubing 21, from compression to stretching and vice versa, will restore the mechanical, retractable feather grips to the operating position. In this way, the mechanism with "continuous J", 23 coupled with the use of compression and stretching loads, transmitted by means of the suspension means, flexible tubing, are used to ensure the activation and deactivation of 25 mechanical gripping feathers at the bottom of the well.

- The first set of the punching loads 136 is triggered selectively, by means of a 27 remote actuation, via the cable line 102, for communication with the first head 132 of selective trigger, to penetrate the column 82 of the tubing and the shell / ring 29 84 cement and establish a hydraulic communication with the 86 formation through some perforations 230 ... 231, which occur. It should be understood that any set of perforations, if desired, can be a set with one perforation, although multiple perforations generally provide improved treatment results. 33

It must also be understood that more than one segment of the rifle assembly can be triggered if the target number of perforations is to be achieved, 35 if a missed missed trigger is to be remedied or if it is simply intended an increase in the number of perforations. It should also be understood that range 37 is not necessarily limited to a single sand-tank. With this invention, multiple sand intervals can be perforated and subjected to treatment, as a single floor, using convenient agents for simultaneous deployment within a treatment step.

- As shown in FIG. 2C, the flexible tubing may be displaced, to 41 position the hole of the connection 114 of circulation directly under the perforation 231 of the deepest of this first target area, in order to potentially minimize the support filling 43 above the resealable pacer 120, expandable, and minimize the flow of support material, high speed, beyond the assembly of heavy rods. 45

- The first step of the fracture stimulation treatment is initiated by putting a small volume of fluid into circulation, down the flexible tubing 106, through the hole of the connection 114 of 47

RO 121145 Β1 circulation, by means of a volumetric pump. This is followed by the initiation of stimulation fluid pumping down the annular space between the flexible tubing 106 and the operating column 82, at fracture stimulation rates. The small volume of fluid flowing down the flexible tubing 106 serves to maintain a positive pressure inside the tubing 106, in order to withstand the backward flow of the fluid loaded with support material into the flexible tubing 106 and to withstand the load resistance. breaking of the flexible tubing during the fracturing operations. It should be noted that, as an alternative means, in order to oppose the breakage of the flexible tubing, a mechanism with the internal valves can be used in order to maintain the opening of the circulation connection 114 in the closed position, and then a positive pressure is applied to the tubing. 106 flexible, using a surface pump. As an illustrative example of the design of the fracturing treatment, for the stimulation of a 15-acre hydrocarbon-containing lenticular sand deposit, the first fracture stage could include sub-sections, as follows:

a - 5000 gallons of water with 2% KC1;

b - 2000 gallons of cross-linked gel containing 1 pound / gallon, supporting material; c - 3000 gallons of cross-linked gel containing 2 bags / gallon, supporting material; d - 5000 gallons of cross-linked gel containing 3 bags / gallon, support material, and;

e- 3000 gallons of cross-linked gel containing 4 bags per gallon, support material, so that in the first area, 35000 support material bags are located.

- As shown in FIG. 2C, all sub-sections of the first fracture operation are completed by loading the first fracture 232 with supporting material.

- At the end of the first step of the stimulation treatment, the supporting material in the wellbore must prevent the flexible tubing / heavy rod assembly from moving immediately; the fluid can be circulated through the circulation port 114, to wash and drain the entire support material completely, in order to release the flexible tubing / heavy rod assembly and allow movement.

- As shown in FIG. 3A, the flexible tubing / heavy rod assembly is then pulled up the well hole, until it reaches slightly above the second target area, the deepest, so that the second set of drilling loads 146, contained on a system 144 of the selective ignition / triggering rifles are located slightly above the second target zone, the deepest one, where a precise depth adjustment is again established, based on readings from a detector 128 of column connections and systems with flexible tubing travel counter. The upward movement of the BHA heavy rod assembly, slightly above the second interval to be perforated, will pass the continuous, sliding, retractable J mechanism into the preloading position. Next, a cyclization of compression / stretching loads is performed, to place the "J continuous" mechanism, sliding, mechanical, back to the operating position. The flexible tubing / heavy rod assembly is then moved down, to the position where the piercing charges 146, contained on system 144 of the selective ignition / triggering ports, are directly transverse to the second, deepest area. , where a precise depth adjustment is again established, based on the readings from the detector 128 of column connections and the systems with a flexible tubing travel meter.

- the piercing loads 146, of the second set, are selectively switched on / off, by remote action, by means of the second selective ignition head 142, to break through the column 82 of the pipe and the shell / ring 84 of cement and establish a hydraulic communication with an 86 formation, through some perforations 240 ... 241 resulting.

RO 121145 Β1

- As shown in FIG. 3B, the flexible tubing can be moved down the hole of 1 well, to position the BHA heavy rod assembly with a few feet under the perforation

241 deepest of the second target area. The subsequent displacement of the assembly of 3 heavy BHA rods upstream of the borehole, to position the hole 114 of direct circulation under the perforation 241 the deepest of the second target area, will cyclically bring the mechanical clamps 124 5, reachable, into the pre-locking position, where a subsequent downward movement will force the retractable grips 124, in the locking position, thus preventing 7 further downward movement.

- As shown in FIG. 3C, a downward displacement engages fittings 124 of 9 mechanical fasteners, retractable, with the wall of the pipe column 82, thus preventing further downward movement of the BHA heavy rod assembly. A pressure-horn load is then applied to the flexible tubing and this load closes the circulation connection hole 114 and the equalizing hole 116, and creates a pressure communication 13 between the retractable, expandable pacer 120 and the flexible tubing pressure, interior. Said compression load also blocks the opening of the connection 114 of movement 15 in a position directly below the deepest perforation 241 of this second target area, to minimize the possibility of the supporting material filling the space of 17 above the packer 120 removable, expandable, and to minimize the flow of the support material, at high speed, beyond the heavy rod assembly and the expandable pack, 19 retractable, positioned between the first perforated interval and the second perforated interval.

18-0 another compression load is applied downwards, on the flexible tubing / 21, the assembly of heavy rods, to try the mechanical grips 124, retractable, and to be sure that an additional downward force does not translate 23 through a further movement of the BHA heavy rod assembly down the borehole.

- As shown in FIG. 3D, the retractable, expandable pacifier 120 is actuated 25 by pressurizing the flexible tubing 106, to perform a hydraulic seal above and below the retractable and expandable pacifier 120. A compression load 27 is maintained on the BHA heavy rod assembly to maintain the pressure communication between the flexible, internal tubing pressure and the retractable, expandable pacifier 120, to hold the circulation port 14 and the equalization port 116, higher. , closed, and holding the mechanical grips 124, retractable, in the actuated and locked position, 31 mentioned. The retractable, expandable pacer 120 is maintained in the actuated state, by maintaining the pressure in the flexible tubing 106, by means of a 33 pump system, from the surface, it is mentioned, as an alternative, that the retractable, expandable pacer could be maintained. In an actuated state, by blocking the pressure in the element that uses 35 an internal valve, remotely actuated, from the surface, by means of a signaling means compatible with other components of the BHA heavy rod assembly and another 37 signaling means , present.

The second stage of the fracture stimulation treatment is initiated with fluid 39 pumped down the annular space between the flexible tubing 106 and the 82 column of tubing, at fracture stimulation rates, while maintaining the compression load on the entire 41 heavy BHA rods, in the sense of keeping the opening of the circulation connection 114 and the equalization hole 116, closed, and maintaining the pressure of the flexible tubing at a level sufficient for 43 to withstand the breaking resistance of the flexible tubing column, to keep the pacifier 120 retractable, expandable, in expanded condition and to serve as hydraulic sealing 45 between the pressure existing in the annular space above the packer, before, during and after the fracture operation, and the pressure existing in the borehole, sealed, below the packable, expandable packer 47 .

RO 121145 Β1

All sub-sections of the fracture operation are subjected to pumping, leaving a minimum sub-transfer of the last sub-section, loaded with supporting material, into the wellbore, so that no over-processing of the fracture treatment occurs.

If, during this step of the treatment, it seems that the packing integrity of the packer 120 is reachable, expandable, then this stage of treatment could be suspended temporarily, to try the packing sealing integrity of the packer, above, existing perforations, for example, perforations 240 of fig. 3D, after fixing the pack 120 reusable, expandable, in the raw pipe. If it is necessary to perform the integrity test of the seal, then it would be desirable to carry out a circulation / washing operation, in order to be certain that any supporting material, which may be present in the well hole, is circulated outside. drill hole, prior to testing. The circulation / washing operation could be performed by opening the hole of the circulation connection 114 and then pumping the circulating fluid down the flexible tubing 106, to circulate the support material, outside the well hole.

As shown in FIG. 3E, all sub-sections of the second fracturing operation are concluded with the creation of a second fracture 242 with supporting material.

After the end of the fracture operation of the second step and the cessation of the injection of stimulation fluid, down the annular space, formed between the flexible tubing 106 and the operating column 82, a small stretching load is applied to the tubing 106, while maintaining inner tubing pressure flexible.

The small extension applied isolates, first of all, the resealable, expandable pacer from the pressure of the flexible tubing, thus blocking the pressure of a resealable, flexible, expandable pacer 130, and thereby mentioning a positive pressure and printing a significant resistance to axial displacement. of the pack 120 reusable, expandable. In the same movement, the applied extension can then open the opening of the circulation connection 114 and the equalization hole 116, thereby allowing the pressure of the flexible tubing to be vented into the annular space formed by the flexible tubing 106 and the operating column 82, while it is allowed at the same time that the pressures existing above and below the retractable, expandable packer 120 are balanced. The pump of the surface system, which ensures the internal pressure of the flexible tubing, can be stopped after balancing the pressures from the probe sole.

- After balancing the pressures inside the flexible tubing, from the annular space formed by the flexible tubing 106 and the operating column 82, above the pacifier 120 removable, expandable, and from the annular space formed by the assembly of heavy rods and the operating column 82, under the retractable, expandable packer 120, a compression load applied by the flexible tubing will close the opening of the circulation connection 114 and the equalization hole 116, above, before releasing the pressure trapped inside the expandable packer 120, into the flexible tubing 106. This release of the internal pressure in the packer 120, expandable, will allow the respective packer 120 removable, expandable, to withdraw from the wall of the operating column, as shown in fig. 3F, in the absence of a difference of transverse external pressure on the retractable, expandable packer 120, which could otherwise cause forces and displacement that could damage the flexible tubing 106 or the BHA heavy rod assembly.

- At the same time with the packer 120 removable, expandable, it is detached, as shown in fig. 3F, an extension applied to the flexible tubing / heavy rod assembly could deactivate the mechanical fasteners 124, which allow the heavy rod assembly to be able to move and be repositioned upstream of the drill hole.

RO 121145 Β1

- If at the end of the second step of the stimulation treatment, the 1 support material in the wellbore prevents the flexible tubing / heavy rod assembly from moving immediately, then the fluid can be circulated through the hole of the circulation connection 114, 3 to wash over also completely drain the supporting material, in order to release the flexible tubing / heavy rod assembly and allow the 5 heavy rod assembly to move up, after releasing the removable, expandable pack.

- The process, as described above, is repeated until all the planned 7 zones are stimulated individually, fig. 3A to 3F is a set of heavy rods, built for three-zone stimulation. 9

- At the end of the stimulation process, the components of the BHA heavy rod assembly are returned to the running position and the flexible tubing assembly / 11 BHA heavy rod assembly is removed from the wellbore.

- If all the desired target areas have been stimulated, then the probe can be put into operation immediately.

- If it is desirable to stimulate some additional areas, then a flexible tubing coil can be prepared with a slightly modified heavy rod assembly, as shown in fig. 4A. In this assembly, the only modification to the BHA heavy rod assembly 17, according to the preferred embodiment described above, may consist of the addition of a mechanical stopper 164, to the selective ignition set, or to a bridge stopper 164 to the set 19, selective ignition, located below the lowest assembly of selective ignition ports, as shown in fig. 4A. Generally, the mechanical stopper 164 of the selective ignition set 21 may represent either a bridge stopper or a baffle / fracture deflector. A fracture slab would generally be preferred if separate zones 23 are desired to occur simultaneously with the plug, immediately after the stimulation work.

- Modified BHA heavy rod assembly, as shown in fig. 4A, consists 25 of a system of selective ignition drilling rifles, fig. 4A illustrates a rifle system comprising 174,184, and 194 drill bits, with loads 176,186 27 and 196, associated with selective ignition heads 172,182 and 192, a column connector detector 128, holes 114,116 and 122 flow, a pacer 120 retractable, 29 expandable, a device 124 sliding, axial, mechanical, retractable, and a plug 164 with selective ignition bridge, fixed using a selective ignition head 162. The modified 31 BHA heavy rod assembly is inserted into the well, using a lubrication apparatus and a tubing injection head, suspended by a crane or drilling tower, above the well head. 33

- Flexible tubing / heavy rod assembly is inserted into the probe, while the depth is correlated with the column connection detector. 35

- As shown in FIG. 4A, the flexible tubing / heavy rod assembly is inserted into the probe to position the mechanical stopper 164, with selective ignition, above 37 of the last zone 252, previously stimulated.

- As shown in fig. 4B, the detonating head 162, with selective ignition, is triggered to fix the mechanical selective ignition plug 164 above the last previously stimulated zone 252. 41

- After the selective ignition cap-bridge head 162 is activated, to fix the selective ignition cap-bridge, the flexible tubing / heavy rod assembly is 43 then lifted, to a place inside the well hole, so that the first , the lowest, the set of 176 drilling loads, contained in the rifle system with selective ignition, be directly fixed transversely to the next target area, the lowest, which must be perforated, where a precise depth can be adjusted, based on readings from detector 128 of 47 connections

RO 121145 Β1 flexible tubing travel column and counter systems, located on the surface equipment. The action of moving the BHA heavy rod assembly up to the place of the first perforated range will cyclically actuate the mechanical, retractable, 124 grips in the locked position, and will require the cyclical actuation of the axial load of the flexible tubing, by compression and stretching, and conversely, to restore the mechanical fixing feathers, reachable, to the operating position.

As shown in FIG. 4B, the first set of drilling loads 176 on the BHA heavy rod assembly are selectively lit by remote actuation, using the second selective ignition head 172, to break through column 82 and cement sheathing / core 84 with some perforations 270,271 and to establish a hydraulic communication with the 86 formation, through the resulting perforations 270 - 271.

If there is not enough space between the last perforations 250-251, previously placed, and the place of the next set of perforations 270,271, which must be stimulated, in order to allow the proper placement of the BHA heavy rod assembly, for drilling, isolation and stimulation of the for the next set of perforations 270, then the stopper 164 for selective ignition can be fixed below the last perforations 250, 251, previously stimulated, and the reusable, expandable pacer can be used during the first stimulation operation, to isolate the perforations 270. .271, the highest, compared to perforations 250,251, previously stimulated.

The entire process, as described above, is then repeated, as appropriate, until all planned areas are individually stimulated, fig. 4A and 4B represent a set of heavy BHA rods. built for a further stimulation operation of a number of three areas.

Those skilled in the art will recognize that the preferred suspension method, when fluids with support material are involved, is conventional joint tubing or elastic tubing, preferably with one or more circulation holes, so that the material deposits support from the borehole can be easily circulated outside the borehole. Some treatments, for example, fracturing or matrix acidification, may not require such capacity and could be easily performed, with a cable-based deployment system, for example, a cable line, or based on the displacement means at the bottom of the probe.

Those skilled in the art will recognize that, depending on the objectives of a particular work, various pumping systems may be used and the following arrangements may be involved: (a) pumping down the annular space, created between cable or tubing, if the method of deployment uses cable or tubing and the column wall; (b) pumping down, within the flexible tubing or joint tubing, if the suspension method involves the use of flexible tubing or joint tubing and excessive rubbing or erosion with supporting material would not be a concern for the well depths considered; or (c) simultaneous pumping down the annular space created between the tubing (if the deployment method involves tubing) and the wall of the tubing column, and inside the tubing if excessive wear and erosion with supporting material would not be a concern for the depths of the tubing. well, considered.

Fig. 5 illustrates a second embodiment according to the invention, in which the tubing is used as a means of deployment, excessive wear is not a concern and neither the support material, which is not pumped during the work, nor the use of support material a concern. Fig. 5 shows that the flexible tubing 106 is used to suspend the BHA heavy rod assembly and the components of the BHA heavy rod assembly. In this embodiment, the individual areas are treated in successive order, from places located above the surface, of the borehole, to places located at depth

RO 121145 Β1 larger, of the borehole. In this embodiment, as shown in FIG. 5, 1 the orifice of the circulation connection 114 is now placed under the retractable pacifier 120, so that the treatment fluid can be pumped down, inside the flexible tubing 3 106, it can exit the hole of the circulation connection 114 and can be forced in a manner. sure to get into the targeted perforations. As an illustration of the operations, FIG. 5 shows that the retractable, expandable pacer 120 5 was actuated and fixed under perforations 242 which are associated with a fracture 242 of an anterior area. The retractable, expandable pack 120 provides hydraulic insulation 7, so that when the treatment fluid is successively pumped down the tubing 106, said treatment fluid is forced to enter the perforations 230 and 231, 9 previously placed, and to create new 232 hydraulic fractures. The operations are then contained and repeated, as appropriate, for the desired number of areas and intervals of the formation. 11 Fig. 5 illustrates a second embodiment according to the invention, in which the tubing is used as a means of deployment, excessive wear is not a concern, nor is the supporting material 13, which is not pumped during the work, nor the use of supporting material. is a concern. Fig. 5 shows that the flexible tubing 106 is used to suspend the BHA heavy rod assembly and the components of the BHA heavy rod assembly. The individual areas are treated in order. In this embodiment, an expandable, double-packaged, 125-sealing mechanism 125 is used as a resealable sealing mechanism, and the hole of the circulation connection 114 is now placed between a sealing element, 19 expandable, upper, and a sealing element 123, expandable, lower. When the sealing member 121, expandable, upper, and the sealing element 123, expandable, lower, 21 are actuated, then the treatment fluid may be pumped down, inside the flexible tubing 106, to exit the opening of the connection 114 and it would then surely be forced to enter the targeted perforations. As an illustration of the operations, FIG. 6 shows that the sealing element 121, expandable, superior, and the sealing element 123, expandable, inferior, were 25 actuated and fixed transversely on the holes 241, which are associated with the next area to be fractured. The retractable, expandable pacer 120 provides hydraulic insulation, 27 so that when the treatment fluid is successively pumped down the tubing 106, said treatment fluid is forced to enter the perforations 240 and 241, previously placed, 29 and create new 242 hydraulic fractures. The operations are then continued and repeated, as appropriate, for the desired number of areas and intervals of the formation. 31

Fig. 7 illustrates a fourth embodiment according to the invention, where a line

102 cable is used as a deployment means to suspend the 33 BHA rod assembly and the components of the BHA rod assembly. The individual zones are treated in any successive order, from places located above the surface of the borehole, to places 35 located at greater depth, of the borehole. In this embodiment, as shown in FIG. 7, the treatment fluid can be pumped down the annular space, formed between the line 37 102 of the cable and the wall of the operating column, and can be safely forced to penetrate the targeted perforations. In this embodiment, the retractable, expandable pack 120 also contains a system 117 with electric pump, driven by electricity, transmitted to the probe sole, through the cable line, to inflate or deflate the expandable, expandable pack 120 41, using fluid from the borehole. Fig. 7 shows that the retractable, expandable pacer 120 was actuated and fixed under the perforations 241 which are associated with the next area 43 to be fractured. The retractable, expandable pack 120 provides hydraulic insulation so that, when the treatment fluid is subsequently pumped down the annular space 45, between the cable line 102 and the operating column 82, the treatment fluid is forced into the perforations 240 and 241 and create new 242 hydraulic fractures. The operations are then 47 continued and repeated, as is appropriate for the number of formation areas and intervals desired. 49

RO 121145 Β1

A fifth embodiment according to the invention involves the deployment of additional gaskets or tubing, hereinafter referred to as connecting elements, internal and / or external to flexible tubing or joint tubing. As shown in FIG. 8A and FIG. 8B, a tubing member 104 is shown to be held within the flexible tubing 106. In this embodiment, the tubing member 104 is connected to the sealing mechanism 120, releasable, and the sealing mechanism 120, releasable, is now actuated by means of the hydraulic pressure transmitted through the connecting element 104. In general, several connecting elements may be deployed, each within the flexible tubing and / or in the annular space between the flexible tubing and the operating column. In general, the connecting elements may be used to perform a number of different operations, including, but not limited to, the provision of: (a) hydraulic communication of the BHA rod assembly, which includes, but is not limited to, the sealing mechanism and / or the drilling device; (b) flow pipes for injection into the sole of the probe or circulation of additional fluids; and (c) for data collection from measuring devices from the probe sole. It is mentioned that, as shown in fig. 8A, the BHA rod assembly also includes centrifuges 201,203 and 205, which are used to hold the BHA rod assembly centered in the bore hole, when said BHA rod assembly centered in the bore hole is in position. Operating. The use of a connecting element (s) can ensure the possibility of hydraulically coupling and / or disconnecting the mechanical sealing mechanism, irrespective of the hydraulic pressure situation inside the flexible tubing. Then, it allows the method to be extended to the use of a mechanically resealable sealing mechanism that requires independent hydraulic actuation for operation. Drilling devices, which require hydraulic pressure, for selective ignition, can be operated by means of a connecting element. It can then allow the cable line, if deployed with the flexible tubing and the BHA rod assembly, to be used to transmit a channel or channels of electrical signals, when it may be desirable to collect data from the measuring devices located on the heavy rod assembly; or actuating other components of the BHA rod assembly, for example, an electric drive motor at the bottom of the probe, which could provide rotation / torque for components of the BHA rod assembly. Alternatively, a connecting member could be used to operate a hydraulic motor, to actuate various components at the probe sole, for example, a hydraulic motor, to engage or disengage the reseatable sealing mechanism.

The use of a linking element (s) may provide the ability to inject or circulate any fluid from the probe sole to multiple locations when precise control is desired. For example, to help reduce the deposition of the support material on the sealing mechanism, during a hydraulic fractionation treatment with the support material, a linking element (s) could be deployed and used to ensure an independent wash or circulation, continuous or intermittent, in order not to allow the support material to accumulate on the sealing mechanism. For example, one connecting element could operate even above the mechanical sealing mechanism, while the other could operate just below the mechanical sealing mechanism. Then, if a fluid is desired, for example nitrogen, it could be circulated at the bottom of the probe, at any or both places, to wash the supporting material, from the area surrounding the sealing mechanism and thus mitigate the possibility of blocking the BHA rod assembly. due to the accumulation of supporting material, in the case of a fluid flow, it will be remembered that the size of the connecting element and the fluid will

EN 121145 Β1 be chosen, in order to be certain that the desired flow is achieved and that it is not exaggeratedly limited by the frictional pressure of the respective connecting element.

In addition to the connecting elements, contained in the tubing seals, which provide 3 hydraulic communication at the probe sole, as signaling means, for actuating the components of the BHA heavy rod assembly or, possibly, as a means for transmitting 5 signals, for the purpose surface recording of devices from the probe sole, in general, one or more cable lines or fiber optic cables could be deployed in the probe hole to provide electrical or electro-optical communication at the probe sole, as a signaling means, for actuating the components of the 9 BHA heavy rod assembly, or possibly as a means of transmitting the signal, for surface recording of the apparatus from the probe sole. 11

Fig. 9 illustrates a sixth embodiment according to the invention, wherein a displacement system, comprising a displacement system transmission unit 131, upper 13, and a lower displacement system transmission unit 133 is attached to BHA heavy rod assembly and is used to deploy and position the 15 BHA heavy rod assembly within the borehole. In this embodiment, the individual zones are treated in successive order, from deeper places, of the wellbore, to 17 places located above the surface, of the wellbore, the treatment fluid being pumped down the annular space, between the line 102 cable and wall 82 of the operating column, and 19 is certainly forced to enter the targeted perforations. Fig. 9 shows that the retractable, expandable pack 120 was actuated and fixed under the perforations 241, which are associated with the next 21 area to be fractured. The retractable, expandable pacer 120 provides hydraulic insulation such that when the treatment fluid is subsequently pumped down the annular space 23 between the cable line 102 and the operating column 82, the treatment fluid is forced to enter perforations 240 and 241 and to create new 242 hydraulic fractures. The operations are then 25 continued and repeated, as appropriate, for the desired number of zones and intervals of the formation. 27

As an alternative to this sixth embodiment, the displacement system could be self-propelled, controlled by means of electronic computer systems, from 29 desks, and could carry signaling systems at the desks, so that it would not be necessary attach cable or tubing, for positioning, controlling and / or actuating the displacement system. Moreover, the various components of the BHA heavy rod assembly could be ordered using electronic computer systems, from the desk, and can carry signaling systems to the desk, so there is no need to attach cable or tubing. for control and / or actuation of components. For example, the placement system and / or the components of the BHA heavy rod assembly could carry electrical power to the desk, for example, batteries, electronic computer systems and 37 data transmission / reception systems, so that the components the displacement system and the BHA heavy rod assembly could be ordered either remotely, from the surface, with the aid of a remote signaling means, or, alternatively, the various computer systems at the desk could be programmed, at the surface, to execute the sequence of 41 operations desired, when performed in the wellbore.

In the seventh embodiment, according to the invention, abrasive or erosive fluid jets are used as a means for drilling the borehole. The application of abrasive or erosive fluid jets is a common method used in the oil industry to cut and drill tubing gaskets from the well of the well and other components of the well and from the well. The use of flexible tubing or joint tubing by suspending the 47 BHA heavy rod assembly provides a flow pipe for fluid jet cutting technology. 49

RO 121145 Β1

For its application, the BHA heavy rod assembly is configured with a hydraulic drilling tool. This hydraulic drilling tool allows high-speed and high-pressure abrasive / erosive fluid systems or suspensions to be pumped to the well's bottom, through the respective tubing and through the jet nozzles. This abrasive / erosive fluid cuts through the wall of the operating column and through the cement coating / ring and penetrates the formation, to ensure communication through the flow path with the respective formation. Some arbitrary distributions of holes and slots can be placed using this hydraulic drilling tool, until the interval is completed during the stimulation work. In general, abrasive / erosive fluid cutting and drilling can be easily performed in a wide range of pumping conditions, using a wide range of fluid systems, water, gels, oils and fluid, gas / liquid systems combinations, and with a multitude of solid materials, abrasives, sand, ceramic materials, etc., if the use of solid, abrasive material is required for the specific drilling application of the drill hole.

The hydraulic drilling tool replaces the classic, selective ignition, drill gun system, described in the previous six embodiments, and since this hydraulic drilling tool can have a length of one to four feet, the height requirement for the lubrication system, it is reduced to a large extent, to almost 60 feet or more, compared to the required height when using selectively triggered, classic, drilling piston assemblies as a drilling device. The reduction of the height requirement, for the surface lubrication system, provides a number of benefits, including cost price reductions and time reductions in operation.

Fig. 10 illustrates, in detail, a seventh embodiment of the invention, wherein a hydraulic drilling tool 310 is used as a drilling device and a combined tubing 302 is used to suspend the BHA heavy rod assembly in the wellbore.

In this embodiment, a resealable mechanical compressor 316 is used as a resealable sealing device; a 318 column connection detector, mechanically, is used for positioning and controlling the depth of the BHA heavy rod assembly, a reduction valve sleeve 304 with a one-way, full-opening flap type, is used to ensure that the fluid will not flow upstream of a joined tubing 302; a combined reduction sleeve 306 for instrumentation and drilling decoupling is used as a safety device for decoupling; a reduction sleeve 308 with a circulation / equalization port is used to provide a method of circulating the fluid and also of equalizing the pressure above and below a reusable pacifier 316, with mechanical compression, in certain circumstances; and a reduction sleeve 314, with one-way ball retainer, is used to be certain that the fluid can flow only upward, from the bottom of the retractable pack 316, with mechanical compression, to the reduction sleeve 308, for movement / equalization.

The hydraulic drilling tool 310 contains 312 flow holes, which are used to accelerate and direct the abrasive fluid, pumped down the tubing 302, to hydraulically drill, by direct hit on the operating column 82. In this configuration, the mechanical connection column detector 318 is suitably constructed and bonded to the mechanical compression packable 316, so as to allow fluid flow upstream from the bottom of a removable packer 316 with mechanical compression, towards a sleeve 308 with circulation / equalization holes. The cross-sectional flow area, associated with the flow pipes, contained within the circulation / equalization sleeve 308, are sized to provide a cross-sectional flow area,

RO 121145 Β1 substantially larger than the flow area associated with the stream flow ports 312, 1 such that most of the flow, within the joined tubing 302 or the BHA heavy rod assembly, preferably flows through reduction 308 with circulation / equalization holes, 3 only through the flow stream ports 312, when the reduction sleeve 308 with circulation / equalization holes is in the open position. The sleeve 308 with circulation holes / 5 equalization is opened and closed by axial displacement, up and down, of the joined tubing 302. 7 In this embodiment, the joined tubing 302 is preferably used with the mechanical compression packable 316, because the removable packer 316, fixed by mechanical compression 9, can be easily actuated and deactivated by vertical movement and / or a rotation applied via the joined tubing 302. The vertical displacement 11 and / or the rotation is applied by means of the jointed tubing 302, using a snubbing assembly and a winch for the production of the well, with the help of a hydraulic force head 13, as surface means for binding. , installation and removal of the combined tubing 302, in the well hole and outside it. It is mentioned that the machine 15 from the surface, the methods and the procedures associated with the use of an assembly of pressure descent (snubbing), with hydraulic head of force, are common and well known by 17 skilled persons in this field, for binding, installation and removing a tubing jointed in a / from a pressure probe hole. Alternatively, the use of a 19 winch / turret for the production of the well, with the help of a hydraulic force head, and a lowering head in the well, instead of the low pressure assembly, could help 21 binding, installation and removing the tubing jointed in a / from a pressure well hole; this is also well known to those skilled in the art in this field, for tying, installing and removing a tubing jointed in a / from a pressure well. It is further mentioned that the respective configuration with winch 25 / turret for the production of the well and pipes will include manifolds, piping assembly, valves etc., suitable distribution, pipes and valves for adapting the flow to and 27 between all components / adequate surface installations and well hole, which includes, but is not limited to, the joint tubing, the ring space between the joint tubing and the 29 operating column, pumps, fluid reservoirs and eruption beams / beams.

Because the compression-fastened retractable packer is actuated by vertical movement 31 of the coupled and / or rotating tubing 302, the fluid may be pumped down the coupled tubing 302, without the need for additional control valves and / or isolation valves, which 33 otherwise, they may be required if an expandable pack is used as a resealable sealing device. The inner of the jointed tubing 302 is thus used to provide an independent flow pipe between the surface portion and a hydraulic drilling tool 310 so that the abrasive fluid can be pumped down the joined tubing 302 to the tool 37. 310 hydraulic drilling. The jets 312 of the jets, located on the hydraulic drilling tool 310, then create the high-speed abrasive fluid jets, which are directed to 39 drilling the operating column 82 and the cement shell 84 / ring, to establish hydraulic communication. with formation 86. 41

Fig. 10 shows that the hydraulic drilling tool 310 was used to place perforations 320, in order to penetrate an interest interval of the first formation and that the interest interval 43 of the first formation was stimulated with hydraulic fractures 322. Fig. 10 further shows that the hydraulic drilling tool 310 was repositioned inside the borehole and used 45 to place the bore holes 324 in the range of interest of a second formation and that the removable pack 316, fixed with mechanical compression, was actuated for to provide a hydraulic seal 47 inside the borehole, before stimulating the perforations 324 with the fracture treatment, with hydraulic support material, on multiple stages. 49

RO 121145 Β1

It should be noted that the jets 312 of the flow of jets can be located within a length of about 6 holes to a pacer 316 of a leg, retractable, fixed with mechanical compression, so that after the pumping of the second billing stage, with support material, the accumulation of support material on the top of the resealable pacifier 316, fixed with mechanical compression, must be a concern, the abrasive and non-erosive fluid can be pumped down the flexible tubing 302 and through the flow holes 312 and / or reduction sleeve 308 with movement / equalization holes, as necessary to clean the support material on the top of the removable pack 316, fixed by mechanical compression. Furthermore, the hydraulic drilling tool 310 may be rotated when the compression-fastening, removable pack 316 is not actuated, using the coupled tubing 302, which can be rotated with the head at the surface, to further assist in cleaning. the accumulation of support material, which may occur above the retractable pack 316, fixed by compression. Because there are no burrs present, to potentially produce wear and tear on the elastomers of the removable pack 316, fixed by mechanical compression, the service life of the packable 316 pack, fixed by mechanical compression, can be increased compared to applications where they can exist. drill holes.

Further, it will also be noted that the flow control, provided by the reduction sleeve 314 with ball valve and the reduction sleeve 304, of the type with total, one-way control flap, allows only pressure equalization. above and below the resealable pack 316, fixed by mechanical compression, when the pressure below the resealable pack 316, fixed by mechanical compression is greater than the pressure above the respective resealable pack 316, fixed by mechanical compression. In those situations, when the pressure above the resealable pack 316, fixed by mechanical compression, may be greater than the pressure below the resealable pack, fixed by mechanical compression, the pressure above the resealable pack 316, fixed by mechanical compression, may be slightly reduced by performing a regulated countercurrent of the barely stimulated area, using the annular space between the combined tubing 302 and the operating column 82; or by the circulation of a low density fluid, for example, nitrogen, downstream of the combined tubing 302 and upstream of the annular space, between the joined tubing 302 and the operating column 82.

The reduction valve sleeve 304, of the type with total, one-way retention valve, is preferred, as this type of construction adapts to unrestricted pumping of abrasive or erosive fluid to the sole of the well and, moreover, allows the passage of some adjustable balls, which, depending on the specific construction, of the components of the individual BHA heavy rod assembly, can be dropped from the surface to adjust the fluid flow and hydraulic regime of the components of the BHA heavy rod assembly or assures the safe decoupling of the BHA heavy rod assembly. Depending on the specific tool construction, different valve placement configurations can be performed to ensure the functionality provided by the flow control valves, described in this embodiment.

As an alternative to this seventh embodiment, a reduction sleeve could be included, which would contain a nipple that could provide the ability to suspend and secure other metering devices or components of the BHA heavy rod assembly. This nipple, for example, could secure a column connection detector and a gamma radiation tool, which is deployed through the cable line and placed in the respective nipple, to provide additional diagnostics of the position of the

RO 121145 Β1 heavy BHA poles and place of interest intervals of the formation. In addition, 1 hydraulic, abrasive, multiple drilling tools can be deployed as part of the BHA heavy rod assembly, to control cutting characteristics such as hole / slot size, 3 cutting speed, for to adapt various abrasive materials and / or to ensure the redundancy of the system in case of premature failure of the components. 5

Those skilled in the art will understand that many different components can be deployed as part of the heavy rod assembly. The heavy rod assembly 7 may be configured to contain instruments intended for measurements on the properties of the reservoir, fluid and borehole, as appears to be desirable for a given application. For example, thermometers and manometers could be performed to measure the temperature and pressure conditions of the fluid at the probe sole during treatment; a densitometer could be used to measure the effective density of the fluid at the probe sole, which would be particularly useful for determining the distribution and placement of the support material at the probe sole, during a fracturing treatment with hydraulic support material; and a radioactive detection system, for example, a gamma or neutron beam measuring system could be used to locate hydrocarbon carrier areas, or to identify or locate radioactive material within the borehole or formation.

Depending on the components of the specific heavy rod assembly, and whether the drilling device 19 produces holes with burr holes, which may damage the sealing mechanism, the heavy rod assembly could be configured with a tool for removing 21 burrs. from the perforations, which would act to scratch and remove the burrs of the perforations from the column wall. 23 depending on the components of the heavy rod assembly, specific, and whether excessive wear of the components of the heavy rod assembly may occur, in case 25 that said assembly operates in contact with the wall of the pipe column, then on the pipe assembly. heavy poles, centering sleeves could be deployed to provide precise mechanical positioning of the assembly and prevent or minimize the possibility of damage due to the operation of the assembly in contact with the wall of the column 29 of the tubing.

Depending on the components of the specific, heavy rod assembly, and whether 31 piercing loads produce strong shock waves and exaggerate vibrations when detonated, the heavy rod assembly can be configured with vibration damping reductions / shocks / shocks. caused by the detonation of drilling charges.

Depending on the deployment system used and the objectives of a particular work, 35 drilling devices and any other components of the BHA heavy rod assembly may be positioned either above or below the sealing mechanism, retractable, and in any desired order, against each other. The deployment system, whether it is cable line, power line, flexible tubing, conventional joint tubing, or a displacement system 39 at the bottom of the probe, can be used to carry signals, in order to activate the sealing mechanism and / or the drilling device. It would also be possible for such 41 signaling means to be suspended within the conventional joint tubing or flexible tubing, used for suspending the sealing and drilling devices themselves. 43

Alternatively, the signaling means, whether it is electric, hydraulic or other means, could be inserted into the well hole, outside the suspension means, 45 or incorporated or contained by one or more flexible tubing columns or tubing combined, classic. 47

RO 121145 Β1

Regarding the treatments that use systems with high viscosity fluids, in probes deeper than about 8000 feet, it is mentioned that by applying this new invention, some important technological and economic advantages are immediately obtained.

Reducing pressure limitations by rubbing allows the treatment of deeper probes and reduces the requirement regarding the special compositions of fracturing fluids. The frictional pressure limitations are reduced or eliminated because the high viscosity fluid can be pumped down the annular space between the flexible tubing, or other means of attachment, and the operating column. Because the frictional pressure limitations can be reduced or eliminated, compared to those produced when pumping down high viscosity fluid systems, inside the flexible tubing, it turns out that, where this method can be applied, they can be implemented. substantially increased depths. For example, assuming a flexible tubing of 1 1/2 inches carried out in a tubing column with an outer diameter of 5 1/2 inches, at 17 decks / foot, it turns out that the effective flow area, in cross-section, is equivalent to a pipe column having an outer diameter of 5 inches. With this effective flow area, in cross section, well depths of the order of 20,000 feet or more could be treated and higher pumping rates could be achieved, for example, of the order of 30 barrels / minute or more. large, efficient, hydraulic fracturing support material transport, using high viscosity fluids.

Because the typical annular space can have a larger equivalent flow section, conventional fracture fluids, as opposed to special low viscosity fluids, for example ClearFrac fluid, from Dowell - Schlumberger, can be used to reduce pressure drop. by rubbing through flexible tubing. The use of conventional fracturing fluid technology would then allow the formation of formations with temperatures above 250'F, beyond which special fluids, available at high costs, may begin to degrade.

The sealing mechanism used could be an expandable device, a resealable pacer, with mechanical compression fastening, a double pacer construction, with mechanical compression fastening, sealing sleeve devices or any other removable removable device alternative. by means of a suspension means and can provide a hydraulic sealing capacity or an equivalent function. There are both expandable and compression-fastening devices that provide radial clearance between the sealing gasket and the pipe column wall, for example, on the order of 0.25 inches to 1 inch, for expandable devices, or 0.1. ..0.2 bolts, for devices fixed by compression, so that the sealing wear would be drastically reduced or completely eliminated, in a preferred embodiment according to the invention, there would be sufficient clearance between the sealing mechanism, in the deactivated state, and the wall of the tubing column, to allow a rapid movement, at the inlet and outlet of the well, without significant damage to the sealing mechanism or without pressure control problems in relation to the pulsation / piston regime in probe, determined by the movement of the tool. The increased clearance between the sealing surface and the wall of the tubing column, when the sealing is not actuated, would also allow flexible tubing for the assembly of heavy rods to circulate, at the inlet and outlet of the wellbore, at much higher speeds than it is. possible with currently available tubing systems. In addition, in order to minimize the possibility of unwanted wear to the sealing system, in a preferred embodiment, the drilling device must conduct the tubing column wall piercing in such a way as to obtain a perforated hole with an edge. relatively smooth. Alternatively, the sealing mechanism, releasable, with mechanical attachment, may not provide perfect hydraulic sealing and, for example, may have a small clearance around the circumference of the device.

RO 121145 Β1

This small play could be sized to provide a sealing mechanism, if desired, whereby the material forms a transverse bridge on the said small play and provides a seal that can be removed by fluid flow. Moreover, 3 depending on the specific application, it is possible that the stimulation operation can be performed in an economically viable form, even if a perfect hydraulic seal 5 with the respective sealing mechanism, is not obtainable, with mechanical fastening.

Because the drilling device is operated simultaneously with the sealing mechanism, which is retractable, all the components can be ordered in depth, at the same time, using the same measurement standard. This eliminates the depth adjustment problems 9 of the existing methods, when the drilling operations and the stimulation operations are performed using two different measuring systems, at different times 11 and at drill holes, different. A very precise depth adjustment can be achieved by using a pipe column fitting detector, which is the preferred method of depth adjustment 13.

the overall height of each of the individual perforated target ranges is not limited. 15 This contrasts with the problem of existing flexible tubing systems, which, using a device like the double pacer, limits the application to a height of 17 15 ... 30 feet of the perforated range.

As permanent deck plugs are not necessarily used, the cost and risk increase in the well bore associated with drilling operations to remove the deck plug are eliminated. 21

If a flexible tubing is used as a deployment means, it is possible that said flexible tubing gasket, used for the stimulation work, may be suspended in the 23 well head and used as an operating tubing gasket, which could lead at significant cost savings, by eliminating the need to mobilize 25 drilling towers at the well location, for the installation of a classic operating tubing gasket, contained in a combined tubing. 27

The sequence control of the areas to be subjected to the treatment allows the structure of the individual treatment stages to be optimized based on the characteristics of each 29 individual zones. Moreover, the possibility of suboptimal stimulation because new multiple zones are treated simultaneously, is effectively eliminated by the fact that there is only a set of 31 open perforations, exposed to each stage of treatment. For example, in the case of a hydraulic fracturing, this invention may minimize the possibility of over-washing / over-evacuation or suboptimal placement of the supporting material in said fracture. 35

Also, if a problem arises, so that the treatment needs to be completed, then the areas above the borehole, which should be stimulated, have not been compromised, 37 because they still need to be perforated. This is in contrast to the methods of stimulation with flexible tubing or ball sealing, where all perforations must be shot by shot, prior to the respective work. If flexible tubing is unsuccessful, it may be extremely difficult to effectively divert or stimulate a long production 41. In addition, if only one set of perforations is open above the sealing element, then the fluid can be circulated without the possibility of breaking the other 43 multiple sets of open perforations, located above the upper sealing element, as might be expected in the work. with classic flexible tubing. This can minimize 45 or eliminate fluid loss and damage to the formation, when the circulation pressure at the probe sole would thus exceed the pressure in the formation pores. 47

EN 121145 Β1 the entire treatment can be pumped in a single stroke, resulting in significant cost savings, as compared to other methods that require multiple works on the cable line or drilling tower, for inlet and outlet holes. between the treatment steps.

The invention can be applied in multi-step treatments, in wellboreholes, deflected and horizontal, typically, the other classical deviation technology, in wellboreholes, deflected and horizontal, is more demanding due to the fluid transport nature of the material. deviation, at long intervals, typically associated with drill holes, deflected and horizontal.

In the event that a sifting / sorting occurs during the fracture treatment, the invention provides a method of immediate circulation, outside the hole, of the fluid loaded with sand from the annular space, so that the stimulation operations can be resumed without having to handle flexible tubing / BHA heavy rod assembly outside the borehole.

The presence of the flexible tubing system provides a means to measure pressure at the bottom of the probe after perforation or during stimulation operations, based on pressure calculations involving the flexible tubing gasket under closed or low flow conditions.

The presence of the system with conventional tubing or flexible tubing, if used as a means of deployment, provides a means of injecting fluid into the probe sole, independent of the fluid injected into the annular space. This can be useful, for example, in additional applications, such as: (a) holding the sealing mechanism of the BHA rod assembly and the flow holes without accumulation of supporting material, this could cause the tool to be blocked by fluid pumping at the bottom of the well, at a nominal flow, to clean the sealing mechanism and the flow holes; (b) mixing applications from the bottom of the probe, as discussed below; (c) applying acid to the probe's sole during drilling to help clean and communicate the drill hole with the formation; and (d) independent stimulation of two zones, isolated from each other, by means of the resealable sealing mechanism. As such, if a tubing is used as a means of deployment, depending on the specific operations desired and the specific components of the heavy rod assembly, fluid at the probe sole may be circulated at any time; or only when the sealing member is activated, or only when the sealing member is not activated; or while the equalization holes are open or closed. depending on the specific components of the heavy rod assembly and the specific construction of the flow control valves at the bottom of the probe, when they can be used, for example, as integral components of the reduction sleeve with equalization holes, the reduction sleeve with circulation holes or the reduction sleeve with flow holes, flow control valve at the bottom of the probe, can be put into operation by cable line drive, hydraulic drive, flow drive, ratchet j, sliding sleeve or many others means known to those skilled in the art, who are responsible for commissioning and operating the flow control valves at the bottom of the well.

The drilling device may be part of the commercially available drilling systems. These rifle systems could include what will be referred to here as a selective ignition system, "so that a single set of perforator rifles is made up of multiple loads or sets of drilling loads. Each individual set of one or more drilling loads can be remotely and surface-controlled using electrical, radio, pressure or other drive signals. Each set of drilling loads can be designed, number of loads, number of kicks / kicks, hole size, penetration characteristics for optimal drilling of each individual area, which must be subjected to an individual step treatment. With the current technology of selective ignition rifles, there are commercially available rifle systems that could

EN 121145 Β1 allows 30 to 40 intervals to be drilled successively in a single stroke at the sole of the probe. The rifles can be pre-sized and built to ensure the ignition of multiple sets of perforations. The rifles can be placed anywhere on the heavy rod assembly, 3 including either above or below the sealing mechanism, retractable, with mechanical attachment. 5

Intervals can be grouped, for treatment, based on the properties of the deposit, for treatment design considerations or for equipment limitations. After every 7 groups of intervals, preferably 5 to about 20, at the end of a working day, often due to light conditions, or if sealing difficulties 9 are encountered in one or more areas, it would be preferable use a bridge stopper or other mechanical devices to isolate the interval group, already treated, from the next group 11 to be treated. One or more point plugs, with selective ignition set or fracture baffles, could be switched on, in connection with the heavy rod assembly and fixed 13 as desired, during the operation of placing the probe into production, for provide accurate mechanical isolation between perforated intervals and eliminate the need for commissioning of a separate cable line 15 to mount mechanical isolation devices or diversion agents between groups of fracture steps. 17 in general, the method according to the invention can be promptly used in an operating column, having a diameter of 4 1/2 holes to 7 holes, with punching systems and 19 sealing mechanisms, retractable, mechanical, available commercially and could be used in smaller or larger tubing columns, with mechanically sealed 21-ball sealing mechanisms, suitably constructed, for the respective tubing columns, smaller or larger. 2. 3

If selective ignition boreholes are used, each individual rifle may be 2 to 8 feet in length and may contain 8 to 20 of 25 boreholes, located along the borehole, with a load density comprised in a range of 1 to 6 strokes / feet, but preferably 2 to 4 strokes per foot. 27 in a preferred embodiment, a number of 15 to 20 individual rifles could be placed one above the other, so that the total length of the rifle system, 29 assembled, is preferably kept at less than approximately 80 to 100 feet. This total length of the shaft can be run in the borehole, using a 31 surface crane, readily available, and a lubrication system. Larger bore lengths could also be used, but many require additional or 33 surface equipment, depending on the total number of boreholes, which would constitute the complete drilling device. It is noted that in some unique applications, the lengths of the rifles, the number of 35 charges / shotgun, and the density of the blows could be higher or lower than specified above, because the construction of the final drilling system would be influenced by 37 specific characteristics of the formation, present in the wellbore to be stimulated.

In order to minimize the overall length of the rifle system and the heavy rod assembly 39, it may be desirable to use multiple, two or more load carriers, evenly distributed around and centered, welded or otherwise attached on tubing 41 flexible, or tied underneath the mechanical sealing mechanism. For example, if you wish to stimulate 30 areas, where each area is perforated with a 4 43 foot rifle, then a single set of rifles would result in a total length of approximately 150 feet, which would be inappropriate for to be manipulated on the surface. Alternatively, two 45 sets of rifles, located opposite to each other on the flexible tubing, could be deployed, where each assembly could contain 15 rifles, and the total length could be about 47 feet, which could be promptly maneuvered, on the surface, with existing crane and lubrication systems. 49

RO 121145 Β1

An alternative arrangement of the bore or the boreholes would be that one or more boreholes are located above the mechanically sealing mechanism. Two or more separate rifle assemblies may be attached in such a way that the loads are oriented from the components on the heavy rod assembly or flexible tubing. There could also be a single set with denser charged loads, and the ignition mechanism, built to simultaneously ignite / trigger only a subset of loads within a given range, probably all having a given phase orientation.

Although the drilling device, described in this embodiment, has used remote-triggered loads or hydraulic drilling to drill the pipe column and the cement coating / ring, some drilling devices, as an alternative, which include, but are not limited to, Take this, chemical dissolution, or drilling / milling devices could be used within the scope of this invention, in order to create a flow path between the wellbore and the surrounding formation. For the purposes of this invention, the term "drilling device" will be used broadly to include all of the above devices, as well as any actuating device, suspended in the borehole, in order to actuate the loads or other means of drilling, what can be driven by the pipe column or other external means to the heavy rod assembly, or the suspension method used to support the heavy rod assembly.

The heavy rod assembly could contain a motor at the bottom of the probe or another mechanism to ensure rotation / torque in order to adapt an actuation of the mechanical sealing mechanism, which requires rotation / torque, for actuation. Such a device in connection with an orientation device, for example, a gyroscope or a compass, may allow oriented drilling so that the drill holes are located in a preferred compass direction. Alternatively, if conventional, tubing is used, then rotation and torque may be transmitted to the probe sole, by direct rotation of the tubing using a rotating motion actuator, which may be prompt. available on classic wells intervention tower. Some instrumentation devices for measuring the conditions in the well, detector of connections of the pipe column, devices for measuring pressure, temperature and for other measurements, monitoring at the bottom of the well, in real time, the parameters of the stimulation work, the properties of the deposit and / or the performance the probe could also be deployed as part of the heavy rod assembly.

In addition to the mechanical, removable deflection device, other materials / deflection devices could be pumped to the probe sole during treatment, but not limited to these, including sealing materials, in the form of balls or macroparticles such as, for example, sand, ceramic material, supporting material, salts, paraffins, resins or other organic or inorganic compounds, or, as an alternative, fluid systems such as viscous fluids, gels, gelled fluids, foams or other chemically prepared fluids, or other diverting agents injection. The additional deflection material could be used to help minimize the duration of the stimulation treatment, as some time savings could be achieved by reducing the number of mechanical deflection device installations, while still deviating those capacities in the areas. multiple. For example, within a range of 3000 feet, where individual areas, separated by 100 feet, should be subjected to treatment, it may be desirable to use the mechanical, retractable deflection device, which works upward, with increases of 500 feet, and then to deviate, each of the six floors / steps with a diversion agent carried in the treatment fluid. Alternatively, multiple input techniques / methods, at multiple intervals, could be used as a subassembly of the overall range that is intended to be treated. Each of these changes could reduce the number of mechanical fasteners of the mechanical deflection device and probably extend its actual service life.

RO 121145 Β1

If a tubing gasket is used as a deployment means, the respective tubing 1 allows the mixing devices to be deployed at the bottom of the probe and the rapid application of the mixing technology. Specifically, the tubing gasket can be used to pump 3 chemicals to the probe sole and, through the flow holes in the heavy rod assembly, to subsequently mix with fluid pumped into the tubing, through the annular space of the 5 operating column. For example, during a fracturing treatment, it may be desirable to pump nitrogen or carbon dioxide to the probe sole in said tubing and it must be mixed with the treatment fluid at the probe sole so that a return can be adapted. flow aided with nitrogen or carbon dioxide. 9

This method and equipment could be used to treat wells, vertical, deflected or horizontal. For example, the invention provides a method of making multiple fractures, vertical or somewhat vertical, to intersect wells, horizontal or deviated. Such a technique / method could give the possibility of economically producing, in production, multiple drill holes from a single treatment launch site. Treatment of probes with multiple sides could also be performed where the deepest side is first treated; then fix a plug or actuate a sleeve to insulate this deepest side; then the next upward side of the borehole is treated 17; another sleeve is actuated to insulate this side; and the process is repeated for the treatment to be performed on the desired number of 19 sides, within a single borehole.

If selective ignition / trigger wells are used, although 21 are preferable in terms of maximizing the number of intervals that can be subjected to the treatment, the use of short wells, for example, with a length of 4 feet or less, it could, in some situations, limit the productivity of the well, by inducing an increased pressure drop in the near-well area of the well, compared to using longer wells. The productivity of the well could be similarly limited if only a short interval, for example, 4 feet in length or less, is drilled 27 using a hydraulic abrasive jet drill. The possibility of an excessive flow return with support material can also be increased, which leads to reduced stimulation efficiency 29. The flow return should preferably be executed at a low, regulated flow to limit a potential flow return with supporting material. Depending on the results of the flow return, rifle configurations with resin-coated support material or alternatives could be used to improve the effectiveness of the stimulation. In addition, if a tubing or cable is used, then, to help reduce a potential undesirable erosion exerted by the support material on the tubing or cable, due to the bursting of the fluid loaded with support material, when pumped into injection holes with lateral discharge, an isolation device can be installed, upwards, on the 37 head of the well. This isolation device may consist of a flange having attached a short tubing, which descends to the center of the probe head, up to a few feet below the 39 injection holes. The heavy rod assembly and the tubing or cable are inserted inwardly until the tubing of the insulation device. In this way, the tubing of the insulation device detaches the supporting material and isolates the tubing or cable from the direct impact of the supporting material. Such an insulation device would consist of a tubing of adequate diameter, 43 so that it promptly allows the largest outer diameter dimension, associated with the tubing or cable and the assembly of heavy rods, to pass unobstructed. 45 The length of the insulation device shall be sized so that in the event of a failure, the main, lower fracture valve may still be closed, and the probe head, maneuvered down, 47 as necessary, to remove the insulation tool. , depending on the stimulation fluids

EN 121145 Β1 and the injection method, an insulation device would not be necessary if there were no erosion concerns.

Although the tests on the operating conditions of the insulation devices did not show any erosion problems, depending on the construction of the work, there could be some risk of deterioration under the action of erosion, resulting in the tubing assembly of the insulation tool, resulting difficulties in removing it. If an isolation tool is used, a preferred practice would be to maintain the speed of hit on the isolation tool, substantially below the typical erosion limits, preferably below about 180 feet / s and, better, below approx. 60 feet / s.

Another concern with this method is that premature selection may occur if fluid displacement during pumping is not adequately measured because fracture of fluid loaded with support material may be difficult to initiate. , transversely to the next area to be perforated. It may be preferable to use a KCI or other fluid, or a non-gelled fluid system, for support, rather than a gelled support fluid, to better initiate fracturing of the next area. Pumping the work at a higher flow rate with unelected fluid, between floors / steps, to achieve the turbulent evacuation / pushing of the pipe column, will minimize the risk of selecting the support material. Also, contingency rifles, available on the toolkit, would allow the work to continue, after an adequate waiting time.

Although the embodiments analyzed above refer mainly to the beneficial effects of the process according to the invention, when applied to hydraulic fracturing processes, this fact should not be construed as limiting the invention, which is applicable to any situation in the invention. that drilling and drilling other drill operations in a single stroke is beneficial. Those skilled in the art will recognize that many modifications, not specifically mentioned in the given examples, will be equivalent, as a function, for the purposes of this invention.

The present invention will be described in connection with preferred embodiments thereof. However, to the extent that the following description is specific to a particular embodiment or particular use of the invention, it is intended to be illustrative only and should not be regarded as limiting the scope of the invention. On the contrary, the description is intended to cover all alternatives, variants and equivalents that are included in the spirit and scope of the invention, as defined by the appended claims.

The present invention provides a new method and equipment for perforating and stimulating multiple formation intervals, which allow a single area to be treated as an individual treatment step, while eliminating or minimizing the problems associated with the existence of methods with flexible tubing or joint tubing, and thus which provide a significant benefit over the existing methods.

Claims (40)

claims 1. Method of drilling and treatment of multiple intervals, from one or more underground formations, intersected by a well hole, characterized in that it consists of: a - conducting a heavy rod assembly (BHA), using a means of conducting inside said drill hole, said heavy rod assembly (BHA) being provided with a drilling device and a sealing mechanism, mounted one after the other. and whose displacement occurs simultaneously; B 121145 - positioning the heavy rod assembly, within the respective borehole, 1 such that the lower end of the assembly is below the lower target area, using a depth control device; 3 c - drilling of the previously established interval; d - displacing the sealing mechanism, said, so as to establish a hydraulic sealing of the target area, in the respective borehole; e - pumping a treatment fluid into said well hole and into the perforations 7 created by the respective drilling device, without removing the drilling device from the well hole; 9 f - decoupling the sealing mechanism, mentioned; and g - repeating phases b to f, for at least an additional range of those 11 or more subterranean formations, mentioned. Method according to claim 1, characterized in that said means for carrying out said heavy rod assembly is selected from a metal cable, a guide cable or another cable. 15 Method according to claim 1, characterized in that the means is a tubing gasket. 17 Method according to claim 1, characterized in that said sealing mechanism is actuated so as to establish a hydraulic seal below said perforated range. Method according to claim 3, characterized in that said tubing gasket 21 is chosen from a flexible tubing and a joined tubing. 6. Method according to claim 1, characterized in that the 23-rod (BHA) assembly is positioned inside said drill hole, using a depth control device, which can be a pipe column connection detector or a system. measuring from the surface. Method according to claim 1, characterized in that said punching device is a selective trigger punching gun, comprising multiple sets of one or more punching loads, with a shaped load; each 29 of said sets, of one or more loads, with shaped load, being controlled by electrical or optical signal, transmitted by a cable developed in the hole of 31 probe. Method according to claim 1, characterized in that said drilling device 33 is a hydraulic jet cutting device, which uses fluid pumped down said tubing gasket to establish a hydraulic communication path between said respective 35. well hole and one or more intervals of one or more underground formations. 37 Method according to claim 1, characterized in that said treatment fluid is pumped down the annular gap between the tubing gasket and the wellbore. 39 Method according to claim 9, characterized in that the treatment fluid is also pumped down said tubing gasket through the flow holes 41 provided in the heavy rod assembly (BHA) and through said perforations. Method according to claim 9, characterized in that a second treatment fluid 43 is pumped down said tubing gasket, through flow holes in said heavy rod assembly (BHA) and in said perforations. 45 Method according to claim 11, characterized in that said second treatment fluid is nitrogen. 47 RO 121145 Β1 Method according to claim 1, characterized in that the sealing mechanism is a retractable packer. Method according to claim 1, characterized in that the treatment fluid is chosen from an acid solution, an organic solvent or a suspension of the support material and a carrier fluid. Method according to claim 1, characterized in that, before the release of said sealing mechanism, at least one deflecting agent is deployed in said well hole, to block the further flow of the treatment fluid in said perforations. Method according to claim 15, characterized in that the deflecting agent, carried out in said probe hole, is selected from macroparticles, gels, viscous fluids, foams or ball-sealing agents. Method according to claim 1, characterized in that said sealing mechanism is actuated by hydraulic pressure, transmitted from the surface, by a spherical connecting element. Method according to claim 1, characterized in that said drilling device is actuated by hydraulic pressure, transmitted from the surface, by a spherical connecting element. Method according to claim 1, characterized in that said drilling device is actuated by hydraulic pressure, transmitted from the surface, through said well hole. Method according to claim 1, characterized in that said drilling device is actuated by hydraulic pressure, transmitted from the surface, by said tubing gasket. The method according to claim 1, characterized in that said heavy rod assembly (BHA) is repositioned inside the drill hole, before activating said sealing mechanism. 22. Method of drilling and treatment of multiple intervals, from one or more underground formations, intersected by a well hole, characterized in that the method comprises: a - conducting a heavy rod assembly (BHA) within said drill hole, said heavy rod assembly (BHA) being provided with a drilling device, a sealing mechanism and at least one pressure equalization means; b - the drilling of the set interval, from within the underground formation, previously established, by using said drilling device; c - performing the sealing mechanism, said, so as to establish a hydraulic sealing of the target area, in the respective borehole; d - pumping a treatment fluid into said drill hole and into the perforations created by the respective drilling device, without removing the drilling device from the drill hole; e - establishing a pressure communication between the portions above and below the sealing mechanism, mentioned, by at least one means of equalizing the pressure; f - decoupling the sealing mechanism, mentioned; and g - repeating phases (b) to (f), for at least one additional interval of those one or more underground formations, mentioned. RO 121145 Β1 23. Method of drilling and treatment of multiple intervals, from one or more 1 underground formations, intersected by a well hole, according to claim 1, in a variant, characterized in that said method comprises: 3 a - deployment to a heavy rod assembly (BHA), using a means within said drill hole, said 5 heavy rod assembly (BHA) being provided with at least one drilling device and at least one sealing mechanism, said drilling device drilling being positioned under the sealing mechanism, 7 mentioned; b - drilling a target range from underground formations, using at least one said drilling device; c - performing the sealing mechanism, said, so as to establish 11 a hydraulic sealing of the target area, in the respective borehole; d - pumping a treatment fluid into said well hole and into the perforations 13 created by said drilling device, without removing the drilling device from the well hole; 15 e - decoupling the sealing mechanism, mentioned; and f - repeating phases (b) to (e), for at least an additional interval of those 17 underground formations, mentioned. Method according to claim 23, characterized in that said drilling device 19 is devoid of a flow fluid flow channel. The method according to claim 22 or 23, characterized in that the heavy rod assembly 21 (BHA) is repositioned in said well hole and said sealing mechanism is actuated to establish a hydraulic seal below said respective range 23. The method according to claim 1, in another embodiment, wherein the multiple ranges of the formation include a target interval, the deepest, and target intervals, located sequentially further to the surface, characterized in that said method comprises: 27 a - carrying out a heavy rod assembly (BHA) within said drill hole, said heavy rod assembly (BHA) being provided with a drilling device 29 and a sealing mechanism, said drilling mechanism being positioned below said drilling mechanism. sealing; 31 b - drilling of the deepest target range of the underground formations; c - pumping a treatment fluid into the wellbore and into the perforations created in the 33th deepest target range, by the drilling device, without removing the respective drilling device from the wellbore; 35 d - positioning the heavy rod assembly (BHA) in the borehole and using said drilling device to drill the next target range, located 37 successively further aft, between the underground formations; e - repositioning the heavy rod assembly (BHA) in the borehole and actuating said sealing mechanism 39 to hydraulically isolate the perforations created in the next target range, successively located above the surface, from the perforated target range, the deepest; 41 f - pumping a treatment fluid into said drill hole and into the perforations created in the next target range, successively located further to the surface, by the drilling device 43, without removing said drilling device from said drill hole; 45 g - uncoupling the sealing mechanism; and h - the repetition of phases (d) to (g), for at least one additional interval, located 47 successively more above the surface, of the underground formations, in which the perforations created in at least one of the respective target intervals, located successively, at more surface, are hydraulically insulated 49, from the intervals perforated below. RO 121145 Β1 27. Drilling and treatment equipment of multiple intervals, from one or more underground formations, intersected by a well hole, used for the implementation of the method of claim 1 or 22, characterized in that it is provided with: a - a set of heavy rods (27, BHA), adapted to be deployed in the wellbore, by means of a conducting means (102), selected from a metal cable, a guide wire or another cable, the rod assembly (27, BHA) having at least one drilling device (134,144,154), for successive drilling of multiple intervals and at least one sealing mechanism (120); b - the sealing mechanism (120) is capable of establishing a hydraulic seal in the respective borehole and, further, capable of being disengaged, so as to release said hydraulic sealing, to allow the assembly of heavy rods (27, BHA) to move in a different position, inside the borehole, thereby allowing each of the multiple treatment intervals mentioned to be treated separately from the other treatment intervals. 28. The equipment according to claim 27, used for implementing the method of claim 1 or 22, in a variant, characterized in that it is provided with: a - a heavy rod assembly (27, BHA), having at least one drilling device (134,144,154), for successive drilling of said multiple intervals, at least one sealing mechanism (120) and at least one displacement device; b - the displacement device is capable of positioning the respective assembly of different heavy rods, in said drill hole; and c - the sealing device (120) is capable of establishing a seal in the respective borehole and subsequently capable of disengaging said hydraulic seal to allow said respective heavy rod assembly (27 and BHA) to move. in a different position, within the borehole, thereby allowing each of the multiple treatment intervals to be treated separately, from the other intervals subjected to the treatment. The equipment according to claim 27, in another embodiment, characterized in that the delivery means is a tubing gasket (106). The equipment according to claim 29, characterized in that said tubing gasket (106) is a flexible tubing or a joined tubing. The equipment according to claim 27, in another embodiment, characterized in that the carrying means (102) is selected from a metal cable, a guide cable or another cable. 32. The equipment according to claim 27 or 28, characterized in that it comprises a depth control means for positioning the assembly (27 and BHA) of heavy rods in the borehole, which may be a column detector (128) of the column. piping or surface measuring system. The equipment according to claim 27 or 28, characterized in that the sealing mechanism (120) is a retractable packer. 34. The equipment according to claim 27 or 28, characterized in that the drilling device (134, 144 and 154) is a selective trigger drilling rifle, comprising multiple sets, consisting of one or more drilling loads, with a shaped load; each of these sets, of one or more drilling loads, with the shaped load, being controlled and activated by an electrical signal, transmitted through a cable line (102), carried out in the wellbore. RO 121145 Β1 35. The equipment according to claim 27 or 28, characterized in that said sealing mechanism (120) is actuated by the hydraulic pressure, transmitted from the surface, through the well hole. 3 36. The equipment according to claim 28, characterized in that the drilling device (134, 144 and 154) is actuated by the hydraulic pressure, transmitted from the surface, 5 through the tubing gasket (106). 37. The equipment according to claim 28, characterized in that the drilling device 7 is a jet cutting device (312), which uses a fluid pumped down the tubing gasket, to establish a hydraulic communication path between the borehole. 9 and one or more intervals of those underground formations. The equipment according to claim 27, used for implementing 11 of claim 1 or 22, in another embodiment, characterized in that it is provided with; a - an assembly (27, BHA) of heavy rods, adapted to be deployed in said hole 13 of said probe, with the aid of a deployment means (102 and 106), said assembly (27, BHA) of heavy rods, having at least one drilling device (134,144 and 15 154), for the successive drilling of said multiple intervals, and at least one means of equalizing pressure (308); 17 b - the sealing mechanism (316), mentioned, is capable of establishing a hydraulic seal in the respective borehole, and the pressure equalization means (308) 19 being able to establish a pressure communication path, between the portions of the hole. probe, located above and below the sealing mechanism (316), and further, 21 the sealing mechanism (316) is capable of loosening the hydraulic seal, to allow the assembly (27 and BHA) of heavy rods to move into the a different position, within the borehole 23, thereby allowing each of the multiple treatment intervals mentioned to be treated separately from the other treatment intervals. 25 The equipment according to claim 27, used for implementing the method of claim 1 or 22, in another embodiment, characterized in that 27 is provided with: a - an assembly (27 and BHA) of heavy rods, adapted to be deployed in said borehole 29, by means of a deployment means, said assembly (27 and BHA) of heavy rods having at least one drilling device (134, 144 and 154) for 31 successively drilling the said multiple intervals, and at least one sealing device (120), the drilling device (134, 144 and 154) being positioned below the sealing mechanism 33 (120); and b - the sealing mechanism (120) is capable of establishing a hydraulic seal 35 in said well bore and subsequently capable of releasing said hydraulic sealing to allow the assembly (27 and BHA) of heavy rods to engage. move 37 in a different position, within the borehole, thereby allowing each of the said multiple treatment intervals to be treated separately from the other 39 treatment intervals 40. The equipment according to claim 39, characterized in that said perforating device 41 is devoid of a flow fluid flow channel.