Patent Grant
11346157
This application is a United States National Phase Application of International Application PCT/EP2017/062751, filed May 26, 2017, the entire contents of which are incorporated herein by reference.
The present disclosure relates to an abrasive suspension eroding system for the abrasive suspension eroding of a material, for example of a rock or a pipe element, in an existing borehole, to a borehole facility with such an abrasive suspension eroding system and to a method for the abrasive suspension eroding of a material in an existing borehole.
The abrasive suspension eroding system which is disclosed herein is applied for example in existing bores for hydrocarbon-based fossil energy sources such as oil or natural gas, in particular with regard to deep-sea bores, but also bores on land. After an exploitation of an energy source reservoir, specifically an existing bore must be reliably closed at a deep as possible point for the protection of the environment. Herein, the wells usually remain in the bore. The problem on closing the bore is often the fact that the wells laterally displace to one another or are pressed inwards and thus form a blockage, due to tectonic shifts and/or the lowering of the seabed (in particular with slanted and horizontal drill sections) due to the drilling. In order to prevent a leakage of oil or natural gas due to such damage to the well wall, a concrete plug must be placed distally of such damage. However, such damage also entails a blockage or narrowing of the well diameter, so that a section distally of such damage can no longer be reached by conventional tools for placing a concrete plug.
Common drill heads for milling/cutting open the well diameter at the location of damage, given bent wells or ones which are offset to one another, are deflected laterally out of their feed direction and bind. Such bound drill heads or tools which are inadvertently located in the well for other reasons, for instance seized packers, likewise represent a blockage and narrow or block the well, which in professional circles is denoted as a “fish”. The removal of a fish is called “fishing”.
Furthermore, a so-called drilling rig is necessary for the drilling and cutting with a drilling head. A drilling rig is a very large and costly construction on a drilling platform or drilling barge and is configured to carry out the actual borehole drilling and the placing of the wells. For this reason, is basically uneconomical to use such a large and costly construction to drill free existing wells, in order to then be able to close these.
The use of the abrasive suspension eroding system according to the invention disclosed herein, for removing a blockage or for fishing by way of abrasive suspension eroding, compared to common drilling heads on the one hand has the advantage that it is not influenced by way of wells which are bent or offset to one another, in the feed direction, nor does it bind. Furthermore, the abrasive suspension eroding system which is disclosed herein can also be used for radially eroding open wells, in order for example to ensure a radial anchoring of the plug. Concerning the abrasive suspension eroding system which is disclosed herein, for example a nozzle head which is described in WO 2015/124182 can be applied. On the other hand, what is particularly advantageous concerning the abrasive suspension eroding system which is disclosed herein is the fact that no expensive drilling rig is necessary, but a so-called coiled tubing system can be used. The coiled tubing system has a significantly smaller construction and significantly lower operating costs than a drilling rig. Concerning coiled tubing, a coiled steel tube, for example as drilling fluid conduit and/or for the removal of rock samples, is let down into an existing bore. The coiled tubing system can also be used on smaller barges or floating cranes and can therefore be applied more flexibly than a drilling rig. Although a torque transmission as is the case with a drilling rig is not possible via the coiled steel pipe in the case of coiled tubing, however this is indeed not necessary for the abrasive suspension eroding system which is disclosed herein.
According to a first aspect of the present disclosure, an abrasive suspension eroding system is provided, with an eroding unit which can be let down into an existing borehole, for producing a high-pressure erosion jet for the abrasive suspension eroding of material in an existing borehole, wherein the eroding unit is connectable to a drilling fluid conduit and is configured to produce a high-pressure erosion jet from a drilling fluid-abrasive agent suspension: It is not therefore necessary to lay a separate conduit for a water-abrasive agent suspension, but the abrasive suspension eroding system which is disclosed herein permits the use of the existing drilling fluid conduit of a coiled tubing system and the use of the drilling fluid as an abrasive agent carrier for the abrasive suspension eroding.
Drilling fluid, also called drilling mud, is a water-based or oil-based viscous liquid with particular characteristics which fulfill many functions on drilling for fossil energy sources, in order to efficiently convey drilled rock to the surface. For example, drilling fluid for this purpose can be structurally viscous or shear-thinning and/or thixotropic. Drilling fluid often has a greater density than water, for example by 1.5 fold or more. The system which is disclosed herein now appropriates such drilling fluid and gives it a further function, specifically as an abrasive agent carrier for the abrasive suspension eroding of material, for example in the form of a blockage, a narrowing or a well wall, by way of a high-pressure erosion jet consisting of a drilling fluid-abrasive agent suspension.
In particular, one or more outlet nozzles of the eroding unit can be adapted to the particular flow characteristics and/or to the density of the drilling fluid. For example, with a given inlet pressure, the diameter of the outlet nozzles of the eroding unit can be configured larger, for example by more than 50% or more compared to such outlet nozzles which are adapted to water-abrasive agent suspension operation, in order to achieve a necessary minimum exit speed. Alternatively or additionally, an additive can be added to the drilling fluid, said additive briefly rendering the drilling fluid less viscous for the abrasive suspension eroding.
In particular, the nozzle head of the eroding unit can comprise a single-piece face region which by way of openings forms the outlet nozzles which are therefore “integrated” therein. Due to the often high salt content in aggressive drilling fluid, it is indeed the nozzle head which is subjected to the danger of corrosion. On account of the integral design of the outlet nozzles in a carbide end-piece, which can comprise for example tungsten carbide on the surface, it is not only the exit nozzles but also the complete nozzle head which is much better protected from corrosion.
One or more high-pressure erosion jets of the eroding unit can exit the eroding unit at a high pressure of the drilling fluid-abrasive agent suspension of 100 to 2000 bar or more, preferably however in the pressure range of approx. 500-700 bar and erode a pressed-in or offset well, rock, a fish or any other blocking material, to the extent that a region which lies distally of the blockage can be reached with a tool for setting a plug. The high-pressure erosion jets can herein be directed radially obliquely outwards and rotate about a rotation axis, so that the erosion jets form a cone-surface-shaped eroding surface. Given a distal feed, this eroding surface can sweep a blockage or narrowing and advancingly erode this in accordance with the diameter of the cone-surface-shaped eroding surface. On eroding by way of the high-pressure erosion jets, the eroding unit is subjected to hardly any resistance-dependent or angle-dependent recoil or lateral deflection. One or more erosion jets can be directed radially outwards and the nozzle head can be rotated about a concentric or eccentric rotation axis, in order to laterally erode open a well.
Optionally, the system comprises an abrasive agent supply unit which is fluid-connectable to the eroding unit via the drilling fluid conduit and which is fluidically connectable to the drilling fluid conduit upstream of a drilling fluid high-pressure pump. Alternatively, the abrasive agent supply unit or an additional abrasive supply unit can also be fluid-connectable to the drilling fluid conduit downstream of a drilling fluid high-pressure pump, wherein this abrasive agent supply unit then preferably comprises a pressure tank which is fillable with an abrasive agent. In the case of an abrasive agent supply unit which is arranged exclusively downstream behind the drilling fluid high-pressure pump, the drilling fluid high-pressure pump is not subjected to wear by way of the abrasive agent. However, since the refilling of a high-pressure tank with abrasive is basically more complex than refilling in a low-pressure region, the upstream arrangement of the abrasive agent supply unit in front of the drilling fluid high-pressure pump is basically preferred.
Optionally, the abrasive supply unit can be arranged upstream of a drilling fluid high-pressure pump and downstream of a supply pump, wherein the supply pump accelerates the drilling fluid and the abrasive agent is sucked into the drilling fluid due to the accelerated drilling fluid whilst utilizing the Venturi effect. Alternatively or additionally to this, the abrasive agent by way of gravity or assisted by gravity can run from a refilling funnel into a mixing chamber where the abrasive agent is mixed into the drilling fluid. Alternatively or additionally, the abrasive agent can be actively conveyed and/or mixed into the drilling fluid by way of a conveying device such as a conveying screw.
Optionally, the eroding unit can comprise a distal nozzle head section and a proximal anchoring section, wherein the nozzle head section is movable distally relative to the anchoring section. Herein, “distally” is to mean a position which is “deeper” with regard to the borehole direction and “proximally” accordingly a position which is “higher” with respect to the borehole direction. “Distally” therefore means in feed direction and “proximally” counter to the feed direction. By way of the distal movability, a defined feed advance of the nozzle head section can be ensured over a limited stretch during the abrasive suspension eroding. For this, the eroding unit can comprise for example a spindle or piston drive which is preferably driven in a hydraulic manner via the drilling fluid. Additionally or alternatively to a hydraulic drive with drilling fluid as a hydraulic fluid, another hydraulic fluid can possibly also be used, wherein the eroding unit is supplied with hydraulic power via a hydraulic conduit which is led parallel to the drilling fluid conduit, or a drive by way of an electric motor is provided, with regard to which the electric motor is supplied with electrical current via a cable which is led parallel to the drilling fluid conduit.
Optionally, the anchoring section can be anchored in an existing borehole in the rock and/or in a pipe element by way of first lateral anchoring elements. Herewith, the eroding unit can be fixed against axial oscillation, jamming and twisting. The anchoring elements can comprise for example three or more radial projecting toggle levers or spindles which are distributed at the peripheral side and which are radially supported against the well or the rock. After an eroding step, the nozzle head section can possibly be proximally retracted again or, by way of the retracting of the nozzle head section, the proximal anchoring section is “pulled” distally to the nozzle head section when this is indeed not anchored.
Optionally, the system can comprise a control unit which is signal-connected to the eroding unit and by way of which an anchoring of the anchoring section and/or a distal moving of the nozzle head section relative to the anchoring section is controllable. Alternatively or additionally, a nozzle head of the eroding unit or the eroding unit itself can possibly be pivoted with respect to the longitudinal axis, in order to follow a curve in the well or to steer the eroding more greatly onto one side. Such a pivoting can be controllable by way of the control unit. Alternatively or additionally, the cone angle of a cone-shaped eroding surface which is defined by the alignment of the outlet nozzles can be controllable by way of an adjustable alignment of the outlet nozzles by way of the control unit. Alternatively or additionally, the control unit can influence or control the erosion jets by way of one or more apertures or the like. Alternatively or additionally, the control unit can control the feed advance of the nozzle head with respect to the eroding unit and/or the feed advance of the eroding unit itself.
Optionally, the nozzle head section can be anchored in an existing borehole in the rock and/or in a pipe element in a distally extended position relative to the anchoring section by way of two lateral anchoring elements. Herewith, the eroding unit can be anchored in an existing borehole in the rock and/or in a pipe element by way of the two lateral anchoring elements, if the first anchoring elements are not anchored and vice versa. On anchoring the distal nozzle head section by way of the two lateral anchoring elements, a retraction of the nozzle head section into the anchoring section leads to the anchoring section being pulled distally if indeed the first anchoring elements are not anchored. The eroding unit can move through the bore in the manner of a caterpillar on account of this. Alternatively or additionally, the eroding unit can comprise advance elements such as wheels, chains, crawler legs, worm rollers or the like, in order to ensure a controllable feed advance of the eroding unit. Given vertical or slanted bores, the intrinsic weight of the eroding unit together with the drilling fluid conduit and other accessories can be utilized for the feed advance (drive). The eroding unit can preferably be coupled at the proximal side to a tool guide with feed elements, said tool guide being present at the distal end of the drilling fluid conduit and normally guiding a drill head, so that the eroding unit is advanced by way of the tool guide.
Optionally, the nozzle head section can comprise a distal nozzle head and a proximal nozzle head base, wherein the nozzle head is rotatable relative to the nozzle head base about a rotation axis. This rotation axis can lie concentrically or eccentrically to the longitudinal axis of tie nozzle head. An eccentric rotation has the advantage that the nozzle head can be configured smaller and that there exists more space for the away-transport of drilling fluid, abrasive agent and eroded material. As already described previously, a cone-surface-shaped eroding surface can be produced with one or more oblique erosion jets, in order to advancingly erode all material which is located within a cross section which is defined by the base surface of the cone-surface shaped eroding surface.
Optionally, the eroding unit can comprise at least one first outwardly directed nozzle and at least one inwardly directed second nozzle, wherein the at least one inwardly directed second nozzle has a distance to the rotation axis of the nozzle head. “Inwardly/outwardly directed” here can mean that the erosion jet out of the nozzle intersects the rotation axis or runs skew to this.
The eroding unit can optionally comprise at least two first nozzles which are aligned at a different angle with respect to the rotation axis, and/or at least two second nozzles, of which at least one is aligned such that the erosion jet intersects the rotation axis, and/or at least one is aligned such that the erosion jet runs skewly to the rotation axis. In order to achieve a maximal erosion performance, it is advantageous for each erosion jet to run at a different angle with respect to the rotation axis and to compliment the respective cone-surface-shaped eroding surfaces such that a maximal volume removal rate is achieved.
According to a second aspect of this disclosure, a borehole facility with a drilling fluid conduit and with an abrasive suspension eroding system which is described above is provided, wherein the eroding unit is fluid-connected to the drilling fluid conduit. Herein, the abrasive suspension eroding system preferably comprises an abrasive agent supply unit which is fluid-connected to the eroding unit via the drilling fluid conduit and which is fluid-connected to the drilling fluid conduit upstream of the drilling fluid high-pressure pump. The borehole facility therefore apart from the abrasive suspension eroding system comprises the drilling fluid conduit and preferably also the drilling fluid high-pressure pump.
According to a third aspect of the present disclosure, a method for the abrasive-suspension eroding within an existing borehole is provided, with the steps:
The method is preferably used with deep-sea bores for hydrocarbon-based fossil energy sources such as oil or natural gas if a well of a borehole is to be closed at a point which is not reachable with the necessary tool for closure on account of a blockage or narrowing. After the above steps and a successful erosion of the blockage or narrowing, a concrete plug can be set distally of this blockage or narrowing, in order to close the well for the reliable protection of the environment.
Optionally, the method further comprises a distal moving of a distal nozzle head section of the eroding unit relative to a proximal anchoring section of the eroding unit. Herewith, the nozzle head section can be moved distally in a defined manner during the eroding, in order to advancingly erode a certain volume. Herein, similarly to drilling with a drilled head, the eroded material as well as the abrasive agent which is used for eroding is floated or flushed to the surface by way of the drilling fluid.
The method can optionally comprise an anchoring of a proximal anchoring section by way of first lateral anchoring elements. Herewith, a defined position of the eroding unit can be kept during the eroding.
The method can optionally comprise an anchoring of a distal nozzle head section in a position which is extended distally relative to the anchoring section, by way of second lateral anchoring elements. Herewith, the anchoring section can be pulled distally to the nozzle head section in a following manner and a caterpillar-like advance realized.
Optionally, the method can comprise a controlling of the anchoring and/or of the distal moving by way of a control unit which is signal connected to the eroding unit. The control unit can be arranged above ground and control all functions of the eroding unit via an electrical, optical or hydraulic signal lead.
Optionally, the method can comprise a rotating of a distal nozzle head of the nozzle head section relative to a proximal nozzle head base of the nozzle head section about a rotation axis, wherein the rotation axis can run eccentrically or concentrically to the longitudinal axis of the nozzle head. As already described previously, a cone-surface-shaped eroding surface can thus be produced with one or more oblique erosion jets, in order to progressively erode any material which is located within a cross section which is defined by the base surface of the cone-surface-shaped eroding surface. An eccentric rotation of the nozzle head on the one hand has the advantage that the nozzle head, given the same sweep radius, can be configured smaller and on the other hand more space is present to the top for the away-transport of drilling fluid, abrasive agent and eroded material.
Optionally, the feeding of the abrasive agent into the drilling fluid conduit by way of the abrasive agent supply unit can take place upstream of a drilling fluid high-pressure pump. On account of this, one does not need to provide a pressure tank for feeding abrasive agent into the high-pressure region which lies downstream of the drilling fluid high-pressure pump, by which means a simple, continuous refilling of abrasive agent is rendered possible.
The disclosure is hereinafter explained in more detail by way of embodiment examples which are represented in the drawings. The various features of novelty which characterize the invention are pointed out with particularity in the claims annexed to and forming a part of this disclosure. For a better understanding of the invention, its operating advantages and specific objects attained by its uses, reference is made to the accompanying drawings and descriptive matter in which preferred embodiments of the invention are illustrated.
In the drawings:
Referring to the drawings, a deep-sea bore 1 in the sea bed 3 is shown in
In order to now be able to place a plug below or distally of the narrowing 6, the cross section at the narrowing 6 must be opened to such an extent that a suitable tool for placing a plug passes through it. Conventional solutions with a drill cutting head however are often deflected laterally at such a narrowing 6 and bind. For this reason, here an abrasive suspension eroding system is used in combination with a drilling fluid conduit 9 of a borehole facility 10, wherein the drilling fluid conduit 9 is normally envisaged for efficiently conveying drilled rock to the surface on drilling with a drilling cutting head. The drilling fluid conduit 9 is brought into the deep-sea bore 1 via a platform 7 of the borehole facility 10, here in the form of a ship. An eroding unit 11 is fluid-connected to the drilling fluid conduit 9 at the distal end of the drilling fluid conduit 9. The eroding unit 11 is positioned in the deep-sea bore 1 within the well 5 directly above the narrowing 6. The eroding unit 11 is mechanically coupled to the drilling fluid conduit 9 in a manner such that the eroding unit 11 is positionable from the platform 7 by way of rolling in and rolling out the drilling fluid conduit 9. Herein, the intrinsic weight of the drilling fluid conduit 9 and of the eroding unit 11 can be used in the distal direction or an advance device can be provided, in particular for the advance given horizontal or relatively non-steep sections of the stretch.
The eroding unit 11 comprises a distal nozzle head section 13 and a proximal anchoring section 15. The anchoring section 15 can be anchored by way of lateral anchoring elements 16, here in the form of toggle levers. The nozzle head section 13 is extendable in the distal direction relative to the anchoring section 15. A nozzle head 17 which is rotatable relative to a nozzle head base 19 of the nozzle head section 17 is located at the distal end of the nozzle head section 13. Several outlet nozzles are arranged at a face side of the nozzle head 17. The outlet nozzles are arranged such that exiting erosion jets form a jet fan. On rotation of the nozzle head 17, each erosion jet which encloses an angle with the rotation axis R sweeps a cone-surface-shaped eroding surface. Concerning erosion jets which have a radially inwardly directed component and which intersect the rotation axis R or run skew to this, an eroding surface in the form of an outer surface of a rotation body of two cones or truncated cones which lie on one another with their tips results.
The borehole facility 10 further comprises a drilling fluid return 14, through which the drilling fluid together with the eroded material and the abrasive agent is flushed to the surface to the platform 7. The drilling fluid thus runs through a circuit, wherein the drilling fluid which is delivered to the surface is separated from the eroded material and abrasive agent on the platform 7 and is processed for reuse.
In
In
With the embodiment in
In
Abrasive agent is added to the drilling fluid, so as to be able to use the drilling fluid which is available to the eroding unit 11 at a high pressure of 500-700 bar via the drilling fluid conduit 9 for abrasive eroding. In the embodiment which is shown in
For this, the drilling fluid-abrasive agent suspension together with eroded material such as eroded rock or the material of a fish or of a well wall can brought to the surface by way of a suction pump 41 via the drilling fluid return 14 which is received in the borehole 1. The suction pump 41 can possibly also only assist an already existing pressure difference and/or one which is produced by the drilling fluid high-pressure pump 25, said pressure difference pressing the drilling sludge upwards. The drilling fluid which is brought to the surface is led into a processing module 43. The processing module 43 comprises a shaker or shale shaker which separates the drilling fluid from rock, so that the drilling fluid can be recycled and can be led from the processing module 43 into the drilling fluid tank 39. Here, the processing module 43 also comprises an abrasive agent separator 44, so that the abrasive agent can also be reused and possibly in a direct manner can be fed again in wet or moist form or after a drying, to the circuit via the refilling funnel 37. Additionally to the abrasive agent, an additive such as long-chained polymers can also be admixed via the mixing chamber. Such long-chained polymers can be water-soluble and can serve for improving the focusing of the erosion jets or of the abrasive agent which is contained therein, for increasing the exit speed and for reducing the wearing in high-pressure components.
In the embodiment according to
On eroding, the nozzle head section 13 is extended distally relative to the anchored anchoring section 15 so that the cone-surface-shaped eroding surfaces sweep a volume of the fish 20, in order to hence advancingly erode this. In b), a maximal distal position of the nozzle head section 13 relative to the anchoring section 15 is reached, so that the rest of the fish 20 cannot be advancingly eroded if the eroding unit 11 is not advancingly driven. This can be effected via an advance device or, as is shown in c) and d), via second anchoring elements 53 which in the form of toggle levers are extended laterally out of the nozzle head section 13 and anchor the nozzle head section 13 in the well 5. The first anchoring elements 16 of the anchoring section 15 are retracted again. From c) to d), by way of retracting the anchored nozzle head section 13 into the anchoring section 15, one succeeds in the no longer anchored anchoring section 15 not pulling distally to the nozzle head section 13. The control unit 27 which controls all of this ensures a corresponding necessary feed of the drilling fluid conduit 9 and of the signal lead 23. In d), the nozzle head section 13 is then maximally retracted into the anchoring section 15, so that the second anchoring elements 53 can be retracted whist the first anchoring elements 16 can be extended again (see e)). In e), a further eroding step begins as in a) now for the remainder of the fish 20 at a deeper or more distal position. In f), the fish 20 has been completely advancingly eroded and the well section can be reached for placing the plug which lies below the (no longer existing) fish 20.
The numbered indications of the components or movement directions as “first”, “second”, “third” etc. have herein been selected purely randomly so as to differentiate the components or the movement directions amongst one another, and can also be selected in an arbitrarily different manner. Hence these entail no hierarchy of significance.
Equivalent embodiments of the parameters, components or functions which are described herein and which appear to be evident to a person skilled in the art in light of this description are encompassed herein as if they were explicitly described. Accordingly, the scope of the protection of the claims is also to include equivalent embodiments. Features which are indicated as optional, advantageous, preferred, desired or similarly denoted “can”-features are to be understood as optional and as not limiting the protective scope.
The described embodiments are to be understood as illustrative examples and no not represent an exhaustive list of possible alternatives. Every feature which has been disclosed within the framework of an embodiment can be used alone or in combination with one or more other features independently of the embodiment, in which the features have been described. Whilst at least one embodiment is described and shown herein, modifications and alternative embodiments which appear to be evident to a person skilled in the art in the light of this description are included by the protective scope of this disclosure. Furthermore the term “comprise” herein is neither to exclude additional further features or method steps, nor does “one” exclude a plurality.
While specific embodiments of the invention have been shown and described in detail to illustrate the application of the principles of the invention, it will be understood that the invention may be embodied otherwise without departing from such principles.
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/EP2017/062751 | 5/26/2017 | WO | 00 |
| Publishing Document | Publishing Date | Country | Kind |
|---|---|---|---|
| WO2018/215074 | 11/29/2018 | WO | A |
| Number | Name | Date | Kind |
|---|---|---|---|
| 4534427 | Wang | Aug 1985 | A |
| 5381631 | Raghavan | Jan 1995 | A |
| 7540327 | Billingham | Jun 2009 | B2 |
| 8757269 | Tabor | Jun 2014 | B2 |
| 20050173123 | Lund | Aug 2005 | A1 |
| 20120118562 | McAfee | May 2012 | A1 |
| 20130284440 | McAfee | Oct 2013 | A1 |
| Number | Date | Country |
|---|---|---|
| 2359037 | Aug 2001 | GB |
| 2015124182 | Aug 2015 | WO |
| Number | Date | Country | |
|---|---|---|---|
| 20200080383 A1 | Mar 2020 | US |
