Patent Application
20160201430
The invention concerns a method for isolation of a permeable zone in a subterranean well, for example in a petroleum well, water well or geothermal well. Moreover, the the method may be used in any type of subterranean well, including a production well, injection well, deviation well, horizontal well, etc.
More specifically, the invention concerns a method wherein a plug is established along a longitudinal section of a well, and substantially across a complete cross section of the longitudinal section, thereby preventing undesired fluid flow to or from a permeable zone in the well.
In, for example, a subterranean petroleum well, isolation of a permeable zone, or isolation between permeable and potential separate zones in the well, may prove essential to be able to control and optimize the course of production from the well. In the process of draining a permeable reservoar and/or weakening existing barriers for isolation between various reservoir zones, fluid streams within the reservoir may change. Such changes may arise by virtue of changing the composition of fluid components in the production stream and/or by virtue of the production stream decreasing or, at worst, ceasing. Further, such changes may arise when a production well extends through a subterranean reservoir and produces oil from an upper oil zone in the reservoir, whereas a lower zone of the reservoir contains water, also referred to as formation water. Usually, the oil will flow into the tubular production string of the well via well perforations formed within the oil zone. As the well production continues and the reservoir is drained for oil, a separating surface between underlying water and overlying oil in the reservoir will move gradually upward within the reservoir. Oftentimes, such a separating surface is referred to as an oil-water contact. Finally, the separating surface will come into contact with, hence in flow communication with, said well perforations, which define the well's influx region from the reservoir. Thereby, water from the reservoir will start to penetrate into the tubular production string via the well perforations and the influx region, which originally was formed exclusively within the oil zone of the reservoir. Thus, an increasingly larger proportion of water will be mixed together with oil during the course of production, whereby the production stream attains a gradually increasing water content during the course of production.
Moreover, if the production stream's pressure drop across the well perforations is of a certain magnitude, so-called water coning of said separating surface (oil-water contact) may arise around the influx region of the well. Such a water coning implies that the separating surface, due to said pressure drop, is lifted up locally around the well perforations. By so doing, water may flow into the well earlier than what would have been the case without such a water coning effect around the influx region of the well. Depending on the physical nature of the reservoir, especially in cases where the reservoir has a relatively low permeability, the oil-water contact of the reservoir may be comprised of a transition zone instead of a relatively sharp separating surface. In such a transition zone, as viewed from below and upward, a gradual transition from primarily water (high water saturation/low oil saturation) to primarily oil (low water saturation/high oil saturation) will exist, whereby the increasing influx of water during the course of production will be more gradual than the case would be when the oil-water contact is comprised of a relatively sharp separating surface.
Gas coning may also arise in a production well, wherein gas from an overlying gas zone may be caused, in a similar manner, to flow prematurely into the well at a particular pressure drop across the perforations of the well in the reservoir.
Both water coning and gas coning involve well-known production-related problems.
Further, a need may exist for isolating two or more permeable zones from each other in a well in order to prevent undesired fluid flow, so-called crossflow, in an annulus in the well. Such permeable zones may exist as adjoining zones, or as separate zones. Typically, said annulus will be an annulus between a pipe string, for example a tubular production string or a tubular injection pipe, and a surrounding borehole wall, i.e. surrounding rocks (formation) defining the borehole wall. In more rare cases, an outer and larger pipe string (pipe body) is used to define an outside of the annulus, whereby the annulus is located between an outer and inner pipe string in the well. Then, a further annulus will exist between the outer pipe string and the borehole wall of the well. Such an outer pipe string is typically used as reinforcement when a production/injection region of a well is located within weak and/or unstable reservoir rocks.
For example, preventing formation water from flowing from a permeable water zone and into a separate, permeable oil zone via such an annulus may be involved in context of such crossflow. It may also involve preventing the formation water from flowing, via the annulus, from the water zone and directly into a production stream from the oil zone. Conversely, it may involve preventing oil from flowing, via such an annulus, from a permeable oil zone and into a separate, permeable water zone.
In an injection well, for example a well for injection of water and/or another fluid into a subterranean reservoir, a similar need may exist for isolating one or more permeable zones in the reservoir. By so doing, the injection stream may be conducted into a desired reservoir zone, and via well perforations located vis-à-vis the reservoir zone. As such, it may involve conducting an injection water stream into, or in vicinity of, a permeable oil zone in a subterranean reservoir, thereby increasing the reservoir pressure and forcing more oil out of the reservoir. In context of such a course of injection, it is also possible to construe that a need may arise for moving the injection stream to one or more other permeable zones in the reservoir, for example to zones in, or in vicinity of, the oil zone of the reservoir. As such, a need may arise for isolating previous injection zones and replacing these with new injection zones in the reservoir. In such cases, too, isolation of a permeable zone, or isolation between various permeable zones, may prove essential to be able to control and optimize the course of injection in such a well.
A well barrier, for example a cement barrier, the purpose of which is to prevent said undesired fluid flow (crossflow) in an annulus between various permeable zones in a well, may also be exposed to large strains, i.a. in the form of substantial pressure- and temperature differences. As such, the well barrier may be exposed to violent forces, including tensile-, compressive- and torsional forces. It is known that such strains over time may cause damage to such a well barrier, whereby the integrity of the barrier, hence its isolation effect, is destroyed completely or partially. Thus, such undesired fluid flow (crossflow) may arise in annuli behind, for example, casings, liners, production pipes and injection pipes. This may reduce or render impossible, in the worst case, further production from, or possibly injection into, a subterranean well.
Accordingly, the object of the invention is to remedy or to reduce at least one of the disadvantages of the prior art, or at least to provide a useful alternative to the prior art.
The object is achieved by virtue of features disclosed in the following description and in the subsequent claims.
The invention concerns a method for isolation of a permeable zone in a subterranean well, wherein the well, at least in a portion where the isolation is to be carried out, is provided with a pipe body, wherein the method comprises the following steps:
(A) lowering a perforation tool into the pipe body onto a longitudinal section L1 of the well where the isolation is to be carried out;
(B) by means of the perforation tool, forming holes in the pipe body along the longitudinal section L1;
(C) by means of a flushing tool attached to a lower portion of a flow-through pipe string, and lowered into the pipe body onto the longitudinal section L1, pumping a flushing fluid down through the pipe string, out through at least one flow-through outlet in the flushing tool, into the pipe body and further out, via holes in the pipe body, into an annulus between an outside of the pipe body and a surrounding well body, thereby cleaning the annulus;
(D) pumping a fluidized plugging material down through the pipe string and out through the flushing tool, into the pipe body and further out into the annulus via holes in the pipe body;
(E) placing the fluidized plugging material along the longitudinal section L1 of the well, after which the plugging material forms a plug covering substantially a complete cross section T1 of the well, whereby the plug fills an inside of the pipe body and the annulus between the outside of the pipe body and the surrounding well body.
The distinctive characteristic of the method is that at least one of the at least one outlet in the flushing tool is angled non-perpendicularly relative to a longitudinal axis of the flushing tool, whereby a corresponding discharge jet from the flushing tool also will be non-perpendicular to the longitudinal axis of the flushing tool.
This configuration of the at least one outlet in the flushing tool ensures that a very effective flushing and cleaning of both the pipe body and the annulus outside the pipe body is achieved. This ensures good filling and good adhesion of the subsequent plugging material both in the pipe body and in the annulus.
Said pipe body may be comprised of a well pipe of a type known per se, for example of a casing or a liner. The pipe body may also be a part of a longer pipe string.
Further, said surrounding well body normally will be comprised of a borehole wall, i.e. of rocks (formation) defining the borehole wall, and then within the region of the well comprising said longitudinal section L1 to be isolated. This is discussed above.
In some cases, the surrounding well body may be comprised of another and larger pipe body, i.e. with a larger diameter, than the former pipe body, whereby a pipe-in-pipe constellation is present within this region of the well. This, too, is discussed above. In a production section or injection section of a well, however, it is relatively uncommon to use such an outer pipe body and an inner pipe body disposed in a pipe-in-pipe constellation in order to complete the well. If said longitudinal section L1 of the well comprises such a pipe-in-pipe constellation to be isolated, the perforation tool must form holes both through the inner and the outer pipe bodies along the longitudinal section L1 of the well.
Hereinafter, all references to a pipe body will relate to the primary pipe body, which will be the inner pipe body in a pipe-in-pipe constellation.
Yet further, said (primary) pipe body may be comprised of a tubular production string in a production well.
Alternatively, this pipe body may be comprised of a tubular injection string in an injection well.
Moreover, the present perforation tool may comprise a perforation gun of a type known per se. Such a perforation gun comprises explosive charges arranged in a desired manner for allowing a corresponding arrangement of holes to be made through the pipe wall of the pipe body. Other types of perforation tools or cutting tools may also be used in the present method, for example a water cutting tool based on abrasive perforation.
Such perforation or cutting through the pipe wall of the pipe body is appropriate to ensure good circulation of a plugging material from the inside of the pipe body and out into the annulus (possibly the annuli) at the outside of the pipe body. Provided the number, distribution and shape of the holes in the pipe wall are not sufficient to ensure good circulation for subsequent flushing and plugging, the perforation step may be carried out in an undamaged/unperforated portion of the pipe body, or against an already perforated portion of the pipe body. A preferred distribution of holes in the pipe body may be in the order of 12 holes per foot arranged in a 135/45 degree phase within said longitudinal section L1.
Upon forming a plug covering substantially a complete cross section T1 of the well, it is possible to isolate one or more permeable zones in a subterranean well. This may prove advantageous in, for example, a case where it is desirable to isolate a particular permeable zone, or where it is desirable to prevent undesired fluid flow (crossflow) in an annulus behind a pipe body in the well, for example in an annulus behind a tubular production string or a tubular injection string. For example, the case may be that a previously set barrier element has lost its integrity, whereby undesired fluid production from one permeable formation/zone to another permeable formation/zone takes place via such an annulus. Thus, a plug covering the complete cross section will be able to isolate the formation/zone, which is producing the undesired fluid flow, from the other, receiving formation/zone in the well. Various such well situations are also described in further detail above.
With respect to the prior art, it is know to establish a well plug by means of a method and a washing tool as shown and described in Norwegian patent application No. 20111641 entitled “Method for combined cleaning and plugging in a well, washing tool for directional washing, and use of the washing tool”. NO 20111641 corresponds to international publication WO 2012/096580 A1.
Unlike the washing tool according to NO 20111641 (and WO 2012/096580 A1), the present flushing tool is used both for flushing and plugging of the longitudinal section L1 of the well. In addition, the flushing tool is primarily intended for reuse and, further, may be readily modified for various well specific purposes.
Further, and before step (D), the present method may comprise disposing and anchoring a plug base in the pipe body, and below the longitudinal section L1 of the well. For example, the plug base may comprise a mechanical plug, and possible a packer element, of a type known per se.
If the longitudinal section L1 is located far from the bottom of the pipe body, it may be necessary to set such a plug base so as to form a base for the fluidized plugging material in the subsequent plugging operation, i.e. in steps (D) and (E) of the method. On the other side, if the longitudinal section L1 is located at a relatively short distance from the bottom of the pipe body, it may be unnecessary to set such a plug base in the pipe body. Instead, the fluidized plugging material is filled from the bottom of the pipe body and upward until the plugging material covers the longitudinal section L1 of the well.
Yet further, the flushing tool may comprise a first section for discharge of the flushing fluid, and a second section for discharge of the fluidized plugging material. Thereby, the first section may be arranged with an optimum configuration and size of outlets for optimum discharge of the flushing fluid, whereas the second section may be arranged with an optimum configuration and size of outlets for optimum discharge of the fluidized plugging material. In order to avoid potential setting and plugging of plugging material, outlets for the plugging material possibly may be larger than the outlets for the flushing fluid.
The flushing tool may also be formed with several outlets, wherein the outlets are angled within ±80° of a plane being perpendicular to the longitudinal axis of the flushing tool, whereby the discharge jets from the longitudinal axis of the flushing tool also are distributed within ±80° of said plane. This will prove particularly appropriate with respect to cleaning of the annulus (possibly the annuli) given, then, that it will be easier for the flushing fluid, having such angled discharge jets, to gain access to various places in the annulus, thus achieving an optimum flushing and cleaning effect in the annulus.
In this context, at least one of the at least one outlet in the flushing tool may be provided with a nozzle, for example a nozzle of a suitable size and/or shape. Thereby, several outlets in the flushing tool possibly may be of a particular size, whereas nozzles in the outlets may have different sizes and/or shapes, whereby the discharge jets from the nozzles may be different. By so doing, it is also easy to modify the flushing tool and its associated flushing effect in order to achieve the desired effect.
Yet further, step (C) of the method, i.e. the flushing step, may comprise rotating the pipe string whilst flushing, and/or moving the pipe string in a reciprocating motion whilst flushing. This may produce a very thorough cleaning on the inside and outside of the pipe body along the longitudinal section L1 of the well.
Further, the method may comprise adding an abrasive agent to the flushing fluid. Such an abrasive agent may comprise small particles of particulate mass, for example sand particles. Use of an abrasive agent in the flushing fluid may prove particularly appropriate if the annulus (possibly the annuli) outside the pipe body is completely or partially filled with, for example, cement residues, formation particles, precipitated drilling mud components and/or other casting materials or fluids. Such material may prove difficult to remove without abrasive agents present in the flushing fluid.
According to the method, an abrasive agent may thus be added to the flushing fluid in an amount corresponding to between 0.05 weight percent and 1.00 weight percent. In a particularly preferred embodiment, circa 0.1 weight percent of an abrasive agent, for example sand, may be added to the flushing fluid.
In a further embodiment of the method, the flushing fluid may be discharged from the at least one outlet of the flushing tool at a discharge velocity of at least 15 metres per second. Tests show that 15 metres per second is a limit value above which the flushing tool is able to clean sufficiently.
It is more advantageous for the flushing fluid to be discharged from the at least one outlet of the flushing tool at a discharge velocity of at least 50 metres per second. Said tests also have shown that the flushing is particularly effective when the flushing fluid has a discharge velocity of at least 50 metres per second.
Further, the flushing fluid possibly may be discharged from the at least one outlet of the flushing tool as a substantially rotation-free discharge jet. The advantage thereof is that there is no need, then, for nozzles that possibly may provide a rotational effect to the discharge jet, insofar as such nozzles usually require more space for support.
Moreover, the fluidized plugging material may comprise cement slurry, which constitutes the most common plugging material in most wells.
As an alternative or addition, the fluidized plugging material may comprise a fluidized particulate mass. A somewhat different use of a fluidized particulate mass in a well is described, among other places, in WO 01/25594 A1 and in WO 02/081861 A1.
Furthermore, the flushing fluid may comprise drilling mud. This will be a suitable flushing fluid given that drilling mud usually is readily available and also functions as a pressure barrier in a well.
Yet further, a displacement body may be used in the present method to further displace and distribute the fluidized plugging material in the pipe body and further out into the annulus. Such a displacement body is shown and described, among other places, in Norwegian patent application No. 20120099 entitled “Apparatus and method for positioning of a fluidized plugging material in an oil well or gas well”, which corresponds to international publication WO 2012/128644 A2.
In a further embodiment, the method may also comprise, before step (A), the following steps:
Obviously, this embodiment of the method saves on time and cost, which is of particularly great significance for well operations offshore.
In this context, a lower end portion of the flushing tool possibly may be releasably connected to the perforation tool; and
This may prove particularly appropriate provided it is possible to leave the perforation tool in the pipe body, and below the longitudinal section L1 of the well. This may prove appropriate to save on operational time and/or if the perforation tool is of a drillable material, for example aluminium or similar.
By comparison, a combined perforation- and washing tool is described in said NO 2011641, which corresponds to WO 2012/096580 A1. The perforation tool and the washing tool may be joined or individually releasable from an associated pipe string.
In an alternative embodiment, the method may also comprise, before step (C), the following steps:
Such an embodiment of the method may prove necessary provided it is not possible to leave the perforation tool in the well, for example due to lack of space in the pipe body.
In context of the method, the longitudinal section L1 possibly may be located vis-à-vis a permeable reservoir zone, thereby forming the plug vis-à-vis the permeable reservoir zone. As such, the permeable reservoir zone may comprise, for example, an oil-water contact in a subterranean reservoir.
As an alternative, the longitudinal section L1 possibly may be located vis-à-vis a portion of the annulus where crossflow exists, thereby forming the plug vis-à-vis this crossflow portion of the annulus. For example, water from a water zone may thus be prevented from flowing into a separate oil zone via the annulus, or vice versa, or the water may be prevented from flowing into a production stream from the oil zone.
Further, the method may comprise, after step (E), a step of forming, by means of a perforation tool, at least one hole in the pipe body (i.e. through the wall of the pipe body) along a portion of the well located above the longitudinal section L1 where the plug has been set and covers substantially the complete cross section T1 of the well. This may prove necessary if, for example, existing production perforations are plugged up or closed off from the rest of the well in context of the isolation. Thus, for example, new perforations may be formed higher up in an oil zone in a reservoir after having isolated an underlying oil-water contact by means of such a plug.
As an alternative or addition, the method may comprise, after step (E), a step (F) of drilling out a central, through-going portion of the plug in the pipe body, whereby at least a cross-sectional section T3 of the plug remains in the annulus outside the pipe body. By so doing, the pipe body and the well are re-opened so as to establish contact with equipment and rocks located below the longitudinal section L1 and the plug.
In this context, the method may comprise, after step (F), a step of forming, by means of a perforation tool, at least one hole in the pipe body (i.e. through the wall of the pipe body) along a portion of the well located below the longitudinal section L1 where the plug has been set and drilled out. This, for example, may be desireable in a case where it is to be produced from, or injected into, a permeable well zone located below the plug.
Hereinafter, two exemplary embodiments of the present method are described, wherein the embodiments are depicted in the accompanying drawings, where:
The Figures are schematic and merely show steps, details and equipment being essential to the understanding of the invention. Further, the Figures are distorted with respect to relative dimensions of elements and details shown in the Figures. The Figures are also somewhat simplified with respect to the shape and richness of detail of such elements and details. Elements not being central to the invention may also have been omitted from the Figures. Hereinafter, equal, equivalent or corresponding details in the Figures will be given substantially the same reference numerals.
Hereinafter, reference numeral 1 denotes a subterranean production well within which the present method is used. Well fluids and already established pressure barriers, which will be known to a skilled person, are not shown in the Figures.
Further,
It is therefore desirable, in this embodiment, to remove, or at least to reduce, such undesired influx of water 10 into the production stream. This is achieved by isolating the entire reservoir 8 from the rest of the well 1. Subsequently, it is desirable to form new perforations 214 in the production pipe 211 vis-à-vis a separate, deeper oil reservoir 20 in the well 1, as shown in
In this context, it is also mentioned that such new perforations 214, in an embodiment not shown, just as well may be formed in a separate petroleum reservoir located above the reservoir 8 in the well 1.
Reference is now made to said second embodiment of the method, which is illustrated in
| Number | Date | Country | Kind |
|---|---|---|---|
| 20131213 | Sep 2013 | NO | national |
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/NO2014/050151 | 8/26/2014 | WO | 00 |
