CA2681043A1 - Method of interconnecting subterranean boreholes - Google Patents
Method of interconnecting subterranean boreholes Download PDFInfo
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- CA2681043A1 CA2681043A1 CA002681043A CA2681043A CA2681043A1 CA 2681043 A1 CA2681043 A1 CA 2681043A1 CA 002681043 A CA002681043 A CA 002681043A CA 2681043 A CA2681043 A CA 2681043A CA 2681043 A1 CA2681043 A1 CA 2681043A1
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- Prior art keywords
- borehole
- earth formation
- boreholes
- cavity
- creating
- Prior art date
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- Abandoned
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- 238000000034 method Methods 0.000 title claims abstract description 37
- 239000012530 fluid Substances 0.000 claims abstract description 44
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 31
- 239000000463 material Substances 0.000 claims abstract description 24
- 238000004891 communication Methods 0.000 claims abstract description 12
- 239000004215 Carbon black (E152) Substances 0.000 claims description 18
- 229930195733 hydrocarbon Natural products 0.000 claims description 18
- 150000002430 hydrocarbons Chemical class 0.000 claims description 18
- 239000004568 cement Substances 0.000 claims description 13
- 239000011347 resin Substances 0.000 claims description 6
- 229920005989 resin Polymers 0.000 claims description 6
- 239000011148 porous material Substances 0.000 claims description 2
- 230000001939 inductive effect Effects 0.000 claims 1
- 238000004519 manufacturing process Methods 0.000 description 11
- 239000007788 liquid Substances 0.000 description 6
- 238000007667 floating Methods 0.000 description 4
- 239000011435 rock Substances 0.000 description 4
- 238000005553 drilling Methods 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 2
- 230000000135 prohibitive effect Effects 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 101100194817 Caenorhabditis elegans rig-6 gene Proteins 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N phenol group Chemical group C1(=CC=CC=C1)O ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 description 1
- 239000000088 plastic resin Substances 0.000 description 1
- 238000009991 scouring Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 229920001187 thermosetting polymer Polymers 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/17—Interconnecting two or more wells by fracturing or otherwise attacking the formation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
- E21B43/305—Specific pattern of wells, e.g. optimising the spacing of wells comprising at least one inclined or horizontal well
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Bulkheads Adapted To Foundation Construction (AREA)
Abstract
A method is disclosed of connecting a first borehole (1) to a second borehole (2), said boreholes being formed in an earth formation (3) and extending at a mutual distance. The method comprises inserting a volume of hardenable fluidic material (24) into a space (22) in the earth formation extending between the first and second boreholes, and allowing the hardenable fluidic material to harden so as to form a body of hardened material between the first and second boreholes. At least one fluid channel (26) is created in said body of hardened material, each fluid channel providing fluid communication between the first borehole and the second borehole.
Description
METHOD OF INTERCONNECTING SUBTERRANEAN BOREHOLES
The present invention relates to a method of connecting a first borehole to a second borehole, said boreholes being formed in an earth formation and extending at a distance from each other.
In operations for the production of oil or gas from a subterranean reservoir at a remote location, such as an offshore location, it is general practice to produce hydrocarbon fluid from one or more wells to a production platform located at the site of the wells. The production platform can be fixedly installed on the seabed, such as a jack-up platform or a gravity based platform, or it can be floating at the sea surface, such as a floating production storage and offloading (FPSO) vessel.
Generally, one or more wells are drilled into the reservoir from directly below the platform, and hydrocarbon fluid is produced from the wells through risers extending between the seabed and the platform.
Most offshore fields also involve one or more satellite wells located at a distance from the platform and tied to the platform by pipelines on the seabed.
Offshore platforms, especially those in deep water, attribute considerably to the costs of exploiting offshore hydrocarbon reservoirs. In some instances, installing an offshore platform may even be prohibitive to economical exploitation of the reservoir. In view thereof it has been proposed to use relatively small subsea production systems instead of fixed or floating platforms for producing oil or gas from offshore fields.
Such subsea systems are arranged to receive hydrocarbon fluid from one or more wells to initially separate the produced stream into a gas stream and a liquid stream, and to pump the separated streams to an onshore production facility. Alternatively the produced fluids can be transported in multi-phase flow from the subsea system to an onshore facility through a single pipeline, hence without initial separation of gas from liquid.
Although conventional technologies can be applied for the exploitation of some remote hydrocarbon fluid reservoirs, a variety of applications require improved systems and methods to produce hydrocarbon fluid in an economical way. For example, the production of hydrocarbon fluid from reservoirs located below Arctic offshore waters can prove difficult, if not impossible, with conventional technologies. Generally Arctic conditions prohibit continued operation of offshore facilities throughout the year, for example because the sea is frozen a large part of the year. For this reason, conventional offshore drilling and / or production platforms are considered inadequate for continued operation throughout the year in Arctic conditions.
Moreover, exposure of pipelines to scouring from floating ice and/or hazards associated with unstable permafrost, can be prohibitive.
US patent application 2004/0079530 Al discloses a method of interconnecting subterranean boreholes, whereby a first borehole extends into an offshore hydrocarbon reservoir, and whereby a second borehole is drilled from a surface location horizontally displaced from the surface location of the first borehole such that a lower, substantially horizontal, section thereof intersects the first borehole to provide fluid communication between the first and second boreholes.
The present invention relates to a method of connecting a first borehole to a second borehole, said boreholes being formed in an earth formation and extending at a distance from each other.
In operations for the production of oil or gas from a subterranean reservoir at a remote location, such as an offshore location, it is general practice to produce hydrocarbon fluid from one or more wells to a production platform located at the site of the wells. The production platform can be fixedly installed on the seabed, such as a jack-up platform or a gravity based platform, or it can be floating at the sea surface, such as a floating production storage and offloading (FPSO) vessel.
Generally, one or more wells are drilled into the reservoir from directly below the platform, and hydrocarbon fluid is produced from the wells through risers extending between the seabed and the platform.
Most offshore fields also involve one or more satellite wells located at a distance from the platform and tied to the platform by pipelines on the seabed.
Offshore platforms, especially those in deep water, attribute considerably to the costs of exploiting offshore hydrocarbon reservoirs. In some instances, installing an offshore platform may even be prohibitive to economical exploitation of the reservoir. In view thereof it has been proposed to use relatively small subsea production systems instead of fixed or floating platforms for producing oil or gas from offshore fields.
Such subsea systems are arranged to receive hydrocarbon fluid from one or more wells to initially separate the produced stream into a gas stream and a liquid stream, and to pump the separated streams to an onshore production facility. Alternatively the produced fluids can be transported in multi-phase flow from the subsea system to an onshore facility through a single pipeline, hence without initial separation of gas from liquid.
Although conventional technologies can be applied for the exploitation of some remote hydrocarbon fluid reservoirs, a variety of applications require improved systems and methods to produce hydrocarbon fluid in an economical way. For example, the production of hydrocarbon fluid from reservoirs located below Arctic offshore waters can prove difficult, if not impossible, with conventional technologies. Generally Arctic conditions prohibit continued operation of offshore facilities throughout the year, for example because the sea is frozen a large part of the year. For this reason, conventional offshore drilling and / or production platforms are considered inadequate for continued operation throughout the year in Arctic conditions.
Moreover, exposure of pipelines to scouring from floating ice and/or hazards associated with unstable permafrost, can be prohibitive.
US patent application 2004/0079530 Al discloses a method of interconnecting subterranean boreholes, whereby a first borehole extends into an offshore hydrocarbon reservoir, and whereby a second borehole is drilled from a surface location horizontally displaced from the surface location of the first borehole such that a lower, substantially horizontal, section thereof intersects the first borehole to provide fluid communication between the first and second boreholes.
A problem of the known method of interconnecting subterranean boreholes relates to the difficulty to drill the second borehole such that it intersects the first borehole. Moreover, the two boreholes can be unaligned at the point of intersection so that it becomes difficult, or impossible, to install a liner at the location of the intersection. Also, the two boreholes may have to be drilled at an undesirably high inclination angle relative to each other to create the intersection.
It is therefore an object of the invention to provide an improved method of interconnecting first and second boreholes formed in an earth formation, which method overcomes the problems of the prior art.
In accordance with the invention there is provided a method of connecting a first borehole to a second borehole, said boreholes being formed in an earth formation and extending at a mutual distance, the method comprising:
- inserting a volume of hardenable fluidic material into a space in the earth formation extending between the first and second boreholes, and allowing the hardenable fluidic material to harden so as to form a body of hardened material between the first and second boreholes;
and - creating at least one fluid channel in said body of hardened material, each fluid channel providing fluid communication between the first borehole and the second borehole.
With the method of the invention it is achieved that there is no longer a need to drill the boreholes exactly so that one borehole intersects the other borehole.
Moreover it is achieved that there is no abrupt change of direction of the boreholes at the location where the connection is made, so that a liner (or casing) can be installed more easily at said location. Also, due to the relative hardness of the body of hardened material, there is a reduced risk of erosion at the location of the connection during continued production of hydrocarbon fluid through the fluid channel(s) formed therein.
Suitably, said space provides fluid communication between the first borehole and the second borehole. For example, said space can include a plurality of pores of the earth formation.
In a preferred embodiment, the method of the invention comprises creating a cavity in the earth formation, said cavity forming at least a part of said space.
To reduce the size of the cavity, suitably the cavity extends between a selected location of the first borehole and a selected location of the second borehole, and wherein said mutual distance of the boreholes is minimal from the selected location of the first borehole to the selected location of the second borehole.
An exemplary way of creating the cavity in the earth formation, is to create at least one flow passage in the earth formation, each flow passage providing fluid communication between the first borehole and the second borehole. Such flow passage can be created, for example, by perforating the earth formation using a shaped charge.
To enlarge the diametrical size of the flow passage, suitably fluid is induced to flow through the flow passage so as to erode the earth formation surrounding the flow passage to form the cavity.
Each fluid channel is preferably formed by perforating the body of hardened material.
It is therefore an object of the invention to provide an improved method of interconnecting first and second boreholes formed in an earth formation, which method overcomes the problems of the prior art.
In accordance with the invention there is provided a method of connecting a first borehole to a second borehole, said boreholes being formed in an earth formation and extending at a mutual distance, the method comprising:
- inserting a volume of hardenable fluidic material into a space in the earth formation extending between the first and second boreholes, and allowing the hardenable fluidic material to harden so as to form a body of hardened material between the first and second boreholes;
and - creating at least one fluid channel in said body of hardened material, each fluid channel providing fluid communication between the first borehole and the second borehole.
With the method of the invention it is achieved that there is no longer a need to drill the boreholes exactly so that one borehole intersects the other borehole.
Moreover it is achieved that there is no abrupt change of direction of the boreholes at the location where the connection is made, so that a liner (or casing) can be installed more easily at said location. Also, due to the relative hardness of the body of hardened material, there is a reduced risk of erosion at the location of the connection during continued production of hydrocarbon fluid through the fluid channel(s) formed therein.
Suitably, said space provides fluid communication between the first borehole and the second borehole. For example, said space can include a plurality of pores of the earth formation.
In a preferred embodiment, the method of the invention comprises creating a cavity in the earth formation, said cavity forming at least a part of said space.
To reduce the size of the cavity, suitably the cavity extends between a selected location of the first borehole and a selected location of the second borehole, and wherein said mutual distance of the boreholes is minimal from the selected location of the first borehole to the selected location of the second borehole.
An exemplary way of creating the cavity in the earth formation, is to create at least one flow passage in the earth formation, each flow passage providing fluid communication between the first borehole and the second borehole. Such flow passage can be created, for example, by perforating the earth formation using a shaped charge.
To enlarge the diametrical size of the flow passage, suitably fluid is induced to flow through the flow passage so as to erode the earth formation surrounding the flow passage to form the cavity.
Each fluid channel is preferably formed by perforating the body of hardened material.
In an advantageous embodiment of the method of the invention, the first borehole extends into a reservoir zone of the earth formation containing hydrocarbon fluid.
Suitably the reservoir the first borehole extends substantially parallel to a boundary of the reservoir zone.
To prevent an undesired high drawdown of reservoir fluid at the location of the connection of the two boreholes, it is preferred that the first borehole is provided with a liner passing from outside the body of hardened material to within the body of hardened material.
The hardenable material can be selected, for example, from cement and resin such as a phenolic-based thermoset plastic resin.
The invention will be described hereinafter in more detail and by way of example, with reference to the accompanying drawings in which:
Fig. 1 schematically shows an embodiment of two wellbores interconnected with the method of the invention;
Fig. 2 schematically shows a detail of the embodiment of Fig. 1;
Fig. 3 schematically shows cross-section 3-3 of Fig. 2 during an initial stage of the method of the invention;
Fig. 4 schematically shows cross-section 3-3 of Fig. 2 during a subsequent stage of the method of the invention;
Fig. 5 schematically shows cross-section 3-3 of Fig. 2 during a further stage of the method of the invention;
Suitably the reservoir the first borehole extends substantially parallel to a boundary of the reservoir zone.
To prevent an undesired high drawdown of reservoir fluid at the location of the connection of the two boreholes, it is preferred that the first borehole is provided with a liner passing from outside the body of hardened material to within the body of hardened material.
The hardenable material can be selected, for example, from cement and resin such as a phenolic-based thermoset plastic resin.
The invention will be described hereinafter in more detail and by way of example, with reference to the accompanying drawings in which:
Fig. 1 schematically shows an embodiment of two wellbores interconnected with the method of the invention;
Fig. 2 schematically shows a detail of the embodiment of Fig. 1;
Fig. 3 schematically shows cross-section 3-3 of Fig. 2 during an initial stage of the method of the invention;
Fig. 4 schematically shows cross-section 3-3 of Fig. 2 during a subsequent stage of the method of the invention;
Fig. 5 schematically shows cross-section 3-3 of Fig. 2 during a further stage of the method of the invention;
Fig. 6 schematically shows cross-section 3-3 of Fig. 2 during a final stage of the method of the invention; and Fig. 7 schematically shows cross-section 7-7 of Fig. 6.
Referring to Fig. 1 there is shown a first wellbore 1 and a second wellbore 2 formed in an earth formation 3 which includes a reservoir zone 4 containing hydrocarbon fluid. The first wellbore 1 extends from a drilling rig 6 at surface into the earth formation 3 such that a lower section 8 of the first wellbore 1 extends inclined into the reservoir zone 4. The second wellbore 2 extends from a hydrocarbon fluid production facility 9 at surface into the earth formation 3 whereby a lower section 10 of the second wellbore extends substantially horizontally, or deviated, into the reservoir zone 4. The lower sections 8, 10 of the respective first and second wellbores 1, 2 do not directly intersect each other, but extend at a distance from each other whereby the shortest distance is about one or several meters. The area in which the first and second wellbores 1, 2 cross each other, is indicated by reference sign 'A'.
The area 'A' is shown in more detail in Figs. 2 and 3, whereby Fig. 3 is a cross-sectional view taken along line 3-3 of Fig. 2. The first wellbore 1 is provided with a casing 12 extending to about the bottom of the wellbore 1, and the second wellbore 2 is provided with a liner 14 extending in the lower wellbore section 10. The liner 14 has a plurality of inlet openings (or perforations) 16 to allow hydrocarbon fluid from the reservoir zone 4 to flow into the liner 14. However a portion 18 of the liner 14 extending near the first wellbore 1 is solidly formed, that is, the liner portion 18 is not provided with inlet openings (as shown in Fig. 2). Furthermore, a portion of the casing 12 nearest the second wellbore 2 is provided with a plurality of primary perforations 20. The primary perforations 20 extend further through the earth formation surrounding the casing 12 and the liner 14 so as to provide fluid communication between the wellbore 1 and the wellbore 2.
In Fig. 4 is shown the area 'A' after a cavity 22 has been formed in the earth formation. The cavity 22 encloses a portion of the liner 14 and extends to the casing 12, at the location thereof where the primary perforations 20 are formed.
In Fig. 5 is shown the area 'A', in the view along line 3-3 of Fig. 2, after the cavity 22 has been filled with a body of cement 24 or other substantially impermeable material.
In Figs. 6 and 7 is shown the area 'A' after a series of secondary perforations 26 have been formed in the casing 12, which extend further through the body of cement 24 and the liner 14 so as to provide fluid communication between the wellbore 1 and the wellbore 2.
During normal operation, the first wellbore 1 is drilled such that the lower section 8 thereof crosses the lower section 10 of the second wellbore at a relatively short distance, for example a distance between 0.2-2 meters. A perforating gun (not shown) is then lowered into the first wellbore 1 and operated so as to form the primary perforations 20 which extend through the casing 12, the earth formation 3 and the liner 14 so as to provide fluid communication between the first wellbore 1 and the second wellbore 2 (as shown in Figs. 2 and 3).
Referring to Fig. 1 there is shown a first wellbore 1 and a second wellbore 2 formed in an earth formation 3 which includes a reservoir zone 4 containing hydrocarbon fluid. The first wellbore 1 extends from a drilling rig 6 at surface into the earth formation 3 such that a lower section 8 of the first wellbore 1 extends inclined into the reservoir zone 4. The second wellbore 2 extends from a hydrocarbon fluid production facility 9 at surface into the earth formation 3 whereby a lower section 10 of the second wellbore extends substantially horizontally, or deviated, into the reservoir zone 4. The lower sections 8, 10 of the respective first and second wellbores 1, 2 do not directly intersect each other, but extend at a distance from each other whereby the shortest distance is about one or several meters. The area in which the first and second wellbores 1, 2 cross each other, is indicated by reference sign 'A'.
The area 'A' is shown in more detail in Figs. 2 and 3, whereby Fig. 3 is a cross-sectional view taken along line 3-3 of Fig. 2. The first wellbore 1 is provided with a casing 12 extending to about the bottom of the wellbore 1, and the second wellbore 2 is provided with a liner 14 extending in the lower wellbore section 10. The liner 14 has a plurality of inlet openings (or perforations) 16 to allow hydrocarbon fluid from the reservoir zone 4 to flow into the liner 14. However a portion 18 of the liner 14 extending near the first wellbore 1 is solidly formed, that is, the liner portion 18 is not provided with inlet openings (as shown in Fig. 2). Furthermore, a portion of the casing 12 nearest the second wellbore 2 is provided with a plurality of primary perforations 20. The primary perforations 20 extend further through the earth formation surrounding the casing 12 and the liner 14 so as to provide fluid communication between the wellbore 1 and the wellbore 2.
In Fig. 4 is shown the area 'A' after a cavity 22 has been formed in the earth formation. The cavity 22 encloses a portion of the liner 14 and extends to the casing 12, at the location thereof where the primary perforations 20 are formed.
In Fig. 5 is shown the area 'A', in the view along line 3-3 of Fig. 2, after the cavity 22 has been filled with a body of cement 24 or other substantially impermeable material.
In Figs. 6 and 7 is shown the area 'A' after a series of secondary perforations 26 have been formed in the casing 12, which extend further through the body of cement 24 and the liner 14 so as to provide fluid communication between the wellbore 1 and the wellbore 2.
During normal operation, the first wellbore 1 is drilled such that the lower section 8 thereof crosses the lower section 10 of the second wellbore at a relatively short distance, for example a distance between 0.2-2 meters. A perforating gun (not shown) is then lowered into the first wellbore 1 and operated so as to form the primary perforations 20 which extend through the casing 12, the earth formation 3 and the liner 14 so as to provide fluid communication between the first wellbore 1 and the second wellbore 2 (as shown in Figs. 2 and 3).
In a subsequent step, a stream of liquid, such as brine or drilling fluid, is pumped from surface into the first wellbore 1. The stream of liquid passes into the lower wellbore section 8, and flows from there via the primary perforations 20 into the lower section 10 of the second wellbore 2. The stream of liquid is then discharged from the second wellbore 2 through the surface production facility 9. The stream of liquid flows at high velocity through the primary perforations 20 and thereby erodes the rock material around the perforations 20. Upon continued pumping of the stream of fluid, virtually all rock material around the primary perforations 20 erodes away so that, as a result, the cavity 22 is formed in the earth formation 3 (as shown in Fig. 4).
During a next phase, cement is pumped into the lower section 8 of the first wellbore 1, and thence via the primary perforations 20 of the casing 12 into the cavity 22. Upon hardening of the cement, the body of hardened cement 24 forms in the cavity 22 (as shown in Fig. 5).
A perforating gun (not shown) is then lowered into the first wellbore 1 and operated so as to form the secondary perforations 26 which extend through the casing 12, the body of hardened cement 24, and the liner 14 so as to provide fluid communication between the first wellbore 1 and the second wellbore 2 (as shown in Fig. 6).
The sets of primary perforations 20 and the sets of secondary perforations 26 can be shot with the same perforating gun, however it may be preferred to use different perforation guns depending on the hardness of the rock to be penetrated (for the primary perforations 20) and the hardness of the cement to be penetrated (for the second perforations 26).
Alternatively, a suitable abrasive jetting tool may be used to create the primary perforations and/or the secondary perforations by jetting a fluid stream containing abrasive particles against the rock formation and/or the body of cement.
In this manner it is achieved that hydrocarbon fluid produced from the reservoir zone 4, can flow from the second wellbore 2 to the first wellbore 1, or vice versa, via the secondary perforations 26. For example, if the second wellbore 2 extends below the sea, and the first wellbore 1 extends to an onshore surface location, produced hydrocarbon fluid can flow from the lower section 10 of the second wellbore 2, via the secondary perforations 26, into the lower section of the first wellbore 1 and from there to the onshore surface location. Also, both wellbores can be formed below the seabed.
It should be noted that, by virtue of the absence of inlet openings in the liner, hydrocarbon fluid can only flow into the liner 14 at some distance from the body of cement 24. It is thereby achieved that undesired high drawdown of hydrocarbon fluid from the reservoir zone 4 in the region near the body of cement 24, is prevented.
Instead of pumping cement into the cavity, a hardenable resin can be pumped into the cavity. Upon hardening of the resin, a body of hardened resin is formed in the cavity, whereafter the secondary perforations are formed in the body of hardened resin.
During a next phase, cement is pumped into the lower section 8 of the first wellbore 1, and thence via the primary perforations 20 of the casing 12 into the cavity 22. Upon hardening of the cement, the body of hardened cement 24 forms in the cavity 22 (as shown in Fig. 5).
A perforating gun (not shown) is then lowered into the first wellbore 1 and operated so as to form the secondary perforations 26 which extend through the casing 12, the body of hardened cement 24, and the liner 14 so as to provide fluid communication between the first wellbore 1 and the second wellbore 2 (as shown in Fig. 6).
The sets of primary perforations 20 and the sets of secondary perforations 26 can be shot with the same perforating gun, however it may be preferred to use different perforation guns depending on the hardness of the rock to be penetrated (for the primary perforations 20) and the hardness of the cement to be penetrated (for the second perforations 26).
Alternatively, a suitable abrasive jetting tool may be used to create the primary perforations and/or the secondary perforations by jetting a fluid stream containing abrasive particles against the rock formation and/or the body of cement.
In this manner it is achieved that hydrocarbon fluid produced from the reservoir zone 4, can flow from the second wellbore 2 to the first wellbore 1, or vice versa, via the secondary perforations 26. For example, if the second wellbore 2 extends below the sea, and the first wellbore 1 extends to an onshore surface location, produced hydrocarbon fluid can flow from the lower section 10 of the second wellbore 2, via the secondary perforations 26, into the lower section of the first wellbore 1 and from there to the onshore surface location. Also, both wellbores can be formed below the seabed.
It should be noted that, by virtue of the absence of inlet openings in the liner, hydrocarbon fluid can only flow into the liner 14 at some distance from the body of cement 24. It is thereby achieved that undesired high drawdown of hydrocarbon fluid from the reservoir zone 4 in the region near the body of cement 24, is prevented.
Instead of pumping cement into the cavity, a hardenable resin can be pumped into the cavity. Upon hardening of the resin, a body of hardened resin is formed in the cavity, whereafter the secondary perforations are formed in the body of hardened resin.
Claims (16)
1. A method of connecting a first borehole to a second borehole, said boreholes being formed in an earth formation and extending at a distance from each other, the method comprising:
- inserting a volume of hardenable fluidic material into a space in the earth formation extending between the first and second boreholes, and allowing the hardenable fluidic material to harden so as to form a body of hardened material between the first and second boreholes;
and - creating at least one fluid channel in said body of hardened material, each fluid channel providing fluid communication between the first borehole and the second borehole, wherein the step of creating said at least one fluid channel comprises perforating the body of hardened material.
- inserting a volume of hardenable fluidic material into a space in the earth formation extending between the first and second boreholes, and allowing the hardenable fluidic material to harden so as to form a body of hardened material between the first and second boreholes;
and - creating at least one fluid channel in said body of hardened material, each fluid channel providing fluid communication between the first borehole and the second borehole, wherein the step of creating said at least one fluid channel comprises perforating the body of hardened material.
2. The method of claim 1, wherein said space provides fluid communication between the first borehole and the second borehole.
3. The method of claim 1 or 2, wherein said space includes a plurality of pores of the earth formation.
4. The method of any one of claims 1-3, further comprising creating a cavity in the earth formation, said cavity forming at least a part of said space.
5. The method of claim 4, wherein the cavity extends between a selected location of the first borehole and a selected location of the second borehole, and wherein said mutual distance of the boreholes is minimal from the selected location of the first borehole to the selected location of the second borehole.
6. The method of claim 4 or 5, wherein the step of creating said cavity in the earth formation comprises creating at least one flow passage in the earth formation, each flow passage providing fluid communication between the first borehole and the second borehole.
7. The method of claim 6, wherein the step of creating said at least one flow passage comprises perforating the earth formation using a shaped charge.
8. The method of claim 6 or 7, further comprising inducing fluid to flow through each flow passage so as to erode the earth formation surrounding the flow passage to form the cavity.
9. The method of any one of claims 1-8, wherein said hardenable material is selected from cement and resin.
10. The method of any one of claims 1-9, wherein the first borehole extends into a reservoir zone of the earth formation containing hydrocarbon fluid.
11. The method of claim 10, wherein the reservoir zone has a boundary, and wherein the first borehole extends substantially parallel to said boundary.
12. The method of claim 10 or 11, wherein the second borehole extends to the earth surface.
13. The method of any one of claims 1-12, further comprising arranging a liner in the first borehole, the liner passing from outside the body of hardened material to within the body of hardened material.
14. A wellbore system comprising first and second boreholes formed in an earth formation, said boreholes being connected to each other with the method of any one of claims 1-13.
15. The method substantially described hereinbefore with reference to the accompanying drawings.
16. The method substantially described hereinbefore with reference to the accompanying drawings.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| EP07105066.0 | 2007-03-28 | ||
| EP07105066 | 2007-03-28 | ||
| PCT/EP2008/053617 WO2008116896A2 (en) | 2007-03-28 | 2008-03-27 | Method of interconnecting subterranean boreholes |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2681043A1 true CA2681043A1 (en) | 2008-10-02 |
Family
ID=38441998
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002681043A Abandoned CA2681043A1 (en) | 2007-03-28 | 2008-03-27 | Method of interconnecting subterranean boreholes |
Country Status (7)
| Country | Link |
|---|---|
| US (1) | US20100181114A1 (en) |
| CN (1) | CN101641496A (en) |
| AU (1) | AU2008231767A1 (en) |
| BR (1) | BRPI0809527A2 (en) |
| CA (1) | CA2681043A1 (en) |
| GB (1) | GB2461426A (en) |
| WO (1) | WO2008116896A2 (en) |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| AU2014395134B2 (en) | 2014-05-17 | 2017-04-20 | Halliburton Energy Services, Inc. | Establishing communication downhole between wellbores |
| US11156073B2 (en) * | 2020-02-28 | 2021-10-26 | Saudi Arabian Oil Company | Drilling wellbores in a multilayered reservoir |
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-
2008
- 2008-03-27 US US12/532,595 patent/US20100181114A1/en not_active Abandoned
- 2008-03-27 CA CA002681043A patent/CA2681043A1/en not_active Abandoned
- 2008-03-27 WO PCT/EP2008/053617 patent/WO2008116896A2/en active Application Filing
- 2008-03-27 CN CN200880009832A patent/CN101641496A/en active Pending
- 2008-03-27 AU AU2008231767A patent/AU2008231767A1/en not_active Abandoned
- 2008-03-27 BR BRPI0809527-2A2A patent/BRPI0809527A2/en not_active Application Discontinuation
-
2009
- 2009-09-14 GB GB0916109A patent/GB2461426A/en not_active Withdrawn
Also Published As
| Publication number | Publication date |
|---|---|
| GB0916109D0 (en) | 2009-10-28 |
| CN101641496A (en) | 2010-02-03 |
| GB2461426A (en) | 2010-01-06 |
| BRPI0809527A2 (en) | 2014-10-14 |
| WO2008116896A3 (en) | 2008-11-13 |
| WO2008116896A2 (en) | 2008-10-02 |
| AU2008231767A1 (en) | 2008-10-02 |
| US20100181114A1 (en) | 2010-07-22 |
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