EP3159478A1

EP3159478A1 - Downhole completion system sealing against the cap layer

Info

Publication number: EP3159478A1
Application number: EP15191258.1A
Authority: EP
Inventors: Paul Hazel
Original assignee: Welltec AS
Current assignee: Welltec AS
Priority date: 2015-10-23
Filing date: 2015-10-23
Publication date: 2017-04-26

Abstract

The present invention relates to a downhole completion system for completing a well having a top, comprising a formation comprising a cap layer having an upper end and a lower end, a borehole extending through the cap layer to provide an inner cap layer face, a first well tubular metal structure arranged in the borehole comprising a first annular barrier and a second annular barrier. Each annular barrier comprises a tubular part, the tubular part being mounted as part of the first well tubular metal structure, an expandable tubular surrounding the tubular part, each end section of the expandable tubular being connected with the tubular part, an annular barrier space between the tubular part and the expandable tubular, and an expansion opening in the tubular part through which pressurised fluid passes for expanding the expandable tubular and bringing the annular barrier from an unexpanded position to an expanded position, wherein the first annular barrier is arranged at the upper end, and in the expanded position the expandable tubular of the first annular barrier overlaps the cap layer, and the second annular barrier is arranged at the lower end, and in the expanded position the expandable tubular of the second annular barrier overlaps the cap layer. Furthermore, the present invention relates to a completion method for a downhole completion system.

Description

Field of the invention

The present invention relates to a downhole completion system for completing a well. Furthermore, the present invention relates to a completion method for a downhole completion system.

Background art

Hydrocarbons in a reservoir are trapped by overlying rock formations with lower permeability functioning as a seal layer, also referred to as a cap layer or cap rock. Thus, in order to obtain the contents of the oil reservoir, it is usually necessary to drill through the seal layer if the reservoir is not just seeping and does not have such seal layer. When completing a well, the first and upper part of the well is drilled, and the seal layer is then penetrated. Subsequently, the upper casing is run in the hole, and cement is pumped down through the casing shoe and further out of the bottom of the borehole and upwards into the annulus surrounding the casing to fill up the annulus between the casing and the borehole wall. When pumping cement down the casing, corresponding to filling up 200 metres of annulus, the remaining cement is pumped out and after some curing time, the cement shoe is drilled out and the lower part of the well is completed by drilling into the reservoir. The cement is presumed to seal between the cap rock and the casing, but the cement cannot be tested by pressurisation from below the cement, since the pressurised fluid would leak out through the formation below the seal layer. Thus, whether or not the cement forms a proper seal against the cap rock cannot be tested before drilling further into the formation, opening the reservoir and thus releasing the reservoir pressure. Many types of cement, e.g. cement having radioactive particles, have been used in order to be able to test the sealing property of the cement, but none of these attempts have been very successful. Therefore, today many wells are leaking since the cement does not seal sufficiently.

Summary of the invention

It is an object of the present invention to wholly or partly overcome the above disadvantages and drawbacks of the prior art. More specifically, it is an object to provide an improved completion system, wherein it is possible to test the sealing against the cap layer.
The above objects, together with numerous other objects, advantages and features, which will become evident from the below description, are accomplished by a solution in accordance with the present invention by a downhole completion system for completing a well having a top, comprising:

a formation comprising:
- a cap layer having an upper end and a lower end,
a borehole extending through the cap layer to provide an inner cap layer face,
a first well tubular metal structure arranged in the borehole comprising
a first annular barrier and a second annular barrier, each annular barrier comprising:
- a tubular part, the tubular part being mounted as part of the first well tubular metal structure,
- an expandable tubular surrounding the tubular part, each end section of the expandable tubular being connected with the tubular pa rt,
- an annular barrier space between the tubular part and the expandable tubular, and
- an expansion opening in the tubular part through which pressurised fluid passes for expanding the expandable tubular and bringing the annular barrier from an unexpanded position to an expanded position,
wherein the first annular barrier is arranged at the upper end, and in the expanded position the expandable tubular of the first annular barrier overlaps the cap layer, and the second annular barrier is arranged at the lower end, and in the expanded position the expandable tubular of the second annular barrier overlaps the cap layer.

In the expanded position, the first annular barrier, the second annular barrier, the first well tubular metal structure and the cap layer may enclose a confined space.
Moreover, the first well tubular metal structure may comprise a sensor unit arranged between the first annular barrier and the second annular barrier and configured to measure a property of a fluid in the confined space.
Also, the sensor unit may be comprised in the first annular barrier or the second annular barrier.
The downhole completion system according to the present invention may further comprise a pressurisation device for pressurising the first well tubular metal structure.
Furthermore, the pressurisation device may be arranged at the top of the well tubular metal structure.
Additionally, the pressurisation device may be arranged in a tool inserted into the first well tubular metal structure.
In addition, the downhole completion system according to the present invention may further comprise one or more third annular barrier(s) arranged between the first annular barrier and the second annular barrier.
Further, the sensor unit may comprise a communication device configured to communicate sensor data.
The downhole completion system may further comprise a tool having a communication module adapted to receive the sensor data.
Also, elastomeric seals may be arranged on an outside of the expandable tubular.
Moreover, the first annular barrier or the second annular barrier may comprise a valve device in fluid communication with the expansion opening.
Furthermore, the sensor unit may be connected with the valve device.
The valve device may have a first position in which fluid is allowed to flow from the first well tubular metal structure to the annular barrier space and a second position, providing fluid communication between the annular barrier space and the confined space.
Further, the first annular barrier or the second annular barrier may comprise a plurality of sensor units.
The downhole completion system according to the present invention may further comprise a second well tubular metal structure extending at least partly within the first well tubular metal structure and extending below the cap layer.
Also, one of the annular barriers may be made solely of metal material.
In addition, the sensor unit may comprise a sensor such as a pressure sensor or a temperature sensor.
Moreover, each annular barrier may comprise a plurality of sensors.
The second well tubular metal structure may be suspended from the first well tubular metal structure.
Additionally, an annular barrier may be arranged between the first well tubular metal structure and the second well tubular metal structure.
Further, the second well tubular metal structure may comprise one or more annular barriers.
The present invention also relates to a completion method for a downhole completion system as described above, comprising the steps of:

identifying the cap layer,
introducing the first well tubular metal structure into the borehole,
arranging the first annular barrier and the second annular barrier at least partly opposite the cap layer, so that the expandable tubular of the first annular barrier and the second annular barrier overlaps the cap layer, and
expanding the expandable tubular of the first annular barrier and the second annular barrier to abut the inner cap layer face to enclose a confined space.

The completion method according to the present invention may further comprise the step of pressurising the confined space to a predetermined pressure.
In addition, the completion method according to the present invention may further comprise the step of determining if the pressure in the confined space is kept substantially constant over a period of time to verify the sealing properties of at least one of the annular barriers against the cap layer.
Said method may also comprise the step of determining the pressurisation performed by the sensor unit.
Also, the step of pressurisation may be performed from the top of the well.
Moreover, the step of pressurisation may be performed by means of a tool inserted into the first well tubular metal structure.
Furthermore, the completion method according to the present invention may comprise the step of shifting a valve device of one of the annular barriers from a first position providing fluid communication from an inside of the first well tubular metal structure to the annular barrier space to a second position providing fluid communication between the annular barrier space and the confined space.

Brief description of the drawings

The invention and its many advantages will be described in more detail below with reference to the accompanying schematic drawings, which for the purpose of illustration show some non-limiting embodiments and in which

Fig. 1 shows a partly cross-sectional view of a downhole completion system having unexpanded annular barriers,
Fig. 2 shows the downhole completion system of Fig. 1 having expanded annular barriers,
Fig. 3 shows a partly cross-sectional view of another downhole completion system having a tool for expansion of the annular barriers,
Fig. 4 shows an annular barrier having a valve device,
Fig. 4A shows a cross-sectional view of part of a valve device of an annular barrier having a bore with a piston in an initial position,
Fig. 4B shows the piston of Fig. 4A in its closed position,
Fig. 5A shows another embodiment of the valve device having a piston in its initial position,
Fig. 5B shows the piston of Fig. 5A in its closed position,
Fig. 6 shows a perspective of part of an annular barrier,
Fig. 7 shows a partly cross-sectional view of a downhole completion system having three annular barriers, and
Fig. 8 shows a partly cross-sectional view of a downhole completion system having a second well tubular metal structure.

All the figures are highly schematic and not necessarily to scale, and they show only those parts which are necessary in order to elucidate the invention, other parts being omitted or merely suggested.

Detailed description of the invention

Fig. 1 shows a downhole completion system 1 for completing a well 2 in a formation 4 comprising hydrocarbon-containing fluid, such crude oil and/or gas. The formation has a cap layer 5 having an upper end 6 and a lower end 7 and being substantially impermeable, preventing the hydrocarbon-containing fluid from emerging from the reservoir before a borehole 8 is drilled in the formation and extends through the cap layer. The cap layer is also called the seal or cap rock which is a unit with low permeability that impedes the escape of the hydrocarbon-containing fluid from the reservoir in the formation. Common cap layers or seals include evaporates (sedimentary rocks), chalks and shales. The cap layer thus seals off the reservoir until a borehole is drilled.
The drilled borehole provides an inner cap layer face 9 of the cap layer 5. The downhole completion system 1 further comprises a first well tubular metal structure 10 arranged in the borehole. The downhole completion system 1 comprises a first annular barrier 11a and a second annular barrier 11b. Each annular barrier comprises a tubular part 12 which is mounted as part of the first well tubular metal structure and an expandable tubular 14 surrounding the tubular part. Each end section 31, 32 of the expandable tubular is connected with the tubular part, defining an annular barrier space 15 (shown in Fig. 2) between the tubular part and the expandable tubular. The tubular part comprises an expansion opening 16 through which pressurised fluid passes for expanding the expandable tubular and bringing the annular barrier from an unexpanded position as shown in Fig. 1 to an expanded position, as shown in Fig. 2. In the expanded position, the expandable tubular abuts the inner cap layer face, so that the first annular barrier is arranged at the upper end of the cap layer, and the expandable tubular of the first annular barrier overlaps the cap layer, and so that the second annular barrier is arranged at the lower end of the cap layer, and the expandable tubular of the second annular barrier overlaps the cap layer. Thus, in the expanded position, the first annular barrier, the second annular barrier, the first well tubular metal structure and the cap layer enclose a confined space 17. When the first annular barrier and/or the second annular barrier have been expanded, they form part of the main barrier, so that the hydrocarbon-containing fluid from the reservoir can only flow up through the first well tubular metal structure when drilling further into the formation and the reservoir opening up the reservoir.
The first well tubular metal structure has an outer face 26 on which a sensor unit 18 is arranged between the first annular barrier and the second annular barrier, as shown in Figs. 1 and 2. The sensor unit 18 is configured to measure a property of a fluid in the confined space to verify that the first annular barrier and the second annular barrier isolate the confined space and thus confirm that the first annular barrier and the second annular barrier provide the main barrier against the cap layer. Thus by means of the present downhole completion system, testing of the seal between the cap layer and the well tubular metal structure is possible. Such testing has not been possible in the prior art solutions. In the prior art solutions, the cap layer is covered with cement so that the pressurised test fluid pumped down the well tubular metal structure leaks out into the permeable formation below the cap layer, and thus it is not possible to test whether it is the cement leaking or the test fluid leaking into the permeable part of the formation. Furthermore, cement tends to deteriorate when subjected to fluid and temperature fluctuations, and especially if the fluid can enter pores in the cement layer and be trapped in the cement. Then as the temperature rises and falls, the fluid creates micro-bores in the cement.
In Fig. 3, the sensor unit 18 is comprised in the first annular barrier and arranged in the confined space 17. The downhole completion system further comprises a pressurisation device 19 for pressurising the inside of the first well tubular metal structure and thus expanding the annular barriers by letting pressurised fluid in through the expansion opening 16 and into the annular barrier space 15. The first annular barrier further comprises a valve device 23 in fluid communication with the expansion opening 16, as shown in Figs. 4 and 6. The valve device has a first position, in which fluid is allowed to flow from the first well tubular metal structure to the annular barrier space, as shown in Figs. 4A, 5A and a second position, providing fluid communication between the annular barrier space and the confined space, as shown in Figs. 4B, 5B. In Fig. 3, the sensor unit is connected with the valve device and forms part of the first annular barrier.
When having such valve device, the fluid pressure in the confined space is equalised with the pressure in the annular barrier space during temperature fluctuations, and thus by having a valve device in fluid communication with the confined space, no fracturing or leaking will occur during such temperature fluctuations.
In Fig. 1, the pressurisation device is arranged at the top of the well tubular metal structure and in Fig. 3, the pressurisation device is arranged in a tool 20 inserted into the first well tubular metal structure. The tool comprises isolation means for isolation of a part of the first well tubular metal structure opposite the expansion opening 16 for pressurising the annular barrier space 15.
The annular barrier has a first opening 16 in fluid communication with the inside of the first well tubular metal structure and a second opening 17A in fluid communication with the annular barrier space 15, as shown in Fig. 4. When the inside of the tubular part is pressurised, fluid flows into the annular barrier space 15 expanding the expandable tubular 14 to the expanded position as shown in Fig. 2.
As shown in Fig. 4, the annular barrier further comprises a bore 18A having a bore extension and comprising a first bore part 19A having a first inner diameter ID₁, as shown in Fig. 4A, and a second bore part 120 having an inner diameter ID₂, as shown in Fig. 4A, which is larger than that of the first bore part. The first opening 16 and the second opening 17A are arranged in the first bore part and are displaced along the bore extension. The annular barrier further comprises a piston 121 arranged in the bore. As shown in Fig. 4B, the piston comprises a first piston part 122 having an outer diameter OD_P1 substantially corresponding to the inner diameter of the first bore part 19A and comprising a second piston part 123 having an outer diameter OD_P2 substantially corresponding to the inner diameter of the second bore part 120. As shown in Fig. 4A, the annular barrier further comprises a rupture element 124 preventing movement of the piston until a predetermined pressure in the bore is reached. The piston comprises a fluid channel 125 being a through-bore providing fluid communication between the first and second bore parts.
By having a piston with a fluid channel, fluid communication between the first and second bore parts is provided so that upon rupture of the rupture element, the piston can move, resulting in fluid communication to the inside of the tubular part being closed off. In this way, a simple solution without further fluid channels is provided, and due to the fact that the second piston part has an outer diameter which is larger than the first piston part, the surface area onto which fluid pressure is applied is larger than that of the first piston part, and thus the pressure moves the piston when the annular barrier is expanded and pressure has been built up for breaking the rupture element 124, which allows the piston to move. The annular space 131 is fluidly connected with the borehole via a hole 61, shown in Fig. 4A, and the pressure in the annular space can thus be relieved.
In Figs. 5A and 5B, the rupture element is a shear disc, and in Figs. 4A and 4B the rupture element is a shear pin. Depending on the isolation solution required to provide isolation downhole, the rupture element is selected so that the rupture element breaks at a pressure higher than the expansion pressure but lower than the pressure rupturing the expandable tubular or jeopardising the function of other completion components downhole. In Figs. 5A and 5B, the bore and the piston 121 are arranged in a connection part 126 connecting the expandable tubular 14 with the tubular part 12. In Figs. 4A and 4B, the bore and piston are arranged in the tubular part 12.
In Figs. 4A and 4B, the piston has a first piston end 127 at the first piston part 122 and a second piston end 128 at the second piston part 123, the first piston end having a first piston face 129 and the second piston end having a second piston face 130, and the second piston face having a face area which is larger than a face area of the first piston face in order to move the piston towards the first bore end. The difference in face area creates a difference in the force acting on the piston, causing the piston to move to close off the fluid communication between the first opening 16 and the second opening 17A.
As shown in Fig. 4A, the first piston part 122 extends partly into the second bore part 120 in an initial position of the piston and forms an annular space 131 between the piston and an inner wall 132 of the bore. Upon movement of the piston when the fluid presses onto the second face area 130, the piston movement is stopped when the second piston part reaches the first bore part, so that the second piston part rests against an annular face 133 created by the difference in inner diameter of the first and the second bore parts, which is shown in Fig. 4B. The annular space 131 is fluidly connected with ambient and thus pressure-relieved via a hole 61, thus allowing movement of the piston.
In Figs. 4A and 4B, the annular barrier further comprises a locking element 138 adapted to mechanically lock the piston when the piston is in the closed position blocking the first opening, as shown in Fig. 4B.
In Fig. 4A, the second piston part comprises the locking element arranged in the second piston end of the piston, the locking element being springy elements 139 projecting outwards but being suppressed in a third bore part 136 when the piston is in the initial position and the springy elements are released when the piston moves to block the first opening and the springy elements thus project radially outwards as shown in Fig. 4B. Thus, the locking element is collets forming in the second piston end of the piston. The second bore part 120 is arranged between the first bore part and the second bore part, and the third bore part has an inner diameter which is larger than the inner diameter of the second bore part.
When using a mechanical lock preventing backwards movement of the piston, there is no need for a check valve to prevent the return of the piston when the pressure inside the annular barrier increases. In this way, the risk of dirt preventing closure of the check valve and the risk that a pressure increase in the annular space of the barrier forces the piston to return and provide fluid communication from the inside of the tubular part again is thus eliminated. In the known solutions using check valves, the expandable tubular has a potential risk of breaking or rupturing when fracking the formation with colder fluid, such as seawater. By permanently blocking the fluid communication between the annular space and the inside of the well tubular structure, the expandable tubular will not undergo so large changes in temperature and pressure, and thus the risk of rupturing is substantially reduced.
In Fig. 5A, the annular barrier comprises a locking element 138 which is arranged around the second piston part 123. The bore further comprises a third opening 137 in the second bore part 120, which third opening is in fluid communication with the annular barrier space 15 and the annulus or borehole 8.
In Fig. 3, the sensor unit comprises a communication device 21 configured to communicate sensor data to another communication unit further up the well or to a communication module 28 in the tool shown in Fig. 3 adapted to receive the sensor data.
As shown in Fig. 7, the downhole completion system may further comprise one or more third annular barrier(s) 11c arranged between the first annular barrier 11a and the second annular barrier 11b. Each annular barrier comprises a sensor unit 18, so that the confined space 17 between the first annular barrier 11a and the third annular barrier 11c can be tested to verify the sealing properties of the first annular barrier from below which would also be the direction in which the hydrocarbon-containing fluid from the reservoir would apply pressure onto the annular barrier. Also, the confined space 17 between the third annular barrier 11c and the second annular barrier 11b can be tested from below to verify sufficient sealing properties of the third annular barrier. By having a third sensor unit below the second annular barrier, also the sealing abilities of the second annular barrier may be verified. The annular space above the first annular barrier is called the B-annulus B and this is normally not pressurised during production but may be tested during completion of the well and later on.
As shown in Fig. 4, the first annular barrier may comprise elastomeric seals 22 on an outside of the expandable tubular. And in Fig. 7, the second and third annular barriers 11b, 11c are made solely of metal and have no sealing elements on the outer face of the expandable tubular.
In another embodiment, the downhole completion system comprises at least one annular barrier made solely of metal, preferably only annular barriers made solely of metal, so that a metal to rock seal is established between the well tubular metal structure and the cap layer. When having a metal to rock seal, the downhole completion system is prepared for plug and abandonment (P&A), and the well can easily be abandoned without having to enter the B-annulus to also fill that with cement to abandon the well, since the seal to cap rock is a metal to rock seal and thus approved for abandonment.
In Fig. 8, the downhole completion system further comprises a second well tubular metal structure 24 extending at least partly within the first well tubular metal structure and extending below the cap layer. The second well tubular metal structure 24 is suspended from the first well tubular metal structure and may also be called a liner hanger or a production casing. The second well tubular metal structure 24 extends into the reservoir for producing hydrocarbon-containing fluid and is connected with the first well tubular metal structure by means of an annular barrier or another packer. The second well tubular metal structure may comprise one or more annular barriers.
The sensor unit comprises a sensor 25, such as a pressure sensor, a temperature sensor or similar sensors. One sensor unit may comprise a plurality of sensors. The sensors may be different types of sensors so as to measure different properties of the confined space or the fluid in it.
In order to complete the well, a borehole is drilled down through the cap layer and the extent of the cap layer is identified. Then, the first well tubular metal structure is submerged and introduced into the borehole, and the first annular barrier and the second annular barrier are arranged at least partly opposite the cap layer, so that the expandable tubular of the first annular barrier and the second annular barrier overlaps the cap layer. Subsequently, the expandable tubular of the first annular barrier and the second annular barrier is expanded to abut the inner cap layer face to enclose a confined space and provide the main barrier of the completion. Then, the confined space is pressurised to a predetermined pressure by means of the valve device shifting position from a first position providing fluid communication from an inside of the first well tubular metal structure to the annular barrier space to a second position providing fluid communication between the annular barrier space and the confined space. Thus, the annular barrier space equalises its pressure with the confined space, and the pressure in the confined space is monitored to watch if it is kept substantially constant over a period of time to verify the sealing properties of at least one of the annular barriers against the cap layer. The pressure in the confined space is determined and monitored by the sensor unit. The step of pressurisation is performed from the top of the well or by means of a tool inserted into the first well tubular metal structure. First the expandable tubular is expanded and then the confined space is pressurised.
A stroking tool may be used for pressurising an isolated zone opposite the expansion opening. The stroking tool is a tool providing an axial force. The stroking tool comprises an electrical motor for driving a pump. The pump pumps fluid into a piston housing to move a piston acting therein. The piston is arranged on the stroker shaft. The pump may pump fluid into the piston housing on one side and simultaneously suck fluid out on the other side of the piston.
By fluid or well fluid is meant any kind of fluid that may be present in oil or gas wells downhole, such as natural gas, oil, oil mud, crude oil, water, etc. By gas is meant any kind of gas composition present in a well, completion, or open hole, and by oil is meant any kind of oil composition, such as crude oil, an oil-containing fluid, etc. Gas, oil, and water fluids may thus all comprise other elements or substances than gas, oil, and/or water, respectively.
By a well tubular metal structure, casing, liner or production casing is meant any kind of pipe, tubing, tubular, liner, string etc. used downhole in relation to oil or natural gas production.
In the event that the tool is not submergible all the way into the casing, a downhole tractor can be used to push the tool all the way into position in the well. The downhole tractor may have projectable arms having wheels, wherein the wheels contact the inner surface of the casing for propelling the tractor and the tool forward in the casing. A downhole tractor is any kind of driving tool capable of pushing or pulling tools in a well downhole, such as a Well Tractor®. Although the invention has been described in the above in connection with preferred embodiments of the invention, it will be evident for a person skilled in the art that several modifications are conceivable without departing from the invention as defined by the following claims.

Claims

A downhole completion system (1) for completing a well (2) having a top (3), comprising:
- a formation (4) comprising:
- a cap layer (5) having an upper end (6) and a lower end (7),

- a borehole (8) extending through the cap layer to provide an inner cap layer face (9),

- a first well tubular metal structure (10) arranged in the borehole comprising

- a first annular barrier (11a) and a second annular barrier (11b), each annular barrier comprising:
- a tubular part (12), the tubular part being mounted as part of the first well tubular metal structure,

- an expandable tubular (14) surrounding the tubular part, each end section (31, 32) of the expandable tubular being connected with the tubular part,

- an annular barrier space (15) between the tubular part and the expandable tubular, and

- an expansion opening (16) in the tubular part through which pressurised fluid passes for expanding the expandable tubular and bringing the annular barrier from an unexpanded position to an expanded position,

wherein the first annular barrier is arranged at the upper end, and in the expanded position the expandable tubular of the first annular barrier overlaps the cap layer, and the second annular barrier is arranged at the lower end, and in the expanded position the expandable tubular of the second annular barrier overlaps the cap layer.
A downhole completion system according to claim 1, wherein in the expanded position the first annular barrier, the second annular barrier, the first well tubular metal structure and the cap layer enclose a confined space (17).
A downhole completion system according to claim 1 or 2, wherein the first well tubular metal structure comprises a sensor unit (18) arranged between the first annular barrier and the second annular barrier and configured to measure a property of a fluid in the confined space.
A downhole completion system according to any of the preceding claims, wherein the sensor unit is comprised in the first annular barrier or the second annular barrier.
A downhole completion system according to any of the preceding claims, further comprising a pressurisation device (19) for pressurising the first well tubular metal structure.
A downhole completion system according to any of the preceding claims, further comprising one or more third annular barrier(s) (11c) arranged between the first annular barrier and the second annular barrier.
A downhole completion system according to any of the preceding claims, wherein the sensor unit comprises a communication device (21) configured to communicate sensor data.
A downhole completion system according to any of the preceding claims, wherein the first annular barrier or the second annular barrier comprises a valve device (23) in fluid communication with the expansion opening.
A downhole completion system according to any of the preceding claims, further comprising a second well tubular metal structure (24) extending at least partly within the first well tubular metal structure and extending below the cap layer.
A downhole completion system according to any of the preceding claims, wherein one of the annular barriers is made solely of metal material.
A downhole completion system according to any of the preceding claims, wherein the sensor unit comprises a sensor (25) such as a pressure sensor or a temperature sensor.
A completion method for a downhole completion system (1) according to any of claims 1-11, comprising the steps of:
- identifying the cap layer,

- introducing the first well tubular metal structure into the borehole,

- arranging the first annular barrier and the second annular barrier at least partly opposite the cap layer, so that the expandable tubular of the first annular barrier and the second annular barrier overlaps the cap layer, and

- expanding the expandable tubular of the first annular barrier and the second annular barrier to abut the inner cap layer face to enclose a confined space.
A completion method according to claim 12, further comprising the step of pressurising the confined space to a predetermined pressure.
A completion method according to claim 12 or 13, further comprising the step of determining if the pressure in the confined space is kept substantially constant over a period of time to verify the sealing properties of at least one of the annular barriers against the cap layer.
A completion method according to any of claims 12-14, further comprising the step of shifting a valve device of one of the annular barriers from a first position providing fluid communication from an inside of the first well tubular metal structure to the annular barrier space to a second position providing fluid communication between the annular barrier space and the confined space.