NO20211431A1 - System and method for pressure testing of a liner lap - Google Patents

System and method for pressure testing of a liner lap Download PDF

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Publication number
NO20211431A1
NO20211431A1 NO20211431A NO20211431A NO20211431A1 NO 20211431 A1 NO20211431 A1 NO 20211431A1 NO 20211431 A NO20211431 A NO 20211431A NO 20211431 A NO20211431 A NO 20211431A NO 20211431 A1 NO20211431 A1 NO 20211431A1
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NO
Norway
Prior art keywords
sealing element
pressure
liner
casing
fluid
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Application number
NO20211431A
Other versions
NO347299B1 (en
Inventor
Nader Behjat
Grant Mackenzie Knight
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Well Set P&A As
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Publication date
Application filed by Well Set P&A As filed Critical Well Set P&A As
Priority to NO20211431A priority Critical patent/NO347299B1/en
Publication of NO20211431A1 publication Critical patent/NO20211431A1/en
Publication of NO347299B1 publication Critical patent/NO347299B1/en

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/117—Detecting leaks, e.g. from tubing, by pressure testing
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/005—Monitoring or checking of cementation quality or level
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M3/00—Investigating fluid-tightness of structures
    • G01M3/02—Investigating fluid-tightness of structures by using fluid or vacuum
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M3/00—Investigating fluid-tightness of structures
    • G01M3/02—Investigating fluid-tightness of structures by using fluid or vacuum
    • G01M3/26—Investigating fluid-tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors
    • G01M3/28—Investigating fluid-tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables or tubes; for pipe joints or seals; for valves ; for welds
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M3/00—Investigating fluid-tightness of structures
    • G01M3/02—Investigating fluid-tightness of structures by using fluid or vacuum
    • G01M3/26—Investigating fluid-tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors
    • G01M3/28—Investigating fluid-tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables or tubes; for pipe joints or seals; for valves ; for welds
    • G01M3/2807—Investigating fluid-tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables or tubes; for pipe joints or seals; for valves ; for welds for pipes
    • G01M3/2815—Investigating fluid-tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors for pipes, cables or tubes; for pipe joints or seals; for valves ; for welds for pipes using pressure measurements

Description

SYSTEM AND METHOD FOR PRESSURE TESTING OF A LINER LAP
FIELD
The present invention relates to pressure testing of the liner lap between a liner and a casing in a wellbore.
BACKGROUND
In normal well construction of an oil and gas well, a series of casing sections are run into the well and cemented in place. When the well extends to the zone of the formation from which hydrocarbons will be extracted, i.e. the reservoir, a liner is typically hung from a liner hanger located at the bottom of the lowest casing in the series of casing sections. In this connection, the liner has a smaller outer diameter than the casing from which it hangs.
Typically, the liner is set inside the casing by cement at an overlap region referred to as the ‘liner lap’. Cementing of the liner into the casing is a complicated process, which is prone to problems often resulting in a poor-quality seal between the liner and the casing, which may lead to hydrocarbons flowing between the liner and the wellbore, and entering the casing via the defective cement in the liner lap. Such inflow of hydrocarbons is highly undesirable as is well known in the art.
There is therefore a need to inflow test the liner lap, which means exposing the liner lap between the liner and the casing to a reduced hydrostatic pressure to determine if the sealing mechanisms used in this location, such as cement, block the flow of hydrocarbons as intended. In some situations it is also desirable to perform a positive pressure test on the liner lap, that is the opposite to the inflow test, i.e. providing an increased hydrostatic pressure to determine if the sealing mechanisms used in this location, such as cement, block the flow of wellbore fluid from the wellbore through the liner lap, as intended.
Attempts have been made to efficiently and accurately perform tests to ensure that hydrocarbons do not leak through the liner lap or the liner itself.
US 2014/0338896 A1 discloses methods of determining whether a wellbore sealing operation has been performed correctly, and to liners which facilitate the determination of whether a wellbore sealing operation has been performed correctly. Pressure sensors are located on or in the liner or casing, such that the pressure in the annulus can be monitored during a cementing operation. The data relating to the pressures is sent to the surface by a variety of means, and this indicates to the operator at the surface if the cementing operation has been performed correctly.
US2019/0162049A1 discloses a clean-out assembly which can be used to perform an inflow test on the reservoir liner (not the liner lap). This is arranged by running drillpipe into the polished bore receptacle at the top of the liner. This arrangement allows for an inflow test of the liner itself to be performed i.e. the test is along the liner internal diameter. However, the most common route of leakage of hydrocarbons is through the seal created by the cement at the liner lap.
The invention has for its object to remedy or to reduce at least one of the drawbacks of the prior art, or at least provide a useful alternative to prior art.
The object is achieved through features, which are specified in the description below and in the claims that follow.
SUMMARY
The invention is defined by the independent patent claims. The dependent claims define advantageous embodiments of the invention.
According to a first aspect of the invention, there is provided a pressure test tool for pressure testing a liner lap between a liner and a casing in a wellbore, the pressure test tool comprising: an upper sealing element; a lower sealing element; and a pressure adjustment means; wherein the upper sealing element is configured to form a seal against an internal surface of a casing in use, and the lower sealing element is configured to form a seal against an internal surface of a liner in use, thereby creating an isolated volume in use, between the upper sealing element and the lower sealing element, wherein the pressure adjustment means is configured to increase or decrease the pressure in the isolated volume, in use, thereby creating a pressure differential across the liner lap to perform a pressure test of the liner lap.
The pressure test tool is advantageous in that it creates an isolated volume, allowing the pressure within the isolated volume to be quickly and easily adjusted when compared with adjustment of a much larger volume. Additionally, using an isolated volume at the liner lap allows for pressure testing of the liner lap without requiring that the entire liner, which may be thousands of meters long, be exposed to an increased or decreased pressure. This is particularly advantageous if there is other equipment or sensitive areas in the liner which it is desirable to shield from reduced pressures or in order to prevent the well becoming ‘under-balanced’ meaning that the hydrostatic pressure generated by the fluid column in the well no longer exceeds the pore pressure in the reservoir rock formations.
The pressure adjustment means may be configured to adjust the pressure in the isolated volume by either: moving fluid from the isolated volume to an upper fluid volume above the upper sealing element or a lower fluid volume below the lower sealing element, to create an underbalance in the isolated volume, thereby inflow testing the liner lap or by moving fluid from an upper fluid volume above the upper sealing element or a lower fluid volume below the lower sealing element to the isolated volume to create an overbalance in the isolated volume, thereby creating a positive pressure test on the liner lap.
The pressure adjustment means may be a pump.
The pressure adjustment means may be a piston.
The pressure adjustment means may be a pressure adjustment chamber.
The upper sealing element may be an expandable packer or a conformable packer. The conformable packer may be a swab cup.
The lower sealing element may be an expandable packer or a conformable packer. The conformable packer may be a swab cup. The lower sealing element may be configured to seal against the polished bore receptacle in the liner.
The upper sealing element may be expandable from a collapsed configuration to an expanded configuration, wherein in the collapsed configuration the upper sealing element is configured to be run into a casing without forming a seal with the internal surface of the casing, and in the expanded configuration the upper sealing element is configured to form a seal with the internal surface of the casing.
The lower sealing element may be expandable from a collapsed configuration to an expanded configuration, wherein in the collapsed configuration the lower sealing element is configured to be run into a casing and liner without forming a seal with the internal surface of the casing or the internal surface of the liner, and in the expanded configuration the lower sealing element is configured to form a seal with the internal surface of the liner.
The pressure test tool may further comprise: a fluid inlet port; and a fluid outlet port; wherein the fluid inlet port is located between the upper sealing element and the lower sealing element, and is in fluid communication with the pressure adjustment means, and the fluid outlet port is located above the upper sealing element or below the lower sealing element, and is in fluid communication with the pressure adjustment means. This is advantageous as the upper sealing element may, in some examples, create a seal above which is a volume of fluid which is open to the surface, and therefore the volume of this fluid may be increased without increasing the pressure of the fluid in the wellbore.
Alternatively, the fluid inlet port may be located above the upper sealing element or below the lower sealing element, and be in fluid communication with the pressure adjustment means and the fluid outlet port is located between the upper sealing element and the lower sealing element, and is in fluid communication with the pressure adjustment means.
The pressure test tool may further comprise: an upper pressure sensor configured to measure a pressure in the casing above the upper sealing element in use; and/or an intermediate pressure sensor configured to measure a pressure in the isolated volume in use; and/or a lower pressure sensor configured to measure a pressure in the liner below the lower sealing element in use.
The pressure adjustment means may be further configured to adjust the pressure of the fluid in a lower fluid volume below the lower sealing element.
The pressure adjustment means may be configured to adjust the pressure in the lower fluid volume by either: moving fluid from the above the lower sealing element to the lower fluid volume below the lower sealing element, thereby increasing the pressure in the lower fluid volume below the lower sealing element, and/or moving fluid from the lower fluid volume below the lower sealing element to above the lower sealing element, thereby decreasing the pressure in the lower fluid volume below the lower sealing element.
According to a second aspect of the invention, there is provided a method of pressure testing a liner lap between a casing and a liner, comprising the steps of:
a. providing a pressure test tool according to the first aspect of the invention;
b. running the pressure test tool into the casing and partially into the liner, such that the upper sealing element is located in the casing and the lower sealing element is located in the liner;
c. sealing the upper sealing element against an internal surface of the casing and sealing the lower sealing element against an internal surface of the liner, thereby creating an isolated volume;
d. activating the pressure adjustment means to increase or decrease the pressure in the isolated volume, thereby pressure testing the liner lap. The method is advantageous in that it allows the pressure within the isolated volume to be quickly and easily adjusted when compared with adjustment of a much larger volume. Additionally, the resulting pressure test data will be less ambiguous and easier to interpret when testing a smaller volume. Additionally, using the method to reduce the pressure of an isolated volume at the liner lap allows for inflow testing of the liner lap without requiring that the entire liner, which may be thousands of meters long, be exposed to a reduced pressure. This is particularly advantageous if there is other equipment or sensitive areas in the liner which it is desirable to shield from reduced pressures or in order to prevent the well becoming ‘under-balanced’ meaning that the hydrostatic pressure generated by the fluid column in the well no longer exceeds the pore pressure in the reservoir rock formations.
Step c. may further comprises the steps of:
i) expanding the upper sealing element from a collapsed configuration to an expanded configuration, and
ii) expanding the lower sealing element from a collapsed configuration to an expanded configuration.
According to a third aspect of the invention, there is provided a method of pressure testing a liner and a liner lap between a casing and the liner, comprising the steps of:
a. providing a pressure test tool according to the first aspect of the invention;
b. running the pressure test tool into the casing and partially into the liner, such that the upper sealing element is located in the casing and the lower sealing element is located in the liner;
c. sealing the lower sealing element against an internal surface of the liner to create a lower fluid volume below the lower sealing element; d. activating the pressure adjustment means to increase or decrease the pressure in the lower fluid volume, thereby pressure testing the liner; e. sealing the upper sealing element against an internal surface of the casing and, thereby creating an isolated volume between the upper sealing element and the lower sealing element;
f. activating the pressure adjustment means to increase or decrease the pressure in the isolated volume, thereby pressure testing the liner lap.
BRIEF DESCRIPTION OF THE DRAWINGS
Embodiments of the invention will now be described with reference to the following drawings, in which:
Fig.1 shows a known arrangement of a liner lap;
Fig.1b shows a pressure test tool being run in a collapsed configuration to the location required to perform a pressure test of the liner lap;
Fig.1c shows the pressure test tool of Fig.1b in an expanded configuration, ready to perform a pressure test of the liner lap;
Fig.1d shows another pressure test tool being run in a collapsed configuration to the location required to perform a pressure test of the liner lap;
Fig.1e shows the pressure test tool of Fig.1d with a lower sealing element in an expanded configuration for increasing the pressure within the liner; and
Fig.1f shows the pressure test tool of Fig.1d in an expanded configuration, reading to perform a pressure test of the liner lap.
For clarity reasons, some elements may in some of the figures be without reference numerals. A person skilled in the art will understand that the figures are just principal drawings. The relative proportions of individual elements may also be distorted.
DETAILED DESCRIPTION OF THE DRAWINGS
In the following is described examples of preferred embodiments illustrated in the accompanying drawings
Figs. 1a-1c
Fig.1a shows a simplified schematic of a known well construction configuration comprising a tubular casing 100 made of steel and configured to maintain the form of a wellbore (not shown) in a manner so well known it need not be described herein. The casing 100 extends from a uphole end 101 of the casing 100 to a downhole end 102 of the casing 100. A tubular liner 200 extending from an uphole end 201 of the liner 200 to a downhole end (not shown), and of smaller diameter than the diameter of the casing 100, has been run into the casing 100 until the uphole end 201 is close to the downhole end 102 of the casing 100, leaving an overlapping annular region called the liner lap 300 at or near to the downhole end 102 of the casing 100.
It will be understood by those skilled in the art that a myriad of other equipment may be used in conjunction with the casing 100 and/or liner 200, particularly around their connection, such as, but not limited to, casing shoes and liner hangers. Where casing shoes and liner hangers are used, the liner lap 300 may be the space between the casing shoe and the liner hanger.
Stressing the adaptability of the invention, it is herein described in an example with no casing shoe or liner hanger, and the liner lap 300 is merely, in the presently described example, a region of overlap between the casing 100 and the liner 200 which is sealed to stop an undesirable flow of hydrocarbons 400 from a formation (not shown) adjacent to the liner 200, into the casing 100, through the liner lap 300.
In the standard simplified well construction configuration shown in Fig.1a the liner lap 300 comprises cement 301 although it is again stressed that the liner lap 300 may comprise any plurality of sealing devices or equipment.
Referring now to Fig.1b, a pressure test tool 500 has been run into the casing 100 and liner 200 such that an upper sealing element 501 is operatively engageable with the internal surface of the casing 100 and a lower sealing element 502 is operatively engageable with the internal surface of the liner 200. In this connection, still referring to Fig.1b, the pressure test tool 500 is run into the casing 100 and liner 200 in a collapsed configuration, wherein the upper sealing element 501 does not form a seal with the casing 100 and the lower sealing element 502 does not form a seal with the liner 200 while the tool 500 is being run in.
The upper 501 and lower 502 sealing elements are expandable packers in the presently described example. In other examples (not shown) the upper 501 and lower 502 sealing elements may be conformable packers. It will be understood that the upper 501 and lower 502 sealing elements may be any component configured to be movable from a collapsed configuration, which allows the pressure test tool 500 to be run into the casing 100 and liner 200 without forming a seal with the casing 100 or liner 200, and then moved to an expanded configuration shown in Fig.1c where the upper sealing element 501 forms a seal with the casing 100 and the lower sealing element 502 forms a seal with the liner 200.
When the pressure test tool 500 is run into the casing 100, the lower sealing element 502 may be moved from the collapsed to the expanded configuration and then the upper sealing element 501 is similarly moved from the collapsed to the expanded configuration. Alternatively, when the pressure test tool 500 is run into the casing 100, the upper sealing element 501 may be moved from the collapsed to the expanded configuration and then the lower sealing element 502 is similarly moved from the collapsed to the expanded configuration. Alternatively, both sealing elements 501, 502 may be moved from the collapsed to the expanded configuration at the same time.
Communication with the sealing elements 501, 502 may be configured to be via electric wireline, mud pulse telemetry, radio waves, or any other known and commonly used downhole communications technique, the configuration of which would be well within the capabilities of a person skilled in the art.
Once the tool 500 has been set in the expanded configuration shown in Fig.1c, an isolated volume 600 is created between the upper sealing element 501 and the lower sealing element 502. The isolated volume 600 is separate from a first volume 601 above the upper sealing element 501 and a second volume 602 below the lower sealing element 502. It will be understood that the upper volume 601 may be a volume of wellbore fluid reaching to the surface, or may be another isolated volume for a different purpose. The lower volume 602 is a volume of wellbore fluid within the liner 200. The lower volume 602 may extend for several thousand meters below the lower sealing element 502. Due to the location of the upper sealing element 501 providing a pressure tight seal against the casing 100, and the location of the lower sealing element 502 providing a pressure tight seal against the liner 200, the liner lap 300 is exposed to the isolated volume 600. In this regard, changes (increase or decrease) in pressure in the isolated volume 600 are applied to the liner lap 300, allowing an pressure test to be conducted on the liner lap 300 by adjusting the pressure within the isolated volume, as will now be described.
As shown in Fig.1c, the tool 500 comprises a pump 503 connected to an inlet port 504 in fluid communication with the isolated volume 600 and an outlet port 505 in fluid communication with the upper volume 601. The pump 503 is configured to pump fluid from the isolated volume 600 to the upper volume 601, thereby reducing the pressure in the isolated volume 600 such that an inflow test can be conducted.
Alternatively to the arrangement shown in Fig.1c, the pump 503 may be connected to an outlet port 505 in fluid communication with the lower volume 602, and the pump 503 may then by configured to pump fluid from the isolated volume 600 to the lower volume 602, thereby reducing the pressure in the isolated volume 600 such that an inflow test can be conducted.
Although not shown in Figs 1b or 1c, it will be understood that the pump 503 may be configured to pump fluid from the upper 601 or lower 602 volume to the isolated volume 600, thereby increasing the pressure in the isolated volume 600 such that a positive pressure test can be conducted. In this regard, the inlet port 504 shown in Fig. 1c would be replaced by an outlet port, and the outlet port 505 shown in Fig.1c would be replaced by an inlet port.
Referring again to the inflow test arrangement shown in Fig.1c, as the pressure in the isolated volume 600 is reduced, the liner lap 300 is inflow tested, i.e. the sealing performance at the liner lap 300 is tested, and if not sufficient, hydrocarbons will flow through the liner lap 300 to inside the isolated volume 600, thereby confirming that a previously created seal at the liner lap 300 is not sufficient.
The tool 500 may, in some examples (not shown in Figs.1a-1c), comprise an upper pressure sensor configured to measure a pressure in the casing 100 above the upper sealing element 501. Alternatively, or additionally, the tool 500 may comprise an intermediate pressure sensor configured to measure a pressure in the isolated volume 600. Alternatively, or additionally, the tool 500 may comprise a lower pressure sensor configured to measure a pressure in the liner 200 below the lower sealing element 502. Communication with the upper pressure sensor, intermediate pressure sensor and lower pressure sensor may be configured to be via electric wireline, mud pulse telemetry, radio waves, or any other known and commonly used downhole communications technique, the configuration of which would be well within the capabilities of a person skilled in the art.
Figs. 1d-1f
An alternative configuration to that shown in Figs.1a-1c is now shown in Figs. 1d-1f. In a pressure test tool 500’ shown in Figs.1d-1f, many similar components to those of the pressure tool 500 of Figs.1a-1c are indicated with the addition of a ’ after the reference. Referring now to Fig.1d, the pressure test tool 500’ has been run into the casing 100 and liner 200 such that an upper sealing element 501’ is operatively engageable with the internal surface of the casing 100 and a lower sealing element 502’ is operatively engageable with the internal surface of the liner 200. Similarly to the pressure test tool 500 of Figs.1a-1c, the pressure test tool 500’ comprises a pump 503’ operatively connected to an inlet port 504’ between the upper sealing element 501’ and the lower sealing element 502’. Additionally, the pump 503’ is operatively connected to an upper outlet port 505’ above the upper sealing element 501’ and a lower outlet port 506’ below the lower sealing element 502’. The pump 503’ is configured to pump fluid from the above the lower sealing element 502’ to below the lower sealing element 502’, and to pump fluid from an isolated volume 600’ between the upper sealing element 501’ and the lower sealing element 502’ to above the upper sealing element 501’ as will now be explained.
Still referring to Fig.1d, the pressure test tool 500’ is run into the casing 100 and liner 200 in a collapsed configuration, wherein the upper sealing element 501’ does not form a seal with the casing 100 and the lower sealing element 502’ does not form a seal with the liner 200 while the tool 500’ is being run in.
The upper 501’ and lower 502’ sealing elements are expandable packers in the presently described example. In other examples (not shown) the upper 501’ and lower 502’ sealing elements may be conformable packers.
It will be understood that the upper 501’ and lower 502’ sealing elements may be any component configured to be movable from a collapsed configuration, which allows the pressure test tool 500’ to be run into the casing 100 and liner 200 without forming a seal with the casing 100 or liner 200, and then moved to a first expanded configuration shown in Fig.1e where the lower sealing element 502’ forms a seal with the liner 200 and the upper sealing element 502’ does not form a seal with the casing 100. When in this first expanded configuration, the pump 503’ is activated to pump fluid from above the lower sealing element 502’ to below the lower sealing element 502’, thereby increasing the pressure within the lower volume 602’ below the lower sealing element 502’ in the liner 200. The pump 503’ may draw fluid from above the lower sealing element 502’ from the inlet port 504’, or from another inlet port (not shown) located anywhere on the tool 500’ above the lower sealing element 502’. Such pumping of fluid to below the lower sealing element 502’ increases the pressure within the liner 200 such that the liner can be pressure tested. To allow pressure testing of the liner 200, the tool 500’ comprises a lower pressure sensor 510’ configured to measure the pressure in the lower volume 602’ in the liner 200 below the lower sealing element 502’. This measured pressure is also useful for verifying the integrity of the lower sealing element 502’ during a future pressure test of the liner lap 300.
In a second expanded configuration shown in Fig.1f, the lower sealing element 502’ forms a seal with the liner 200 and the upper sealing element 501’ forms a seal with the casing 100. An isolated volume 600’ is created between the upper sealing element 501’ and the lower sealing element 502’. The isolated volume 600’ is separate from a first volume 601’ above the upper sealing element 501’. It will be understood that the upper volume 601’ may be a volume of wellbore fluid reaching to the surface, or may be another isolated volume for a different purpose. A pressure test can then be performed on the isolated volume 600’ in a similar manner to as described with reference to Fig.1c, i.e. fluid can be pumped from the isolated volume to the first volume 601’ above the upper sealing element 501’ to create a decreased pressure in the isolated volume 600, thereby inflow testing the liner lap 300. It will again be understood that the inlet 504’ and outlet 505’ valves may be reversed such that the tool 500’ can perform a positive pressure test on the liner lap after pressure testing of the liner 200 as explained above with reference to Fig.1c.
Communication with the sealing elements 501’, 502’ may be configured to be via electric wireline, mud pulse telemetry, radio waves, or any other known and commonly used downhole communications technique, the configuration of which would be well within the capabilities of a person skilled in the art.
It will be understood that the tool 500, 500’ may be run on electric wireline, drill pipe, coiled tubing, or any other known means of intervention. It is within the realms of the skilled person to be able to make the required modifications to the upper or lower sections of the tool 500, 500’ to suitably adapt the tool 500, 500’ to be run on a particular means of introducing the tool 500, 500’ into a well.
It will be within the capabilities of a person skilled in the art to determine suitable increases and/or decreases in pressure in the above-mentioned examples and in further examples not illustrated. As an example only, a pressure differential across the liner lap of between 3000kPa and 15,000kPa may be used, for example a pressure differential of 10,000kPa may be used.
It will be appreciated that the pressure adjustment means shown is an example of a suitable pressure adjustment means. However, other pressure adjustments means may also be used. As another non-limiting example, the pressure adjustment means may be configured to increase or decrease the pressure in the isolated volume by use of a pressure adjustment chamber in the tool. In this configuration, the pressure in the isolated volume may be adjusted by extracting fluid from the isolated volume into the pressure adjustment chamber to decrease the pressure in the isolated volume, or by delivering fluid to the isolated volume from the pressure adjustment chamber to increase the pressure in the isolated volume. In some examples, the pressure adjustment chamber may be located inside the tool, or alternatively the pressure adjustment chamber may be located on an external surface of the tool.
It should be noted that the above-mentioned embodiments illustrate rather than limit the invention, and that those skilled in the art will be able to design many alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses shall not be construed as limiting the claim. Use of the verb "comprise" and its conjugations does not exclude the presence of elements or steps other than those stated in a claim. The article "a" or "an" preceding an element does not exclude the presence of a plurality of such elements.
The mere fact that certain measures are recited in mutually different dependent claims does not indicate that a combination of these measures cannot be used to advantage.

Claims (15)

1. A pressure test tool for pressure testing a liner lap between a liner and a casing in a wellbore, the pressure test tool comprising:
an upper sealing element;
a lower sealing element; and
a pressure adjustment means;
wherein the upper sealing element is configured to form a seal against an internal surface of a casing in use, and the lower sealing element is configured to form a seal against an internal surface of a liner in use, thereby creating an isolated volume in use, between the upper sealing element and the lower sealing element,
wherein the pressure adjustment means is configured to increase or decrease the pressure in the isolated volume, in use, thereby creating a pressure differential across the liner lap to perform a pressure test of the liner lap.
2. The pressure test tool of claim 1, wherein the pressure adjustment means is configured to adjust the pressure in the isolated volume by either:
i) moving fluid from the isolated volume to an upper fluid volume above the upper sealing element or a lower fluid volume below the lower sealing element, to create an underbalance in the isolated volume, thereby inflow testing the liner lap or ii) moving fluid from an upper fluid volume above the upper sealing element or a lower fluid volume below the lower sealing element to the isolated volume to create an overbalance in the isolated volume, thereby creating a positive pressure test on the liner lap.
3. The pressure test tool of claim 1 or 2, wherein the pressure adjustment means is a pump or a piston or a pressure adjustment chamber.
4. The pressure test tool of any preceding claim, wherein the upper sealing element and/or the lower sealing element are expandable or conformable packers.
5. The pressure test tool of any preceding claim, wherein the lower sealing element is configured to seal against a polished bore receptacle in the liner.
6. The pressure test tool of any preceding claim, wherein the upper sealing element is expandable from a collapsed configuration to an expanded configuration, wherein in the collapsed configuration the upper sealing element is configured to be run into a casing without forming a seal with the internal surface of the casing, and in the expanded configuration the upper sealing element is configured to form a seal with the internal surface of the casing.
7. The pressure test tool of any preceding claim, wherein the lower sealing element is expandable from a collapsed configuration to an expanded configuration, wherein in the collapsed configuration the lower sealing element is configured to be run into a casing and liner without forming a seal with the internal surface of the casing or the internal surface of the liner, and in the expanded configuration the lower sealing element is configured to form a seal with the internal surface of the liner.
8. The pressure test tool of any preceding claim, further comprising:
a fluid inlet port; and
a fluid outlet port;
wherein the fluid inlet port is located between the upper sealing element and the lower sealing element, and is in fluid communication with the pressure adjustment means, and the fluid outlet port is located above the upper sealing element or below the lower sealing element, and is in fluid communication with the pressure adjustment means.
9. The pressure test tool of any preceding claim, further comprising:
a fluid inlet port; and
a fluid outlet port;
wherein the fluid inlet port is located above the upper sealing element or below the lower sealing element, and is in fluid communication with the pressure adjustment means and the fluid outlet port is located between the upper sealing element and the lower sealing element, and is in fluid communication with the pressure adjustment means.
10. The pressure test tool of any preceding claim, further comprising:
a upper pressure sensor configured to measure a pressure in the casing above the upper sealing element in use, and/or;
an intermediate pressure sensor configured to measure a pressure in the isolated volume in use, and/or;
a lower pressure sensor configured to measure a pressure in the liner below the lower sealing element in use.
11. The pressure test tool of any preceding claim, wherein the pressure adjustment means is further configured to adjust the pressure of the fluid in a lower fluid volume below the lower sealing element.
12. The pressure test tool of claim 11, wherein the pressure adjustment means is configured to adjust the pressure in the lower fluid volume by either:
i) moving fluid from the above the lower sealing element to the lower fluid volume below the lower sealing element, thereby increasing the pressure in the lower fluid volume below the lower sealing element, and/or
ii) moving fluid from the lower fluid volume below the lower sealing element to above the lower sealing element, thereby decreasing the pressure in the lower fluid volume below the lower sealing element.
13. A method of pressure testing a liner lap between a casing and a liner, comprising the steps of:
a. providing a pressure test tool according to any of claims 1 to 12; b. running the pressure test tool into the casing and partially into the liner, such that the upper sealing element is located in the casing and the lower sealing element is located in the liner;
c. sealing the upper sealing element against an internal surface of the casing and sealing the lower sealing element against an internal surface of the liner, thereby creating an isolated volume; and
d. activating the pressure adjustment means to increase or decrease the pressure in the isolated volume, thereby pressure testing the liner lap.
14. The method of claim 13, wherein step c. further comprises the steps of:
iii) expanding the upper sealing element from a collapsed configuration to an expanded configuration, and iv) expanding the lower sealing element from a collapsed configuration to an expanded configuration.
15. A method of pressure testing a liner and a liner lap between a casing and the liner, comprising the steps of:
a. providing a pressure test tool according to claim 11 or 12; b. running the pressure test tool into the casing and partially into the liner, such that the upper sealing element is located in the casing and the lower sealing element is located in the liner;
c. sealing the lower sealing element against an internal surface of the liner to create a lower fluid volume below the lower sealing element; d. activating the pressure adjustment means to increase or decrease the pressure in the lower fluid volume, thereby pressure testing the liner; e. sealing the upper sealing element against an internal surface of the casing and, thereby creating an isolated volume between the upper sealing element and the lower sealing element; and
f. activating the pressure adjustment means to increase or decrease the pressure in the isolated volume, thereby pressure testing the liner lap.
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