Patent Application
20220010641
The invention relates to a device for efficient unloading of collected debris from a well in the ground, in which the debris is collected and transported out of the well with a wireline or coiled tubing operated tool string, comprising a wellbore cleanout tool that gathers debris downhole, for then to be hoisted out of the well and unloaded. Said wellbore cleanout tool could be an auger based, suction based, or jetting based tool conveyed on wireline, or it could be a venturi basket conveyed and operated on coiled tubing, or some other tool design based on other working principle or combination thereof, as would be appreciated by a person skilled in the art. More particularly, the well is associated with the production of hydrocarbons, by means of producing hydrocarbons from it or injecting driving fluids such as gas or water into it, and the unloading of the wellbore cleanout tool is carried out when the tool string is positioned in a lubricator at the top of the well. Even more particularly, the device for unloading the wellbore cleanout tool is connected to the lubricator such that the lubricator extends above and below the device. The device comprises sealing means and an outlet such that the debris is transported out of the wellbore cleanout tool, through the device and the outlet and to a suitable external receptacle. In one embodiment of the invention, the process of emptying the wellbore cleanout tool is carried out in such a manner that the pressure within the lubricator is maintained at a level substantially corresponding with the well pressure.
It is well known in the petroleum industry that debris and deposits, collectively termed debris, may accumulate in the production tubular of a well. The debris may be in the form of sand or other particles produced into the wellbore from the reservoir, or salt or other agents that deposit on the production tubing in the form of layers or bridges of scale, wax and asphaltenes, or it may be in the form of particles that have settled out from drilling mud, or from other origin as would be appreciated by a person skilled in the art. Said debris may form a narrow passage choking the production flow or may block the production flow and/or wellbore completely. It is also known that mud remnants accumulating on top of completion barriers which are used when completing a well, prevent correct operation of said barriers, and must be removed to access and open the completion barrier, hence bringing the completion operation forward. Also, debris often forms an obstacle for the passing of intervention tools and make well intervention work difficult.
The particles may be fine particles such as fine sand and silt. Sand may be produced from one or several production zones, and some production zones may be blocked completely. Production tubing in deviating and in horizontal wells, and also S-formed well paths comprising horizontal and vertical portions, may be particularly exposed for settling of debris and congestion. Production from a petroleum well is most efficient when the well path is clean and free from sand and debris.
It is known to use coiled tubing washing/circulation techniques for cleaning constricted or blocked wells, where the debris is circulated out of the well, sometimes in one continuous motion, instead of the debris sequentially being collected into a wellbore cleanout tool, hoisted and unloaded as per the invention herein. Such coiled tubing operation may wash out a considerable amount of debris in a short time, which is advantageous, because in a short time a portion of considerable length can be washed out and blocked production zones reopened. However, coiled tubing conveyed operation suffers from several disadvantages measured up against wireline conveyed operations, in particular on offshore installations. A coiled tubing operation involves transporting and rigging numerous heavy equipment units, including the coil reel, and a tower comprising a gooseneck for introduction of the coiled tubing into the well. Thus, a considerable number of units are transported by ship to an offshore installation or on trucks to land based units, and a number of heavy lifts being required to install the equipment in place. For offshore operations, the lifting of heavy equipment modules, hence the entire clean out operation, may be paused due to bad weather. In addition, installation of the coiled tubing equipment may require relocation of other equipment or entail other associated consequences to the logistics and operative priorities on said offshore installation. Finally, a relatively high number of personnel is required for the conduct of coiled tubing operations.
After completed mission, the coiled tubing is demobilized with the same logistic implications. The total cost of a coiled tubing operation is high, therefore a clean out operation may be put off as long as possible and may even be avoided.
In many cases, where debris must be transported out of a well in stages, the use of coiled tubing is replaced by wireline and, in some cases, combined wireline—tractor-powered mechanical cleanout technology. In one embodiment, powered mechanical cleanout technology utilizes mechanical means for directly, such as using a transport auger, or indirectly, such as operating a pump, to create suction transporting debris into a collecting chamber. In alternative embodiments, the collecting chamber may collect debris by applying a sub-pressure in the collecting chamber relative to the ambient pressure (hydrostatic bailer principle) and opening a valve arrangement when the tool has been landed on top of the debris, to create a suction effect. A general feature for all wireline conveyed wellbore cleanout tool technologies is that when the collecting chamber is full, the tool is hoisted to the surface of the well, whereupon the collecting chamber is emptied. Pending on the scope of the operation and the total volume of debris in the well, the tool may be prepared for a new run, and the exercise repeated until a relevant volume of debris has been removed from the well. There are limitations to this method with respect to what volumes that can be retrieved from the well in one run, and the method is time consuming because of the total time taken to sequentially/repeatedly rig tools into the lubricator, perform the cleanout operation in the well, hoist the tool out, empty it, prepare it for a new run and rig it into the lubricator again.
As a precautionary measure, to avoid the production and accumulation of produced debris, wells may be drained gently to avoid that sand and silt are brought into the production tubing.
Cleaning wells for debris by means of wireline-operated tools is overall efficient if the volume of debris is limited. Here, a roundtrip in the well collects a rather small volume of debris per run. However, the mobilization of wireline is easy compared to the mobilization of a coiled tubing operation, and the total work and logistic effort involved is very moderate in comparison. On the other hand, a wireline-operated tool is inefficient in removal of substantial amounts of debris compared to a coiled tubing wash out operation.
As per the above, method selection for debris cleanout operations often becomes a trade-off between volume of debris present in the well and the total cost of a cleanout operation conducted on wireline or coiled tubing, respectively. In some situations, the total cost favours a coiled tubing operation, and, in some situations, a wireline conveyed cleanout operation being the preferred choice. An ordinary coiled tubing operation on an offshore installation may last for between two and four weeks from start of mobilization and to complete demobilization. An ordinary wireline operation may last for a comparable shorter period, typically from 5 to 10 days. A round trip with a wireline using current technology and tools may last for 6-12 hours. Known wellbore cleanout equipment has a capacity of collecting between 10 and 50 litres of debris in each round trip in the well.
Washing out the debris by circulating fluids from the surface of the well is only possible using coiled tubing and cannot be performed with wireline operated tools (as there is no top to bottom circulation means associated with this service).
To illustrate further, the below example is given, relating to a wireline operation for cleaning out debris in a well having a production tubing with an internal diameter of 177.8 mm (7 inch):
Further to the above example; for this scenario, coiled tubing would normally be the preferred choice to clean out the well. Despite an easier mobilisation exercise and lower daily cost, the time consumption for a wireline orchestrated cleanout operation as per the above example would typically be too long to justify.
A collected volume of 50 litres is generally recognized as a large volume for a round trip using a wireline-based wellbore cleanout tool. In many cases, the collecting capacity per run may be smaller due to restrictions in the well path, limiting the outer diameter of the cleanout tool, and also due to height limitations on the tool sluice system, which is termed as the lubricator. The length of the lubricator is related to rigging constraints, such as crane height, and the maximal permitted length of tool string being defined by the lubricator height again.
U.S. Pat. No. 5,893,417 discloses an apparatus for preventing leakage and spillage of oil from a wellhead or a wireline lubricator when the lubricator is disconnected from a Christmas Tree, i.e. after bleeding off the pressure within the lubricator. The apparatus is connected to the bottom of the lubricator.
In view of the above, there is a clear need for improving existing systems and methods for cleaning a production tubing in a petroleum well. Key to making wireline-based cleanout operations more efficient is to reduce the turnaround time associated with a run in the well. One enabler being emerging wireline cable technologies that allow for a higher running and hoisting speed than what is possible with prior art technology. Another enabler, according to the present innovation, being a system and method that significantly reduces the time associated with unloading a wireline-based wellbore cleanout tool on the surface and preparing it for a subsequent run. Traditionally, as per prior art, a wireline-based wellbore cleanout tool has to be lifted out of the lubricator, unloaded, prepared for a new run and then hoisted into the lubricator again in conjunction with each run in the well. This, together with the time it takes to bleed off pressure from the lubricator before lifting the tool out, and re-pressurising the lubricator prior to running the tool in the hole again, being a major contributor to a long turnaround time, hence overall time it takes to remove larger amounts of debris from a well using wireline. The main goal of the present invention is to enable surface unloading and between-run maintenance of a wellbore cleanout tool without removing it from the lubricator between runs.
The invention has as 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.
The invention is defined by the independent patent claims. The dependent claims define advantageous embodiments of the invention.
In a first aspect the invention relates more particularly to a circulation unit for connecting to a lubricator. The lubricator is suitable for housing a wireline operated tool string for collecting debris within a petroleum well. The circulation unit comprises a house provided with an upper lubricator connection and at least one lower internal seal member. The seal member is adapted to seal against an outer surface of the tool string. The circulation unit is provided with an outlet above the seal member and the outlet is connected to a reservoir. The circulation unit is provided with a lower lubricator connection. The house, the upper lubricator connection and the lower lubricator connection form a through passage for the tool string. The upper lubrication connection and the lower lubrication connection are adapted for connection to a pressurized lubricator.
A primary fluid surrounds the tool string when the tool string is hoisted into the lubricator. The primary fluid may be a well fluid. The circulation unit is a device that guide a secondary fluid which has been introduced into the lubricator, out of the lubricator through an outlet in the circulation unit.
The upper lubricator connection may comprise a box portion with external threads. The lower lubricator connection may comprise a pin portion, a flange and a collet provided with internal threads. Such box portion and pin portion are known in the art of assembling a lubricator from lubricator sections by threaded connections.
The lower seal member may seal against the surface of the tool string when the lower seal member is in an active position. The lower seal member may be retracted from the surface of the tool string when the lower seal member is in a passive position. In an alternative embodiment the lower seal member may be a wiper seal.
The circulation unit may comprise a second upper seal member and the second seal member may be positioned above the outlet. The upper seal member may seal against the surface of the tool string when the upper seal member is in an active position. The upper seal member may be retracted from the surface of the tool string when the upper seal member is in a passive position. In an alternative embodiment the upper seal member may be a wiper seal.
The circulation unit may comprise an inlet and the inlet may be positioned above the lower seal member. The inlet may be positioned below the upper seal member.
The circulation unit may comprise opening means for displacing a displaceable sliding port on the tool string. The sliding port may be displaced axially along the longitudinal direction of the tool string. The sliding port may be displaced rotationally along the periphery of tool string. The opening means may be an internal constriction. The opening means may be a locking profile. The circulation unit may be provided with orientation means that engage with corresponding orientation means in the outlet of the wellbore clean out tool such that the holes in the gate portion are oriented and aligned with respect to the holes in the outlet of the circulation unit.
The invention also concerns a lubricator assembly comprising a lubricator and a circulation unit as described above. The lubricator assembly may be provided with a filter cleaning unit for cleaning a filter in the tool string. The filter may be positioned on the surface of a wellbore cleanout tool. The filter may be positioned on a sliding port connected to the wellbore cleanout tool. The filter cleaning unit may be positioned below the circulation unit.
In a second aspect the invention relates more particularly to a tool string for collecting debris within a petroleum well, said tool string comprises a wellbore cleanout tool which forms a leading end portion and an opposite outlet end portion, and is provided with filling means at an inlet at the leading end portion. The outlet end portion comprises an outlet mandrel at an outlet for unloading collected debris. The outlet mandrel comprises a gate portion with through holes, and the tool string further comprises a sliding port provided with a filter adapted to cover the gate portion and slidable to uncover the gate portion. The sliding port is adapted to be displaced within a lubricator provided with a circulation unit. The lubricator and the circulation unit may form parts of a lubricator assembly.
In a third aspect the invention relates more particularly to a method for unloading a filled wellbore cleanout tool positioned in a tool string. The wellbore cleanout tool forms a leading end portion and an opposite outlet end portion, where the method comprises:
The circulation unit may be provided with an opening means, said opening means may displace a sliding port to uncover the through holes in the gate portion. The opening means may be a constriction, or a locking profile as explained above.
The lubricator assembly may be provided with a filter cleaning unit, and wherein a filter in the wellbore cleanout tool's outlet may be cleaned by displacing the tool string until the outlet is positioned within the filter cleaning unit. The filter may be positioned on a sliding port. The filter may be positioned on a wall of the wellbore cleanout tool below the sliding port. Below is in the direction of a front tool of the tool string.
In one embodiment the cleanout tool is emptied within the lubricator by using the well pressure as driving force. Well fluid enters the cleanout tool through the inlet at the leading end portion and collected debris is forced out through the outlet at the opposite end of the cleanout tool, the lubricator via the circulation unit's outlet 3 and into a reservoir.
In alternative embodiment the cleanout tool is emptied by isolating the lubricator from the well. A cleaning fluid is pumped into the lubricator below the circulation unit. This enables cleaning fluid to be directed into the leading end portion of the wellbore cleanout tool to help drive the collected debris out of the wellbore cleanout tool and lubricator via the circulation unit's outlet 3 and into a reservoir.
In the following are described examples of preferred embodiments illustrated in the accompanying drawings, wherein:
In the drawings, the reference numeral 100 indicates a known arrangement for a pressure-controlled wireline intervention in a petroleum well (not shown).
As is common on many wireline operations on offshore installations, the riser 130 extends above a deck 101 through a hole 102. Depending on local conditions the deck 101 may be e.g. a hatch deck, a skid deck or an intervention deck. The pressure control device 180 is adapted to the type of cable 190. E.g. if the cable 190 is a slick line, the pressure control device 180 is a stuffing box system, if the cable 190 is a braided wire line cable, the pressure control device 180 is a grease injection head (GIH), as known to the skilled person.
The lubricator 160 forms a sluice for the tool string 200. The pressure control device 180 forms a tight pressure barrier at the top, and the quick test sub 150 may form a tight pressure barrier at the bottom of the lubricator 160. As per prior art way of conducting a wireline based wellbore cleanout operation, each time the tool string 200 is to be removed from the lubricator 160 after a run into the well, the cut valve/work valve 120 is closed, and the manifold 155 or the manifold 135 is opened to reduce the pressure, and the lubricator 160 is drained for fluid through the manifold 155 or the manifold 135. In some cases, the lubricator 160 is additionally flushed with nitrogen to remove all residuals and any hydrocarbon gases. Thereafter the lubricator 160 is opened, usually in the quick test sub 150. Thereafter the lubricator 160 is lifted off the quick test sub 150, whereupon the tool string 200 is laid down on deck using methodology as would be known to a person skilled in the art. For operations involving a known wellbore cleanout tool, when the tool is laid down, debris unloading is performed, together with any between-run maintenance, prior to hoisting it into the lubricator 160 again for another run in the well. This is a time-consuming procedure, and the operators may also be exposed to associated risks such as falling objects, exposure to hydrocarbons and other wellbore material such as low radioactivity material.
An arrangement 1 for a pressure-controlled wireline intervention in a petroleum well provided with a circulation unit 2 is shown in
According to one embodiment of the invention, the outlet 30 is connected to a reservoir such as a debris separator 3 by a tube system 31. The tube system 31 is provided with valves 33. The tube system 31 guides hydrocarbons, water, sand and other unloaded debris from a cleanout tool 230 from the lubricator 160 to the debris separator 3. The tube system 31 is robust and suited for the purpose. The debris separator 3 may be a test separator permanently installed on the facility or a temporary installed test separator. A temporary installed debris separator 3 may be connected to a permanently installed test separator further downstream. For this embodiment, the intention being to perform the unloading of the wellbore cleanout tool 230 without bleeding off the lubricator 160 pressure, or at least, with the lubricator partially pressurized, which is beneficial from a time consumption point of view. For this embodiment, it is seen as an advantage to provide the riser 130, lubricator 160, tube system 31 and debris separator 3 with pressure gauges 35. The pressure gauges 35 may be digital gauges. The digital gauges could also be sensors for detecting; temperature, density, particle, volume and flow. In this embodiment, the well pressure is the driving force for emptying the cleanout tool 230. Well fluid enters an inlet 233 at a leading end portion 231 of the wellbore cleanout tool 230 and drives the collected debris out of the wellbore cleanout tool 230 and lubricator 160 via the outlet 30 and into the separator 3.
The circulation unit's 2 house 29 is further provided with an inlet 20 for an injection of a cleaning fluid. The cleaning fluid may be a wash medium, such as a well fluid, monoethyl glycol (MEG), water, nitrogen gas, etc. For the embodiment shown in
In another embodiment of the invention, shown in
The tool string 200 is shown in
The wellbore cleanout tool 230 working principle may be an auger-based collecting system, a suction tool collecting system with or without a bit in the end, or a suction, jetting and rotating collecting system. Alternatively, the collecting system mechanism may be a mechanical collecting device (not shown) used on a mechanical tool string where gravitation forces are used to displace the collecting device into the debris and thereby filling the collecting device.
The circulation unit 2 is shown in a first embodiment in
The circulation unit 2 is shown in a second embodiment in
The wellbore cleanout tool 230 comprises an outlet mandrel 43 at the outlet 4 (see
The sliding port 41 may be provided with a resilient biasing means (not shown) that bias the sliding port 41 axially along the outlet mandrel 43 to cover the gate portion 45 when the wellbore cleanout tool 230 is run and operated in the well. The resilient biasing means may be a coil spring. After hoisting the wellbore cleanout tool 230 out after an ended cleanout run in the well, upon entering the circulation unit 2, an opening means within the circulation unit 2 displaces the sliding port 41 axially towards the front tool 240 when the outlet 4 is displaced upwardly within the circulation unit 2. The opening means may be the constriction 25 which is adapted to open the sliding port 41. As per this embodiment, upon hoisting the wellbore cleanout tool 230 into the circulation unit 2, the biasing means is further tensioned by the axial displacement of the sliding port 41 towards the front tool 240. After unloading, the wellbore cleanout tool 230 is lowered downwardly out of the circulation unit 2, whereupon the biasing means forces the sliding port 41 axially along the outlet mandrel 43 towards the cable head 210, covering the through holes 49 in the gate portion 45 again. In an alternative embodiment, the circulation unit 2 is provided with a locking profile (not shown) which engage with locking dogs onto the sliding port 41 to facilitate shifting this open, as would be appreciated by a person skilled in the art. In yet another embodiment, the circulating unit 2 is provided with orientation means that engage with corresponding orientation means in the outlet 4, that orient and align the holes in the gate portion 45 with respect to the holes in the outlet 30 of the circulation unit 2.
In an alternative embodiment (not shown) a portion of the outlet mandrel 43 is provided with a filter in the mandrel wall adjacent the gate portion 45. The filter is exposed when the sliding port 41 is axially displaced to cover the through holes 49 of the gate portion 45.
In a further alternative embodiment, the tool string 200 is not provided with a filter at the outlet 4. This may be the case for a wellbore cleanout tool 230 that uses flow to create a suction and/or jetting effect to clean the well, and where there is a debris retention filter in the internals of the tool. In this embodiment the sliding port 41 covers the gate portion 45 when the wellbore cleanout tool 230 collects debris downhole. For all embodiments, the gate portion 45 of the wellbore cleanout tool 230 is in direct contact and/or communication with the wellbore cleanout tool's 230 collecting chambers housing the collected debris.
During collection of debris within the well, the sliding port 41 covers the gate portion 45 as shown in
Operation of the outlet 4 is shown in
In an alternative embodiment, the lubricator 160 is further provided with a filter cleaning unit 5 as shown in
In a further alternative embodiment, the lubricator 160 is further provided with an inspection unit (not shown). The inspection unit may be an optical camera, an infrared camera, an X-Ray scanner, an ultrasound scanner, a magnetic resonance scanner or an inspection window. This inspection unit may be a supplement to tool string instrumentation to check and verify the debris collecting tool string before an additional roundtrip into the well.
The tool string 200 is shown in an alternative embodiment in
The wellbore cleanout tool 230 may comprise transporting means (not shown) such as a pump or an auger to transport debris into the wellbore cleanout tool's 230 collecting chamber. In one embodiment, the front tool 240 assists in loosening consolidated debris within the well. Typically, a motor (not shown) within the motor housing 225 is supplied with electrical energy through the cable 190, whereupon it powers relevant tool modules such as the front tool 240, a pump or an auger. In one embodiment, the sliding port 41 serves an active purpose in the downhole cleanout operation by retaining the debris within the wellbore cleanout tool 230. In alternative embodiments, debris retention means such as filters may be located elsewhere in the wellbore cleanout tool 230. Here, the sliding port 41 mainly serves the purpose of establishing communication between the wellbore cleanout tool's 230 collecting chamber and the circulation unit 2 during the unloading activity on surface. When the wellbore cleanout tool 230 is full, or all debris has been collected from the well, the tool string 200 is hoisted out of the well and returned to the lubricator 160.
In one embodiment, the wellbore cleanout tool 230 is a mechanical bailer or pump bailer, with a top portion of the bailer adapted as per the invention herein, such as with a spring forced sliding sleeve that uncovers a gate portion 45 when the bailer abuts the constriction in the circulation unit 2, enabling the unloading of debris from the bailer via the circulation unit 2 as per methods described herein.
In one embodiment the circulation unit 2 may be provided with a tool catcher (not shown) that grips the tool string 200 and keep the tool string fixed in a correct position. In other embodiments the tool catcher 170 grips the tool string 200.
In one embodiment of the invention, the valves which isolates the lubricator 160 from the well may be closed after the tool string 200 is fixated. In another embodiment they remain open. This may depend on regulatory guidelines, relevant operational constraints, conditions at the well site, and on what type of debris receiving and debris management system that is being used to unload debris on the surface e.g. debris separator 3 or non-pressurized tank 300.
For any of the above embodiments, it is considered advantageous that the wellbore cleanout tool's 230 surroundings inside the pressure control arrangement 1 being filled with liquid and not gas. If gas is present, it would be preferred to close the valves and fill the surroundings between the tool string 200 and the lubricator 160 with a suitable liquid, such as monoethyl glycol (MEG).
After fixation of the tool string 200, the lower seal 23 is activated. If the circulation unit 2 is provided with an upper seal 22, the upper seal 22 is activated. The portion of an annulus below the lower seal 23 is then isolated from the annulus above the lower seal 23. If an upper seal 22 is present, the annulus above the upper seal 22 is then isolated from the annulus below the upper seal 22. An annulus portion forms between the activated lower seal 23 and the activated upper seal 22.
The inlet 20 is positioned in the annulus portion above the lower seal 23, and below the upper seal 22, if the upper seal 22 is present. The outlet 30 is positioned in the annulus portion above the lower seal 23, and below the upper seal 22, if the upper seal 22 is present. The gate portion 45 is positioned in the annulus portion above the lower seal 23, and below the upper seal 22, if the upper seal 22 is present, as well.
For the embodiment of the invention using a debris separator 3 capable of operating at elevated pressure conditions, this is connected to the outlet 30. A wash medium (not shown), such as well fluid, MEG, water or nitrogen gas flows or is being pumped through the injection hose 21 and the inlet 20 and enters the annulus portion within the circulation unit 2. This flow may clean the gate portion 45. The wellbore cleanout tool 230 is now ready for unloading.
Unloading may be performed by several methods. In one embodiment, where the pressure control arrangement 1 is kept at an elevated pressure during unloading, the pressure within the debris separator 3 may be lowered to create a pressure difference between the debris separator 3 and the pressure control arrangement 1. Debris is unloaded by flow from the pressure control arrangement 1 and/or the well, through the wellbore cleanout tool 230, out the gate portion 45 and the outlet 30 to the debris separator 3, the flow being caused by said pressure difference.
In another embodiment, a flow of cleansing fluid may be provided to the leading end portion 231 by the pump 6 pumping cleansing fluid into the inlet 60 on the pressure control arrangement 1 that is located below the circulation unit 2, such as the manifold 135. The resulting flow causing the unloading of debris from the wellbore cleanout tool 230 to take place out the gate portion 45 and the outlet 30 to the debris separator 3 or a non-pressurized disposal tank 300.
In another embodiment, the flow of wash medium through the circulation unit 2 may create a similar suction effect within the wellbore cleanout tool 230.
In a preferred embodiment of the invention, in order to unload the wellbore cleanout tool 230, the means for filling and/or operating the wellbore cleanout tool 230 such as an auger, a pump or other working mechanism of the wellbore cleanout tool 230, being activated at the same time as pumping fluids by the pump 6 into the wellbore cleanout tool 230 via the leading end portion 231, out the gate portion 45 and the outlet 30 to the debris separator 3 or a non-pressurized disposal tank 300 as described above.
In one embodiment, the main means for unloading debris upwards in the wellbore cleanout tool 230, out through the gate portion 45 and the outlet 30 being the same means as are used for collecting debris and filling the wellbore cleanout tool 230 downhole, such as an auger, a pump or other working mechanism of the wellbore cleanout tool 230, or a combination of such means.
According to a preferred embodiment, the pressure difference between the wellbore cleanout tool's 230 inlet at the leading end portion 231, and the circulation unit 2 is monitored to control the unloading operation. Cleaning fluid from the manifold 63 enters the wellbore cleanout tool's 230 inlet at the leading end portion 231 to drive out and in addition volumetric replace any unloaded debris. In one embodiment, volumetric displacement monitoring means are used to verify that the wellbore cleanout tool 230 collected debris downhole, and in addition for monitoring and verifying the unloading operation in general.
For the embodiment where the collected debris of the wellbore cleanout tool 230 is unloaded into a dedicated debris separator 3, the cleaning fluid may be residual fluid from the lubricator 160 and/or the well. For this embodiment, the cut valve/work valve 120 may be kept open whilst unloading the wellbore cleanout tool 230, whereupon unloading of the wellbore cleanout tool 230 takes place by well fluids flushing through the wellbore cleanout tool 230, the circulation unit 2, via the tube system 31 and into the debris separator 3. The flow rate may be controlled by the debris separator's 3 outlet valves, and the unloading continues until all collected debris from the wellbore cleanout tool 230 has been unloaded to the debris separator 3. The debris separator 3 may further be provided with a measuring glass so that the volume of collected debris is monitored. By this procedure, unloading of the wellbore cleanout tool 230 is performed in a fully closed system without any hazardous exposure of chemicals to the crew.
According to a preferred embodiment, for cases where the wellbore cleanout tool 230 is unloaded to a debris separator 3 or a non-pressurized disposal tank 300, cleaning fluid is pumped into the lubricator 160 below the lower seal 23, e.g. through the manifold 135 on the riser 130. The debris separator 3 or disposal tank 300 may be provided with means for monitoring weight to assess the amount of collected debris.
When the unloading is completed, the inlet 20 and the outlet 30 are closed. In one embodiment, the wellbore cleanout tool 230 is provided with a PCP pump (Progressive Cavity Pump, also known as a Moineau pump after the inventor) or other suitable pump type as a means for filling the wellbore cleanout tool 230. Here, upon unloading the wellbore cleanout tool 230, functionality of the PCP pump (verification of functionality prior to a subsequent run) is checked by running the pump against the closed volume inside the closed circulation unit 2. If pressure is rising and maintained at some elevated value, this being an indication that the tool's pump is working properly.
If the wellbore cleanout tool 230 is provided with a check valve (not shown) at the wellbore cleanout tool's 230 lower end portion, the check valve may be tested by closing the outlet 30 and by pumping a fluid through the inlet 20. Pressure will build up inside the wellbore cleanout tool 230 if the check valve is intact and working properly.
According to a preferred embodiment, when the tool string 200 is disconnected from the tool catcher inside the circulation unit 2 or the tool catcher 170, the inlet 20 and the outlet 30 are closed automatically as a safety measure. In one embodiment, this is verified by a sensor. In one embodiment, it is not possible to disconnect the tool string 200 from the tool catcher before the inlet 20 and the outlet 30 are completely closed.
The seals 22 and 23 are deactivated prior to disconnecting the tool string 200.
Before the next round-trip in the well, a filter test may be performed by flushing fluid through the wellbore cleanout tool 230 and through the filter whilst measuring delta pressure across it. Dependent on the arrangement, this may be performed in several different ways. In one embodiment, where the filter 41 is embedded in sliding port 47, prior to testing the filter, the through holes 49 in the gate portion 45 are closed by sliding the sliding port 47 to a closed position. This may be achieved by slightly lowering the tool string 200 within the circulation unit 2. If the tool string 200 is provided with a pump, the pump may be used to create fluid circulation to verify the filter with respect to plugging and restriction. If the tool string 200 is not provided with a pump, the lower seal 23 is activated to isolate the outside of the lower portion of the tool string 200 from the outside of the upper portion. Then, fluid is pumped into the lubricator 160 through the manifold 135 via the pump 6 and led into and through the wellbore cleanout tool 230 and the filter whilst monitoring delta pressure, to verify that the filter has not been plugged or damaged.
When performing flow tests through the wellbore cleanout tool 230 and filter 47 after unloading, fluids should pass unrestricted through the wellbore cleanout tool 230 and through the filter 47. If any resistance monitored, e.g. pressure drop of significance is observed, this indicates that the filter 47 is blocked or partly blocked. If so, according to one embodiment of the invention, the tool string 200 is lowered such that the filter 47 is positioned within the filter cleaning unit 5. The filter cleaning unit 5 is activated and the nozzles 53 spray a pressurized cleaning fluid over the filter 47. The wellbore cleanout tool 230 may be hoisted and lowered several times past active nozzles 53 to clean the filter 47 properly. In one embodiment, where the filter is located in the wall of the mandrel 43 below the sliding port 41, e.g. closer to the front tool 240, the filter cleaning procedure is the same.
In one embodiment, other equipment in the tool string 200, such as electrical motor(s) assemblies, wireline, tractor and anchoring means (not shown) may also be tested and/or prepared for a subsequent run with the tool string 200 hanging within the intact (not disconnected) lubricator 160. For example, lubricator 160 modules could be tailored for filling relevant tools with hydraulic oil between runs. After successful testing the tool string 200 is ready for another decent into the well.
Several modifications are possible within the frame of the present invention. The outlet 4 may be positioned closer to the inlet portion of the wellbore cleanout tool 230. There may be more than one outlet 4. The filter cleaning unit may be positioned within the circulation unit 2. This would be appreciated by a person skilled in the art.
For all embodiments, the invention provides the advantage that unloading of the wellbore cleanout tool 230 is performed within the lubricator 160, avoiding disconnecting and/or remove the lubricator 160 for unloading the wellbore cleanout tool 230.
For the embodiment where the wellbore cleanout tool 230 is unloaded into a pressurized debris separator 3, no pressure safety barrier is broken, and pressure testing before the next decent is not necessary. The process is a closed process and the field crew is not exposed to hazardous chemicals.
For all embodiments, the associated wireline operation for removing debris from a petroleum well becomes more efficient than previous known art and techniques conveyed on wireline. Experience indicate that prior art technology for removing debris from a well on wireline could be conducted in a pace of approximately three runs (trips in the well) per 24 hours as a high estimate. The inventors estimate that applying a design and method according to the present invention, enables six runs and even more per 24 hours, in particular if combining with novel types of wireline that permit a substantially higher running speed than wireline technology of current art.
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.
| Number | Date | Country | Kind |
|---|---|---|---|
| 20181450 | Nov 2018 | NO | national |
| Filing Document | Filing Date | Country | Kind |
|---|---|---|---|
| PCT/NO2019/050249 | 11/12/2019 | WO | 00 |
