MX2008016052A

MX2008016052A - Methods and apparatus for wireline drilling on coiled tubing.

Info

Publication number: MX2008016052A
Application number: MX2008016052A
Authority: MX
Inventors: Spyro Kotsonis; Warren Zemlak; Iain Cooper
Original assignee: Schlumberger Technology Bv
Priority date: 2006-06-15
Filing date: 2007-06-12
Publication date: 2009-02-06
Also published as: RU2436929C2; GB2454373A; RU2009101029A; EP1867831B1; EP1867831A1; CA2655245A1; GB0823035D0; US20090321141A1; WO2007144157A1

Abstract

Apparatus for drilling an underground borehole, comprising: - a tubular conveyance system (18) including an electric cable and a supply of drilling fluid, the supply of drilling fluid being arranged in use to pump fluid from the surface down the inside of the tubular conveyance (18) so as to return to the surface via the annulus between the outside of the tubular conveyance (18) and the borehole; - a drilling system (20) comprising an electrically powered pump (28) and a drilling motor (22), the pump (28) being arranged in use to pump fluid from the borehole outside the drilling system (20) up through the inside of the drilling system (20); - a connector (30) connecting the drilling system (20) to the tubular conveyance system (18), through which the pump (28) and motor (22) are connected to the electric cable, and - a flow diverter at which flow down the inside of the tubular conveyance system (18) is diverted into the annulus, and flow up the inside of the drilling system (20) is diverted into the annulus.

Description

METHOD AND APPARATUS FOR DRILLING WINDING IN ROLLED PIPING TECHNICAL FIELD This invention relates to methods and apparatus for drilling holes that is particularly applicable for drilling with wire boring apparatus carried in rolled pipe.

Background of the technique Current common coiled tubing (CTD) uses high hydraulic power delivered from the surface through the coiled tubing (CT) to feed a positive displacement drilling (PDM) motor which in turn feeds the drill of drilling. This high drilling energy needs a large diameter CT that demands larger surface installations.

The current path change methods in a CTD regularly involve a fixed bend in the PDM, and a hydraulic or hydraulic over electric means to rotate the azimuth bend. Apart from the larger and heavier surface equipment, this form of CT drilling is limited in scope by the buckling limit of the CT, and It involves a conversion of low hydraulic energy efficiency to the distance in feet of drilling.

Patent No. 2 548 616 describes a method for drilling a well with a conduit to the surface through which a fluid is pumped (current CTD). The option of a cable in the CT with an electric motor in the bottom of the hole assembly by actuating the drill is also described but the conduit still provides the axial thrust for the drilling.

EP 0 110 182 describes an apparatus with a crawler tractor / tractor (with anchors and a stroker), an umbilical from the surface for communications and feeding an electric pump feeding the hydraulic tractor, and steering methods. The means for turning the bit are described as purely hydraulic (either from the hydraulic distribution system, or from a hydraulic line from the surface.) The CT is also described.

Patent US 6 629 570 describes a high power electric motor capable of drilling in the CT. In use the drilling fluid flows through the motor and returns to the surface through the drill and ring (common circulation).

WO 2004 011766 describes a drilling system fed by wire line in which the fluid produced from the hole is circulated as drilling fluid. A downhole pump is used to perform the common or reverse circulation through the downhole drilling tool. The flow to the surface is through the production pipeline around the cable.

Other documents describing wireline drilling systems include WO 2004 072437 and WO 2005 071208.

The object of the invention is to provide a drilling apparatus that does not need high capacity CT due to the reduced requirements of hydraulic power which still provides effective cleaning of the hole in the drilling zone to prevent it from sticking. The invention achieves this objective by providing electrical power to the drilling system through a cable and providing a flow diverter to allow the downward drilling fluid to flow around the outlet of the drilling assembly while using the normal ring flow above the system. of perforation for the good transport of cuts.

DESCRIPTION OF THE INVENTION One aspect of the invention is an apparatus for drilling an underground hole, consisting of: a tubular transport system including an electric cable and a drilling fluid supply, the supply of the drilling fluid is arranged in use to pump fluid from the surface down the interior of the tubular transport to return to the surface through the ring between the outside of the tubular transport and the hole; - a drilling system consisting of a drilling motor powered by electricity and a pump which is arranged in use to pump fluid from the hole out of the drilling system upwards through the interior of the drilling system; - a connector that connects the drilling system to the tubular transport system and to the electric cable; Y - a flow diverter in which the downward flow of the interior of the tubular transport system is diverted towards the ring, and the upward flow of the interior of the drilling system is diverted towards the ring.

The use of the flow diverter makes it possible to provide reverse ciation (ciation from the ring to the BHA) where the drilling is being carried out improving the hole cleaning in small diameter holes and reducing the risk of adhesion.

Preferably, the drilling system has separate rotary and axial control mechanisms. It is particularly preferred that the axial drive mechanism contains a crawler tractor system. The drill motor can consist of an electric motor powered through the electric cable. The drilling system usually contains an electric pump but may contain a jet pump instead of the pump powered by electricity.

Usually the tubular transport system contains rolled pipe. This can be a simple rolled tube or it can contain various sections joined end to end. Because the drilling action is handled by the drilling system, it is not necessary that the tubular transport system provide the torsion for a rotary drilling action or high axial rigidity to transfer the weight in the rock necessary for drilling.

In a particularly preferred configuration, the flow diverter is part of the connector. Otherwise, the flow diverter is placed in the tubular conveyor above the connector.

In use, the flow diverter can direct part of the downward drilling fluid around the outside of the drilling system and the rest of the fluid return to the surface around the outside of the tubular conveyance. In this way, the reverse ciation around the drilling system changes to common ciation around the tubular transport, which allows for the transportation of improved cuts in the main part of the hole. The flow diverter may be arranged to divert the flow from the inner side of the drilling system to the ring above the point at which it deflects the flow from the tubular conveying system to the ring.

One embodiment of the apparatus further contains a jet system that includes one or more flow nozzles arranged to direct jets of fluid into the bore to eliminate accumulated deposits. Preferably, the flow nozzles are adjustable in order to change the flow direction of the fluid thereof.

In this mode, the flow diverter can direct the fluid to the flow nozzles to send jets and further contains an adjustable valve for varying the amount of fluids directed through the flow nozzles and the amount of fluid directed to the ring.

The apparatus may also contain a rotating crown driven by the motor for use in the subsequent flaring. A turbine driven by fluid flow of the tubular transport system can be connected to drive the crown through a gear train. An electric generator can be connected to the turbine and an electric motor connected to the crown through the gear train, the turbine of the generator being used to power the electric motor and drive the crown.

Another aspect of the invention is a method of drilling an underground hole using an apparatus containing a tubular transport system including an electric cable and a drilling fluid supply; A drilling system consisting of a pump powered by electricity and a drill motor; A connector connecting the drilling system to the tubular transport system, through which the pump and motor are connected to the cable electric; and a flow diverter; The method consists in: - pumping fluid from the surface down the inner side of the tubular conveyance in order to return it to the surface by means of the ring between the outer part of the tubular conveyance and the needle; Y using the pump powered by the drilling system to pump fluid from the hole that is on the outside of the drilling system up through the inner side of the drill and drilling system; - diverting the downward flow of fluid from the interior of the tubular conveyance system to the annulus, and diverting the downward flow from the interior of the perforation system and the annulus using the flow diverter; Y - using the drilling motor to drill the hole using the drilling system.

Preferably, the method consists in diverting part of the drilling descending fluid around the outside of the drilling system and the rest of the fluid return it to the surface around the outside of the tubular transport.

It is also preferred that the method further consists in directing jets of fluid from one or more fires of a jet system into the bore to eliminate accumulated deposits. The flow nozzles can be adjusted in order to change the flow direction of these.

The fluid can be diverted to the jet flow nozzles by using the flow diverter and adjusting a valve to vary the amounts of fluid directed through the flow nozzles and the amount of fluid directed toward the ring.

The method can also consist of the back flaring of the hole using the drilling system. The back flaring can be done using a rotary crown driven by the drilling motor and / or a hydraulic system.

BRIEF DESCRIPTION OF THE DRAWINGS Figure 1 shows a drilling operation using the apparatus according to a first embodiment of the invention; Figure 2 shows details of the connection and flow diverter of Figure 1; Figure 3 shows a drilling operation using the apparatus according to a second embodiment of the invention; Y Figure 4 shows details of the jet nozzles and the resulting turbulent flow pattern in a third embodiment of the invention.

Modes for Carrying Out the Invention The drilling operation shown in Figure 1 is conducted using a conventional CT unit 10 and injector / pressure control 12 installation on the surface of the well 14 and is used to drill a lateral well 16 which extends outwardly from the main well 14. The side well has been started in the usual manner by grinding a window in the liner and drilling laterally using a whip fist to provide deviation in the direction of the drilling. The drilling apparatus consists of a CT 18 transport system carrying a drilling assembly 20 at its lower end. The transport system 18 contains a CT that has an electric cable running inward from the surface. The weight of the tool is carried by the CT 18, so that the electric cable only needs to be able to support its weight. A drilling fluid provider forms part of the CT 10 unit on the surface and pumps down drilling fluid into the CT.

The drilling assembly contains a motor section 22 that includes an electric motor that provides a rotary drive to a drill bit 24. Immediately behind the engine section is a crawler tractor unit 26 that contains an open-hole tractor to provide axial control to the drill bit 24. Acting together, the electric motor and the crawler tractor unit 26 provide the control to the drill bit 24 to allow the drilling to proceed. The track tractor unit 26 can also be operated in reverse to pull the motor section and bit from the hole. A pump section 28 is mounted on the crawler tractor unit 26 and has a pump electric mounted on it. A channel extends from the drill bit upwards towards the engine section 22 and section of the crawler tractor 26 to the pump so that in normal use, the pump can extract fluid and perforated cuts upwards through the drill bit 24 and inside the drill assembly 20.

The drilling assembly 20 is connected to the end of the CT by means of a connection unit 30. The proportion unit '30 provides a mechanical connection between the CT and the drilling assembly 20 and an electrical connection between the electrical cable and the electrical components of the drilling assembly 20.

In the embodiment of Fig. 1, the connection unit 30 also consists of a flow diverter as shown in more detail in Fig. 2. The flow diverter is formed by flow channels 32, 34 in the flow unit. connection 30. The flow channel 32 is connected to the interior of the CT so that the fluid that is flowing under the CT is vented to the ring surrounding the CT and the piercing assembly via the lower ports 36 in the lower part of the connector 30. The fluid that comes out of these lower ports 36 it flows mainly back to the surface in the ring but a part of this fluid also flows down the ring around the drill assembly 20 to be pulled up through the bit 24 by the action of the pump. The flow channel 34 connects to the channel running through the interior of the drill assembly 20 and is withdrawn towards the ring by means of the upper ports 38 on the upper part of the connector 30 above the lower ports 36. In this way any Fluid and vent cuts through the upper ports 38 are brought back to the surface in the ring by the increased flow of fluids leaving the lower ports 36. In this form, the cuts are conserved outside the ring around the perforation 20 reducing the probability of ^ accumulation and adhesion in the smallest annular space. The ring vent above the drill assembly 20 allows normal well control to be exercised and avoids the possibility of return of the hydrocarbons to the surface at the CT.

The connector shown in Fig. 2 also has a rear flare device consisting of a rotary crown 40 mounted on the top of the connector 30. The crown 40 is driven by a turbine and gear train (not shown), the turbine is driven by the flow of fluid along the tool. In an alternative embodiment, the turbine can drive an electric generator (alternator) to power an electric motor to drive the crown 40. Still another version can take electric power from the cable. In use, the crown 40 can be operated when the piercing assembly 20 is pulled out of the hole and allows any lips or ridges that are formed to be uniform and easily allow the passage of the piercing assembly 20 from the hole with less likelihood of adherence.

Fig. 3 shows a further embodiment of the invention in which the flow diverter is placed in the main well 14 in order to reduce the problems related to the transport of cuts in the lateral hole 16 and possible contamination of the deposit with infiltration of the cuts through the wall of the hole. The CT is divided during deployment, as described in European Patent Application No. 05291698.8 and the flow diverter 42 is inserted at this point. The combination with a CT 44 connector between the CT between the drill assembly 20 allows the drilled cuts to be returned to the main well 14 (preferably a coated section) ejecting the cuts from the flow diverter 42 and the ring. The circulation of the conventional drilling fluid at this point is used to transport the cuts to the surface. This proposal eliminates the transport of cuts in the section of the ring of the open hole of the lateral well 16 and therefore decreases the possibility of accumulation of cut platforms. This in turn reduces the risks of adhesion when pulling the drill assembly 20 out of the hole.

Once the drilling operation has been carried out, the task of pulling the drilling assembly 20 out of the hole (POOH) can potentially encounter problems depending on the condition of the drilled hole. The solutions depend on the condition of the POOH. The drill assembly 20 may include sensors to evaluate the condition of the hole for the risk of accumulation of solids that may potentially impede BHA movement and / or CT in the well. The sensors included in the tool to detect these conditions include sensors of inner diameter, azimuth density neutron, and internal and annular pressure.

? As the drill assembly 20 is pulled back, it can drag cuts left in the hole and these can eventually accumulate sufficiently to create a barrier through which it can not be pulled using only the CT. A solution for this case is to send the jet fluid back to the ring while the POOH mobilizes the cuts and transports them in the ring, so that they do not accumulate to cause a potential problem of adhesion. The jet fluid may be provided by means of nozzles preferably at or near the connector 30 but potentially in other parts of the drill assembly 20 or elsewhere in the CT. A preferred form of the jet arrangement is shown in Fig. 4. The nozzles 46 are configured to provide a jet flow with a helical swirl as it exits a nozzle. These nozzles are known in other well cleaning applications and can be applied mutatis mutandis to this application.

The jet arrangement may include a mechanism using hydraulic or electrical signals that allow the direction of flow from the nozzle to allow the flow to be adjusted from the nozzle in the vicinity of the cuts, to further mobilize the cuts, or to give Some directional jet approach as necessary. The dictation of the flow velocity to the outward and backward jet will give more control in cleaning efficiency for specific conditions. As mentioned above, the conditions incorporated in the tool (for example internal and annular pressures) can be used to determine the condition, optimal jet configuration and to confirm the effectiveness of the cleaning operation (for example, by decreasing the density of circulation ECD equivalent).

Hydraulic signaling may include methods such as changes and modulation of flow velocity from the pump of the surface unit, and drop of balls. Electrical signals may include solenoid activation, or the use of bi-stable valves (to decrease the need for high power consumption for extended periods of time as is the case with traditional solenoids). These bi-stable valves are described in EP113578.

A pure jet of a flange as the tool is pulled (or pulled) back may not be enough to overcome the "step" it encounters. Shallow formations such as shales, detachment of coal, or other such formations can cause long steps to form them. In that case, a mechanical means to soften the flange or perforate any of the protruding formations (to a dimension larger than the diameter of the tool) may be necessary. Various solutions are described above in relation to Fig. 2.

One solution to this problem is to use an electric motor to drive a rotating crown. However, because the hydraulic power of the CT flow is available, other methods are possible to create the flaring action without consuming power from the wired cable.

One of those proposals involves using CT flow to power a turbine whose axes rotate the crown to flaring by means of a gear train. Others involve the use of CT flow to power a turbine connected to an alternator to create electric power that can then run an electric motor that turns the crown to flaring through a gear train.

The use of both techniques, the back flared with a crown, can be particularly advantageous. rotary and jet, for difficult conditions when a method can only prove slow or less effective.

In the simplest configuration, as shown in Fig. 2, all the flow through the CT exits in the flow diverter in the connector 30 above the drill assembly 20 and below the CT connection. If enough output ports are provided 36 and the flow rate is sufficient, the cuts are transported in the ring, but the jet is not made and extra mobilization of the cuts is not achieved. From the flow leaving the CT, a small percentage flows down around the drill assembly 20 as the pump pushes the fluid through the drill 24 and up through the drill assembly 20 in "reverse" circulation, and then exits above the exit ports 36 so that the lower flow and cuts are mixed with the flow of the CT living outside the flow diverter.

In another embodiment, a downward valve may also be included to dictate the flow rate divided between the exit ports 36 and the jet nozzles 46. Apart from being able to switch between jet and single flow, this valve can also produce impulses of pressure to eliminate harder flanges in a way similar as that described in US5944123 and US6062311. The valve can be activated by electricity using surface commands, or hydraulically commanded using flow variation schemes (eg jet switches over a specific flow rate and pressure drop).

An additional advantage of energy available in the CT fluid is the ability to feed a jet pump in the pump section 28. That jet pump can replace the electric motor that drives the pump. The use of a jet pump will create a small increase in surface energy needs but has the advantage that the length of the tool can be considerably reduced (pump, transmission, gearbox, motor, oil compensation, control of engine and electronic controls), while increasing the reliability.

In addition, a dual pump system can be used to circulate around the drill assembly in the side hole 16 and, to act as a booster in the well 14 to circulate the cuts to the surface. Other changes can be made while they are within the scope of the invention.

Claims

REIVI DICACIONES

Apparatus for drilling an underground hole, consisting of: - a tubular transport system including an electric cable and a drilling fluid supplying device, the drilling fluid supplying being arranged in use to pump fluid from the surface below the interior of the conveyance tubular in order to return to the surface through the ring between the outside of the tubular conveyance and the hole; - a drilling system consisting of a drilling motor powered by electricity and a fixed pump in use to pump fluid from the outer hole above the drilling system through the interior of the drilling system; - a connector connecting the drilling system to the tubular transport system and the electric cable, and - a flow diverter in which the flow downstream of the interior of the tubular conveyance is diverted to the ring and the flow up the interior of the drilling system it is diverted towards the ring.
The apparatus according to claim 1, wherein the drilling system has separate axial and rotary control mechanisms.
The apparatus according to claim 2, wherein the axial control mechanism consists of a crawler tractor system.
The apparatus according to claim 1, 2 or 3, wherein the drilling motor consists of an electric motor powered through the electric cable.
The apparatus according to claim 1, 2 or 3, wherein the drilling system contains a jet pump for pumping fluid through the drilling system.
The apparatus according to any of the preceding claims, wherein the tubular transport system consists of a rolled pipe.
The apparatus according to any of the preceding claims, wherein the flow diverter is part of the connector.
The apparatus according to any of claims 1-6, wherein the flow diverter is positioned in the tubular conveyance above the connector.
The apparatus according to any of the preceding claims, wherein in use, the flow diverter directs part of the drilling fluid below the outside of the drilling system and the rest of the fluid back to the surface around the outside of the conveyance. tubular.
The apparatus according to any of the preceding claims, wherein the flow diverter is arranged to divert flow from the interior of the drilling system to the ring above the point at which the diverter flows from the tubular transport system to the ring .
The apparatus according to any of the preceding claims, further contains a jet system including one or more flow nozzles arranged to direct jets of fluid into the bore to eliminate accumulated deposits.
12. The apparatus according to claim 11, wherein the flow nozzles are adjustable in order to change the flow direction of the fluid therefrom.
13. The apparatus according to claim 11 or 12, wherein the flow diverter directs the fluid to the jet stream nozzles and further contains an adjustable valve for varying the amount of fluid directed through the flow nozzles and the amount of fluid directed towards the ring.
14. The apparatus according to any of the preceding claims, further contains a rotary crown driven by a motor powered for use in the subsequent flaring.
15. The apparatus according to claim 14, wherein the motor is a motor is an electric motor powered by the electric cable.
16. The apparatus according to claim 14, further contains a turbine driven by the fluid flow of the tubular transport system and connected to drive the crown through a gear train.
17. The apparatus according to claim 16, further contains an electric generator connected to the turbine and an electric motor connected to the crown through the gear train, the output of the generator is used to power the electric motor and drive the crown.
18. A method for drilling an underground hole using an apparatus consisting of a tubular conveyance system that includes an electric cable and a drilling fluid supply; a drilling system containing a pump powered by electricity and a drilling motor; A connector connecting the drilling system to the tubular transport system, through which the pump and the motor are connected to the electric cable; and a flow diverter, the method consists in: - pumping fluid from the surface below the interior of the tubular conveyance in order to return it to the surface through the ring between the outside of the tubular conveyance and the hole; and - use the pump powered by electricity from the drilling system to pump fluid from outside the hole above the system drilling through the interior of the drilling system; - diverting the flow of fluid under the interior of the tubular transport system to the ring, and diverting the flow up the interior of the drilling system to the ring using the flow diverter; and - use the drilling motor to drill the hole using the drilling system.
The method according to claim 18, consists in diverting a part of the drilling fluid below around the outside of the drilling system and the rest of the fluid back to the surface around the outside of the tubular conveyance.
20. The method according to claim 18 or 19, further contains a jet director of the fluid from one or more nozzles of a jet system within the bore to eliminate accumulated deposits.
21. The method according to claim 20, further consists in adjusting the flow nozzles in order to change the direction of fluid flow therefrom.
22. The method according to claim 18, 19 or 20, consists of directing the flow to the flow nozzles for jetting using the flow diverter and adjusting a valve to vary the amount of fluid directed through the flow nozzles and the amount of fluid directed towards the ring.
23. The method according to any of claims 18-22, further consists of the post-flaring of the hole using an additional electric motor in the drilling system.
24. The method according to claims 18-22, consists in the subsequent flaring using a rotary crown used by the drilling motor.
25. The method according to claims 23 or 24, consists of the subsequent flaring using a jet system.