AU2013301466A1

AU2013301466A1 - Downhole turbine-driven system

Info

Publication number: AU2013301466A1
Application number: AU2013301466A
Authority: AU
Inventors: Jorgen Hallundbaek; Lars Mangal; Ricardo Reves Vasques
Original assignee: Welltec AS
Current assignee: Welltec AS
Priority date: 2012-08-10
Filing date: 2013-08-09
Publication date: 2015-03-26
Also published as: US20150218900A1; CN104541018A; RU2015107658A; BR112015002298A2; WO2014023829A1; MX2015001608A; CA2881336A1; EP2696026A1; EP2882927A1

Abstract

The present invention relates to a downhole system for performing an operation in a well downhole. The system comprises an elongated tubing string (3) for conducting fluid in the well; a turbine (7) driven by the fluid for driving a shaft (8); a generator (9) driven by the turbine by means of the shaft, a fluid-driven driving section (5) comprising a pump (6) driven by the fluid supplied through the shaft for propelling the fluid-driven driving section and the tubing string forward in the well, and an electrically driven driving section (10) comprising an electrical motor(ll) powered by the generator (9) for propelling the driving section and the tubing string forward in the well, wherein the fluid-driven driving section (5) is arranged between the generator (9) and the electrically driven driving section (10).

Description

WO 2014/023829 PCT/EP2013/066724 1 DOWNHOLE TURBINE-DRIVEN SYSTEM Field of the invention The present invention relates to a downhole system for performing an operation 5 in a well downhole, comprising an elongated tubing string for conducting fluid in the well. Background art 10 Hydrocarbon wells often have more than one branch or lateral radiating from the main borehole. The laterals may again have laterals and be of various lengths. When a borehole having a long lateral have been completed, the borehole is treated with acid to make the hydrocarbon-containing fluid flow and the production is initiated. In order to perform an acid treatment in a lateral, the 15 coiled tubing is pushed down through the borehole or cased hole into the lateral. However, when the coiled tubing is pushed down from surface, it tends to curl as its moves into the lateral which is more horizontal than the main borehole, and at some point the coiled tubing gets stuck in the lateral. The laterals are therefore not made as long as it is actually possible to drill them, as the later acid and 20 service equipment is not able to enter the last part of such long laterals, as the known equipment cannot enter laterals with such a small diameter. Summary of the invention 25 It is an object of the present invention to wholly or partly overcome the above disadvantages and drawbacks of the prior art. More specifically, it is an object to provide an improved downhole system capable of servicing a long lateral with a tubing string. 30 The above objects, together with numerous other objects, advantages, and features, which will become evident from the below description, are accomplished by a solution in accordance with the present invention by a downhole system for performing an operation in a well downhole, comprising: - an elongated tubing string for conducting fluid in the well, 35 - a turbine driven by the fluid for driving a shaft, P1439PC00 WO 2014/023829 PCT/EP2013/066724 2 - a generator driven by the turbine by means of the shaft, and - a fluid-driven driving section comprising a pump driven by the fluid supplied through the shaft for propelling the fluid-driven driving section and the tubing string forward in the well, 5 wherein the system further comprises an electrically driven driving section comprising an electrical motor powered by the generator for propelling the driving section and the tubing string forward in the well, the fluid-driven driving section being arranged between the generator and the electrically driven driving section. 10 In an embodiment, the pump may be driven by the shaft of the turbine. Furthermore, the elongated tubing string may be coiled tubing. 15 Furthermore, the driving sections may have outer diameters of less than 7 inches, preferably less than 6 inches, and more preferably less than 5 inches. Moreover, the tubing string may have a length of at least 5 km, preferably a length of at least 7 km, more preferably a length of at least 9 km, and even more 20 preferably a length of at least 10 km. Additionally, the generator and the electrical motor may be electrically connected through an electrical connection extending through the fluid-driven driving section. 25 Also, the fluid from the tubing string may be supplied to the pump of the fluid driven driving section through a fluid channel extending through the turbine and the generator. 30 In addition, a pressure control valve may be arranged in the fluid channel for reducing the passage of fluid to the pump of the fluid-driven driving section. Further, a flow diverter valve may be arranged in the fluid channel for diverting the fluid supplied to the channel to the turbine. 35 Moreover, the driving section may comprise propelling units contacting an inner surface of the well for propelling the driving sections forward in the well. P1439PC00 WO 2014/023829 PCT/EP2013/066724 3 Also, the propelling units may be non-hydraulically driven units and driven by the electrical motor. Furthermore, the propelling units may be wheels contacting an inner surface of 5 the well. In an embodiment, each wheel may be arranged on a projectable wheel arm. In addition, the wheel arms of the fluid-driven driving section may project in a 10 first direction from a section housing, and the wheel arms of the electrically driven driving section may project in a second direction substantially perpendicular to the first direction. Furthermore, the electrical motor may drive the wheels of the electrically driven 15 driving section. Moreover, each propelling unit of the electrically driven driving section may comprise an electrical motor powered by the generator. 20 Additionally, the electrically driven driving section may comprise a pump driven by the electrical motor for driving the electrically driven driving section forward in the well. The downhole system may further comprise a second electrically driven driving 25 section driven by the generator through an electrical connection in the other electrically driven driving section arranged closest to the tubing string. In one embodiment, the electrically driven driving section arranged closest to the tubing string may comprise a pump for driving hydraulically driven propelling 30 units. Moreover, the second electrically driven driving section may comprise propelling units which are non-hydraulically driven units. 35 In another embodiment, each propelling unit of the second electrically driven driving section may comprise an electrical motor powered by the generator. P1439PC00 WO 2014/023829 PCT/EP2013/066724 4 Furthermore, the electrically driven driving section may comprise a rechargeable battery. The downhole system may further comprise a flow diverter for diverting at least 5 part of the fluid from the tubing string into the well. It is hereby possible to perform acid treatment of the well after the tubing string has been pulled all the way into the very long lateral by starting to pump an acid composition into the tubing string from surface. 10 In an embodiment, the flow diverter may be arranged in a dispersion unit for dispersion of fluids, such as chemical reactants in the well. The chemical reactants may be acid or base containing fluid. 15 The downhole system may further comprise an inflation unit for shielding the driving section while a stimulation operation is performed or the well is treated with an acid or base containing fluid. 20 Furthermore, the downhole system may comprise a detachment unit for detaching the driving section from the tubing string. In an embodiment, the detachment unit may be comprised in the dispersion unit. 25 Furthermore, the downhole system may comprise several electrically driven driving sections, all powered by the generator. Moreover, the downhole system may comprise several generators driven by the shaft. 30 Finally, the present invention relates to a stimulation method for performing acid treatment of a long lateral by the downhole system described above, comprising the steps of: - connecting the turbine with the tubing string, 35 - connecting the generator with the turbine, - connecting the fluid-driven driving section with the turbine, P1439PC00 WO 2014/023829 PCT/EP2013/066724 5 - connecting the electrically driven driving section with the fluid-driven driving section so that electricity is conducted from the generator to the electrically driven driving section, - supplying pressurised fluid into the tubing string, 5 - pulling the tubing string into the lateral by means of the driving sections, and - supplying fluid having an acid concentration down the tubing string to an outlet in the downhole system for treating the lateral with acid. Brief description of the drawings 10 The invention and its many advantages will be described in more detail below with reference to the accompanying schematic drawings, which for the purpose of illustration show some non-limiting embodiments and in which 15 Fig. 1 shows a downhole system according to the present invention, Fig. 2 shows a side view of a downhole system according to the invention, Fig. 3 shows a side view of another downhole system according to the invention, 20 Fig. 4 shows a side view of the downhole system according to Fig. 1, Fig. 5 shows a side view of another embodiment of the downhole system, 25 Fig. 6 shows a cross-sectional view of the fluid-driven driving section shown in Fig. 4, Fig. 7 shows a side view of another downhole system, 30 Fig. 8 shows a side view of yet another downhole system, Fig. 9 shows a side view of yet another downhole system in its deflated position, and 35 Fig. 10 shows the downhole system in its inflated and detached position. P1439PC00 WO 2014/023829 PCT/EP2013/066724 6 All the figures are highly schematic and not necessarily to scale, and they show only those parts which are necessary in order to elucidate the invention, other parts being omitted or merely suggested. 5 Detailed description of the invention Fig. 1 shows a hydrocarbon well 2 having laterals radiating from a main borehole 12. In one of the long laterals 13, a tubing string 3, also called coiled tubing, is being pulled into the more horizontal part of the lateral 13 by two driving 10 sections 5, 10, being a fluid-driven driving section 5 and an electrically driven driving section 10. The driving sections 5, 10 propel themselves and the tubing string within a casing 15 in the lateral. The driving sections 5, 10 are connected with the end 14 of the tubing string which is the furthest away from a well head 30 at the top of the well at the surface or seabed. When entering long laterals by 15 forcing a tubing string down the well, the tubing string will curl at some point also called the "coiled tubing hang-up point" - which causes the string to get stuck. By arranging the driving sections in front of the tubing string, the end of the tubing string is forced forward, preventing the string from curling and getting stuck, and the tubing string is thereby pulled further into the lateral beyond the 20 hang-up point. Today, laterals are made as long as operation and service equipment are able to operate and service along the entire length of the lateral. Once the operation equipment is able to enter further into the ground, the borehole and the laterals 25 can be made longer. Laterals are made with a substantially smaller diameter than the main borehole, which limits the diameter of the equipment and service tools and thus the types of equipment and tools capable of entering even the final and smallest part of a long lateral. Before a well is able to produce, it is subjected to acid treatment. In order to treat even the final part of the lateral, i.e. the part 30 which is the furthest away from the main borehole, with acid, the tubing string supplying the acid needs to be pulled almost all the way to the end of the lateral. If this is not done, the tubing string will curl, which will render acid treatment of the entire lateral impossible and thereby prevent it from producing hydrocarbons. Pulling tools which are able to pull the tubing in the narrow and long laterals 35 therefore need to be self-powered as they cannot be powered sufficiently through wireline from surface. P1439PC00 WO 2014/023829 PCT/EP2013/066724 7 Therefore, between the driving sections 5, 10 and the tubing string 3, a turbine 7 is connected with the tubing string and is driven by high pressure fluid supplied through the tubing string from the top of the well. The turbine 7 drives a generator 9 supplying power through the fluid-driven driving section 5 to the 5 electrically driven driving section 10. When the driving sections enter the end or final part of the lateral, the lateral diameter is highly reduced, meaning that the diameter of the driving sections needs to be equally smaller. Therefore, there is no room in the first fluid-driven driving section for supplying fluid to a second driving section, and the second driving section therefore needs to be electrically 10 driven, as electricity can be conducted through the fluid-driven driving section to the next electrically driven driving section 10. The electrically driven driving section 10 comprises propelling units 18 in the form of wheels, and each wheel comprises an electrical motor for rotating the 15 wheel and propelling the driving unit and the tubing string forward in the well. Thus, the electrically driven driving section comprises non-hydraulically driven propelling units which are directly driven by the generator 9 through a control package 25. The downhole system may comprise several electrically driven driving sections arranged successively and all driven by the generator, as shown 20 in Figs. 9 and 10. The propelling units 18 of the electrically driven driving section 10 may also be rotating units 36 around which a track 37 is arranged as shown in Fig. 3. One rotating unit 18 per track comprises an electrical motor 11 driving the track 37 or 25 belt and thus propelling the driving section forward in the well. As shown in Fig. 4, the fluid-driven driving section 5 comprises a pump 6. The pump 6 is either driven by the rotational shaft of the turbine or by the fluid which is supplied to the pump through a fluid channel 16 penetrating the turbine 7 and 30 the generator 9. The electrically driven driving section 10 comprises the electrical motor 11 powered by the generator for providing a propelling motion of the electrically driven driving section 10. The propelling units of the second driving section are driven by the motor 11 arranged between the driving sections, said motor driving a pump which drives an internal separate hydraulic system driving 35 hydraulic motors in each wheel of the second driving section 10. P1439PC00 WO 2014/023829 PCT/EP2013/066724 8 In Fig. 4, part of the high pressure fluid drives the turbine 7 and thus the generator 9, and the generator powers the motor of the electrically driven driving section 10, and part of the fluid drives the pump 6 of the fluid-driven driving section 5. The fluid in the tubing string 3 thus powers the driving section or 5 sections as the tubing string is pulled into the long lateral 13 (as shown in Fig. 1) by the self-propelling driving sections. Hereby, the fluid from the tubing string is used to drive the tubing string forward in the lateral, and the fluid in the tubing string is simultaneously and/or subsequently used to perform an operation. The tubing string is thus able to enter even long and narrow laterals, such as laterals 10 longer than 2 km and having an inner diameter of the casing or borehole smaller than 7 inches. In order to propel the driving sections and the tubing string forward or backward in the well, the driving sections comprise propelling units 18, such as wheels 39, 15 for contacting an inner surface of the casing or borehole in the well, as shown in Figs. 2, 4-5, and 7-10. The wheels 39 are arranged on projectable wheel arms 19 projecting from a housing 20 of the driving sections 5, 10. In Fig. 5, the wheel arms of the fluid-driven driving section project in a first 20 direction 21 from a section housing, and the wheel arms of the electrically driven driving section project in a second direction 22 substantially perpendicular to the first direction. The wheels are pressed into contact with the inner face of the casing or borehole by the projectable wheel arms for propelling the driving sections forward in the well. 25 The wheels of the fluid-driven driving section are rotated as each wheel comprises a hydraulic motor 23. All the hydraulic motors 23 of the fluid-driven driving section 5 are driven by the pump 6. 30 The wheels of the electrically driven driving section shown in Fig. 5 are also driven by a pump 24 comprised in the electrically driven driving section, which pump is driven by the electrical motor and drives the hydraulic motors 23 in each wheel 39. 35 In Figs. 2 and 7, the wheels 39 of the electrically driven driving section 10 each comprises an electrical motor 11 powered by the generator 9. As shown in Fig. 7, the electrically driven driving section 10 may comprise a control package 25 and P1439PC00 WO 2014/023829 PCT/EP2013/066724 9 a rechargeable battery 26. The rechargeable battery 26 may be charged as the tubing string is pushed down into the first part of the well where there is no risk of the tubing string curling and getting stuck, and when the tubing string enters the last part of the well, the electrically driven driving section 10 is activated to 5 pull the end of the tubing string into the lateral. The generator 9 generates electricity for powering the electrical motor arranged in the electrically driven driving section. The generator and the electrical motor are electrically connected through an electrical connection 17 extending through 10 the fluid-driven driving section 5, as shown in Fig. 6. In Fig. 4, a pressure control valve 28 is arranged in the fluid channel 16 for reducing the passage of fluid to the pump of the fluid-driven driving section. In this way, the pressure of the pressurised fluid does not need to be controlled as 15 accurately from surface to avoid harming the components of the pump. If the pressure of the fluid is too high and in order to prevent damage of the components of the turbine and the generator, a flow diverter 29 is arranged in connection with the turbine for diverting at least part of the fluid supplied to the turbine out through an outlet 33 and into the well surrounding the downhole 20 system, as shown in Fig. 5. As shown in Fig. 7, a flow diverter valve 31 is arranged in the fluid channel for diverting the fluid supplied to the channel to the turbine, and thus, if the pressure of the fluid in the channel is too high, more fluid is allowed to pass through the 25 turbine. When the tubing string 3 has been pulled all the way into the long lateral and the acid operation is to be performed, the fluid having a high acid concentration is supplied down through the tubing string. When performing this type of 30 operation, the downhole system may comprise a flow diverter 29, as shown in Fig. 5, for diverting at least part of the fluid from the tubing string into the well to eliminate the need for detaching the driving sections to let the fluid out of the tubing to perform the acid treatment or acid stimulation of the well. The flow diverter 29 is arranged in a dispersion unit 32 for dispersion of a chemical 35 reactant, such as acid, in the well which is supplied to the chemical dispersion unit through the tubing string 3. P1439PC00 WO 2014/023829 PCT/EP2013/066724 10 In Fig. 2, the dispersion unit 32 comprises a ball seat 40 which is activated by dropping a ball 41 down the tubing string to move the seat and enable passage of the fluid to the outlets 33. The ball in the ball seat closes the passage of fluid to the turbine. 5 A downhole system comprising both a fluid-driven driving section and an electrically driven driving section is shown in Fig. 7. This downhole system further comprises an operational tool arranged in front of the driving section and the furthest away from the tubing string. When the tubing string has been pulled to a 10 certain position in the well, the enormous amount of power in the pressurised fluid in the tubing string can be used to generate power through the turbine and the generator to drive the operational tool. The operational tool 38 shown in Figs. 2 and 7 may be any kind of tool, such as a 15 setting tool, a release tool, a stroker tool, a key tool, a logging tool, etc. Due to the enormous amount of power in the pressurised fluid in the tubing string, the logging tool may operate when the tubing string is pulled down into the well without diminishing the propelling speed of the driving sections. 20 The downhole system shown in Fig. 9 comprises an inflation unit 35. The inflation unit 35 is inflated to shield the driving section while performing a stimulation operation, such as treating the well with acid or base containing fluid. The inflation unit 35 can be any kind of packer inflatable by high pressure fluid. The inflation unit 35 is inflated e.g. by dropping a ball of one size into the fluid to 25 move the ball seat from a position where the fluid is allowed to pass into the turbine to a second position where the fluid is let into the inflation unit. After inflation of the inflation unit, a second and larger ball is dropped, moving the ball seat to a third position where the fluid is let into the well. 30 The downhole system may further comprise a detachment unit 43 arranged inside the dispersion unit 32 for detaching the driving sections from the tubing string, as shown in Fig. 9. Each driving section comprises a battery 26 and a control package 25 so that when the driving sections are detached from the tubing string and when e.g. the acid treatment has been performed, the driving 35 sections are able to propel themselves out of the well. P1439PC00 WO 2014/023829 PCT/EP2013/066724 11 The detachment of the tubing string may take place when the second ball is dropped and the ball seat is moved into a second position where the tubing string is detached from the driving section, thus allowing the fluid to enter into the well. 5 When the inflation unit has been inflated and the driving sections have been detached from the tubing string, as shown in Fig. 10, the tubing string may be pulled backwards, and the stimulation operation, such as the acid treatment, may be initiated. 10 Instead of having an inflation unit 35, the detached tubing string may be pulled further backwards to prevent damage of the driving sections while e.g. the acid treatment is performed. Timers may be used for deflating the inflation unit and activating the driving 15 section to propel themselves out of the well. The electrical motor of the electrically driven driving section may also drive a gearing system driving the propelling units 18 or belts, and one electrical motor is thus able to drive several propelling units or even all propelling units. 20 When the downhole system comprises a second electrically driven driving section, this electrically driven driving section is driven by the generator through an electrical connection 17 in the other electrically driven driving section arranged closest to the tubing string. Hereby, a large number of electrically driven driving 25 sections can be mounted onto the tubing string for pulling the tubing string forward in the well. In another embodiment, the electrically driven driving section arranged closest to the tubing string may comprise a pump for driving the hydraulically driven 30 propelling units each comprising a hydraulic motor 23. Thus, an electrically driven driving section powered by the generator may comprise electrical motors in each wheel or hydraulic motors in each wheel, the hydraulic motors being driven by a pump driven by the electricity from the 35 generator. P1439PC00 WO 2014/023829 PCT/EP2013/066724 12 In the event that two driving sections, such as one fluid-driven driving section and one electrically driven driving section, are not able to pull the tubing string all the way into the lateral, the downhole system may comprise several electrically driven driving sections all powered by the generator, as shown in Fig. 5 8. The downhole system may also comprise several generators driven by the output shaft 8 of the turbine in order to gain more power for pulling the tubing string. In order to perform acid treatment or other fluid stimulations, such as scale 10 removing operations, of the lateral of the well, the downhole system is mounted by connecting the turbine with the tubing string and connecting the generator with the turbine so that the generator is driven by the output shaft 8. Then, the fluid-driven driving section is connected with the turbine so that the fluid channel 16 is connected with the pump 6 of the fluid-driven driving section, and the 15 electrically driven driving section is then connected with the fluid-driven driving section so that electricity is conducted from the generator through the fluid driven driving section to the electrically driven driving section. The pressurised fluid is supplied down the tubing string to the turbine and the fluid channel. In this way, the tubing string is pulled directly into the lateral by the fluid-driven 20 driving section by means of the pressurised fluid and by the electrically driven driving section by means of the turbine, the generator and the electrical motor. When the tubing string is in place for performing the acid treatment or another stimulation operation, fluid having a particular composition, e.g. an acid or base concentration, or fluid comprising enzymes, is supplied down through the tubing 25 string to an outlet 33 in the downhole system for treating the lateral with acid. The downhole system may comprise a dispersion unit 32 for dispersion of the fluid, such as acid or base, into the lateral. The dispersion unit may also comprise valves angled so that the unit is rotated as the pressurised acid containing fluid 30 enters through the valves. Driving sections capable of containing long laterals may have an outer diameter of less than 5 inches and more preferably less than 4 inches. By long laterals is meant laterals, branches or side tracks having a length of at least 4 km, more 35 preferably a length of at least 5 km, and more preferably a length of at least 7 km. P1439PC00 WO 2014/023829 PCT/EP2013/066724 13 By fluid or well fluid is meant any kind of fluid that may be present in oil or gas wells downhole, such as natural gas, oil, oil mud, crude oil, water, or a chemical composition, such as an acid composition. By gas is meant any kind of gas composition present in a well, completion, or open hole, and by oil is meant any 5 kind of oil composition, such as crude oil, an oil-containing fluid, etc. Gas, oil, and water fluids may thus all comprise other elements or substances than gas, oil, and/or water, respectively. By a casing is meant any kind of pipe, tubing, tubular, liner, string etc. used 10 downhole in relation to oil or natural gas production. The driving sections may be a downhole tractor or any kind of driving tool capable of pushing or pulling tools in a well downhole, such as a Well Tractor®. 15 Although the invention has been described in the above in connection with preferred embodiments of the invention, it will be evident for a person skilled in the art that several modifications are conceivable without departing from the invention as defined by the following claims. 20 P1439PC00

Claims

1. A downhole system (1) for performing an operation in a well downhole (2), comprising: 5 - an elongated tubing string (3) for conducting fluid (4) in the well, - a turbine (7) driven by the fluid for driving a shaft (8), - a generator (9) driven by the turbine by means of the shaft, and - a fluid-driven driving section (5) comprising a pump (6) driven by the fluid supplied through the shaft for propelling the fluid-driven driving section and the 10 tubing string forward in the well, wherein the system further comprises an electrically driven driving section (10) comprising an electrical motor (11) powered by the generator for propelling the driving section and the tubing string forward in the well, the fluid-driven driving section being arranged between the generator and the electrically driven driving 15 section.

2. A downhole system according to claim 1, wherein the generator and the electrical motor are electrically connected through an electrical connection (17) extending through the fluid-driven driving section. 20

3. A downhole system according to claim 1 or 2, wherein the fluid from the tubing string is supplied to the pump of the fluid-driven driving section through a fluid channel (16) extending through the turbine and the generator. 25

4. A downhole system according to any of the preceding claims, wherein the driving section comprises propelling units (18) contacting an inner surface (27) of the well for propelling the driving sections forward in the well.

5 A downhole system according to claim 4, wherein the propelling units are 30 non-hydraulically driven units and driven by the electrical motor.

6. A downhole system according to claims 4 or 5, wherein the propelling units are wheels (39) contacting an inner surface (27) of the well. 35

7. A downhole system according to claim 6, wherein each wheel is arranged on a projectable wheel arm (19). P1439PC00 WO 2014/023829 PCT/EP2013/066724 15

8. A downhole system according to any of claims 4-7, wherein each propelling unit of the electrically driven driving section comprises an electrical motor (11) powered by the generator. 5

9. A downhole system according to any of the preceding claims, wherein the electrically driven driving section comprises a pump (24) driven by the electrical motor for driving the electrically driven driving section forward in the well.

10. A downhole system according to any of the preceding claims, wherein the 10 electrically driven driving section comprises a rechargeable battery (26).

11. A downhole system according to any of the preceding claims, further comprising a flow diverter (29) for diverting at least part of the fluid from the tubing string into the well. 15

12. A downhole system according to claim 11, wherein the flow diverter is arranged in a dispersion unit for dispersion of fluids, such as chemical reactants in the well. 20

13. A downhole system according to any of the preceding claims, further comprising an inflation unit (35) for shielding the driving section while a stimulation operation is performed or the well is treated with an acid or base containing fluid. 25

14. A downhole system according to any of the preceding claims, further comprising a detachment unit for detaching the driving section from the tubing string. P1439PC00