CN111021946B - Well drilling speed-increasing process for changing bottom hole confining pressure distribution by middle energy accumulation - Google Patents
Well drilling speed-increasing process for changing bottom hole confining pressure distribution by middle energy accumulation Download PDFInfo
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- CN111021946B CN111021946B CN201911404712.9A CN201911404712A CN111021946B CN 111021946 B CN111021946 B CN 111021946B CN 201911404712 A CN201911404712 A CN 201911404712A CN 111021946 B CN111021946 B CN 111021946B
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- 238000005553 drilling Methods 0.000 title claims abstract description 231
- 238000000034 method Methods 0.000 title claims abstract description 40
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- 238000005520 cutting process Methods 0.000 claims abstract description 229
- 239000012530 fluid Substances 0.000 claims abstract description 129
- 230000001133 acceleration Effects 0.000 claims abstract description 51
- 238000010248 power generation Methods 0.000 claims description 32
- 239000007788 liquid Substances 0.000 claims description 21
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- 238000011010 flushing procedure Methods 0.000 description 2
- 239000000314 lubricant Substances 0.000 description 2
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B4/00—Drives for drilling, used in the borehole
- E21B4/20—Drives for drilling, used in the borehole combined with surface drive
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
- E21B17/1078—Stabilisers or centralisers for casing, tubing or drill pipes
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/18—Drilling by liquid or gas jets, with or without entrained pellets
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Abstract
The invention provides a well drilling speed-up process for changing bottom-hole confining pressure distribution by middle energy accumulation, which is realized by a well drilling speed-up system for changing bottom-hole confining pressure distribution by middle energy accumulation, wherein the well drilling speed-up system comprises drilling fluid supply equipment, a drill column driving equipment, an upper drill column and a double-speed double-center well drilling speed-up equipment; and the drilling acceleration method comprises: supplying drilling fluid to the upper drill string through a drilling fluid supply device to enable the small cutting head to rotate, and driving the upper drill string to rotate through a drill string driving device on the ground to drive a well hole of a first size to be drilled at the bottom of the well; and then, driving a large cutting head to drill the borehole with the first size through the upper drill string to obtain the borehole with the second size. The drilling speed-up process for changing the bottom hole confining pressure distribution by middle energy accumulation can avoid the problem that the linear velocity of the central point of the drill bit is zero, and is beneficial to improving the drilling speed.
Description
Technical Field
The invention belongs to the technical field of oil and gas drilling acceleration, and particularly relates to a drilling acceleration process capable of further improving the drilling speed and changing the bottom hole confining pressure distribution through middle energy collection.
Background
In the oil and gas well drilling engineering, how to increase the drilling speed is an important subject of research. Although the drilling speed is improved to some extent by optimizing the design of the drill bit structure, for example, developing new drill bit tooth materials, higher performance teeth, etc., the problem that the linear speed of the central point of the drill bit is zero and the linear speed near the central point affects the drilling speed during drilling is still not solved.
Moreover, the inventors have found that this effect is particularly pronounced in PDC bits which are currently in large use. The bit that is pulled out of service is also difficult to find, and this problem is one of the key problems affecting the speed increase of the well.
Disclosure of Invention
The present invention aims to address at least one of the above-mentioned deficiencies of the prior art. For example, the invention aims to provide a drilling acceleration process which can effectively solve the problem that the linear velocity of a central point of a drill bit is zero when drilling, supply and recycle drilling fluid and realize power driving by using the shunted drilling fluid.
In order to achieve the above object, the present invention provides a drilling acceleration process for changing bottom-hole confining pressure distribution by middle energy accumulation, which is realized by a drilling acceleration system for changing bottom-hole confining pressure distribution by middle energy accumulation, wherein the drilling acceleration system comprises a drilling fluid supply device, a drill string driving device, an upper drill string and a double-speed double-core drilling acceleration device; the double-speed double-center drilling speed-up equipment comprises a flow dividing device, an outer cylinder, a downhole power device, a centering device, a large cutting head and a small cutting head, wherein the large cutting head is provided with a first central line, a through hole arranged along the first central line and a first diameter, the small cutting head is provided with a second central line and a second diameter, the second diameter is smaller than the first diameter, and the second central line is parallel to but not coincident with the first central line; the outer cylinder is sleeved outside the underground power device to form an annular space, the left end of the outer cylinder is connected with the upper drill string through the flow dividing device, and the right end of the outer cylinder is connected with the large cutting head through the righting device, so that the large cutting head can drill under the driving of the upper drill string, and the underground power device rotates under the driving of the upper drill string; the downhole power device is provided with a power generation part and a rotation output part, wherein the power generation part can generate power and rotate the rotation output part, and the rotation output part passes through the through hole of the large cutting head and is connected with the small cutting head and can drive the small cutting head to rotate; the righting device is configured to right the power generation portion, the rotary output portion, or the small cutting head; said flow divider being configured to divide the drilling fluid in the upper drill string into a first flow and a second flow, wherein said first flow enters said annulus and lubricates the large cutting head, and said second flow enters the power generation portion of said downhole power unit; the drill string driving device is connected with the double-speed double-core drilling speed-up device through the upper drill string and can drive the upper drill string to rotate; the drilling fluid supply apparatus is connected to and supplies drilling fluid into the upper drill string. And the drilling acceleration method comprises: supplying drilling fluid to the upper drill string through a drilling fluid supply device to enable the small cutting head to rotate, and driving the upper drill string to rotate through a drill string driving device on the ground to drive a well hole of a first size to be drilled at the bottom of the well; and then, driving a large cutting head to drill the borehole with the first size through the upper drill string to obtain the borehole with the second size.
In an exemplary embodiment of the invention, the distance between the first centerline and the second centerline may be 1/50-1/10 of the first diameter.
In an exemplary embodiment of the invention, the distance between the first centerline and the second centerline may be 1/40-1/20 of the first diameter.
In an exemplary embodiment of the invention, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 2 to 9: 1.
in an exemplary embodiment of the invention, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 4 to 7: 1.
in an exemplary embodiment of the invention, the cutting head may have a jet channel with a decreasing radial cross-sectional area, one end of the jet channel receiving the second fluid flow through the power generation portion and emitting from the other end of the jet channel.
In an exemplary embodiment of the present invention, the pressure of the liquid stream ejected from the other end of the ejection channel is 1.5 to 2.1 times that of the liquid stream received at one end.
In an exemplary embodiment of the invention, the righting device may have a quincunx-like cavity capable of righting the power generation portion or the rotational output portion, or capable of righting the portion of the cutting bit coupled with the rotational output portion.
In an exemplary embodiment of the invention, the flow diversion device may have a water diversion member, wherein the water diversion member is provided with a central bore and a plurality of water diversion bores, the plurality of water diversion bores being capable of communicating drilling fluid in an upper drill string with the annulus and forming the first flow, the central bore being capable of communicating drilling fluid of an upper drill string with the power generation section and forming the second flow.
Compared with the prior art, the beneficial effects of the invention comprise at least one of the following:
1. the linear speed of the central point of the large drill bit can be prevented from being zero during drilling, and the drilling speed can be improved;
2. compared with the well with the same size, the torque and the cost of the bottom hole power drilling tool are reduced under the condition of realizing the same rotating speed;
3. under the conditions of not increasing the discharge capacity of the drilling fluid and the pressure of the pump, the speed-up effect of jet drilling can be formed in the middle of the bottom of the well;
4. the drilling fluid can be supplied and circulated, and the small cutting head is driven to rotate by the shunted drilling fluid;
5. the large cutting head and the small cutting head are arranged in a non-centrosymmetric manner, so that the small cutting head not only can rotate at a high speed under the driving of a downhole power device, but also can simultaneously revolve around the central axis of the large cutting head; therefore, the problems that the theoretical cutting speed of the central point of the drill bit is zero and the linear speed near the central point is low are solved, and the drilling speed is favorably improved.
Drawings
FIG. 1 illustrates a process flow diagram of an exemplary embodiment of a well acceleration process with central concentrating to change the bottom hole confining pressure distribution in accordance with the present invention;
FIG. 2 is a schematic diagram of a two-speed dual-center drilling acceleration apparatus in an exemplary embodiment of a mid-zone energy concentrating modified bottom-hole confining pressure distribution drilling acceleration process according to the present invention;
FIG. 3 illustrates a schematic structural view of a flow diversion apparatus in an exemplary embodiment of a downhole acceleration process with central energy concentration to alter the bottom hole confining pressure distribution in accordance with the present invention;
FIG. 4 shows a right side view of FIG. 3;
FIG. 5 shows a pictorial representation of FIG. 3;
FIG. 6 illustrates a schematic structural view of a centralizer assembly in an exemplary embodiment of a well acceleration process with central focused varying bottom hole confining pressure distribution in accordance with the present invention;
FIG. 7 shows a right side view of FIG. 6;
FIG. 8 shows a pictorial representation of FIG. 6;
FIG. 9 illustrates a pictorial diagram of a two-speed dual-center drilling acceleration apparatus in an exemplary embodiment of a mid-zone energy concentrating modified bottom-hole confining pressure distribution drilling acceleration process in accordance with the present invention.
The reference numerals are explained below:
1-flow dividing device, 2-outer cylinder, 3-underground power device, 4-righting device, 5-big cutting head, 6-small cutting head, 1 a-water dividing hole, 1 b-central hole, 4 a-inner boss and 4 b-concave surface.
Detailed Description
Hereinafter, a well acceleration process of the present invention in which the bottom-hole confining pressure distribution is changed by middle-concentration will be described in detail with reference to exemplary embodiments. It should be noted that "first," "second," etc. are merely used for convenience of description and for ease of distinction, and are not to be construed as indicating or implying relative importance. "left," "right," "inner," and "outer" are merely for convenience of description and relative orientation or positional relationship, and do not indicate or imply that the referenced components must have that particular orientation or position.
In general, in order to solve the problem that the linear velocity of the central point of the drill bit is zero, the inventor provides a drilling acceleration process for changing the bottom hole confining pressure distribution by middle energy accumulation. The double-speed double-center drilling speed-up equipment in the drilling speed-up process is characterized in that a large cutting head (also called a large drill bit) with a first central line, a through hole arranged along the first central line and a first diameter is arranged; and a small cutting head (also referred to as a small drill) having a second centerline and a second diameter; and ensuring that the second diameter is smaller than the first diameter, the second centerline being parallel to but not coincident with the first centerline to achieve "bi-centering". At the same time, the large cutting head receives a first power for rotary drilling through the upper drill string and is provided with lubrication by drilling fluid from the upper drill string; the small cutting head obtains a second power for rotary drilling through the downhole power device, which is equivalent to the small cutting head rotating around the second central line, and the upper drill string can also drive the downhole power device to further drive the small cutting head to rotate, which is equivalent to the small cutting head revolving around the first central line, thereby realizing double speed.
FIG. 1 illustrates a process flow diagram of an exemplary embodiment of a wellbore acceleration process with central concentrating modified bottom-hole confining pressure distribution according to the present invention.
As shown in fig. 1, in a first exemplary embodiment of the present invention, a well acceleration process with a central concentrating to change a bottom hole confining pressure distribution may include the steps of:
and starting a drilling acceleration system for changing the bottom-hole confining pressure distribution by middle energy collection, and descending an upper drill column of the double-speed double-core drilling acceleration equipment into the underground target position. Specifically, a drill string is used to run a two-speed dual-center drilling acceleration apparatus down to a downhole location to be drilled (e.g., downhole, face of rock to be drilled, etc.). The two-speed double-center drilling speed-up method can be used for drilling speed-up of vertical wells and can also be used for drilling speed-up of horizontal wells. However, the present invention is not limited thereto as long as the dual speed dual core drilling acceleration apparatus can be lowered downhole using the drill string.
The small cutting head is caused to rotate by supplying drilling fluid to the upper drill string through a drilling fluid supply device, and the upper drill string is driven to rotate by a drill string driving device at the surface so as to drill a borehole of a first size at the bottom of the well. Specifically, the drilling fluid is supplied to an upper drill string through a drilling fluid supply device, the drilling fluid enters a flow dividing device of the double-speed double-center drilling speed-increasing device through the interior of the upper drill string and is divided into a first fluid flow and a second fluid flow, the second fluid flow enters a downhole power device to generate power, and a small cutting head of the double-speed double-center drilling speed-increasing device rotates under the driving of the downhole power device. Meanwhile, the upper drill string is driven to rotate by the drill string driving device on the ground, so that the double-speed double-center drilling speed-up device rotates along with the upper drill string, and the underground power drill string liquid of the double-speed double-center drilling speed-up device rotates along with the upper drill string, so that the small cutting head connected with the double-speed double-center drilling speed-up device also rotates (namely revolves around the first central line) under the driving of the upper drill string. The two work together to make the small cutting head drill a borehole (also called a slim hole) of a first size at the bottom of the well to form a hollow rock body. Here, the small cutting head has a high angular velocity and thus also a high linear cutting velocity under the combined action of rotation and revolution, whereas the large cutting head is rotated only by the upper drill string, the angular velocity being lower than that of the small cutting head. For example, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 2 to 9: 1. For another example, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 4 to 7: 1. the small cutting head first contacts the position to be drilled and drills the middle part which is difficult to drill out of the borehole of the first size, and the rock mass around the borehole of the first size becomes relatively easy to drill.
And then, driving a large cutting head to drill the borehole with the first size through the upper drill string to obtain the borehole with the second size. Specifically, the large cutting head of the two-speed dual-center drilling acceleration device drills away rock mass around a borehole of a first size under the drive of the upper drill string to form the borehole of a desired size, i.e., a borehole of a second size. During drilling, the small cutting head rotates at a high speed to continuously form a first-size borehole, and the large cutting head continuously drills away rock mass around the first-size borehole to form a second-size borehole. At a particular depth, the small cutting head drills a borehole of a first size, and after a certain time interval the large cutting head drills away the rock mass surrounding the borehole of the first size. Here, the time interval between the small bore hole drilled by the small cutting head and the rock mass around the small bore hole drilled by the large cutting head is determined by the downhole drilling formation, the drilling fluid properties, and the overall system design process.
At the same time, the drilling fluid in the upper drill string is sprayed to the bottom of the well through the spraying channel on the small cutting head for spraying drilling. That is, while the cutting bit drills a first size hole to form a hollow rock mass, a portion of the drilling fluid (e.g., a second fluid stream) from the upper drill string enters from one end of the jetting passage on the cutting bit and jets from the other end of the jetting passage to the bottom of the well (e.g., a hollow rock mass, a small hole, etc.) for jet drilling. For example, the pressure of the liquid stream ejected from the other end of the ejection channel is 1.5 to 2.1 times that of the liquid stream received at one end. For another example, the pressure of the liquid flow ejected from the other end of the ejection channel is 1.4 to 2.5 times that of the liquid flow received at one end. Here, after the drilling fluid passes through the diversion device, about 50% -60% of the drilling fluid enters the downhole power device, and the part of the drilling fluid enters the small cutting head after driving the rotary output part of the downhole power device to rotate, so that jet drilling is carried out. The cross section of the injection channel on the small cutting head is gradually reduced, so that the drilling fluid can form high-speed injection at the outlet of the injection channel, and the high-speed injection drilling fluid can scour the well bottom at a high flow rate, help the small cutting head to break rock and improve the rock breaking efficiency of the small cutting head, and can better clean the well bottom and the drill bit, prevent the drill bit from cutting tooth mud packets and accelerate drilling.
FIG. 2 is a schematic diagram of a two-speed dual-center drilling acceleration apparatus in an exemplary embodiment of a mid-zone focused modified bottom hole confining pressure distribution drilling acceleration process according to the present invention.
As shown in fig. 2, in the present exemplary embodiment, the drilling acceleration process of the middle-concentrated varying bottom-hole confining pressure distribution is realized by a drilling acceleration system of the middle-concentrated varying bottom-hole confining pressure distribution, which includes a drilling fluid supply device, a drill string driving device, an upper drill string, and a dual-center drilling acceleration device. The double-speed double-center drilling speed-up equipment comprises a flow dividing device 1, an outer cylinder 2, a downhole power device 3, a righting device 4, a large cutting head 5 and a small cutting head 6.
The large cutting head 1 has a first centre line (i.e. parallel to the left-right direction in fig. 2), a through going hole arranged along said first centre line, and a first diameter. The cutting bit 6 has a second centre line and a second diameter. And, the second diameter is smaller than the first diameter, and the second centerline is parallel to but not coincident with the first centerline. That is, both the first center line and the second center line are parallel to the left-right direction in fig. 2, but a predetermined distance exists therebetween. For example, the distance between the first centerline and the second centerline may be 1/50-1/10 of the first diameter. As another example, the distance between the first centerline and the second centerline may be 1/40-1/20 of the first diameter.
The outer cylinder body 2 is sleeved outside the downhole power device 3, and an annular space is formed between the outer cylinder body and the downhole power device. And the left end of the outer cylinder 2 is connected with an upper drill string (not shown in fig. 2) through the diversion device 1, and the right end of the outer cylinder 2 is connected with the large cutting head 5 through the centering device 4, so that the large cutting head 5 can drill under the driving of the upper drill string, and the downhole power device 3 rotates under the driving of the upper drill string. That is, the diverter device 1, the outer cylinder 2, the centralizer 4 and the large cutting head 5 are fixed integrally with the upper drill string and are rotatable together.
The downhole power unit 3 may have a power generation portion and a rotation output portion. Wherein the power generation section (e.g., the left section of the downhole power unit 3 in fig. 2) is capable of generating power and rotating the rotation output section. Further, the downhole power device can also form an annular space with the outer cylinder, and a power generation part of the downhole power device is fixedly connected with one or more of the upper drill string, the flow dividing device, the outer cylinder, the centering device and the large cutting head, so that the downhole power device can be driven by the upper drill string to rotate. The rotary output portion (e.g., the right portion of the downhole power unit 3 in fig. 2) is coupled to the small cutting head through the through hole of the large cutting head and can drive the small cutting head to rotate. That is, the downhole power device can generate power through the power generation part and drive the small cutting head to rotate around the second center line through the rotation output part; simultaneously, due to the drive of the upper drill string, the underground power device and the small cutting head can also revolve around the first central line. Thus, the angular velocity of the small cutting head will be greater than the angular velocity of the large cutting head. For example, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 2 to 9: 1. for another example, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 4 to 7: 1.
as shown in fig. 2, the centralizing means is arranged to centralize the power generating section of the downhole power means, thereby centralizing the small cutting head. That is, the centralizer is capable of centralizing the deflection caused by the rotation of the cutting head. However, the present invention is not limited thereto. For example, the centralizer may also be arranged to centralize the rotary output of the downhole power unit; or directly, centralize the cutting head, e.g., centralize the portion of the cutting head coupled to the rotational output. For example, the righting device may have a quincunx-like cavity that can more stably right the power generation portion or the rotational output portion, or can more stably right the portion of the cutting bit coupled with the rotational output portion.
The flow divider is configured to separate the drilling fluid in the upper drill string into a first flow and a second flow. The first fluid flow enters an annulus between the outer barrel and the downhole power plant and is able to flow to the large cutting head to lubricate the large cutting head. The second fluid stream enters a power generation section of the downhole power unit and serves as a power source for the power generation section. That is, the power generation section can convert the power of the second fluid flow into the rotational motion of the rotation output section. For example, the flow diversion device can have a water diversion member that can have a central aperture and a plurality of water diversion apertures disposed thereon. Wherein the plurality of cutwater holes are capable of communicating drilling fluid in an upper drill string with the annulus and forming the first fluid stream; the central bore is configured to communicate drilling fluid of an upper drill string with the power generation section and form the second fluid stream.
In addition, the small cutting head may also have a jet channel with a gradually decreasing radial cross-sectional area. One end of the jetting passage receives the second fluid flow passing through the power generation portion and is jetted out from the other end of the jetting passage to be jetted toward an object to be drilled (e.g., a surface to be drilled).
A drilling fluid supply apparatus is connected to and supplies drilling fluid into the upper drill string. For example, the supplied drilling fluid may be used to flush clean the bottom of the well, carry cuttings, and provide power. That is, the drilling fluid supply device may be connected to the upper drill string via a line, and the drilling fluid may enter the two-speed dual-center drilling acceleration device via a flow passage in the upper drill string to assist the two-speed dual-center drilling acceleration device in drilling. The supplied drilling fluid can be used for supplying power to a downhole power device of the two-speed double-center drilling speed-increasing equipment and performing jet drilling through a jet channel on the small cutting head. On the other hand, the drilling fluid can also play a role in lubricating and cooling the large cutting head, so that the service life of the large cutting head is prolonged; even more, the drilling fluid can also act as a lubricant cooling the small cutting head, thereby also extending the service life of the small cutting head. Meanwhile, the drilling fluid can also flush and purify the well bottom after entering the well bottom, and rock debris generated by drilling is carried to the ground for treatment. In addition, the drilling fluid supply equipment can comprise a mud tank, a drilling pump, a water tap, a high-pressure pipeline, a mud returning groove and the like, and the equipment can form a drilling fluid circulation path together with an upper drill string and the two-speed double-core speed-increasing equipment, wherein the drilling fluid circularly flows in the circulation path, and the functions of flushing and purifying the well bottom, carrying rock debris and providing power are achieved.
The drill string driving device is connected with the double-speed double-core drilling speed-increasing device through the upper drill string and can drive the upper drill string to rotate. Specifically, the drill string driving device drives the upper drill string to rotate, and the upper drill string drives the two-speed double-core drilling speed-up device connected with the upper drill string to rotate and drill. For example, drill string drive equipment may include rotary tables and drilling tools (e.g., drill collars, centralizers, dampers, mating joints, etc.). The turntable drives the upper drill column to rotate, the upper drill column drives the double-speed double-core drilling speed-up equipment to rotate and drill, and the drilling tool and the upper drill column are matched to assist the upper drill column to rotate.
FIG. 1 illustrates a process flow diagram of an exemplary embodiment of a wellbore acceleration process with central concentrating modified bottom-hole confining pressure distribution according to the present invention.
As shown in fig. 1, in a second exemplary embodiment of the present invention, a well acceleration process with a central concentrating to change a bottom hole confining pressure distribution may include the steps of:
and starting a drilling acceleration system for changing the bottom-hole confining pressure distribution by middle energy collection, and descending an upper drill column of the double-speed double-core drilling acceleration equipment into the underground target position. That is, the drill string is used to run the two-speed dual-core drilling acceleration apparatus down to a downhole location to be drilled (e.g., downhole, face of rock to be drilled, etc.). The two-speed double-center drilling speed-up method can be used for drilling speed-up of vertical wells and can also be used for drilling speed-up of horizontal wells. However, the present invention is not limited thereto as long as the dual speed dual core drilling acceleration apparatus can be lowered downhole using the drill string.
The small cutting head is caused to rotate by supplying drilling fluid to the upper drill string through a drilling fluid supply device, and the upper drill string is driven to rotate by a drill string driving device at the surface so as to drill a borehole of a first size at the bottom of the well. Specifically, the drilling fluid is supplied to an upper drill string through a drilling fluid supply device, the drilling fluid enters a flow dividing device of the double-speed double-center drilling speed-increasing device through the interior of the upper drill string and is divided into a first fluid flow and a second fluid flow, the second fluid flow enters a downhole power device to generate power, and a small cutting head of the double-speed double-center drilling speed-increasing device rotates under the driving of the downhole power device. Meanwhile, the upper drill string is driven to rotate by the drill string driving device on the ground, so that the double-speed double-center drilling speed-up device rotates along with the upper drill string, and the underground power drill string liquid of the double-speed double-center drilling speed-up device rotates along with the upper drill string, so that the small cutting head connected with the double-speed double-center drilling speed-up device also rotates (namely revolves around the first central line) under the driving of the upper drill string. The two work together to make the small cutting head drill a borehole (also called a slim hole) of a first size at the bottom of the well to form a hollow rock body. Here, the small cutting head has a high angular velocity and thus also a high linear cutting velocity under the combined action of rotation and revolution, whereas the large cutting head is rotated only by the upper drill string, the angular velocity being lower than that of the small cutting head. For example, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 2 to 9: 1. For another example, the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head may be 4 to 7: 1. the small cutting head first contacts the position to be drilled and drills the middle part which is difficult to drill out of the borehole of the first size, and the rock mass around the borehole of the first size becomes relatively easy to drill.
And then, driving a large cutting head to drill the borehole with the first size through the upper drill string to obtain the borehole with the second size. Specifically, the large cutting head of the two-speed dual-center drilling acceleration device drills away rock mass around a borehole of a first size under the drive of the upper drill string to form the borehole of a desired size, i.e., a borehole of a second size. During drilling, the small cutting head rotates at a high speed to continuously form a first-size borehole, and the large cutting head continuously drills away rock mass around the first-size borehole to form a second-size borehole. At a particular depth, the small cutting head drills a borehole of a first size, and after a certain time interval the large cutting head drills away the rock mass surrounding the borehole of the first size. Here, the time interval between the small bore hole drilled by the small cutting head and the rock mass around the small bore hole drilled by the large cutting head is determined by the downhole drilling formation, the drilling fluid properties, and the overall system design process.
At the same time, the drilling fluid in the upper drill string is sprayed to the bottom of the well through the spraying channel on the small cutting head for spraying drilling. That is, while the cutting bit drills a first size hole to form a hollow rock mass, a portion of the drilling fluid (e.g., a second fluid stream) from the upper drill string enters from one end of the jetting passage on the cutting bit and jets from the other end of the jetting passage to the bottom of the well (e.g., a hollow rock mass, a small hole, etc.) for jet drilling. For example, the pressure of the liquid stream ejected from the other end of the ejection channel is 1.5 to 2.1 times that of the liquid stream received at one end. For another example, the pressure of the liquid flow ejected from the other end of the ejection channel is 1.4 to 2.5 times that of the liquid flow received at one end. Here, after the drilling fluid passes through the diversion device, about 50% -60% of the drilling fluid enters the downhole power device, and the part of the drilling fluid enters the small cutting head after driving the rotary output part of the downhole power device to rotate, so that jet drilling is carried out. The cross section of the injection channel on the small cutting head is gradually reduced, so that the drilling fluid can form high-speed injection at the outlet of the injection channel, and the high-speed injection drilling fluid can scour the well bottom at a high flow rate, help the small cutting head to break rock and improve the rock breaking efficiency of the small cutting head, and can better clean the well bottom and the drill bit, prevent the drill bit from cutting tooth mud packets and accelerate drilling.
FIG. 2 is a schematic diagram of a two-speed dual-center drilling acceleration apparatus in an exemplary embodiment of a mid-zone focused modified bottom hole confining pressure distribution drilling acceleration process according to the present invention. FIG. 3 illustrates a schematic diagram of a diverter assembly in an exemplary embodiment of a downhole acceleration process with central focusing to alter the bottom hole confining pressure distribution in accordance with the present invention. FIG. 4 shows a right side view of FIG. 3; and FIG. 5 shows a pictorial representation of FIG. 3.
As shown in FIG. 2, in the exemplary embodiment, a wellbore acceleration system for a mid-zone focused modified bottom hole confining pressure distribution may include a drilling fluid supply, a drill string drive, an upper drill string, and a two-speed dual-core wellbore acceleration device. The double-speed double-center drilling speed-up equipment comprises a flow dividing device 1, an outer cylinder 2, a downhole power device 3, a righting device 4, a large cutting head 5 and a small cutting head 6.
In the exemplary embodiment, the left end of the outer cylinder 2 is connected with the upper drill string through the diversion device 1, and the right end of the outer cylinder 2 is connected with the large cutting head 5 through the centralizing device 4, so that the rotation torque of the upper drill string is transmitted to the large cutting head 5, and the large cutting head 5 can drill rotationally under the driving of the upper drill string. The outer cylinder 2 is indirectly connected with the upper drill string, and the outer cylinder 2 is indirectly connected with the large cutting head 5. For example, the left end of the outer cylinder 2 is connected with the right end of the shunt device 1 through threads, and the left end of the shunt device 1 is connected with the upper drill string through threads, so that the outer cylinder 2 is connected with the upper drill string, and the outer cylinder 2 can be driven by the upper drill string to rotate; the right end of the outer cylinder 2 is in threaded connection with the left end of the righting device 4, and the right end of the righting device 4 is in threaded connection with the left end of the large cutting head 5, so that the righting device 4 and the large cutting head 5 can rotate together with the outer cylinder 2. However, the present invention is not limited thereto, and the upper drill string and the flow dividing device, the flow dividing device and the outer cylinder, the outer cylinder and the centralizer, and the centralizer and the large cutting head may be connected by other means (for example, snap-fitting), as long as the connection of the upper drill string, the flow dividing device, the outer cylinder, the centralizer and the large cutting head and the transmission of the torque of the upper drill string can be realized.
In the present exemplary embodiment, the downhole power unit 3 is disposed inside the outer cylinder 2, and the downhole power unit 3 and the outer cylinder 2 are in a fixed state therebetween. The underground power device 3 can rotate under the driving of an upper drill column together with the outer cylinder body 2, and an annular space through which drilling fluid can flow is formed between the inside of the outer cylinder body 2 and the outside of the underground power device 3. For example, the downhole power unit 3 is disposed inside the outer cylinder 2 and is not in contact with the outer cylinder 2, and the space between the inside of the outer cylinder 2 and the outside of the downhole power unit 3 is an annulus through which drilling fluid flows.
The left end of the underground power device 3 is fixedly connected with the water diversion component of the flow diversion device 1 through threads, so that the outer cylinder body 2 and the underground power device 3 are in a fixed state. The upper drill column rotates to drive the flow dividing device 1 to rotate, and the flow dividing device 1 rotates to drive the outer cylinder 2 and the underground power device 3 to rotate. Of course, there are many ways of securing the outer barrel 2 to the downhole power unit 3. For example, a fastener may be provided between the inner wall of the outer cylinder 2 and the downhole power unit 3, which fastener is capable of allowing the passage of drilling fluid (e.g., the first fluid stream) while securing the outer cylinder 2 and the downhole power unit 3. However, the invention is not limited to this, and the outer cylinder and the downhole power device may be fixed in other ways as long as the outer cylinder and the downhole power device can be fixedly arranged.
In the exemplary embodiment, a flow divider is provided that is capable of dividing the drilling fluid in the upper drill string into a first flow and a second flow. The first fluid flow enters an annulus between the outer barrel and the downhole power plant and is able to flow to the large cutting head to lubricate the large cutting head. The second fluid stream enters a power generation section of the downhole power unit and serves as a power source for the power generation section. That is, the power generation section can convert the power of the second fluid flow into the rotational motion of the rotation output section. For example, the flow diversion device can have a water diversion member that can have a central aperture and a plurality of water diversion apertures disposed thereon. Wherein the plurality of cutwater holes are capable of communicating drilling fluid in an upper drill string with the annulus and forming the first fluid stream; the central bore is configured to communicate drilling fluid of an upper drill string with the power generation section and form the second fluid stream. For example, as shown in fig. 3-5, the flow diversion device 1 can be a cylinder-like structure. The water distribution component is arranged in the cylinder body along the radial section and comprises a central hole 1b and a plurality of water distribution holes 1a which are arranged around the central hole 1b and are not communicated with the central hole 1 b. A portion of the drilling fluid from the upper drill string enters the central bore 1b to form a second fluid stream; another portion of the drilling fluid enters the plurality of cutwater holes 1a to form a first stream. The central hole 1b or the peripheral wall thereof extends towards the right end and is in threaded connection with the left end of the downhole power device 3, so that the second liquid flow enters the power generation part of the downhole power device 3 to provide a power source. A plurality of water distribution holes 1a are associated with the annulus between the outer cylinder 2 and the downhole power unit 3 so that a first flow of fluid can enter the annulus and ultimately the large cutting head 5 to cool and lubricate the large cutting head 5. Here, the number of the plurality of water distribution holes 1a may be 2 to 6, and the water distribution holes 1a may be circular or elliptical water distribution holes. The ratio of the sum of the radial cross-sectional areas of the plurality of water distribution holes 1a to the radial cross-sectional area of the central hole 1b, that is, the ratio of the flow rates of the first liquid flow and the second liquid flow, may be 1: 0.5 to 2, for example 1: 1, etc. The drilling fluid from the upper drill string has a preset pressure, and the flow rates of the first fluid flow and the second fluid flow can be controlled by controlling the ratio of the radial sectional area of the water distribution holes 1a to the radial sectional area of the central hole 1b, so that the purpose of shunting is achieved. However, the present invention is not limited thereto, and the diversion device may have other structures as long as the diversion of the drilling fluid in the upper drill string can be achieved.
In the present exemplary embodiment, the downhole power unit has a power generation portion and a rotation output portion. The power generation unit is configured to generate power by the second fluid flow and rotate the rotation output unit. The rotation output portion is configured to be coupled to the small cutting head through the through hole of the large cutting head and to be capable of driving the small cutting head to rotate. For example, the power generating part of the downhole power device 3 may be a hydraulic drive motor or a hydraulic drive turbine, the second hydraulic flow drives the power generating part to rotate, the power generating part drives the rotation output part to rotate, and the rotation output part drives the small cutting head 6 connected with the rotation output part to rotate through the through hole of the large cutting head 5. Or the left end extension part of the small cutting head 6 passes through the through hole of the large cutting head 5 to be connected with the rotation output part, so that the rotation is driven by the rotation output part. However, the present invention is not limited thereto, and the downhole power device may have other structures as long as the downhole power device can generate power and drive the small cutting head to rotate under the action of the second fluid flow.
In the exemplary embodiment, the righting device can be provided with a plum blossom-like cavity, the plum blossom-like cavity can right a power generation part or a rotary output part of a downhole power device, or can right a part to be righted such as a part where a small cutting head is connected with the rotary output part, the part to be righted shakes in an outer cylinder, friction is reduced, and the stability and the service life of the double-speed double-center drilling speed-increasing equipment are improved.
FIG. 6 illustrates a schematic structural view of a centralizer assembly in an exemplary embodiment of a well acceleration process with central focused varying bottom hole confining pressure distribution in accordance with the present invention; FIG. 7 shows a right side view of FIG. 6; FIG. 8 shows a pictorial representation of FIG. 6.
As shown in fig. 6 to 8, the right end of the centering device 4 may be a cavity shaped like a plum blossom. The radial section of the plum blossom-shaped cavity is plum blossom-shaped. The plum blossom-like cavity can be arranged on the inner wall of the right end part of the righting device 4 and is surrounded by a plurality of inner bosses 4a along the circumferential direction. Of course, the cavity similar to the quincunx shape may be arranged in central symmetry along the central axis of the centering device 4, or in non-central symmetry along the central axis of the centering device 4, and is determined according to the specific situation of the part to be centered. For example, when the righted component is arranged in a non-centrosymmetric manner, the plum blossom-like cavity is also arranged in a non-centrosymmetric manner; when the righted part is arranged in a central symmetry manner, the plum blossom-like cavities are also arranged in a central symmetry manner. Here, the top surfaces of the inner bosses 4a are curved to fit the outer surface of the member to be centered, and the curved shape of the top surfaces of the plurality of inner bosses 4a is located on an imaginary circumference having a diameter slightly larger than the diameter of the member to be centered. Concave surfaces 4b are formed between two adjacent inner bosses 4a, and the number of concave surfaces 4b is equal to the number of inner bosses 4 a. Here, the concave surface may be a circular arc shape, a U shape, or a V shape. While the centering device 4 centers the centered member, the second fluid flow entering the annulus may enter the large cutting head 5 through the passage between the outer surface of the centered member and the quincunx-like cavity to cool and lubricate the large cutting head 5. The concave surface is provided here in order to increase the cross-sectional area of the passage through which the drilling fluid flows. However, the present invention is not limited in this regard and the centralizer may have other configurations as long as it is capable of centralizing the component being centralized and allowing the flow of drilling fluid (e.g., the first fluid stream) therethrough.
In the exemplary embodiment, the small cutting head and the large cutting head are arranged in a non-centrosymmetric manner, and the diameter of the small cutting head is smaller than that of the large cutting head, so that the small cutting head can revolve around the central axis of the large cutting head under the drive of an upper drill string while rotating at a high speed under the drive of a downhole power device, thereby forming composite rotary drilling and solving the problem of low drilling speed caused by the linear velocity of the central point of the drill bit during drilling. For example, the central axis of the large cutting head 5 is a first centre line. The large cutting head 5 is provided with a through going hole along a first centre line. The penetration is used for coupling the rotary output portion of the downhole power unit 3 through with the small cutting head 6, or for coupling the left end portion of the small cutting head 6 through with the rotary output portion. The diameter of the large cutting head 5 is a first diameter, which may be the diameter of the outer periphery of the cutting cones on the large cutting head 5. The centre axis of the small cutting head 6 is the second centre line and the diameter of the small cutting head 6 is the second diameter. When the second diameter is smaller than the first diameter and the first centerline is parallel to but not coincident with the second centerline, the small cutting head 6 and the large cutting head 5 are disposed non-centrosymmetrically.
Here, the distance between the first centerline and the second centerline may be 1/50 ~ 1/10 of the first diameter, such as 1/30 first diameter, 1/20 first diameter, and the like. When the distance between the first central line and the second central line is smaller than 1/50 the first diameter, the linear cutting speed of the central point of the drill bit is improved to some extent; when the distance between the first center line and the second center line is controlled to be 1/50-1/10 first diameter, the cutting speed of a center point line of the drill bit can be well improved, and the drilling speed can be well improved; when the distance between the first centre line and the second centre line is larger than 1/10 the first diameter, the chance of wear of the small cutting head 6 is increased, which may reduce the tool life to some extent.
The small cutting head 6 rotates at a high speed under the drive of the downhole power device 3 and revolves around the first central line to do compound motion under the drive of the upper drill string. As shown in fig. 2, the small cutting head 6 extends beyond the large cutting head 5 by a distance (denoted L) so that the small cutting head 6 can first contact the bottom of the well to drill a small borehole in the bottom of the well, forming a hollow rock mass; the large cutting head 5 then drills the hollow rock mass away to form the final desired borehole. Here, 0 < L < 0.6m, and further 0.2 < L < 0.5 m. When L is more than 0.2 and less than 0.5m, better drilling speed improvement and tool service life can be obtained; when L is greater than 0.6m, a large load is applied to the downhole power unit 3, which may reduce the service life to some extent.
When drilling operation is carried out, the small cutting head 6 rotates at a high speed under the drive of the underground power device 3, and simultaneously revolves around the first central line under the drive of the upper drill column to do composite motion, and meanwhile, the large cutting head 5 rotates under the drive of the upper drill column. Here, the rotation speed of the large cutting head 5 can be controlled within a range of 60 to 80 revolutions per minute. The rotation speed range of the small cutting head 6 can be controlled to be 200-600 revolutions/min, and the revolution speed range of the small cutting head 6 can be controlled to be 60-80 revolutions/min. The angular velocity of rotation of the large cutting head 5 is R, the sum of the angular velocities of rotation and revolution of the small cutting head 6 is R, and the ratio R: R of the angular velocity R of the small cutting head 6 to the angular velocity R of the large cutting head 5 may be 2 to 9:1, more preferably 4 to 7: 1. when the ratio of R to R is controlled to be 2-9: 1, the drilling speed-up effect is better; when R is less than 2, the drilling speed is improved to a certain extent; when the R is more than 9, the power requirement of the downhole power device is higher, the abrasion probability of the small cutting head is increased, and the service life is reduced to a certain extent.
In the present exemplary embodiment, the cutting head 6 is further provided with a jet channel with a gradually decreasing cross-sectional area of the flow channel, and the second fluid enters the cutting head after driving the rotary output part to rotate, and is jetted to the bottom of the well through the jet channel to perform high-pressure jet drilling. For example, the small cutting head 6 is provided with a plurality of jet channels along the second center line, and the cross-sectional area of the jet channels in the radial direction is gradually reduced. The second fluid drives the power generating part to rotate and then enters the cutting head 6 via the rotation output part, e.g. its central through hole. The second flow may enter from the larger cross-section end of the spray channel of the cutting bit 6, where the pressure gradually increases, eventually forming a spray flow from the smaller cross-section end of the spray channel. The sprayed drilling fluid (namely the second fluid flow) can scour the well bottom at a high flow rate, helps the drill bit to break rock and improves the rock breaking efficiency of the drill bit, and can better clean the well bottom and a small cutting head, prevent cutting tooth mud bags and accelerate drilling. For example, the pressure of the liquid stream ejected from the other end of the ejection channel is 1.5 to 2.1 times that of the liquid stream received at one end. For another example, the pressure of the liquid flow ejected from the other end of the ejection channel is 1.4 to 2.5 times that of the liquid flow received at one end. For example, a physical schematic diagram of the present exemplary embodiment may be as shown in fig. 9.
A drilling fluid supply apparatus is connected to and supplies drilling fluid into the upper drill string. For example, the supplied drilling fluid may be used to flush clean the bottom of the well, carry cuttings, and provide power. That is, the drilling fluid supply device may be connected to the upper drill string via a line, and the drilling fluid may enter the two-speed dual-center drilling acceleration device via a flow passage in the upper drill string to assist the two-speed dual-center drilling acceleration device in drilling. The supplied drilling fluid can be used for supplying power to a downhole power device of the two-speed double-center drilling speed-increasing equipment and performing jet drilling through a jet channel on the small cutting head. On the other hand, the drilling fluid can also play a role in lubricating and cooling the large cutting head, so that the service life of the large cutting head is prolonged; even more, the drilling fluid can also act as a lubricant cooling the small cutting head, thereby also extending the service life of the small cutting head. Meanwhile, the drilling fluid can also flush and purify the well bottom after entering the well bottom, and rock debris generated by drilling is carried to the ground for treatment. In addition, the drilling fluid supply equipment can comprise a mud tank, a drilling pump, a water tap, a high-pressure pipeline, a mud returning groove and the like, and the equipment can form a drilling fluid circulation path together with an upper drill string and the two-speed double-core speed-increasing equipment, wherein the drilling fluid circularly flows in the circulation path, and the functions of flushing and purifying the well bottom, carrying rock debris and providing power are achieved.
The drill string driving device is connected with the double-speed double-core drilling speed-increasing device through the upper drill string and can drive the upper drill string to rotate. Specifically, the drill string driving device drives the upper drill string to rotate, and the upper drill string drives the two-speed double-core drilling speed-up device connected with the upper drill string to rotate and drill. For example, drill string drive equipment may include rotary tables and drilling tools (e.g., drill collars, centralizers, dampers, mating joints, etc.). The turntable drives the upper drill column to rotate, the upper drill column drives the double-speed double-core drilling speed-up equipment to rotate and drill, and the drilling tool and the upper drill column are matched to assist the upper drill column to rotate.
In summary, the drilling acceleration process of the invention for changing the bottom hole confining pressure distribution by middle energy gathering has one or more of the following advantages:
1. the system has good stability and service life, and can control the whole system;
2. the drilling fluid can be supplied and circulated, and the small cutting head is driven to rotate by the shunted drilling fluid;
3. compared with the well with the same size, the torque and the cost of the bottom hole power drilling tool are reduced under the condition of realizing the same rotating speed;
4. under the conditions of not increasing the discharge capacity of the drilling fluid and the pressure of the pump, the speed-up effect of high-pressure jet drilling can be formed in the middle of the bottom of the well;
5. the large cutting head is driven by the rotary table, the small cutting head is driven by the rotary table and the underground power device together, and the small cutting head has higher angular velocity than the large cutting head, so that the small cutting head has higher linear velocity, and the drilling speed is improved.
Although the present invention has been described above in connection with the exemplary embodiments and the accompanying drawings, it will be apparent to those of ordinary skill in the art that various modifications may be made to the above-described embodiments without departing from the spirit and scope of the claims.
Claims (6)
1. A well drilling speed-up process for changing bottom-hole confining pressure distribution through middle energy gathering is characterized in that the well drilling speed-up process is realized through a well drilling speed-up system for changing the bottom-hole confining pressure distribution through the middle energy gathering, and the well drilling speed-up system comprises a drilling fluid supply device, a drill column driving device, an upper drill column and a double-speed double-center well drilling speed-up device;
wherein, the double-speed double-core drilling speed-up equipment comprises a flow dividing device, an outer cylinder body, an underground power device, a righting device, a large cutting head and a small cutting head, wherein,
the large cutting head has a first centerline, a through hole disposed along the first centerline, and a first diameter, the small cutting head has a second centerline and a second diameter, the second diameter being smaller than the first diameter, the second centerline being parallel to but not coincident with the first centerline, the distance between the first and second centerlines being 1/50-1/10 of the first diameter;
the outer cylinder is sleeved outside the underground power device to form an annular space, the left end of the outer cylinder is connected with the upper drill string through the flow dividing device, and the right end of the outer cylinder is connected with the large cutting head through the righting device, so that the large cutting head can drill under the driving of the upper drill string, and the underground power device rotates under the driving of the upper drill string;
the downhole power device is provided with a power generation part and a rotation output part, wherein the power generation part can generate power and rotate the rotation output part, and the rotation output part passes through the through hole of the large cutting head and is connected with the small cutting head and can drive the small cutting head to rotate;
the righting device is arranged to right the power generation part, the rotary output part or the small cutting head, and is provided with a plum blossom-like cavity which can right the power generation part or the rotary output part or right the part of the small cutting head connected with the rotary output part;
said flow divider being configured to divide the drilling fluid in the upper drill string into a first flow and a second flow, wherein said first flow enters said annulus and lubricates the large cutting head, and said second flow enters the power generation portion of said downhole power unit;
the small cutting head exceeds the large cutting head by a distance L, and L is more than 0.2 and less than 0.5 m;
the drill string driving device is connected with the double-speed double-core drilling speed-up device through the upper drill string and can drive the upper drill string to rotate;
the drilling fluid supply device is connected with the upper drill string and supplies drilling fluid into the upper drill string;
and the drilling acceleration process comprises: supplying drilling fluid to the upper drill string through a drilling fluid supply device to enable the small cutting head to rotate, and driving the upper drill string to rotate through a drill string driving device on the ground to drive a well hole of a first size to be drilled at the bottom of the well; then, driving a large cutting head to drill the borehole with the first size through an upper drill string to obtain a borehole with a second size, wherein the ratio of the angular speed of the small cutting head to the angular speed of the large cutting head is 2-9: 1;
the rotating speed range of the large cutting head is controlled to be 60-80 revolutions per minute, and the rotating speed range of the small cutting head is controlled to be 200-600 revolutions per minute.
2. The well acceleration process of middle cumulative modified bottom hole confining pressure distribution according to claim 1, characterized in that the distance between the first and second center lines is 1/40 ~ 1/20 of the first diameter.
3. The process of claim 1, wherein the ratio of the angular velocity of the small cutting head to the angular velocity of the large cutting head is 4-7: 1.
4. the process of claim 1, wherein the small cutting head has a jet channel with a gradually decreasing radial cross-sectional area, one end of the jet channel receiving the second fluid stream flowing through the power generation section and emitting from the other end of the jet channel.
5. The drilling acceleration process for changing the bottom-hole confining pressure distribution through the middle energy gathering of claim 4, wherein the pressure of the liquid flow ejected from the other end of the ejection channel is 1.5-2.1 times that of the liquid flow received by one end.
6. The process of claim 1, wherein the flow diversion device comprises a diversion member having a central bore and a plurality of diversion holes, wherein the plurality of diversion holes are configured to communicate drilling fluid in the upper drill string with the annulus and form the first flow, and wherein the central bore is configured to communicate drilling fluid in the upper drill string with the power generation section and form the second flow.
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| CN104563860A (en) * | 2013-10-27 | 2015-04-29 | 中国石油化工集团公司 | Double-stage double-rotating-speed well drilling device |
| CN107386960A (en) * | 2017-08-04 | 2017-11-24 | 四川深远石油钻井工具股份有限公司 | A kind of drilling speed device with composite drill bit |
| CN109989707A (en) * | 2019-04-23 | 2019-07-09 | 西南石油大学 | Based on the motor-driven double speed PDC drill bit of turbine generation formula |
| CN110029934A (en) * | 2019-04-23 | 2019-07-19 | 西南石油大学 | Double speed PDC drill bit based on screw drive |
| CN110029933A (en) * | 2019-04-23 | 2019-07-19 | 西南石油大学 | Based on turbo-driven double speed PDC drill bit |
| CN110374512A (en) * | 2019-06-17 | 2019-10-25 | 河北锐石钻头制造有限公司 | A kind of concentric type twin-stage double speed PDC drill bit |
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