WO2021120720A1 - 钻井工具及确定其参数的方法 - Google Patents
钻井工具及确定其参数的方法 Download PDFInfo
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- WO2021120720A1 WO2021120720A1 PCT/CN2020/114857 CN2020114857W WO2021120720A1 WO 2021120720 A1 WO2021120720 A1 WO 2021120720A1 CN 2020114857 W CN2020114857 W CN 2020114857W WO 2021120720 A1 WO2021120720 A1 WO 2021120720A1
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- WIPO (PCT)
- Prior art keywords
- impact
- rotating
- sleeve
- drilling tool
- rod
- Prior art date
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- 238000005553 drilling Methods 0.000 title claims abstract description 167
- 238000000034 method Methods 0.000 title claims abstract description 29
- 238000011144 upstream manufacturing Methods 0.000 claims abstract description 77
- 230000006835 compression Effects 0.000 claims abstract description 17
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Classifications
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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
- E21B4/06—Down-hole impacting means, e.g. hammers
- E21B4/10—Down-hole impacting means, e.g. hammers continuous unidirectional rotary motion of shaft or drilling pipe effecting consecutive impacts
-
- 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
- E21B4/16—Plural down-hole drives, e.g. for combined percussion and rotary drilling; Drives for multi-bit drilling units
-
- 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
- E21B4/06—Down-hole impacting means, e.g. hammers
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/10—Geometric CAD
- G06F30/17—Mechanical parametric or variational design
Definitions
- the invention relates to the field of drilling technology, in particular to a drilling tool.
- the invention also relates to a method for determining the parameters of the drilling tool.
- the drilling tool can be used to speed up drilling in oil and gas exploration and development, and can also be used to speed up drilling in mining, quarrying, geological exploration, water wells, geothermal and other fields.
- Rotary percussive drilling technology is one of the effective methods of rapid drilling. It uses various percussive drilling tools to drive the hammer through the drilling fluid to generate high-frequency impact dynamic load, which causes the volume of the rock to be broken, thereby improving the efficiency of rock breaking. This type of technology has developed rapidly since its inception.
- the present invention proposes a drilling tool.
- the invention also proposes a method for determining the parameters of the drilling tool.
- This drilling tool changes the speed-increasing mechanism of traditional percussion drilling tools, and combines the principles of rotary percussion drilling and elastic energy storage to make a major breakthrough in drilling technology. It is especially applied to deep and ultra-deep wells in the lower part of difficult-to-drill formations, and it has significant speed and efficiency improvements. Effect and good application prospects.
- the drilling tool is more durable and has a long service life.
- a drilling tool including: an upstream drilling tool; a downstream drill bit; and an impactor connected between the upstream drilling tool and the downstream drill bit; In the state, the impactor causes the upstream drilling tool to generate elastic compression, and in the second state, the upstream drilling tool releases the elastic compression, and the impact is applied to the downstream drill bit through the impactor.
- the upstream drilling tool Under the action of the impactor, the upstream drilling tool can be elastically compressed.
- the elastic compression of the upstream drilling tool will provide impact to the impactor when released.
- the impact will be transmitted to the downstream drill bit, so that the downstream drill bit can impact the formation.
- the drill bit can impact the formation while rotating and drilling, so as to break the formation more easily. Through this arrangement, it is more conducive to improve drilling efficiency and reduce drilling costs.
- the impactor includes: a rotary driving part configured to rotate around its axis; a rotary working part, an upper end of the rotary working part and a lower end of the rotary driving part Engaged, the lower end of the rotary working part is connected with the downstream drill bit, the rotary working part can be driven by the rotary driving part to rotate around its axis, and can be axially relative to the rotary driving part
- a rotary driving part configured to rotate around its axis
- the rotary working part can be driven by the rotary driving part to rotate around its axis, and can be axially relative to the rotary driving part
- an impact generating part the impact generating part is sleeved outside the rotating working part, the upper end of the impact generating part is against the upstream drilling tool, and the lower end of the impact generating part works with the rotation
- the impact-generating portion moves upstream to make the upstream drilling tool elastically compressed
- the upstream drilling tool releases the elastic compression, so that the impact-generating portion moves toward The
- the rotation driving part includes a cylindrical driving rod, the upper end of the driving rod is engaged with a power source, the rotation working part includes a cylindrical rotating rod, and the upper end of the rotating rod is connected to the power source.
- the lower end of the driving rod is engaged by a driving key, the lower end of the rotary rod is connected with the downstream drill bit, the upper end of the rotary rod is inserted into the lower end of the driving rod, and a flange is constructed outside the upper end of the rotary rod.
- the driving key extending in the axial direction of the rotating rod is configured with a driving groove extending along the axial direction of the driving rod inside the lower end of the driving rod, and the driving key is fitted in the driving groove Inside, the rotating rod is fixed relative to the driving rod in the circumferential direction, and can move relative to the driving rod in the axial direction.
- the impact generating portion includes an impact sleeve, the impact sleeve is sleeved on the outer side of the rotating rod, and the impact sleeve includes a first sleeve section with a smaller inner diameter and a larger inner diameter.
- a large second sleeve section the second sleeve section is connected below the first sleeve section, at the connection point between the first sleeve section and the second sleeve section
- the inner side of the impact sleeve is formed with an upper driven tooth;
- the rotating rod includes a first rotating section with a smaller outer diameter and a second rotating section with a larger outer diameter.
- the second rotating section is connected to the first rotating section.
- a lower driving tooth is formed on the outer side of the rotating rod at the connection between the second rotating section and the first rotating section; the upper driven tooth matches the lower driving tooth
- the upper driven tooth and the lower driving tooth are configured with an upward tooth section inclined upstream in a direction opposite to the rotation direction, and an upward tooth section connected to the upward tooth section along the opposite direction to the rotation direction.
- the inclination of the ascending tooth segment is smaller than the inclination of the descending tooth segment for the descending tooth segment inclined downstream.
- the rotating rod further includes a third rotating section connected to the lower end of the second rotating section, the outer diameter of the third rotating section is greater than the outer diameter of the second rotating section, and the An upstream impact step is formed between the second rotating section and the third rotating section.
- the lower end of the impact sleeve is opposite to the impact step and can impact with the impact step. When the lower end is in contact with the impact step, there is a gap between the upper driven tooth and the lower driving tooth in the axial direction.
- a cylindrical outer shell is sleeved on the outer side of the impact sleeve, and the outer shell and the impact sleeve are slidably engaged with each other through directional keys, and the upper end of the outer shell is connected to the The upstream drilling tool is connected, wherein the directional key extending in the axial direction is configured on the outer side of the impact sleeve, and the directional groove extending in the axial direction is configured on the inner side of the outer shell, the directional key Fitted into the directional groove, so that the impact sleeve is fixed relative to the outer shell in the circumferential direction and can move relative to the outer shell in the axial direction.
- the outer shell includes an upper shell part connected with the upstream drilling tool and a lower shell part connected below the upper shell part, and at least a part of the drive rod sleeve is provided in In the upper housing part, a rotating bearing is provided between the upper housing part and the driving rod, allowing the driving rod to rotate relative to the upper housing part, and the lower housing part surrounds
- the impact sleeve the lower end of the upper housing part is inserted into the upper end of the lower housing part, and a support sleeve is provided between the lower end of the upper housing part and the upper end of the impact sleeve, The impact sleeve applies force to the upper housing part through the support sleeve, thereby causing the upstream drilling tool to be elastically compressed.
- a groove is configured on the side wall of the third rotating section of the rotating rod, and a limit protruding radially outward relative to the third rotating section is installed in the groove.
- a cylindrical outer casing is sleeved on the outer side of the impact sleeve, the outer casing extends downward to surround the third rotating section, and the lower end of the outer casing is configured to extend radially inward
- the clamping part, the limiting block is located upstream of the clamping part and is configured to abut the clamping part to limit the downstream movement of the rotating rod relative to the outer housing.
- the upstream drilling tool includes a drill pipe and a drill collar connected under the drill pipe.
- the method includes the following steps :
- the minimum weight on bit required for drilling is determined through a formula
- Drilling parameters include weight on bit, displacement, speed, or/and determine the structural parameters of the rotating rod and impact sleeve of the drilling tool according to the minimum weight on bit required for drilling.
- the structural parameters include the lower driving teeth and the upper driven teeth. Number of teeth and tooth height.
- the advantage of the present invention is that the drilling tool of the present application combines the principles of rotary percussion drilling and elastic energy storage, which changes the speed-up mechanism of traditional percussive drilling tools, and can achieve higher frequency and higher stroke. To impact the formation, which can make the formation easier to break. This can effectively improve drilling efficiency and reduce drilling costs.
- the speed-up and efficiency-increasing effect is more significant.
- Figure 1 shows a schematic diagram of a drilling tool according to an embodiment of the present invention
- Figure 2 shows an embodiment of the drilling tool upstream of the drilling tool in Figure 1;
- Figure 3 shows a partial schematic diagram of a part of the drilling tool in Figure 1;
- Figure 4 shows a partial schematic diagram of another part of the drilling tool in Figure 1;
- Figure 5 shows a partial schematic diagram of another part of the drilling tool in Figure 1;
- Figure 6 shows a partial schematic diagram of the impact sleeve of the drilling tool in Figure 1;
- Fig. 7 shows a partial schematic diagram of the rotating rod of the drilling tool in Fig. 1.
- FIGS 1-7 show an embodiment of a drilling tool 1 according to the present invention.
- the drilling tool 1 includes an upstream drilling tool 10, a driving mechanism 20, an impactor 30, and a downstream drill bit (not shown) arranged in order from top to bottom.
- the upstream drilling tool 10 includes a drill rod 11, a drill collar 12 connected downstream of the drill rod 11, and a stabilizer 13 connected downstream of the drill collar 12.
- the upstream drilling tool 10 itself has certain elasticity, and when a certain compressive force is applied to the upstream drilling tool 10 after the well depth reaches a certain depth, it will produce a certain displacement compression. This compression allows the upstream drill tool 10 to store a certain amount of energy. This application uses this energy to drive the downstream drill bit for impact rock breaking. The specific process is detailed below.
- the driving mechanism 20 includes a cylindrical casing and a power source enclosed in the cylindrical casing.
- the housing is connected downstream of the stabilizer 13.
- the drive mechanism 20 can be a conventional screw power including a bypass valve assembly, an anti-drop assembly, a motor assembly, and a cardan shaft assembly.
- the upper assembly of the drilling tool can also be a special high torque structural parameter screw power drilling tool upper assembly including a special bypass valve assembly, a special anti-drop assembly, a special motor assembly and a special cardan shaft assembly.
- turbodrill upper assembly including a turbine section with an impeller set, a turbine cardan shaft and a turbine bearing section, and it can be specially made including a turbine section with a special impeller set, a special turbine cardan shaft and a special turbine bearing Section of the upper assembly of the turbodrill.
- the power source may be a screw motor or a turbodrill.
- the structure of the above-mentioned driving mechanism 20 is all existing, and will not be repeated here.
- the impactor 30 includes a rotation driving part, which may be configured as a cylindrical driving rod 34 (FIG. 3 ), for example.
- the drive rod 34 extends in the axial direction, and its upstream end is engaged with the power source, so that the drive rod can be driven by the power source to rotate.
- the impactor 30 also includes an outer shell.
- the outer shell includes an upper housing part 31 and a lower housing part 41 connected under the upper housing part 31.
- the upstream end of the upper housing part 31 is connected to the cylindrical housing of the driving mechanism 20. Since the driving mechanism 20 can be configured in different forms, the upper end of the upper housing part 31 is connected to the upper end of the housing of the screw or turbodrill bearing assembly. match.
- At least a part of the driving rod 34 extends in the upper housing part 31, and a rotating bearing is provided between the driving rod 34 and the upper housing part 31, which includes a bearing static which is arranged in the upper housing part 31 by means of clamping.
- the sleeve 32 and the movable bearing sleeve 33 arranged between the static bearing sleeve 32 and the driving rod 34 and capable of rotating relative to the static bearing sleeve 32.
- the driving rod 34 can freely rotate relative to the upper housing part 31.
- the downstream end of the drive rod 34 extends into the lower housing portion 41 described above.
- the upper end of the static bearing sleeve 32 abuts against the outer ring of the screw or turbine bearing string (the drive mechanism 20 itself includes the bearing string).
- a second limiting step 321 facing downstream is provided on the outer wall of the static bearing sleeve 32.
- a first limiting step 311 facing upstream is provided on the inner wall of the upper housing portion 31. After installation, the first limiting step 311 is provided.
- the position step 311 cooperates with the second limit step 321 to achieve the purpose of axially limiting the bearing sleeve 32.
- the above arrangement can ensure the effect of tightening the outer ring of the screw or turbine bearing string through the static bearing sleeve 32.
- the bearing sleeve 33 is fixedly connected to the outer wall of the upper end of the drive rod 34 in the manner of interference fit, and its upper end surface abuts against the inner ring of the screw or turbine bearing string, and its lower end surface abuts the shoulder of the drive rod 34 for installation and positioning. 341.
- the bearing sleeve 33 acts to push up the inner ring of the screw or turbine bearing string in the axial direction.
- the setting of the rotating bearing plays a role in preventing the drive rod 34 and the upper housing part 31 from being worn.
- a support sleeve 42 (described in detail below) is arranged opposite to the axial lower end of the static bearing sleeve 32, so that the static bearing sleeve 32 can play the role of supporting the upper, lower, tightening, and transmitting force.
- a rotary working part is provided downstream of the driving rod 34, and the rotary working part may be configured as a cylindrical rotary rod 43, for example, and at least a part of the rotary rod 43 is surrounded by the lower housing part 41.
- the rotating rod 43 includes a first rotating section 431, a second rotating section 432, a third rotating section 433, and a fourth rotating section 434 that are sequentially connected from upstream to downstream.
- the inner diameters of these rotating segments 431, 432, 433, and 434 are the same.
- the outer diameter of the first rotating section 431 is smaller than the outer diameter of the second rotating section 432, the outer diameter of the second rotating section 432 is smaller than the outer diameter of the third rotating section 433, and the outer diameter of the third rotating section 433 is smaller than the fourth rotating section 434 The outer diameter.
- the upstream end of the rotating rod 43 ie, the upstream end of the first rotating section 431 as shown in FIG. 3 is inserted into the downstream end of the driving rod 34.
- a driving key 431A extending in the axial direction is configured on the outer side wall of the first rotating section 431, and a driving groove extending in the axial direction is configured on the inner side wall of the driving rod 34.
- the driving groove matches the driving key 431A, so that when the driving key 431A is inserted into the driving groove, the rotating rod 43 can rotate with the driving rod 34 and move in the axial direction relative to the driving rod 34.
- the impactor 30 further includes an impact sleeve 44 sheathed outside at least a part of the rotating rod 43.
- the impact sleeve 44 includes an upstream first sleeve section 441 and a second sleeve section 442 connected downstream of the first sleeve section 441.
- the outer diameters of the first sleeve section 441 and the second sleeve section 442 are the same.
- the inner diameter of the first sleeve section 441 is smaller than the inner diameter of the second sleeve section 422.
- the first sleeve section 441 of the impact sleeve 44 is sleeved on the outside of the first rotating section 431 of the rotating rod 43, and the second sleeve section 442 is sleeved on the second The outer side of the rotating section 432.
- the rotating rod 43 can rotate relative to the impact sleeve 44.
- a lower driving tooth 432B is configured at the connection between the first rotating section 431 and the second rotating section 432 of the rotating rod 43, and the tooth surface of the lower driving tooth 432B is substantially facing upward.
- an upper driven tooth 441B is configured at the connection between the first sleeve section 441 and the second sleeve section 442, and the tooth surface of the upper driven tooth 441B is generally facing downward.
- the upper driven tooth 441B and the lower driving tooth 432B may be substantially configured in a wave-shaped form as shown in FIGS. 6 and 7.
- the wave trough of the upper driven tooth 441B is opposite to the wave crest of the lower driving tooth 432B.
- the rotating rod 43 moves upstream against the impact sleeve 44.
- the wave crest of the upper driven tooth 441B is opposite to the wave crest of the lower driving tooth 432B
- the wave trough of the upper driven tooth 441B is opposite to the wave trough of the lower driving tooth 432B.
- the impact sleeve 44 moves downstream in the axial direction and impacts the rotating rod 43.
- the downstream drill bit described above is installed at the downstream end of the rotating rod 43. The impact on the rotating rod 43 can thus be transmitted to the downstream drill bit, so that the downstream drill bit impacts the formation downward while rotating drilling.
- the wave-like upper driven tooth 441B and the lower driving tooth 432B include an upward tooth segment and a downward tooth segment connected to the upward tooth segment.
- the upward tooth section of the lower drive tooth 432B is inclined upward along the direction opposite to the direction of rotation of the rotating rod 43, while the downward tooth section of the lower drive tooth 432B is along the direction opposite to the direction of rotation of the rotating rod 43. Tilt down.
- the inclination of the upward tooth section is relatively gentle, and the inclination of the downward tooth section is relatively steep, so that the impact sleeve 44 can have a greater speed when it impacts toward the rotating rod 43. That is, the impact sleeve 44 can move upstream with respect to the rotating rod 43 at a relatively slow speed, and can impact the rotating rod 43 downward at a relatively fast speed.
- the lower housing part 41 is sleeved on the outside of the impact sleeve 44.
- An directional key 441A extending in the axial direction is configured on the outer side wall of the impact sleeve 44, and a corresponding directional groove extending in the axial direction is configured on the inner side wall of the lower housing portion 41.
- the impact sleeve 44 can move in the axial direction relative to the lower housing part 41 but cannot rotate relative to the lower housing part 41.
- the rotation of the impact sleeve 44 can be effectively limited, so as to ensure that the impact sleeve 44 does not rotate together with the rotating rod 43, that is, the relative rotation of the rotating rod 43 with respect to the impact sleeve 44 can be ensured.
- a step surface 433B facing upstream is formed between the second rotating section 432 and the third rotating section 433 of the rotating rod 43.
- the lower end surface 442B of the impact sleeve 44 is opposite to the step surface 433B.
- the lower end surface 442B of the impact sleeve 44 and the step surface 433B of the rotating rod 43 form an impact surface.
- the lower end of the upper housing part 31 is inserted into the upper end of the lower housing part 41, for example, the two can be connected by a threaded drill pipe joint.
- a cylindrical support sleeve 42 is provided between the lower end surface 31A of the upper housing portion 31 and the step 41A in the lower housing portion 41.
- the support sleeve 42 extends radially inward, so that the upper end surface of the support sleeve 42 can be arranged opposite to the lower end surface of the bearing sleeve 32, and the lower end surface of the support sleeve 42 is arranged opposite to the upper end surface of the impact sleeve 44 .
- the support sleeve 42 is affected by its own weight and falls on the step 41A in the lower housing part 41.
- the impact sleeve 44 will press against and push the support sleeve 42, the upper housing portion 31, and the cylindrical housing of the drive mechanism 20 to move upstream together, and thereby push it up.
- the drill rod 11 and the drill collar 12 in the upstream drill tool 10 are moved, so that they are elastically compressed in the axial direction. After that, the upstream drill tool 10 including the drill rod 11 and the drill collar 12 is released from compression, thereby pushing the impact sleeve 44 to move downstream to impact the rotating rod 43.
- a wear-resistant joint 47 is also connected to the lower end of the lower housing part 41, for example, the two are fixed by a threaded connection.
- the anti-wear joint 47 can improve the wear resistance between the lower housing part 41 and the rotating rod 43 to increase the service life of the entire drilling tool 1.
- the anti-wear joint 47 surrounds the third rotating section 433 of the rotating rod 43 and a sliding seal 48 is provided between the anti-wear joint 47 and the third rotating section 433.
- a sealed relative movement in the axial direction can occur between the third rotating section 433 and the anti-wear joint 47 to prevent the mud from leaking out.
- the anti-wear joint 47 is preferably made of alloy steel inlaid with cemented carbide material, or metallurgical combination of alloy steel and S201 material, or metallurgical combination of alloy steel and DT30 material, so that it has sufficient wear resistance.
- the fourth rotating section 434 of the rotating rod 43 is downstream of the anti-wear joint 47.
- a step surface facing upstream is formed between the fourth rotating section 434 and the third rotating section 433.
- a groove is configured on the outer side wall of the third rotating section 433, and a groove protruding radially outward relative to the third rotating section 433 is provided in the groove.
- Limit block 45 In the radial direction, the limiting block 45 is sandwiched between the third rotating section 433 and the lower housing part 41.
- the upper end of the anti-wear joint 47 is inserted into the lower end of the lower housing part 41.
- the upper end surface of the anti-wear joint 47 is opposed to the stop block 45, and the axial movement range of the rotating rod 43 relative to the anti-wear joint 47 can be restricted.
- the limiting block 45 may be configured as two semi-circular stop shoes. After installation, the two stop shoes are hug on the outer wall of the third rotating section 433 at the groove, and the stop shoes are fixed on the outer wall of the third rotating section 433 by the installation cord 46. In the process of tripping and drilling, the limit block 45 follows the rotating rod 43 and falls relative to the lower housing part 41, and sits on the anti-wear joint 47, and strikes the impact sleeve 44, the rotating rod 43 and the limit block 45. Anti-off effect.
- the specific working process of the above-mentioned drilling tool 1 is as follows.
- the above-mentioned drilling tool 1 is lowered into the well to be drilled.
- the rotating rod 43 moves downward relative to the driving rod 34 to a position where the stop block 45 abuts against the upper end surface of the anti-wear joint 47.
- the drilling tool 1 When the downstream drill bit of the drilling tool 1 touches the bottom of the well, the drilling tool 1 is continued to be lowered so that the rotating rod 43 moves upward relative to the driving rod 34 until the upper end surface of the impact sleeve 44 abuts the support sleeve 42.
- drilling can be performed.
- the downstream bit abuts the formation.
- the rotating rod 43 and the downstream drill bit rotate together with the driving rod 34.
- the impact sleeve 44 reciprocates up and down relative to the rotating rod 43.
- the drill rod 11 and the drill collar 12 in the upstream drill tool 10 can be elastically compressed.
- the impact sleeve 44 moves downstream relative to the rotating rod 43, the above-mentioned elastic compression is released, and the impact sleeve 44 is pushed by the upstream drill tool 10 to move rapidly downstream and impacts toward the rotating rod 43, thereby causing the downstream drill bit to impact To the strata.
- the first step is to determine the value of the minimum impact energy W 0 required for drilling according to the rock compressive strength P resistance of the formation to be drilled.
- the formation rock to be drilled can be sampled first, and the rock mechanics characteristics of the obtained sample can be analyzed. For example, the lithology, drillability, hardness, etc. of the sample can be determined here. Then, the compressive strength P resistance of the rock can be determined by the drillability and hardness of the rock, for example, according to the following table.
- the relationship between the impact energy W 0 required to break the rock and the compressive strength of the rock is determined.
- a regression curve of the relationship between the impact energy W 0 required to break the rock and the compressive strength of the rock can be established. Therefore, after the rock compressive strength of the formation is determined, the value of the minimum impact energy W 0 required to break the rock can be determined according to the above relationship curve.
- W 0 0.0067P anti 2 +0.2196P anti +35.571.
- the value of the preset impact energy W for drilling operations can be determined according to the value of the minimum impact energy W 0 required for breaking the rock.
- the value of the preset impact energy W may be substantially equal to the value of the minimum impact energy W 0 or, as required, may be greater than the value of the minimum impact energy W 0.
- the third step is to calculate the minimum weight-on-bit P 1 required for drilling according to the determined value of the preset impact work W.
- the minimum weight-on-bit P 1 required for the drilling is the pressure applied by the drilling tool 1 on the surface phase by the operator during construction.
- P 1 is the minimum weight on bit required for drilling
- W is the preset impact energy
- h is the stroke of the impactor
- L p is the length of the drill rod
- E p is the modulus of elasticity of the drill rod
- L c is the length of the drill collar
- a c is the cross-sectional area of the drill collar
- E c is the elastic modulus of the drill collar.
- the power source such as screw motor and turbodrill
- the driving rod can be determined according to the minimum weight-on-bit P 1 34.
- the torque value required for work and thereby determine the power source model and the parameters of the drive rod 34, and then select and determine all drilling parameters according to the power source design manual.
- drilling parameters include weight on bit, displacement, rotational speed and so on.
- the key structural parameters of the rotating rod 43 and the impact sleeve 44 of the core component of the tool are determined according to the minimum weight on bit P 1 and the stroke h.
- the key structural parameters include the number of teeth and the tooth height of the lower driving tooth and the upper driven tooth.
- the value of the minimum WOB P 1 can also be preset, and the value of the preset impact work W can be determined according to the value of the preset minimum WOB P 1. Then, the value of the preset impact energy W is compared with the value of the minimum impact energy W 0 . If the value of the preset impact energy W is substantially greater than or equal to the value of the minimum impact energy W 0 , then the value of the preset minimum WOB P 1 can be used in subsequent work. Otherwise, reset the value of the minimum weight on bit P 1 and/or the value of at least one of the above parameters, and recalculate until the value of the preset impact energy W is substantially greater than or equal to the value of the minimum impact energy W 0 Value.
- the above-mentioned drilling tool 1 is particularly suitable for vertical well drilling in a hard formation environment with a depth of more than several kilometers.
- the length of the drill rod is at least ten times the stroke h.
- the rigidity of the drill pipe is relatively small, which can be considered as an elastic drill string.
- the deformation is mainly caused by the drill pipe part. produce.
- the increased thrust required to push up a certain stroke decreases rapidly with the increase of drill rods.
- the calculation results show that only 100m drill rods need to be connected, and the required increased thrust rapidly drops from 17.92t to 4.38t. Then gradually tend to 0.
- the drilling tool 1 of the present invention is based on the characteristics of composite dual-drive and the upstream drilling tool 10 for elastic energy storage.
- the upstream drilling tool 10 can produce compression and rebound.
- the potential energy causes the downstream drill bit to generate a countermeasure against the formation.
- the impact of this reciprocation forming a comprehensive effect of high-speed rotation and high-frequency impact. Therefore, the drilling tool 1 of the present invention has the advantages of high rock breaking frequency, high strength, and high efficiency, and has a high speed-increasing effect.
- the upstream drilling tool 10 can provide much greater elastic compression. As a result, the downstream drill bit is allowed to produce relatively large impacts both in frequency and amplitude. This is more conducive to accelerating the drilling speed and drilling efficiency of the drilling tool 1.
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Abstract
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Claims (18)
- 一种钻井工具,包括:上游钻具;下游钻头;以及冲击器,所述冲击器连接在所述上游钻具和所述下游钻头之间;在第一状态下,所述冲击器使所述上游钻具产生弹性压缩,在第二状态下,所述上游钻具释放弹性压缩,通过所述冲击器而对所述下游钻头施加冲击。
- 根据权利要求1所述的钻井工具,其特征在于,所述冲击器包括:旋转驱动部,所述旋转驱动部构造为能进行围绕其轴线的旋转;旋转工作部,所述旋转工作部的上端与所述旋转驱动部的下端相接合,所述旋转工作部的下端与所述下游钻头相连,所述旋转工作部能被所述旋转驱动部驱动着进行围绕其轴线的旋转,并能相对于所述旋转驱动部沿轴向移动;以及冲击发生部,所述冲击发生部套设在所述旋转工作部之外,所述冲击发生部的上端与所述上游钻具相抵,所述冲击发生部的下端与所述旋转工作部相抵;在第一状态下,所述冲击发生部向上游移动而使所述上游钻具发生弹性压缩,在第二状态下,所述上游钻具释放弹性压缩,使得所述冲击发生部向下游移动而向所述旋转工作部施加冲击。
- 根据权利要求2所述的钻井工具,其特征在于,所述旋转驱动部包括筒状的驱动杆,所述驱动杆的上端与动力源相接合,所述旋转工作部包括筒状的旋转杆,所述旋转杆的上端与所述驱动杆的下端通过驱动键接合,所述旋转杆的下端与所述下游钻头相连,所述旋转杆的上端插入到所述驱动杆的下端内,在所述旋转杆的上端外侧构造有沿着所述旋转杆的轴向方向延伸的所述驱动键,在所述驱动杆的下端内侧构造有沿着所述驱动杆的轴线方向延伸的驱动槽,所述驱动键配合在所述驱动槽内,使得所述旋转杆在周向上相对于所述驱动杆固定,并在轴向上能相对于所述驱动杆移动。
- 根据权利要求3所述的钻井工具,其特征在于,所述冲击发生部包括冲击套筒,所述冲击套筒套设在所述旋转杆的外侧,所述冲击套筒包括内径较小的 第一套筒段,以及内径较大的第二套筒段,所述第二套筒段连接在所述第一套筒段之下,在所述第一套筒段和所述第二套筒段之间的连接处的所述冲击套筒的内侧形成上从动齿;所述旋转杆包括外径较小的第一旋转段,以及外径较大的第二旋转段,所述第二旋转段连接在所述第一旋转段之下,在所述第二旋转段和所述第一旋转段之间的连接处的所述旋转杆的外侧形成下驱动齿;所述下驱动齿和所述上从动齿相匹配,在所述旋转杆相对于所述冲击套筒发生旋转时,在所述下驱动齿和所述上从动齿的配合下,所述冲击套筒相对于所述旋转杆而发生轴向的往复移动。
- 根据权利要求4所述的钻井工具,其特征在于,所述上从动齿和所述下驱动齿构造有沿与旋转方向相反的方向向上游倾斜的上行齿段,以及与所述上行齿段相连的沿与旋转方向相反的方向向下游倾斜的下行齿段,所述上行齿段的倾斜度小于所述下行齿段的倾斜度。
- 根据权利要求4所述的钻井工具,其特征在于,所述旋转杆还包括连接在所述第二旋转段下端的第三旋转段,所述第三旋转段的外径大于所述第二旋转段的外径,在所述第二旋转段和所述第三旋转段之间形成朝向上游的冲击台阶,所述冲击套筒的下端与所述冲击台阶相对并能与所述冲击台阶发生冲击,在所述冲击套筒的下端与所述冲击台阶相接触时,所述上从动齿与所述下驱动齿在轴向上存在间隙。
- 根据权利要求4所述的钻井工具,其特征在于,在所述冲击套筒的外侧套设有筒状的外壳体,所述外壳体与所述冲击套筒通过定向键而滑动式接合,所述外壳体的上端与所述上游钻具相连,其中,在所述冲击套筒的外侧构造有沿轴向方向延伸的所述定向键,在所述外壳体的内侧构造有沿轴向方向延伸的定向槽,所述定向键配合到所述定向槽内,使得所述冲击套筒在周向上相对于所述外壳体固定,并在轴向上能相对于所述外壳体移动。
- 根据权利要求7所述的钻井工具,其特征在于,所述外壳体包括与所述上游钻具相连的上壳体部分和连接在所述上壳体部分之下的下壳体部分,所述驱动杆套的至少一部分设在所述上壳体部分内,在所述上壳体部分和所述驱动杆之间设置有旋转轴承,允许所述驱动杆相对于所述上壳体部分发生转动,所述下壳体部分包围所述冲击套筒,所述上壳体部分的下端插入到所述下壳体部分的上端内,在所述上壳体部分的下端与所述冲击套筒的上端之间设置有支撑套,所述冲击套筒通过所述支撑套而向所述上壳体部分施力,并由此使所述上游钻具产生弹性压缩。
- 根据权利要求6所述的钻井工具,其特征在于,在所述旋转杆的第三旋转段的侧壁上构造有凹槽,在所述凹槽中安装有相对于所述第三旋转段径向向外凸出的限位块,在所述冲击套筒的外侧套设有筒状的外壳体,所述外壳体向下延伸至包围所述第三旋转段,在所述外壳体的下端处构造有径向向内延伸的卡接部,所述限位块位于所述卡接部的上游处并构造为能与所述卡接部相抵以限制所述旋转杆相对于所述外壳体向下游的移动。
- 一种用于确定钻井工具的参数的方法,所述钻井工具包括上游钻具、下游钻头和冲击器,所述冲击器连接在所述上游钻具和所述下游钻头之间,在第一状态下,所述冲击器使所述上游钻具产生弹性压缩,在第二状态下,所述上游钻具释放弹性压缩,通过所述冲击器而对所述下游钻头施加冲击,所述上游钻具包括钻杆和连接在所述钻杆之下的钻铤,所述方法包括以下步骤:根据要被钻进的地层的岩石抗压强度来确定钻进所需的最小冲击功的值;根据所确定的最小冲击功的值来确定预设冲击功的值,所述预设冲击功的值不低于所述最小冲击功的值;根据所述预设冲击功的值来确定钻井所需的最小钻压,根据钻井所需的最小钻压来确定动力源和驱动杆工作所需的扭矩值,并由此确定动力源的型号和驱动杆的参数,进而根据动力源手册,选取确定所需钻井参数,该钻井参数包括钻压、排量、转速,或/和根据钻井所需的最小钻压来确定钻井工具的旋转杆和冲击套筒的结构参数,该结构参数包括下驱动齿和上从动齿的齿数、齿高。
- 根据权利要求10所述的方法,其特征在于,所述冲击器包括:旋转驱动部,所述旋转驱动部构造为能进行围绕其轴线的旋转;旋转工作部,所述旋转工作部的上端与所述旋转驱动部的下端相接合,所述旋转工作部的下端与所述下游钻头相连,所述旋转工作部能被所述旋转驱动部驱 动着进行围绕其轴线的旋转,并能相对于所述旋转驱动部沿轴向移动;以及冲击发生部,所述冲击发生部套设在所述旋转工作部之外,所述冲击发生部的上端与所述上游钻具相抵,所述冲击发生部的下端与所述旋转工作部相抵;在第一状态下,所述冲击发生部向上游移动而使所述上游钻具发生弹性压缩,在第二状态下,所述上游钻具释放弹性压缩,使得所述冲击发生部向下游移动而向所述旋转工作部施加冲击。
- 根据权利要求11所述的方法,其特征在于,所述旋转驱动部包括筒状的驱动杆,所述驱动杆的上端与动力源相接合,所述旋转工作部包括筒状的旋转杆,所述旋转杆的上端与所述驱动杆的下端通过驱动键接合,所述旋转杆的下端与所述下游钻头相连,所述旋转杆的上端插入到所述驱动杆的下端内,在所述旋转杆的上端外侧构造有沿着所述旋转杆的轴向方向延伸的所述驱动键,在所述驱动杆的下端内侧构造有沿着所述驱动杆的轴线方向延伸的驱动槽,所述驱动键配合在所述驱动槽内,使得所述旋转杆在周向上相对于所述驱动杆固定,并在轴向上能相对于所述驱动杆移动。
- 根据权利要求12所述的方法,其特征在于,所述冲击发生部包括冲击套筒,所述冲击套筒套设在所述旋转杆的外侧,所述冲击套筒包括内径较小的第一套筒段,以及内径较大的第二套筒段,所述第二套筒段连接在所述第一套筒段之下,在所述第一套筒段和所述第二套筒段之间的连接处的所述冲击套筒的内侧形成上从动齿;所述旋转杆包括外径较小的第一旋转段,以及外径较大的第二旋转段,所述第二旋转段连接在所述第一旋转段之下,在所述第二旋转段和所述第一旋转段之间的连接处的所述旋转杆的外侧形成下驱动齿;所述下驱动齿和所述上从动齿相匹配,在所述旋转杆相对于所述冲击套筒发生旋转时,在所述下驱动齿和所述上从动齿的配合下,所述冲击套筒相对于所述旋转杆而发生轴向的往复移动。
- 根据权利要求13所述的方法,其特征在于,所述上从动齿和所述下驱动齿构造有沿与旋转方向相反的方向向上游倾斜的上行齿段,以及与所述上行齿段相连的沿与旋转方向相反的方向向下游倾斜的下行齿段,所述上行齿段的倾斜 度小于所述下行齿段的倾斜度。
- 根据权利要求13所述的方法,其特征在于,所述旋转杆还包括连接在所述第二旋转段下端的第三旋转段,所述第三旋转段的外径大于所述第二旋转段的外径,在所述第二旋转段和所述第三旋转段之间形成朝向上游的冲击台阶,所述冲击套筒的下端与所述冲击台阶相对并能与所述冲击台阶发生冲击,在所述冲击套筒的下端与所述冲击台阶相接触时,所述上从动齿与所述下驱动齿在轴向上存在间隙。
- 根据权利要求13所述的方法,其特征在于,在所述冲击套筒的外侧套设有筒状的外壳体,所述外壳体与所述冲击套筒通过定向键而滑动式接合,所述外壳体的上端与所述上游钻具相连,其中,在所述冲击套筒的外侧构造有沿轴向方向延伸的所述定向键,在所述外壳体的内侧构造有沿轴向方向延伸的定向槽,所述定向键配合到所述定向槽内,使得所述冲击套筒在周向上相对于所述外壳体固定,并在轴向上能相对于所述外壳体移动。
- 根据权利要求16所述的方法,其特征在于,所述外壳体包括与所述上游钻具相连的上壳体部分和连接在所述上壳体部分之下的下壳体部分,所述驱动杆套的至少一部分设在所述上壳体部分内,在所述上壳体部分和所述驱动杆之间设置有旋转轴承,允许所述驱动杆相对于所述上壳体部分发生转动,所述下壳体部分包围所述冲击套筒,所述上壳体部分的下端插入到所述下壳体部分的上端内,在所述上壳体部分的下端与所述冲击套筒的上端之间设置有支撑套,所述冲击套筒通过所述支撑套而向所述上壳体部分施力,并由此使所述上游钻具产生弹性压缩。
- 根据权利要求15所述的方法,其特征在于,在所述旋转杆的第三旋转段的侧壁上构造有凹槽,在所述凹槽中安装有相对于所述第三旋转段径向向外凸出的限位块,在所述冲击套筒的外侧套设有筒状的外壳体,所述外壳体向下延伸至包围所述第三旋转段,在所述外壳体的下端处构造有径向向内延伸的卡接部,所述限位块位于所述卡接部的上游处并构造为能与所述卡接部相抵以限制所述旋转杆相对于所述外壳体向下游的移动。
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CN109695423A (zh) * | 2018-12-28 | 2019-04-30 | 成都理工大学 | 抑制下部钻柱共振平稳钻压的钻具组合 |
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