DE1084216B - Feed and drilling pressure control device for hydraulic deep drilling motors, z. B. Drilling turbines and methods of operating the facility - Google Patents

Description

The invention relates to a feed and drilling pressure control device for hydraulic deep drilling motors, z. B. drilling turbines in the borehole on the drilling rod used to supply the drilling fluid are suspended to drive a drilling tool, the hydraulic motor and thus the Drilling tool is driven by the drilling fluid flowing through. Furthermore, the The invention relates to a method for operating a deep drilling device of the type described in more detail above. Drilling turbines are often used for driving deep boreholes into the ground for the purpose the detection of oil, gas, salt, sulfur, water, etc.

One of the difficulties that arises with such a deep drilling device is the regulation the operating conditions of the drilling tool and the hydraulic motor; the minute speed of the The drive motor and the drilling tool must be kept between predetermined limits; further must the weight on the drill, referred to below as the drill weight, is carefully adjusted, to regulate the speed at which the drilling tool penetrates the formation in question to avoid damage to the drilling tool and deviations from the desired drilling direction.

It is already a drilling device with a hollow drill rod rotated by means of a surface drive and a drilling tool provided with outlet openings for the drilling fluid known in which a telescopic connection is provided between the drilling tool and the drill pipe, which is connected by an in the differential pressure present in the drilling fluid flow is pressed apart and for advancing or driving serves. In this case, the weight in the feed device acts as the weight on the drill prevailing differential pressure as well as the weight of the drilling tool and the one firmly connected to it Part of the drill pipe below the telescopic connection.

An object of the invention is to provide a deep drilling device with a downhole hydraulic drive motor, in which the operating conditions of the drilling tool and the regulate or influence the hydraulic motor sufficiently.

The deep drilling device according to the invention, with which this goal is achieved, is due to the combination marked with the following features:

The connection between the drilling tool and the drill string includes, besides the hydraulic one Motor known from the deep drilling device described in the penultimate paragraph, as a feed device feed and drilling pressure control device for hydraulic deep drilling motors,

z. B. Drilling Turbines, and Processes

to operate the facility

Applicant:

N.V.DeBataafschePetroleumMaatschappij, The Hague

Representative: Dr.-Ing. F. Wuesthoff, Dipl.-Ing. G. Pulse
and Dipl.-Chem. Dr. rer. nat. E. Frhr. v. Bad luck man,
Patent Attorneys, Munich 9, Sdiweigerstr. 2

Claimed priority:

Great Britain, 10 December 1954

and September 26, 1955

Frank Whittle, Dunsford, Exeter (UK),
has been named as the inventor

Telescopic connection with two hollow extendable and retractable components that are connected to a relative Rotational movement are prevented and of which one component has one or more pistons that with a corresponding number of formed between abutments on the other of the two components Cylinders work together and divide the respective cylinders into two cylinder spaces.

In the simplest arrangement, the cylinder spaces on both sides of the pistons are included the inside of the inner extendable and retractable component or with which the outer extendable and retractable component Component surrounding borehole connected, whereby the pressure difference between the two There are spaces lying on the side of a piston when the named connections are established, in each instant is equal to the difference which then press between the fluids in that Drill string and in the borehole. The latter pressure difference becomes substantial equal to the sum of the pressure drops in the hydraulic motor and across the nozzle openings of the drilling tool. The weight of the drill is essentially equal to the force exerted on the pistons

009 548/76

as a result of the pressure difference applied between each on either side of the piston consists of lying rooms; this pressure difference is proportional to the square of the circulation velocity dility of the drilling fluid, and as a result, you can regulate the drill weight by that one the circulation speed of the drilling fluid varies.

When operating a deep drilling rig with a hydraulic turbine that runs along the drill string downward pumped drilling fluid is driven, which at the same time the feed device actuated, the force applied by the feed device to the drilling tool affects the load the turbine and thus also the turbine speed. Furthermore, the turbine speed is determined by the Affects the hardness of the formation to be drilled, which is why the mutual influence of the feed device and the turbine must be carefully considered to prevent the turbine from running runs too fast or comes to a standstill when drilling through hard or soft formations. aside from that you have to keep the operating speed of the turbine within certain narrow limits, since the efficiency the turbine only at the design speed at its maximum value or in whose proximity is. In that the arrangement is made so that one of the rotational speed on the piston the hydraulic motor dependent pressure difference acts in such a direction that the Deviations in the rotational speed of the hydraulic motor from the value for which it is designed is counteracted by changing the drilling pressure, the turbine speed can be adjusted in spite of the changeable conditions given by the pierced formation within the prescribed Keep boundaries.

With the deep drilling device designed according to the invention it is achieved that even if Formations of widely fluctuating hardness are pierced under the action of the turbine Feed device operates within a relatively narrow speed range.

In order to make the operating behavior of the feed device easier to understand in this regard, the concept of "insensitivity" is introduced here, under which the relationship between one The range of hardness of the formation and the speed range of the turbine when drilling through a formation, to which the stated hardness range is to be understood. The greater the value, the insensitivity a system assumes, the greater the hardness range of the formations that are being drilled can without the turbine speed leaving the predetermined speed range.

About the insensitivity of a hydraulic turbine and a feed device To increase deep drilling equipment, one can use one or more of the methods listed below serve:

1. Connect the lower pressure side of the pistons to the space at the turbine outlet instead of directly the borehole;

2. Use of a turbine whose design speed is equal to the lowest speed is the desired operating speed range and at which there is a pressure drop along the turbine, the speeds that exceed the design speed increases rapidly;

3. Throttling of either the turbine outlet or the turbine inlet at higher turbine speeds with the help of a speed-sensitive throttle valve to control the pressure drop along the turbine to increase with increasing speed;

4. Diverting a portion of the circulating drilling fluid, in such a way that the diverted Part of the drilling fluid flow does not pass through the drilling fluid openings in the drilling tool, so that the drilling fluid circulation through these openings remains essentially constant, although the rate of circulation of drilling fluid flowing down the drill pipe varies;

5. Connect the high pressure side of the pistons to the outlet of one driven by the turbine Pump as well

a) connecting the suction side of the pump to the fluid space at the inlet of the turbine or

b) Connect the suction side of the pump to the low pressure side of the pistons and circulate a servo fluid different from the drilling fluid by the pump and the cylinders;

6. Shutdown of one or more pistons of the feed device by connecting adjacent ones cylindrical spaces what can happen

a) by hand or

b) automatically, with z. B. each piston is then put out of service when between the cylindrical spaces on both sides of the piston in question, a predetermined pressure difference occurs or if the circulation speed of the drilling fluid has a ^ assumes a predetermined value;

7. Use of a feed device with pistons of different diameters when in use of method 6, according to which one or more pistons are put out of operation.

According to the following description, it can occur when operating a deep drilling device according to the invention In addition, it may be desirable to employ a method in which the circulation rate of the drilling fluid flowing through the drill pipe either according to the weight of the drill or according to the drill speed or according to the torque applied to the drilling tool is varied.

The invention is explained in more detail using schematic drawings of several exemplary embodiments.

1 is a schematic longitudinal section through a feed device for a deep drilling device according to the invention ;

Fig. 2 is a schematic longitudinal section through a feed device with a hydraulic turbine and a drilling tool is combined;

Fig. 3, 4, 5 and 6 are graphical representations with respect to a system as described with reference to Fig. 2 for various values of the drilling fluid circulation rate Q of the pressure drop as a function of the turbine speed and the bit weight as a function of the turbine speed and the turbine power as a function of turbine speed and the formation coefficient as a function of turbine speed;

Fig. 6 A is a graphical representation of the relationship between the torque T and the rotational

number N for different values of the circulation speed Q and shows the operating curve W ₀ , along which the drill weight is kept constant;

6B and 6C show the relationship between the circulation speed Q and the torque T (Fig. 6B) and the turbine speed N (Fig. 6C) when the drill weight W _{0 is} kept constant;

7 and 8 show alternative embodiments of the feed device for increasing the insensitivity the system;

9 A and 9 B show two different embodiments of feed devices with a hydraulic pump driven by the turbine while

10 and 11 graphically illustrate the bit weight as a function of turbine speed and the formation coefficient as a function of turbine speed, respectively, for a construction according to FIG. 9A and at different drilling fluid circulation speeds Q ;

Figures 12 and 13 show certain details of the structures of Figure 9A;

14 and 15 show the bit weight versus turbine speed and formation coefficient versus turbine speed curves, respectively for the modified feed devices shown in Figs. 16 and 27, the means which allow adjacent cylindrical spaces to be connected to one another by hand;

17, 18, 19 and 28 show ram devices in which adjacent cylindrical spaces automatically can be connected while

Figures 20, 21 and 22 show the operating curves of the respective feed devices;

23, 24 and 29 show further feed devices in which adjacent cylindrical spaces can be automatically connected to each other, and

Figs. 25 and 26 show the corresponding operating curves.

Figs. 1 and 2 show a feed device in the fully extended position. Two components 3 and 4 are arranged between the lower end of a drill rod 1 (FIG. 1) and a hydraulic turbine 14 (FIG. 2), the component 4 being arranged in the component 3 so that it can be pushed out and pushed in. To transmit the torque from the outer component 3 to the inner component 4, the wedges or wedge tracks indicated at 5 and provided on the upper part of the device are used, which, however, could also be provided at the lower end of the displacement device or at another suitable location. The inner extendable component 4 carries a number of pistons 6 which are sealed against the inner wall of the component 3 in a suitable manner (not shown). Inside the outer component 3, cylinders 7 are formed, the number of which corresponds to that of the pistons 6, and these cylinders work together with the pistons; each cylinder is thus divided into two cylindrical spaces by the associated piston 6. The abutments which separate the cylinders 7 from one another are equipped with suitable sealing means (not shown) in order to seal the adjacent cylinders against one another.

Although the inner extendable component 4 according to FIGS. 1 and 2 is coupled to the drilling tool 2, while the outer component 3 is coupled to the drill string 1, but it is obvious that one is attached an alternative arrangement, the outer component with the drilling tool 2 and the inner retractable Can couple the component to the drill rod 1. It should also be noted that the Fig. 2 between the Drilling tool 2 and the feed device arranged hydraulic turbine 14 also between the Feed device the drill rod 1 can be arranged.

The pumped during operation through the drill string 1 down to the bottom of the borehole Mud enters the retractable Bauo part 4 in the direction of arrow 9 and flows through the inside of the component 4 to get to the hydraulic turbine 14 and the drilling tool 2, where the drilling fluid is expelled through the openings 10.

In the wall of the inner extendable component 4 openings 11 are provided which the cylindrical Connect spaces above the piston 6 with the interior of the component 4. The cylindrical spaces below of the piston 6 are with the space surrounding the component 3, d. H. with the interior of the. borehole, through the openings 12 provided in the wall of the component 3.

The openings 11 are just above the pistons 6, and the openings 12 are just above the abutments 8, so that the openings 11 are always connected to the spaces above the pistons 6, while the openings 12 are always connected to the spaces below the pistons 6 are in connection, regardless of the mutual position of the extendable and retractable components 3 and 4.

The pressure difference between the spaces above and below the piston 6 is the same the pressure difference between the static pressure of the drilling fluid inside the component 4 and the static pressure of the drilling fluid within the borehole. This latter pressure difference is aimed according to the resistance that the turbine 14 and the drilling fluid outlet openings 10 in the drill 2 oppose the drilling fluid flow and it is substantially proportional to the square of the circulation velocity of the drilling fluid. It can be seen that the pressure difference acting on the piston 6 is obtained can vary at will by varying the rate of circulation of the drilling fluid and / or the shape or the size of the nozzle openings 10 is adapted in a suitable manner to the requirements.

The weight on the drill 2 in this arrangement is essentially equal to the total weight of the extendable component 4, the hydraulic turbine 14 and the drill 2, increased the force resulting from the action of the drilling fluid pressure on the surfaces of the pistons 6 Force, and reduced by the force caused by the pressure of the drilling fluid in the borehole is exerted on the undersides of the pistons 6. It should be noted that part of the effective piston area is supplied by the practically closed ends of the inner extendable member 4; with others Words, if the pistons were not present and if the component 4 is only one in another component 3 represented sliding pipe, there would be a force which tends to pull the component 3 out of the component 4 slide out. Further, when there are downward jetting nozzles, the reaction force of the nozzles will result in one in the opposite direction Acting force. In the following description these forces are used for the sake of simplicity not taken into account. It should also be noted that it is advisable to place the drill pipe above the feed

device to be provided with collars to the through the feed device in the upward direction absorb applied reaction force.

The drill weight can be indicated by a weight indicator, as it is with the rotary drilling method Is customary, or the pressure force prevailing in the shank 13 of the drilling tool 2 can be applied suitable means (not shown) measure and the measured values obtained in a suitable manner, e.g. Am Form of an electrical signal, transmitted to the earth's surface. There the measured values are taken from the drill master received, which the drill weight by varying the circulation speed of the Mud regulates.

When the drill weight drops rapidly during drilling and not by increasing it the circulation speed can be set back to the desired value, this means that the ram has reached the end of its stroke, d. that is, components 3 and 4 are fully extended are. By lowering the outer component 3, the plunger can then be fully retracted again.

Obviously, it is preferable to have the drill string 1 continuously with it from the surface of the earth to lower a speed which corresponds approximately to the penetration speed of the drill 2. Then it is only necessary to readjust the feed rate at relatively long time intervals if there is evidence that the ram assembly is either fully extended or is fully retracted. When the speed of advancing the drill string at the Earth's surface, for example, about 12 m / h. and if the drill is actually at a speed of about 15 m / h penetrates, the plunger pistons 6 move with the plunger cylinders 7 a relative speed of about 3 m / hour. downward. Under these conditions, a Lifting movement over a distance of about 1.5 m takes about 30 minutes. When piercing The drill master could then adjust the feed rate of relatively uniform formations of the drill string to match the penetration speed of the drill that a Readjustment at intervals of less than 1 hour is avoided during the drill master then, if the feed rate depended solely on the ram, the drill pipe at intervals of a few minutes.

The bit weight follows, insofar as it is related to the drilling fluid pressure the total pressure drop in the turbine and the drilling fluid outlet openings 10 as well as after the effective one Plunger Plunger Area 6.

This results in neglecting the factors already mentioned:

Values of Q where Q _{1 is} greater than Q ₂ and where Q _{2 is} greater than Q ₃ ; this can be expressed by the following formula:

Ap = F (Q, N)

From equations (1) and (2) we get:

W = A [F (Q ₁ N) + kQz] (3)

and this equation is the basis of that shown in FIG

ίο reproduced curves.

Tests have shown that the performance required in drilling a particular formation based on a coefficient that represents the hardness of the formation and the drill bit diameter, the drill speed and the drill weight, so that this relationship can be defined by the following Can represent equation:

P = KdNW (4)

ao where P is the power to be delivered by the turbine in HP, K is the formation coefficient, which depends on the hardness of the formation and varies from 0.0004 for hard rock to 0.001 for soft rock, d is the diameter of the drill used in inches ( 1 inch

»5 = 25.4 mm), N the minute number of revolutions of the drill, W the weight on the drill used in thousands of pounds (1000 pounds = 454 kg).

Although it is not certain whether this equation (4) is correct under all conditions, it is called Used as the basis for the following consideration of the problem.

For a given drill bit, the diameter d is a constant, while in equation (4) both W and P are functions of N for different circulation speeds Q. This results in:

W = A [F (Q ₁ N) + kQ *], (3)

as shown in Fig. 4, and

P = F '(Q ₁ N),

(5)

as shown in FIG.

It is therefore possible to draw the curves shown in Fig. 6 for different circulation speeds Q , which indicate the relationship between the drill speed N and the formation coefficient K ; this relationship can be derived from equations (4), (3) and (5) as follows:

K =

F '(Q, N)

dNW dNA [F (Q ₁ N) + £ (? ² ]

= F "(Q, N).

= A (AP) = A (Ap

(1)

where W is the weight on the drill, A is the effective piston area of the ram pistons 6, AP is the total pressure difference acting on the pistons 6, Ap is the pressure drop across the turbine, ^{kQ z is} the pressure drop at the drilling fluid outlet openings 10, k is the constant for the drilling fluid -Outlet openings 10, Q the circulation speed of the drilling fluid.

The variable Ap is a function of the turbine speed N and the circulation speed Q. This situation is shown graphically in FIG. 3; here Ap is plotted against N , namely for different. From these curves it can be seen that z. B. when drilling in a soft formation with a high formation coefficient K ₁ at a circulation speed Q ₁ a speed N _{1 is} given, while for a hard formation with the coefficient K ₃ at the same circulation speed Q ₁ a much higher speed AT ₃ results.

It can also be seen that for a given formation coefficient, for example K ₃ , the speed decreases from N ₃ ^r to JV ₃ when the circulation speed is reduced from Q ₁ to Q ₃ .

As mentioned earlier, it is when drilling through formations with widely varying formation coefficients desirable to keep the speed changes of the turbine within narrow limits. From Fig. 6 it becomes clear that this can be achieved by varying the speed of circulation, the Circulation speed depending on the

I 084216

Speed is preferably changed continuously. One can therefore draw a curve W _{c between} points 1, 2 and 3, which lies on the circulation curves Q ₁ , Q ₂ and Q _z and which, with the correct choice of points 1, 2 and 3, can represent an operating curve along which that Drill weight W is kept constant (see Fig. 4).

From Fig. 6 one can see the insensitivity * _ ³

derive this arrangement.

It is obvious that the mode of operation of the deep drilling device follows the operating curve W ₀ in FIG. 6 when the master drill controls the circulation speed Q in such a way that the drill weight W is kept constant at a value W _0. When the drill weight W ₀ decreases, the circulation speed must be increased, and vice versa. This regulation can either take place automatically or be carried out manually by the drill master. As already stated, the drill weight W can be determined with the aid of a suitable weight indicator, or the pressure force prevailing in the shank of the drill 2 can be measured and this measured value in a suitable manner, e.g. B. in the form of an electrical signal, transmitted to the earth's surface.

Another control system can respond to changes in the torque that is measured in the shank of the drill 2 just above the actual drill. The torque-speed curves or 3a the (TIN) curves of a hydraulic turbine are shown for different circulation speeds Q in FIG. 6A. An operating curve for a constant drill weight W ₀ can be drawn with the aid of the values of Q and N which correspond to points 1, 2 and 3 in FIG. By manually adjusting the circulation speed Q with a varying torque in accordance with the curve drawn in FIG. 6B, the drill master can thus keep the drill weight W ₀ constant. This regulation can also be carried out automatically.

Another system for keeping the drill weight constant under variable drilling conditions can be implemented by measuring the speed of the turbine, these measured values ζ. B. as an electrical signal to the earth's surface and adjusts the circulation speed Q according to the curve shown in Fig. 6C. This curve was derived from the curves in FIG. In this case, too, the regulation can take place automatically 5 ζ or be effected manually.

If you make sure that the turbine speed is kept within tight limits, you can get one achieve a greater increase in insensitivity, than is possible while keeping the drill weight constant. A process in which for over a large range of varying formation coefficients a relatively narrow turbine speed range, d. H. high insensitivity is illustrated in FIGS. 7 and 8. The ones shown in these figures Pistons 6 of the feed device are only exposed to the pressure drop along the turbine and not about the total pressure drop between the inside and outside of the drill pipe, the equal to the sum of the pressure drop in the turbine and the pressure drop at the drilling fluid outlet openings 10 is.

For this purpose, the cylindrical spaces are below the pistons 6 in the arrangement according to FIG. 7 with the fluid space at the outlet of the door cantilever (not shown) through the component 3 provided channel -15, the lowermost cylindrical space 16 and the extension 18 of the extendable component 4 extending channel 17 connected.

Fig. 8 shows an alternative construction in which the cylindrical spaces below the pistons 6 are directly connected to the fluid space at the outlet of the turbine, namely by means of a line 19 which is arranged in the interior of the extendable component 4 and at its upper end with the openings 20 and at the other end with the turbine outlet (not shown) in communication stands.

Comparing the operation of the ram device according to FIG. 2 with that of the arrangements illustrated in FIGS. 7 and 8, it can be seen that the drill weight W in the former case to a much greater extent than in the latter case due to changes in the pressure drop kQ ² at the Nozzle openings of the drill is affected; this influence was strongest at the highest drilling fluid circulation speed Q ₁ , ie at the lowest turbine speed N ₁ . In the latter case, this means that points 1 and 3 in FIG. 4 both move constantly to the right along the line W ₀ = , while at the same time the distance between these points 1 and 3, which is proportional to the speed range Ν _Ά to N ₁ is reduced in size. It can be seen that this leads to a steeper operating curve W ₀ in FIG. 5 and thus also to greater insensitivity.

Another method to increase the robustness of the system is to reduce the pressure drop at the drilling fluid outlet openings regardless of the speed of circulation in the essential to keep constant. One can do this. achieve by designing the drilling fluid outlet openings so that the smallest desired Sets the jet speed at the lowest expected circulation speed, and by providing a pressure relief valve between the turbine outlet and the drill, which allows some of the fluid to be below the minimum value Circulation speeds through a channel bypassing the drilling fluid outlet openings stream. An alternative arrangement is obtained by installing pressure relief valves in the drilling fluid outlet openings provides.

In general, a steeper operating curve is obtained, e.g. B. the curve W ₀ in Fig. 6, and thus a greater insensitivity of the system if the differential pressure applied to the piston 6 of the tappet device increases at higher turbine speeds to a greater extent than is shown in FIG.

This can be achieved, for example, by using a turbine whose structural design intended speed equals the lowest speed required for drilling formations Is the speed range and at which the pressure drop is above that provided by the design Speed increases rapidly, since the efficiency of the turbine with these decreases at higher speeds.

Similarly, the desired steeper curves in Figures 3 and 6 can be obtained by artificially increases the pressure drop in the turbine at higher speeds by turning the turbine-009 548/76

outlet or the turbine inlet at the relevant Speed throttles. This can be done with the aid of a throttle valve responsive to changes in speed of suitable construction, which can be achieved in the outlet line or in the inlet line the turbine arranges.

Furthermore, the insensitivity of the system can be increased by regulating the differential pressure applied to the pistons 6 by means of a pump which is driven by the turbine according to FIGS. 9A and 9B. In the arrangement according to FIG. 9A, the pump shaft 21 of the pump 22, which is preferably a positive displacement pump, e.g. B. a gear pump, is driven by the turbine, not shown. A small part of the drilling fluid flowing in the direction of arrow 9 through the interior of the inner extendable component 4 is sucked in through the inlet opening 23 of the pump 22 and pumped under increased pressure through the line 24 and the openings 25 to the cylindrical spaces 7 above the pistons 6 . The increase in pressure will then be a function of the turbine speed N, that is, the pressure increase will increase with increasing speed N.

The drill weight / speed curves, ie the curves for W / N at various circulation speeds occurring in the arrangement according to FIG. 9A, are shown in FIG.

A comparison between the fF / iV curves obtained in this way (FIG. 10) with the WIN km in FIG. 4 shows that the curves in FIG. 10 have a considerably steeper course than the curves in Fig. 4, which is due to the additional effect of the increased pressure from the pump, which in turn increases with increasing speed iV. Accordingly, the associated formation coefficient-speed curves (K / N) in FIG. 11 will be considerably steeper than the corresponding curves in FIG. 6.

If, when drilling through a formation, the entire range of formation hardness values K ₁ to K _{1 is} traversed with a constant drill weight W _c , a very steep operating curve W _c (FIG. 11) is obtained, so that when the circulation speed when drilling through harder parts the formation is reduced from Q ₁ to Q ₄ , only a very narrow range of speed changes (iV ₄ to N ₁ ) is swept. This is a very desirable feature from a turbine operation standpoint.

In Fig. 9A small outlet openings 26 and 26 'are indicated, their structural design from Fig. 12 and 13 can be seen. The outlet openings 26 and 26 ', which connect between the cylindrical Establish spaces 7 above the piston 6 and the borehole, a circulation of the allow the pump 22 pumped fluid in such a way that the cylindrical space 7 on the required pressure can be brought.

In the construction according to FIG. 12, a threaded plug 27, which is sealed by a sealing ring 29, is inserted into the wall of the outer component 3. A hexagonal recess 28 is provided on this stopper in order to make it easier to screw the stopper 27 in and out. The outlet opening 26 is provided in the plug 27, and the opening extends through a hard metal nozzle 30 which is provided in order to prevent excessive wear from the drilling fluid flowing through the opening 26. If the nozzle is worn out or if, under certain conditions, a plug with a nozzle 30 ^: of a larger or smaller diameter is to be used, the plug 27 can be exchanged quickly.

13 shows the abutment 8 of the outer component 3 with upper and lower threaded sections 31 and 31 'respectively, and these threads engage corresponding threads in the upper and lower

ίο Parts 3 or 3 'of the outer component 3. The one above and adjacent cylindrical spaces 7 lying below the abutment 8 are on the surface of the inner slide-out component 4 is sealed by a sealing spring 32. The outlet opening 26 'is connected to the cylindrical space 7 below the abutment 8 via the channel 33, and the channel 33 opens into the space 7 from the underside of the abutment 8. The construction of the stopper with the outlet channel 26 'is similar to that of the stopper 27 shown in FIG. 12.

Figure 9B shows an alternative arrangement in which a turbine driven pump is used. In this case, the pump 22 'is designed as a gear pump, and it is connected by an extension of its shaft 21 to the upper end of the shaft, not shown, of the turbine rotor. The delivery side of the pump 22 ′ is connected to the cylindrical spaces 7 above the pistons 6 via the line 24 and the openings 25. The suction side of the pump 22 'is connected to the cylindrical spaces 7 below the pistons 6 via the line 24' and the openings 12 '. Similar to the arrangement according to FIG. 9A, outlet openings are provided which connect the upper sides with the lower sides of the pistons 6. The pressure P _p supplied by the pump thus acts on all pistons 6, this pressure being a function of the turbine speed. At different circulation speeds Q at which the turbine is operated, relationships between W and N and between K and N which are similar to the relationships illustrated in FIGS. 10 and 11 are obtained for this arrangement. The advantage of this arrangement over the arrangement according to FIG. 9A is that a separate servo fluid can be used to actuate the piston 6. In this way, interruptions in the drilling work due to clogging of the outlet openings 26 and 26 'or the openings 25 (FIG. 9 A) are avoided. The piston 6 are sealed against the cylinder walls by sealing means 32 '(FIG. 9B), while the abutments 8 are sealed against the inner, extendable component 4 by the sealing means 32. The upper sealing means 32 'on the extension of the inner extendable component 4 as well as the sealing means 32 lying furthest below deserve special attention, because these sealing means have the task of separating the zones containing the drilling fluid or the servo fluid from one another.

There is another way to limit the range of turbine speeds by using the cylindrical spaces 7 on the opposite sides of one or more pistons 6 of the feed device connects with each other, whereby the piston 6 in question are put out of operation. At the same time it is necessary either the channel between one of the mentioned rooms 7 and the Inside of the inner extendable component 4 or the channel between the other of the above

To close spaces 7 and the outside of the outer component 3 in order to establish a direct connection between the drilling fluid contained in the component 4 and the drilling fluid in the borehole outside the Component 3 impossible to make.

The result of using these arrangements can be seen in FIG. 14, where the drill weight-turbine speed curves, ie the FF / iV curves, are shown for the circulation speeds Q ₃ , Q ₃ 'and Q ₃ ". The circulating quantities Q ₃ , Q ₃ ', and Q ₃ "of the drilling fluid are equal to each other, and the only difference is that the curve Q ₃ represents the relationship between W and N in the event that all the pistons in activity (cf., Q ₃ in Figure 4), while curve Q ₃ 'represents the change in the relationship between W and N for the case that one piston is inoperative and while curve Q ₃ "represents the case that two pistons are inoperative.

15 shows the formation coefficient-speed curves, ie the K / N curves for the circulation * _{speeds Q 3} , Q ₃ 'and Q ₃ ". From FIG. 15 it can be seen that the turbine speed increases from N ₁ N ₂ increases if drilling begins on a formation with a coefficient of K ₁ while two pistons of the ram assembly are inoperative. At point 2 on curve Q ₃ "another piston is activated and drilling is longitudinal the curve Q ₃ 'continued from point 3 to point 4, with only one piston inoperative. At point 4 of the last piston in operation is set and ear thief to work the curve Q ₃ from the point 5 to the point continued to be longitudinally. 6 It can be seen from FIG. 14 that the bit weight W gradually increases when the drilling work is carried out in the manner shown in FIGS. 14 and 15 by the lines connecting points 1 to 6.

However, this course of drilling work can be changed to include within each of steps 1-2, 3-4 and 5-6 enable drilling with constant bit weight by adjusting the circulation speeds Q changes in the manner described with reference to FIGS.

When the advancing device is withdrawn from the borehole, the pistons can be put out of operation by hand. For this purpose, 4 threaded bores 11 and in the wall of the outer component 3 threaded bores 34 'can be provided according to FIG the openings 11 are arranged just above the pistons 6 provided with the sealing means 35. Each opening 34 'is in alignment with a corresponding opening 11 when the plunger device is fully retracted, and the diameter of each opening 34' is larger than that of the opening 11, so that, as shown in FIG. 16 on the left-hand side, can 'through a threaded plug 11' inserted into the corresponding threaded opening 11 from the outside of the component 3 and through the opening 34th As can be seen in FIG. 16 on the left-hand side, the piston 6 is put out of operation in this way, because the opening 34 ′ communicating with the cylindrical space 7 above the piston 6 and that with the cylindrical space below the piston 6 communicating opening 12 connect the two mentioned spaces with the outside of the outer component 3, ie with the borehole.

If the plug 11 'is removed and the plug 34 is inserted into the opening 34', the result in FIG Fig. 16 shown on the right side state. In this case, the cylindrical space 7 is below of the piston 6 is still in communication with the borehole, but the upper cylindrical space 7 is now with the interior of the inner cylindrical component 4 in connection, and that of the turbine and the Differential pressure prevailing at the nozzle openings of the drill is applied to the piston 6 and carries thus contributes to the weight load on the drill.

The threaded plugs 11 'can also be inserted or removed when the feed device is fully extended. For this purpose are in the wall of the outer extendable component 3 several openings, not shown, are provided, the diameter of which is greater than that of the openings 11, and these openings are in alignment with the openings 11 when the plunger device is pushed out. These last-mentioned openings are closed by means of threaded plugs, which can only be removed for inserting or removing the plugs 11 '.

This work for starting and stopping the pistons 6 must be carried out on the surface of the earth will. In general this is not a disadvantage because of the drilling tool and / or the bearings or the blades of the turbine must be checked or replaced at regular intervals be, and at the same time you can adjust the number of effective pistons 6 according to the requirements adjust resulting from the hardness of the formation to be pierced when resuming the Drilling work.

Under certain conditions, such as when drilling through a formation with a yourself rapidly As the formation coefficient changes, however, it may be desirable to automatically adjust the number of effective pistons set while the feed device is at the bottom of the borehole.

Two alternative arrangements that provide such control are described below enable.

The first arrangement includes a system of spring-loaded valves that are within the piston 6 of the plunger device are arranged so that they the number of pistons in operation 6 increase as the differential pressure applied to pistons 6 increases. The second Arrangement, the pistons 6 are set in action by spring-loaded valves, the be actuated by changes in the circulation rate of the drilling fluid.

The first of these arrangements is shown in Fig. 17; in the present case there is only one piston 6 represented by the several pistons of the feed device, and this piston is extendable on the inner one Component 4 is provided and can slide movements between the abutments 8 on the run outer component 3; the abutments 8 delimit the cylindrical space 7 which is formed by the piston 6 into a lower cylindrical space connected to the borehole, d. H. with the outside of the component 3, in Connection stands, as well as divided into an upper cylindrical space, which either with the interior of the Component 4 or is connected to the lower cylindrical space, whichever depends on it, whether the piston 6 is in operation or not.

In the piston 6 there is provided a valve 36 which is responsive to pressure changes and is shown in FIG. 18 in

ί 0Ί84 2Ϊ6

is reproduced on a larger scale. This valve ordered from a cylindrical valve part 37, which in a cylinder 38 slides. Two forces act on the valve part 37, namely the one under pressure

the speed increases from N ₃ to Ν _Λ , this increase in speed corresponding to an increase in the weight of the drill from W ₃ to W _t (FIG. 20). At the point 4, a pressure difference AP ' _{4 is} reached, the

standing spring 39 exerted force and that '5 is greater than the pressure difference AP ₂ , and still

Force resulting from a difference between the pressure of the component 4 that can be pushed out through the inner part flowing drilling fluid and the fluid pressure prevailing in the borehole. if this pressure difference increases, the valve part 37 is pressed down, and the cylindrical Space 7 above the piston 6 is extended through the channels 40, 41 and 42 with the interior of the interior Component 4 connected. At the same time will

remaining piston is put into operation. As a result, the speed according to FIG. 21 drops to N ₅ , the drill weight increases to W ₅ , and there follows a final section of the drilling work along curve Q ₃ (FIG. 20) between points 5 and 6; this changes the hardness coefficient of the formation from

while the turbine speed is from

changes.
The sudden increase in the weight of the drill in the

K ₅ to K ₁ N ₅ to iV _ß

the connection between the cylindrical spaces 7 15 activation of a piston causes a rotation above and below the piston 6, which is due to the decrease in the number of the turbine, whereby the pressure is increased again

the channels 40, 43 and 44 extends through the valve member 37 interrupted, d. that is, the piston 6 is operated by an increase in the pressure difference set.

If you adjust the valves of the different pistons 6 so that they are at different pressure differences, go into action, one can see the operating conditions indicated in FIGS. 20, 21 and 22 by the curves produce.

When the drilling tool passes a soft formation which gradually becomes harder, the formation coefficient K (FIG. 21) goes back from K ₁ to K _G. The circulation speed is kept constant.

is lowered so that the valve 36 in question shows the tendency to return to its original position and restart the piston; this means that the control of the system oscillates. One Possibility to prevent this is that one according to Fig. 18 and 19 a or 19 b a locking or Triggering device 45 provides, after the valve part 37 has been pressed down into the lower position this valve part holds in the lower position until the pressure difference to a predetermined The value falls below that at which the valve 36 is actuated.

Further arrangements through which piston valves

The valves 36, only one of which is shown in FIG are now set on the surface of the earth in such a way that they are at those pressure differences in

ten, that is, Q ₃ = Q ₃ = Q ₃ ". The curve Q ₃ represents the 30 actuated when the feeder represents the relationship between K and N for the case that is within the borehole, are in FIG. 23 and all Pistons are in operation (see. Q ₃ in Fig. 6), 24 shown, and Figs. 25 and 26 show the curves, while curve Q ₃ applies to the case that a KoI- for the operation of systems in which this ben is out of order, and while the curve Q ₃ " arrangements are provided. This applies when two pistons are put out of operation 35 piston valves have become due to changes in the circulation. speed controlled in such a way that the piston valve,

which is set to a predetermined value of the circulation speed when the circulation speed under these predetermined

Activity, which decreases at the expected flow value, takes place in order to result in the speed Q _{3 assigned} to it. Let the assumed piston be put into operation,
that the drilling work can be carried out under conditions. In the arrangement according to FIG.

which correspond to point 1 on the curve turikanal 46 between two channels 47 and 48, which correspond to Q ₃ ″ in FIG K _1. The forma- 45 connection is a pressure difference. The tion is gradually harder, and between the point valve part 49 is drawn in that position at th 1 and 2 on the curve Q ₃ " (two pistons apart from the Piston 6 would be put out of operation if operation) the turbine speed increases gradually namely as a result of the channels 50, 51 and 52 from N ₁ to N ₂ . From Fig. 20 it can be seen that the connection produced on the top of the drill weight at the circulation speed 50 piston 6 acting is the same as the speed Q ₃ " over the speed range N ₁ to N ₂ of W _{1 on} the underside If the circulation increases to W ₂ and the pressure speed is reduced at the same time, the drop AP along the turbine and the drilling fluid decreases, the pressure difference between the channels 47 outlet openings increases from 4P ₁ to AP ₂ (see Fig 22 and 48, and the valve part 49 rises to the and cf. this diagram with the diagram in 55 connection between the channel 42 and the channel Fig. 3. At the pressure AP ₂ , the valve 36 of a 50 is closed interrupt and actuates the channel 52 via a further two pistons 6 not in operation, upper channel 53 with the upper side of the valve part 49, so that the piston 6 assigned to this advantage can be connected, whereby a Connection between which is put into action. This one valve 36 is set at the top of the tappet piston 6 and the interior of the valve in such a way that it is produced in 60 inner, extendable component 4 when there is a pressure difference AP _2.
Activity occurs. From FIG. 21 it can be seen that FIG. 24 shows a similar arrangement with a

Drilling work then continued along curve Q ₃ , improved mechanism for actuating the valves which control the relationship between K and N for ben 6. The main valve 54 represents the same circulation speed, whereby an auxiliary valve 55 is controlled, which in turn is out of operation with only one piston. At the start 65 through the starting point 3 of this curve applied to a flexible membrane 56, the turbine runs with a pressure differential. This pressure differential speed N ₃ , which is considerably lower than the rotational speed, is a function of the speed of the number N ₂ . Between points 3 and 4 on the mud circulation curve through the inner extensible Q ₃ , the formation becomes even harder, with component 4. FIG. 24 shows this arrangement with a hardness coefficient from K ₃ to K _i during 70 state at to which the valve 54 is in a position

t8

takes in which the piston 6 is in action. When the circulation speed exceeds a predetermined Value increases, the pressure differential increases and the auxiliary valve 55 moves downwards, the channel 57 being connected to the top of the valve 54 via the channel 59. That Valve 54 then moves down and connects the space 7 at the top of the piston 6 with the Space 7 at the bottom of the piston 6 via the channels 58 and 60. At the same time, the connection between the interior of the inner extendable component 4 and the space 7 at the top of the piston 6 established by channels 57 and 58, and the piston thus becomes put out of service. A transfer channel 61 of small diameter extends through the valve 54, to facilitate upward movement of the valve.

The drill weight / speed or QV / N) curves and formation coefficient / speed or (K / N) curves shown in FIGS. 25 and 26 show the chronological sequence of the operations at the beginning of the drilling work in a hard formation with the Formation coefficient K ₁ and the further course when drilling through a formation which gradually becomes softer until the formation coefficient K _{6 is} reached. In Fig. 26 the course of three groups of circulation curves is shown.

In Fig. 26, the _{group delimited by curves Q 3} and Q ₆ , in which Q _{3 is} less than Q ₆ , represents the relationship between K and N for the various values of the circulation velocity which lie _{between Q 3} and Q _6, when all pistons are in operation (see. Fig. 6). The group delimited by the curves Q ₆ 'and Qa , in which Q ₆ ' is equal to Q ₆ but smaller than Qa , shows the relationship between K and N for the various values of the circulation speed that between Q ₆ 'and Q ₀ 'lie when a piston of the feed device is out of order. Finally, the group delimited by curves Q _a " and Q ₁ ", where Q ₀ "is equal to Q / but less than Q ₁ ", represents the relationship between K and N for the various values of the circulation speed which lie between Q _a " and Q ₁ 'when two pistons are out of service.

If one begins with the conditions given by point 1, with a formation with hardness K ₁ , the drill master must regulate the circulation speed from Q ₃ to Q ₆ according to the drill weight W in such a way that the drilling work according to FIG of the curve connecting points 1 and 2, while the formation coefficient gradually increases from K ₁ to K ₂ . When the circulation rate _{has risen to the value Q 6} , the valve, which is set so that it responds at this value, is actuated, and the piston associated with this valve is put out of operation. From Fig. 26 it can be seen that the speed of the turbine, which _{had been reduced from 2V 1} to A ^r ₂ , now increases to / V ₃ . In the hardness range of the formation lying between K ₃ and K ₁ , the drill foreman follows the curve connecting points 3 and 4 in FIG. 25 by adjusting the circulation speed accordingly. At point 4, the circulation _{speed has risen to Q 0} ', with the result that a further valve comes into operation and puts a further piston 6 of the tappet device out of operation. As a result, the turbine speed N _{1 increases} to TV ₅ (FIG. 26), and the drill weight is reduced from W 1 to W _5. Proceed in the same way along the curve connecting points 5 and 6. In contrast to the first arrangement described with reference to FIGS. 17 to 22, in which the pistons 6 are controlled by valves responding to changes in pressure and in which the circulation speed is kept constant over the entire range of the formation coefficients (FIGS. 20, 21 and 22), the arrangement described last requires a continuous readjustment of the circulation speed according to the measured drill weight. This setting can either be done manually or automatically. Further arrangements for putting the pistons 6 out of operation are illustrated in FIGS. 27, 28 and 29. In these arrangements, a piston 6 is put out of operation in that two adjacent cylindrical spaces 7, one of which is below and the other above the abutment separating the two adjacent cylinders, are connected to one another.

As an example, Fig. 27 shows an arrangement in which this connection is made by hand by the drill master when the ram device is withdrawn from the borehole. For this purpose, the abutment 8, which divides the space between the pistons 6 and 6 'into an upper cylindrical space 62 and a lower cylindrical space 63, is provided with a radial bore 64 into which threads are cut over the entire length of the bore . The bore 64 is connected to the cylindrical space 62 by a channel 65 and to the cylindrical space 63 by a channel 66. The outer end of the bore 64 opens on the outside of the outer extendable component 3, ie in the borehole. A threaded plug 67 is screwed into the outer end of the bore 64 and has a recess 68 to facilitate the screwing in and adjustment of the plug. When the plug 67 is in the position shown in FIG. 27, the spaces 62 and 63 are connected to one another by the channels 65 'and 66 and the bore 64. Since the space 63 is under the same pressure as the space above the piston 6, this piston is put out of operation by this connection. If the plug 67 is screwed further into the bore 64 until it assumes the position at 67 'indicated by dashed lines in FIG. 27, the connection between the spaces 62 and 63 is interrupted, while the space 62 is connected to the borehole at the same time , whereby the piston 6 is put into operation again. It can be seen that these processes could also be brought about with the aid of a three-way valve which is inserted into the abutment 8.

FIG. 28 shows an arrangement similar to that described with reference to FIGS. 17 to 22, for pressure differences responsive tax system.

The abutment 8 lying between the cylindrical spaces 62 and 63 has a cylindrical bore 69 in which a cylindrical valve piston 70 is slidably movable. The space 63 is with the bore 69 connected by the channels 71 and 72, while the space 62 via the channels 73 and 74 with the bore 69 is in communication. The valve part 70 has a radial channel 75, which when the valve part 70 assumes one of its end positions, which connects channels 73 and 72 to one another, as shown in FIG. 28 is shown. When the valve part 70 assumes the opposite end position, the channel 74 is through

009 548/76

a further bore 76 of the valve part 70 with the bore 69 and thus also via the opening 77 in FIG the plug 78 with the outside of the outer extendable Component 3, d. H. connected to the borehole.

In the position of the valve part 70 shown in FIG. 28, the spaces 62 and 63 are connected to one another, so that the piston 6 is inoperative, the pressure difference between the interior of the inner slide-out component 4 and the exterior of the outer slide-out component 3, d. H. the one on the piston 6 and 6 'acting pressure difference is below the value at which the valve 70 in Activity occurs, i.e. below the value at which the valve part 70 counteracts the force of the valve spring is pressed to the right.

When the pressure difference increases, as occurs with different progress of the drilling work may be the case, the valve member 70 moves to the right, so that the connection between the rooms 62 and 63 is interrupted, and the space 62 is through the channel 74, the channel 76, the bore 69 and opening 77 in plug 78 communicates with the wellbore. In this way, the piston 6 put into operation again.

Fig. 29 shows an arrangement similar to that described with reference to Figs. 23 to 26, upon changes in the Circulation responsive control device resembles.

The abutment 8, which separates the two cylindrical spaces 62 and 63 from each other, is with a Equipped cylinder 82, in which the valve part 79 is responsive to differences in the flow rate Valve is slidable; this valve is operated by the pressure difference which between the openings 11 and 80 is generated by the flow passing through a venturi part 81. Of the Space 62 is connected to cylinder 82 through channel 83, while space 63 is connected to the cylinder 82 is connected by channels 84 and 85. Furthermore, the cylinder 82 is with the upper end of the cylindrical Space 63 'through the channel 86 and with the outside of the extendable component 3 through the Channel 87 connected. The valve part 79 has a radial channel 88 which, when the valve part 79 is a occupies its end positions, the channels 83 and 84 connects with each other, and further is on the outside of the valve part a recess 89 is provided which connects the channels 83 and 87 to one another when the Valve part 79 assumes the opposite end position.

In the position shown in FIG. 29, the flow in the direction of arrow 9 through the interior of the inner retractable component 4 reaches such a value that the between the openings 11 and 80 prevailing pressure difference, which also acts on the ends of the valve part 79, the valve part counteracts the force of the valve spring 90 has moved into the right end position; the valve spring 90 lies between the Valve part 79 and the plug 91 closing the cylinder 82. The spaces 62 and 63 are now through Channels 83 and 84 and channel 88 connected to one another, so that the piston 6 is out of operation. When the flow decreases, the pressure differential decreases and the valve member 79 becomes through the spring 90 moves to the left. The connection between rooms 62 and 63 is now interrupted, and at the same time the space 62 is through the channel 83, the recess 89 and the channel 87 with connected to the borehole.

From the channel 86 a channel 86 'can branch off, which is connected to the cylinder of a control system - which is provided in an abutment 8, at the upper end of which the space 62 'adjoins.

The arrangements illustrated in FIGS. 28 and 29 offer compared to the arrangements according to FIG. 23 and 24 have the advantage that you can adjust the control valves that must be made when the ram device is pulled out of the borehole, can perform without the extendable components 3 and 4 to dismantle, because with the arrangements

ίο according to Fig. 28 and 29 are the valves from the outside of the outer component 3 accessible from.

Correspondingly, in the arrangement according to FIG. 27, the number of pistons in operation can be determined It is easier to regulate by hand than is the case when using the construction according to FIG. 16.

Normally this is possible with the feed devices according to FIGS. 16, 17, 23, 24, 27, 28 and 29 be to put all but one pistons out of service. When piercing a soft formation in this case the smallest possible drill weight is obtained.

When drilling through a very soft formation, the minimum bit weight required becomes very small be. In order to meet this requirement, a larger number of smaller pistons 6 could be used provide. However, this makes the length of the feed device undesirably large.

It has been shown that another possibility for reducing of W _m i _n without changing the length of the feeding device is that it does not change the number of the pistons, however, ensures that the one piston 6 which is not taken out of operation , has a much smaller area than the other pistons.

It should be noted that there are several of those shown in FIGS. 7, 8, 9A, 9B, 16, 17 to 19, 23, 24, 27, 28 and 29 Combine individually described features in a single system.

Claims (28)

PATENT CLAIMS: 1. Feed and drilling pressure control device for hydraulic drilling motors, e.g. B. drilling turbines that in the deep borehole on the drill rod used to feed the drilling fluid to the drive a drilling tool are suspended and wherein the hydraulic motor and consequently the drilling tool are driven by the drilling fluid, characterized in that between the Drilling tool and the drill pipe except for the hydraulic motor (14) one of two hollow, against each other displaceable, thereby non-rotatably guided, formed as a stamp or cylinder parts (3, 4) existing linkage section is installed, one part of which has at least one piston (6) having, which is formed with a cylinder formed between abutments (8) on the other part (3) (7) cooperates and divides this into two rooms (7; 62, 63), one of which with a high pressure room, the other with a low pressure room connected is. 2. Device according to claim 1, characterized in that the on the upper side of each Piston (6) cylinder space with the inlet side of the turbine (14) through openings (11) is in connection (Fig. 2). 3. Device according to claim 1, characterized in that on the upper side of each Piston (6) lying cylinder space is connected to the outlet (24) of a pump (22), ί084216 which is driven by the turbine (14) (FIGS. 9 A and 9B). 4. Device according to claim 3, characterized in that the inlet end (23) of the pump (22) communicates with the inlet end of the turbine (14) (Fig. 9A). 5. Device according to claim 1 to 3, characterized in that on the lower side each piston (6) lying cylinder space with the borehole through openings (12) in connection stands (Fig. 2). 6. Device according to claim 1 to 3, characterized in that on the lower side each piston (6) lying cylinder space is in communication with the outlet end of the turbine (Figures 7 and 8). 7. Device according to claim 1, characterized in that the on the upper side of each Piston (6) lying cylinder space via lines (24) with the outlet end of a pump (22 ') in Connection is, which is driven by the turbine (14), and that on the lower side each piston (6) lying cylinder space via other lines (24 ') with the inlet end of the Pump (22 ') is in communication (Fig. 9B). 8. Device according to claim 7, characterized in that the cylindrical Spaces (7) and the pump (22 ') fulfilling medium differs from the drilling fluid. 9. Device according to claim 1, characterized in that the turbine (14) has a constructive has intended speed which is equal to the desired minimum operating speed, and that the turbine is designed such that a rapidly increasing pressure drop occurs when the turbine is operated at speeds that exceed the design speed. 10. Device according to claim 1, 2, 5 or 6, characterized in that in the turbine inlet line or in the turbine outlet line a throttle valve responsive to changes in speed is built in. 11. Device according to claim 1, 2, 5 undo, characterized in that control valves are provided to control the pressure drop at the drilling fluid outlet openings of the drilling tool at different circulation speeds of the drilling fluid is essentially constant keep. 12. Device according to claim 1, in which the extendable and retractable components (3 and 4) comprise a plurality of assemblies formed from cylinders (7) and pistons (6), characterized in that that feed elements are provided to one or more of the pistons (6) except Operation (Fig. 16, 17, 23, 24, 27 to 29). 13. Device according to claim 12, characterized in that that the openings (11) are provided with stoppers (H ') and that openings in the wall of the outer extendable component (3) (34 ') are provided which can be connected to the space under low pressure and accommodating the plugs (34), the latter openings (34 ') being larger than the first named openings (11) and wherein the openings (34 ') are coaxial with the openings (11) when the extendable components (3 and 4) are fully retracted (Fig. 16). 14. Device according to claim 12, characterized in that in the two adjacent cylinders (7) separating abutment (8) a substantially radial bore (64) is provided is that with the upper cylinder, the lower cylinder and the outside of the outer Extendable component (3) is in connection, with a plug (67) provided in this bore (64) which, in their various positions, allow either the connection between the two cylinders. (7) (over 64, 65 and 66) to close or make the connection between the To close the outside of the outer extendable component (3) and the bore (64 in FIG. 27). 15. The method for operating a deep drilling system according to claim 1 to 14, characterized in that that the rate of circulation of drilling fluid through the drill pipe is varied according to the drill weight measured in the vicinity of the drilling tool. 16. The method for operating a deep drilling system according to claim 1 to 14, characterized in that that the rate of circulation of drilling fluid through the drill pipe is varied according to the speed of the drilling tool. 17. The method for operating a deep drilling system according to claim 1 to 14, characterized in that that the rate of circulation of drilling fluid through the drill pipe is varied according to the torque measured in the vicinity of the drilling tool. 18. The method for operating a deep drilling system according to claim 12, in which the selected and insertable components, a plurality of assemblies formed from cylinders and pistons comprise, characterized in that adjacent cylindrical spaces each at a predetermined Control pressure differential are short-circuited separately. 19. The method for operating a deep drilling system according to claim 18, characterized in that that the along the hydraulic turbine and the drilling fluid outlet openings of the drilling tool existing total pressure drop is used as the control pressure differential. 20. The method for operating a deep drilling system according to claim 18, characterized in that that the pressure drop across the hydraulic turbine is used as a control pressure difference. 21. The method for operating a deep drilling system according to claim 12, in which the selected and insertable components comprise a plurality of assemblies formed from cylinders and pistons, characterized in that the drilling fluid circulation is varied and that adjacent cylindrical spaces at a predetermined Circulation speed of the drilling fluid can be short-circuited separately. 22. Device for operation according to the method according to claim 18, characterized in that that one or more of the pistons (6) are provided with a valve (36), which by the mentioned Pressure difference is actuated and the piston (6) short-circuits in its one end position (via 40, 43, 38 and 44), while in its other end position it is one of the piston (6) adjacent cylindrical spaces with the interior of the inner extendable component (4) (via the Parts 40, 41, 38 and 42) connects (Figs. 17 to 19). 23. Device for operation according to the method according to claim 18, characterized in that I 084 that one or more of the existing between adjacent cylindrical spaces (62 and 63) Abutments are provided with a valve (70) which is actuated by the aforementioned pressure difference is and that in its one end position the cylindrical Spaces (62 and 63) connects together (via 72, 75 and 73) while it is in its other End position one of the adjacent cylindrical spaces (62) with the outside of the outer extendable component (3) (via the parts 74, 76 and 77) connects (Fig. 28). 24. Device according to claim 22 or 23, characterized in that the valves (36) with a trap part (45) are equipped (Fig. 19). Device for operation according to the method according to claim 1, characterized in that that one or more pistons (6) are equipped with a valve (49) which in its one end position the piston (6) short-circuits (via parts 50, 51 and 52) while it is in its other End position the cylindrical space on one side of the piston (6) with the interior of the inner Extendable component (4) connects (via the parts 48, 53 and 52), the actuation of the Valve (49) from one side by the pressure of the inner extendable component (4) drilling fluid flowing through takes place while the valve is actuated from the other side by a spring as well as by the pressure of the drilling fluid, which is carried out by a in the channel the constriction (46) provided for the inner extendable component flows (FIG. 23). 26. Device for operation according to the method according to claim 21, characterized in that that one or more of the pistons (6) are equipped with a valve (54) in its one End position the piston (6) short-circuits (via 58 and 60) while it is in its other end position the cylindrical space on one side of the piston (6) with the interior of the inner extendable Component (4) connects (via 57 and 58), one side of the valve with its on the other side via a constricted channel (61) in connection, the valve of on the one hand by a spring and by the turbine outlet pressure or the borehole pressure is operated while the valve is operated from the other side by the pressure of the drilling fluid is actuated, which flows through the inner extendable component (4), namely depending on the position of a servo valve (55), its actuation by the pressure difference between the pressure of the drilling fluid flowing through the inner extendable component (4) and the pressure of the one provided in the channel of the inner extendable component (4) Constriction of flowing drilling fluid takes place (Fig. 24). 27. Device for operation according to claim 21, characterized in that one or several of the adjacent cylinders separating abutments (8) with a valve (79) which are actuated by a pressure difference created by the flow in the inner extendable component (4) is generated when this flow creates a constriction (81) in the channel of the inner extendable component (4) happens, the valve (79) in its one End position the cylindrical spaces (62 and 63) above and below the abutment (8) with one another connects (via 83, 88 and 84), while in its other end position it is one of the cylindrical Spaces with the borehole (via the parts 83, 89 and 87) connects (Fig. 29). 28. Device according to one or more of claims 12 to 14 and 22 to 27, characterized in that that at least one of the pistons (6) differs in size from that of the other pistons has distinguishing area. Considered publications:
U.S. Patent No. 2,684,835. In addition 4 sheets of drawings © 009 548/76 6.60