NO20130951A1 - Systems for optimized, intelligent and autonomous drilling operations - Google Patents

Abstract

This invention relates to systems, methods and products for time and cost-effective drilling operations. It combines or redefines processes, provides better downhole information, improves total system communication, adds autonomy and intelligence to components. The systems may include, but are not limited to; at least one continuous drill string element (1), in an interconnection of drill string elements, has a modulus of elasticity (Young's Module) less than 150 GPa and tensile strength greater than 0.60 Gpa and does not transmit an active torque, at least one algorithm and acoustic data from at least one acoustic sensor (13), wherein at least one sensor (13) provides acoustic data, but not limited to, from at least one drilling device (9) at any time of approximately real-time movement and transmitting acoustic data to at least one data processing unit (CPU) (12) for material and pressure identification in all planes and directions in relation to the drilling device, provide variable and optimal torque from at least one drilling motor (11), relative to the surrounding material, to controllable drilling device (9) for approximately real time via controllable shaft (10) . The CPU (12) can, based on at least one algorithm and recorded acoustic data, make the drilling process autonomous by adding drilling device (9) via (10), a directional vector independent of a priori or predefined curvature to at least one drilling device (9). The system will be able to detect pressure increases in the future, ie in all planes in extension of the velocity vector (14b) of the drilling device and thus represent a dynamic "Blow Out Preventer". Autonomy algorithm, which overrides predefined drilling profile, will normally be enabled when at least one sensor (13) provides acoustic data interpreted by at least one CPU (12) to indicate a type of matter in plane other than present in the drilling device at all times pre - programmed motion direction. At least one algorithm can be a software product.

Description

This invention relates to systems, methods and products for time- and cost-effective drilling operations. It combines or makes processes redundant, provides better downhole information, improves total system communication, adds autonomy and intelligence to components, and can ultimately transform entire drilling processes from being incremental to becoming continuous.

Background

Standard (vertical) drilling was carried out with, but is not limited to, derrick, hoist, rotary table, power supply, pumps, rotary housing ("kelly") and supply lines for drilling fluid ("mud"), rigid drill strings consisting of pipes that are continuously threaded together and drill bit. The drilling fluid removes and carries cuttings from the bottom of the borehole up to the surface, lubricates and cools the entire drilling process, as well as balancing the hydraulic pressure in the well by varying the density of the drilling fluid. Casing can be placed in the borehole, preferably with cement ("slurry") between the bore wall and the casing.

In modern (horizontal) drilling, in addition to the above, you can also use combinations of: - Manipulation with rotary bottomhole assemblies ("rotary bottomhole assembly" - BHA) with different types and positions of stabilizers near the drill bit.

- Angle devices ("whipsticks").

- Steering systems ("rotary steerable systems" - RSS) which can use dynamic claws ("pads"), and create lateral forces, which in turn can steer the drill bit. - Downhole drilling fluid motor ("mud motor") driven by the pressure energy from the drilling fluid with steerable shafting, which in turn can provide local torque and direction to the drill bit ("point - the bit" - RSS).

- Surface-adjustable bent housing ("surface-adjustable bent housing").

- Local control systems that indicate the coordinates of the drill bit (angle and azimuth), or more generally logging ("Logging While Drilling" - LWD). - Gamma-ray logging to possibly track sedimentary deposits, or more generally sensor packages that measure data (pressure, temperature, etc.) ("Measurement While Drilling" - MWD). - MWD and LWD can be transmitted to the surface in real time via pulsed telemetric communication via the drilling fluid (or via cabling, see "Known Techniques").

For more information on the state of the art, see, for example, Falczak E. et al. "The Best of Both Worlds - A Hybrid Rotary Steerable System", Oilfield Review, Winter 2011/2012, www.slb.com (Schlumberger).

Drilling as practiced is a time consuming and less productive process by nature in that it;

- Is incremental - rigid drill string elements are joined (threaded together) topside.

- Continuous switching between productivity and replacement of downhole tool packs.

- Drilling fluid motors have limited operating time until overhaul (100 - 125 hours) and capacity (100 - 200 kW).

- Telemetric communication via the drilling fluid is unreliable and has low capacity.

- MWD/LWD provides inadequate information in real time to optimize (minimize) drilling lengths. - Use of a. "whipsticks" and surface-controlled angling joints are all examples that adequate total flexibility is not present in modern drilling operations, taking into account cost and time-saving objectives.

Osmundsen, P. et al. "Exploration drilling productivity at the Norwegian shelf", Journal of Petroleum Science and Engineering, Vol. 73,1-2, 2010, concludes that productivity in terms of drilling in the North Sea has fallen to 67 meters per day (2008) in relation to to 144 meters per day in 2004, while the daily rates have increased by a factor of 2.6 in the period. The cost increase has its background in combinations of more demanding drilling programs and general market conditions. However, it is required to be able to produce more time- and cost-effective drilling systems and operations. This can be done by combining or making redundant processes, providing better downhole information, improving overall system communication, adding autonomy and intelligence to components, and transforming the entire process from being incremental to being continuous.

The industry is very conservative, which means that the development towards a fully integrated new approach, as discussed in this document, will probably have to be gradual.

Known techniques

WO 2005107396 (PCT/US2005/014940) addresses some of the subject by describing a flexible drill string characterized by articulated steel profiles, for placement between a drill bit and a tool joint ("tool joint"). The arrangement must necessarily be able to transmit a torque.

Telemetric transmission of data is unreliable and the amount of data is very limited (approx. 10 bits/second). A solution to the problem is described in MX2011010256 (WO2010115492), which also provides references to similar prior art. The document describes a drilling element (pipe) including at least one optical or electrical line for transmission of MWD/LWD data in real time. Haliburton describes, for example, a tube element with phased-in coaxial cable for the transmission of MWD/LWD data. (http://www.nov.com/WorkArea/linkit.aspx?

LinkIdentifier=id&ItemID=12557)

The use of electric cable for the propulsion of downhole electric power systems is not new in isolation. Chen, A. et al. al "Review of electrical Machine in Downhole Applications and the Advantages", 13 th International Power Electronics and Motion Control Conference (EPE-PEMC) 2008, indicates a relevant compilation of the possibilities in the area.

Halliburton Energy Services Inc describes (WO 2012128765) a fastening device for an ultrasound apparatus via an O-ring. The purpose is to use the transducer as a sensor in MWD/LWD mode.

US20120280492 discloses a composite-to-metal coupling or pipe for transmitting torque ("composite torque pipe").

The components, sub- and total systems described here border on some of the above terms and devices, but they are then integrated in a new and innovative context which, among other things, contains optimization and intelligence.

The invention

All components described in "Introduction" and in "Known techniques" can be included as elements in the present invention's systems, methods, products and apparatus.

A standard drill string element used in the oil & gas context has an internal diameter of 4.125 inches (10.47 cm), length of 31.6 feet (9.65 m). Outer diameter varying from 5.0 to 5.6 inches, with smallest diameter closest to drill point. The steel quality used is usually S-140 or AISI 1045 quality. For casing ("casing"), an outer diameter varying from 20 to 4.5 inches (508 mm -114.3 mm) with a steel quality of possibly H-40, J55, K-55, N-80, C is used -75, L-80, C-90, T-95 or Q-125.

All solid (rigid) structures or pipe arrangements possess some form of flexibility as long as the total loin is sufficient. In order to increase the flexibility and precision of the drilling operation itself in general, and cost-effective and time-saving horizontal drilling activities in particular, minimization of the distance traveled until the desired location becomes central, alongside the reduction or elimination of the use of directional manipulation tools. The primary means of action here is the use of at least one continuous semi-flexible drill string element. The ultimate solutions include systems, methods or products where a total semi-flexible drill string is used, joined by several semi-flexible drill string elements in an approximately topside horizontal joining mode. Here, the drill string elements could be forced to an active bending moment if the drill string is to be used in an approximately vertical mode. A practical transition (top side) could be the use of two-x-two rollers where there will be a bending radius between them.

Increased flexibility is defined as a lower modulus of elasticity, E, (Young's Modulus) in the drill string element, which in turn affects the bending radius of the drill string. This can be defined as;

Where

R = bending radius

E = Modulus of elasticity (Young's Modulus)

dz = outer radius of pipe (drilling element)

x = permissible bending elongation ("strain") [Pa]

(Source http://actamont.tuke.sk/pdf/2004/n3/48wisniowskiziaja.pdf)

As can be seen from (a), the bending radius is directly proportional to the modulus of elasticity, E, (Young's Modulus).

With a lower E - value, the bending radius is reduced.

At the same time, it is important to preserve the tensile strength of the drill string.

The relationship between tensile strength and modulus of elasticity (Young's Modulus), within yield limits, is defined by Hooke's Law;

Where

a = tensile strength

E = Modulus of elasticity

e = Strain (relative elongation - Al/l)

Table 1

Relationship between Young's Modulus (E) and tensile strength for some metals and composites.

Source: http://www.engineeringtoolbox.com/engineering-materials-properties-d_1225.html

Acid-resistant AISI302 steel has an E-value of 180, while structural steel ASTM-A36 has a corresponding value of 200. As can be seen from table 1, AISI 1045 steel has an E-value of 205 GPa and tensile strength a = 0.585 GPa. Corresponding values are 142 GPa and 63.6 GPa (E-values) and 1.71 GPa and 1.1 GPa (tensile strengths) for carbon epoxy and kevlar epoxy respectively. At the same time, the density (weight) is only a fraction of that of corresponding steel grades.

One or more continuous drill string elements can be composed of materials that form combinations of concrete, metals, synthetic materials such as composite materials, fiberglass and the like where Young's Modulus (E) and tensile strength are respectively below 150 GPa and above 0 .60 GPa. Continuous means that at least one drill string element is not jointed. Preferred values are Young's Modulus below 50 GPa and tensile strength above 0.80 GPa. The cost-optimal solution will probably be to use drill string elements with a higher E-value in the possibly vertical part of a drill string and drilling operations, and lower values when deviation drilling takes place. The torque of the drilling device is supplied locally.

The optimal systems, methods and products will be represented by at least one continuous semi-flexible drill string with variable Young's Modulus down to below 50 GPa and tensile strength above 0.80 GPa without torque, with an approximately horizontal (topside) interconnection of drill string elements (with bending moment), which enables torque-free continuous operation.

The term "active torque" is defined to include all drilling operations where one or more drill strings are supplied with a (or several or a variable) torque for the purpose of supplying a drilling device with rotational energy. Normally, such a torque would be applied to the top side via a rotary table. Accordingly, a system that "does not transmit an active torque" is synonymous with a system that includes at least one (downhole) drilling motor. Nevertheless, a system that "does not transmit an active torque" may result in a static or variable torque being temporarily applied to at least one drill string element, but then in a joining context, especially if this or these joinings include threads (female/male) and a screw - connection, or as a result of friction between drill string and surrounding material in the borehole. The intention is therefore that torque to the drilling device should only originate from at least one downhole drilling motor.

Based on table 1, when using, for example, materials with E-values < 100 GPa, a > lGPa and p < 2 (10<3>kg/m<3>), this opens up significantly greater operational flexibility.

For further time and cost optimization, at least one connection of drill string elements (a) can have associated at least one other connection of drill string elements (P) where at least one connection (a) can be released from at least one connection (P) and through which at least one connection (a) can is passed through at least one interconnection (P) and at least one interconnection (P) is made independently of the system for active drilling (a). The term "active drilling" means the interconnection that supplies at least one of drilling fluid, electrical current, fluid, electronic data communication to downhole devices.

In practice, this way it will be possible to drill and place casing in one and the same operation. This will require the use of, for example, a drilling unit with a variable diameter. An example of this is the "dual diameter bit" - the drill bit of Smith Bits (a Schlumberger company), ref http://www.slb.com/services/drilling/drill_bits/quad_d_bit.aspx.

Such a solution would, however, require an attachment and release device for the outer pipe arrangement against, for example, a drill motor module. Figure 1 indicates a principle sketch for a solution to such an attachment and release mechanism. (1) represents the at least one continuous (semi-flexible) drill string element or (a), (2) represents outer drill string, casing or (P). (3) represents (for example) at least one drilling motor module (or similar), (4) is a dynamic claw ("pad"), a form of mirrored RSS, which locks and provides a soft curvature towards the drilling module from the outer pipe arrangement. The attachment mechanism itself can be electromechanical or electrohydraulic. The claw (4) folds down into (3) after releasing (2).

The preferred solution is one or more downhole electric AC or DC drilling motors with steerable shafting with local torque and direction control for the drilling device, with electric power from the top side and associated electronic data communication via at least one power cable.

Figure 2 indicates a continuous drill string element (1) which can include at least one cable (5) for the transmission of electric current and electronic communication/data signals of both analogue and digital nature. It can also contain a service channel (6) for transferring fluid. This can be liquid and/or a gas to increase or decrease the density of the drilling fluid, or supply drilling fluid under pressure to reverse the direction of movement of the drilling device, or meet a sensor - detected pressure increase (ref. mode as "Blow Out Preventer"). It can also transfer cement ("slurry"). Two or more (continuous) drill string elements can be joined using one or more guide shoes (7) and connector - couplings (5a), (6a), where at least one cable (5) and/or at least one service channel (7) are joined. An outer locking screw (8) can lock and secure the connection. A (continuous) drill rod element (1) can be connected to one or more sensors (not shown) via at least one current-carrying cable (5). These sensors can be combinations of analog and digital electromechanical, acoustic (ultrasound), pressure, temperature sensors and the like. These sensors can send electronic data via at least one current-carrying cable (5) to at least one CPU, located topside or downhole.

A (continuous) drill string device (1) can also be connected to a standard steel drill string element where the connection mechanism will be a threaded connection. In this application mode, it will, but not necessarily, be natural that at least one of at least one electrically conducting cable (5) or at least one service channel (6) is not present. This can be in application areas where one or more downhole drilling fluid motors drive a drilling arrangement.

Figure 3 indicates a principle sketch for an acoustic detection and control system. (9) represents a drilling device. This can be of a solid design for percussion application (percussion drill) or a drill bit with a fixed or variable ("dual") diameter. (10) is a steerable shaft, (11) electric or drilling fluid-driven drilling motor [(3) refers to, for example, an entire drilling module with associated devices], (1) drill string (element), (12) represents at least one data processing unit (CPU) containing at least one algorithm that can provide control signals to (11). (12) can be located topside with signal transmission telemetrically via the drilling fluid or electronically via cable. The preferred solution is a local and close location to at least one drilling arrangement (11). Acoustic detection of material in all planes and directions in relation to the drilling unit can be performed by one or more single-element probes or transducers (sensors)

(13). The preferred solution, however, is the use of one or more "Phased Array" (PA) transducers that can electronically scan volumes of matter. Visually, i.e. display to operator in control room, graphical interface based on linear and non-linear analysis can be depicted as combinations of A-Scan (time - amplitude of an ultrasound signal), B-Scan (shows the depth of reflections in relation to linear position), C-Scan (two-dimensional data presentation on top of a plane section), S-Scan (two-dimensional cross-section developed from A-Scan with time delay). See for example Moser, M. Engineering Acoustics, Springer, 2009, Ersoy, O.K. Diffraction, Fourier Optics and Imaging, John Wiley & Sons, Inc, 2007, Shariyat, M. et al Nonlinear thermoelasticity, vibration, and stress wave propagation analyzes of thick FGM cylinders with temperature-dependent material properties, European Journal of Mechanics and Solids, Vol. 29 (3), 2010 for linear and non-linear acoustic analysis, signal processing and imaging. (14a) indicates the scan sector in the x - y plane in the direction of movement of the drilling device, and (15) indicates the scan sector in the x - z plane, variable up to 90 degrees on the x - y plane. However, there are no restrictions on the number of scan profiles and planes and angles between these, which the at least one acoustic sensor can provide.

Table 2 indicates the speeds of P and S waves as well as the density of some materials and compositions of substances. P waves are pressure waves that propagate in the longitudinal direction in matter. S waves are shear waves that are transverse in nature.

Table 2

Some acoustic velocity parameters for porous materials.

Source: Bourbié, T. et. al," Acoustics of Porous Media", Gulf Publishing Company, Book Division, 1987.

Based on, but not limited to, the above theoretical and empirical references, at least one CPU (12) provides, based on at least one algorithm and acoustic data from at least one acoustic sensor (13), where at least one sensor (13) provides acoustic data from at least one drilling device (9) to any time direction of movement in approximately real time, and varying, but not limited to, up to 90 degrees to this at least one drilling element's direction of movement and transmit acoustic data to at least one (preferably locally located) data processing unit (CPU ) (12) with one or more algorithms, for pressure data and material analysis in all planes and directions in relation to the drilling device. Based on at least one algorithm, at least one CPU (12) will be able to provide variable and optimal torque to at least one drilling motor (11), in relation to surrounding matter (density), to steerable drilling device (9) in almost real time via steerable shafting ( 10). Based on at least one algorithm and recorded acoustic data, the CPU can make the drilling process autonomous by supplying the at least one drilling device (9), (10) with a direction vector independent of a priori or predefined curvature (coordinates) to at least one drilling device ( 9). Algorithm for autonomy, which overrides predefined drilling profile, will normally be engaged when at least one sensor (13) provides acoustic data that is interpreted by at least one CPU (12) to indicate a type of matter in a plane other than existing in the drilling rig at any given time pre-programmed direction of movement. This may, but is not limited to, include hydrocarbons (oil and/or gas), minerals or volcanic rocks (Kimberley Pipes) for diamond extraction. The system will be able to detect pressure increases in time via (14a), (14b) and/or (15), i.e. in sectors above, below, to the side and in the extension of the drilling device's velocity vector, and will be able to supply drilling fluid components via service channel (6) in the drill string , and thus represent a dynamic BOP ("Blow Out Preventer").

If a drilling fluid motor (11) is used, this can be controlled by (12) giving control signals to the electromechanical and/or electrohydraulic (not shown) valve arrangement. If there is no direct power source (5), local power source in example (3), but not limited to, can be incorporated in the form of combinations of replaceable battery packs, pressure (piezo) electric generators, dynamos or the like, powered by the kinetic energy of the drilling fluid, and thereby providing electricity to operate detection, control and management systems defined by (10)-(15).

This invention has application on land and/or on or in water.

On this background, a most favorable system, method, or a configuration of products and equipment for drilling consisting of, but not limited to; at least one control system, at least one power source, at least one subsystem for operation and handling of drill string elements, at least one subsystem for procurement and handling of drilling fluid, at least one drilling unit, which system is characterized by combinations of;

a) at least one continuous drill string element (1) in an interconnection of drill string elements has a modulus of elasticity (Young's Modulus) less than 150 GPa and tensile strength greater than 0.60

Gpa and does not transmit an active torque,

b) at least one acoustic sensor (13) with the capacity to provide acoustic data, but not limited to, in the extension of at least one drilling element's direction of movement in approximately real time, to at least one data processing unit (CPU) (12), and this at least one CPU (12) has at least one algorithm and where this at least one CPU (12) according to this at least given one algorithm can provide control signals to at least one drilling motor (11) which transmits a locally active torque to at least one drilling unit (9) via steerable shafting (10), c) at least one connection of drill string elements (a) has associated at least one other connection of drill string elements (P) where at least one connection (a) can be released from at least one connection (P) and through which at least one connection (a) can is passed through at least one interconnection (P) and at least one interconnection (P) is made independently of the system for active drilling (a). Furthermore, such a most favorable system, method or a configuration of products and equipment will be characterized by combinations of; - at least one connection of drill string elements (1) has connected at least one cable (5) for transmission of electric current and electronic signal transmission, - at least one connection of drill string elements (1) has connected at least one service channel (6) for transmission of fluid, - at least one motor (11) receives energy from the drilling fluid provided by the system and can provide an active and varying torque to at least one drilling unit (9), of which at least one motor receives control signals from at least one data processing unit (CPU) (12), - at least one drilling motor ( 11) receives electrical energy from at least one cable (6) provided by the system and can provide an active and varying torque to at least one drilling unit (9), of which at least one motor receives control signals from at least one data processing unit (CPU) (12), - the at least one CPU (12) has at least one algorithm that can interpret and analyze acoustic data from at least one acoustic sensor (13) and can provide, but is not limited to, combinations of type and composition of matter and pressure, - the at least one CPU (12) has at least one algorithm that can interpret and analyze acoustic data from at least one acoustic sensor (13) and can provide pressure data in and around the at least one drilling unit (9) forward in time (in all planes around the extension of the drilling device's velocity vector), - the at least one CPU (12) has at least one algorithm that can provide control signals to the drilling unit (9) via steerable shafting (10) and the given algorithm will be switched on when at least one sensor (13) provides acoustic data which is interpreted by at least one CPU (12) to indicate a type of matter in a plane other than that existing in the drilling device's pre-programmed direction of movement at any given time. - the at least one algorithm is a software product, including, but not limited to, instructions when implemented by at least one CPU (12), means that control signals are given to the drilling unit (9) via steerable shaft (10), and given at least one software product will be connected when at least one sensor (13) provides acoustic data which is interpreted by at least one software product to indicate a type of matter in a plane other than that existing in the drilling device's pre-programmed direction of movement at all times. - at least one subsystem (topside) for operation and handling of drill string elements can provide and receive interconnections of drill string elements on a continuous basis.

The present invention is not limited to the described systems, methods, apparatus or algorithms, in the sense that all generic variations to the systems or devices, such that different arrangements of different components (sub-systems or units), different size and geometric design of components, independent and automatic control and management of components of the (total) systems, continuous or partial (time-limited) connection to any control units, placement of any sensors or meters, built-in or partially or totally integrated systems or solutions, are all obvious variants that can be derived by a skilled person, provided that this description of the claimed invention is available.

As a result, all devices or systems that are functionally equivalent will be included by the scope of this invention, and all modifications to the invention, will lie within the stated claims. Based on the above, all statements are to be interpreted illustratively and not in a limiting context. It is further assumed that all claims must be interpreted so that they cover all generic and specific features of the invention described, and that all aspects related to the invention, without regard to specific use of language, must be included. On this background, all the cited references shall be included as part of this invention's basis, modes of operation, methods, algorithms, products, apparatus and systems.

Claims (9)

1. System for drilling consisting of, but not limited to, at least one control system, at least one power source, at least one subsystem for operation and handling of drill string elements, at least one subsystem for obtaining and handling drilling fluid, at least one drilling unit, which system is characterized by at least one of a) at least one continuous drill string element (1) in an interconnection of drill string elements has a modulus of elasticity (Young's Modulus) less than 150 GPa and tensile strength greater than 0.60 Gpa and does not transmit an active torque, b) at least one acoustic sensor (13) with the capacity to provide acoustic data, but not limited to, in the extension of at least one drill element movement direction in near real time to at least one data processing unit (CPU) (12), and this at least one CPU (12) holds at least one algorithm and where this at least one CPU (12) according to this at least given one algorithm can provide control signals to at least one motor (11) which transmits a locally active torque to at least one drilling unit (9), c) at least one interconnection of drill string elements (a ) has associated at least one other connection of drill string elements (P) where at least one connection (a) can be released from at least one connection (P) and through which at least one connection (a) can be passed through at least one connection (P) and at least one connection (P) is made independently of the system for active drilling (a). 2. System according to claim 1, characterized by at least one of a) at least one connection of drill string elements (1) has connected at least one cable (5) for the transmission of electric current and electronic signal transmission, b) at least one connection of drill string elements (1) has connected at least one service channel (6) for transfer of fluid, 3. System according to claim 1, characterized in that - at least one subsystem for operation and handling of drill string elements can provide and receive interconnections of drill string elements on a continuous basis. 4. System according to claim 1, characterized in that - at least one drilling motor (11) receives energy from the drilling fluid provided by the system and can provide an active and varying torque to at least one drilling unit (9), of which at least one motor receives control signals from at least one data processing unit (CPU) (12). 5. System according to claim 1, characterized in that - at least one drilling motor (11) receives electrical energy from at least one cable (6) provided by the system and can provide an active and varying torque to at least one drilling unit (9), of which at least one motor receives control signals from at least one data processing unit (CPU ) (12). 6. System according to all preceding requirements, characterized in that - the at least one CPU (12) has at least one algorithm that can interpret and analyze acoustic data from at least one acoustic sensor (13) and can provide, but not limited to, combinations of type and composition of matter and pressure. 7. System according to all preceding requirements, characterized in that - the at least one CPU (12) has at least one algorithm that can interpret and analyze acoustic data from at least one acoustic sensor (13) and can provide pressure data in and around the at least one drilling unit (9) forward in time (in all planes in extension of the drilling device's velocity vector). 8. Method according to all preceding requirements, characterized in that - the at least one CPU (12) has at least one algorithm which can provide control signals to the drilling unit (9) via steerable axle (10) and given algorithm will be switched on when at least one sensor (13) provides acoustic data which is interpreted by at least one CPU (12) to indicate a type of matter in a plane other than that existing in the drilling device's pre-programmed direction of movement at all times. 9. Product according to all preceding requirements, characterized in that - the at least one algorithm is a software product, including, but not limited to, instructions when implemented by at least one CPU (12), means that control signals are given to the drilling unit (9) via steerable shaft (10), and given at least one software product will be connected when at least one sensor (13) provides acoustic data which is interpreted by at least one software product to indicate a type of matter in a plane other than that existing in the drilling device's pre-programmed direction of movement at all times.