|Publication number||US5323648 A|
|Application number||US 08/025,704|
|Publication date||Jun 28, 1994|
|Filing date||Mar 3, 1993|
|Priority date||Mar 6, 1992|
|Also published as||CA2091143A1, CA2091143C, DE69303838D1, DE69303838T2, EP0559286A1, EP0559286B1|
|Publication number||025704, 08025704, US 5323648 A, US 5323648A, US-A-5323648, US5323648 A, US5323648A|
|Inventors||Bertrand P. M. Peltier, Emmanuel Detournay, Anthony K. Booer|
|Original Assignee||Schlumberger Technology Corporation|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (30), Referenced by (19), Classifications (7), Legal Events (4)|
|External Links: USPTO, USPTO Assignment, Espacenet|
The present invention relates to a tool for measuring the mechanical properties of a ground formation, typically an underground formation traversed by a borehole such as a hydrocarbon well.
When drilling a well such as a hydrocarbon well, it is necessary to obtain information about the nature of the formation being drilled. While some information can be derived from the drilled material returned to the surface, it is often necessary that measurements be made in situ or on larger samples in order to obtain the necessary information. Certain properties can be measured by lowering a tool into the well and making non-intrusive measurements while the tool is moved vertically. This technique is known as electrical logging. The measurements made by the tool are returned to the surface as signals in a wire cable where they can be detected and analysed. Consequently, the technique is also known as wireline logging. Commonly measured properties relate to inherent properties of the formation such as electromagnetic, nuclear and sonic behaviour of the formation and allow the determination of formation resistivity, natural gamma-ray emission and sonic wave speed. However, wireline logging has not been particularly successful to date in determining mechanical properties of formations since this generally involves destructive testing of a sample. The approaches which have been used previously are either the immobilisation of a tool within the wellbore to allow in situ testing or side-coring to retrieve a sample of rock which is returned to the surface for laboratory testing. This latter approach is expensive and time consuming and neither technique allows a continuous logging approach in which measurements are made continuously as the tool is moved through the borehole.
It is an object of the present invention to provide a tool which can provide mechanical properties of the formations traversed by a borehole in a continuous logging operation.
In accordance with the present invention, there is provided a tool for measuring the mechanical properties of a formation through which a borehole has been drilled, comprising a tool body capable of being lowered into a borehole, the tool body having mounted thereon a cutter which is urged against wall of the borehole so as to cut into the formation; means for determining the depth of cut made by the cutter and for determining the resistance of the rock to cutting; and means for enabling the cutter to be moved through the formation and for analysing the depth of cut and resistance to cutting to determine the mechanical properties of the rock.
Preferably the cutter comprises a polycrystalline diamond compact (PDC) cutter such as are used in drag-type drill bits. The cutter can be mounted on a pad which is connected to the main part of the tool body by resiliently biassed arms which urge the pads and cutter against the borehole wall.
In use the tool is lowered into a borehole and measurements are taken as the tool is withdrawn from the borehole. Transducers can be provided to measure the depth of cut made by the cutter and the resistance to the movement of the cutter through the formation.
The measurements made by the transducers can be analysed in a manner similar to that described in our co-pending European Patent Application Number 91201708.4 which is incorporated herein by reference. The output from the tool can be used to compute the internal friction angle Φ of the rock and other such mechanical properties.
The cutter action can be described by the equation ##EQU1## where δ is the depth of cut
ω is the width of the cutter
μ=Tan (Φ)=internal friction angle of the rock
E0 is a regression parameter.
The data from the transducers provides values of FS Fn and δ and a simple linear regression is used to obtain μ and hence Φ. Alternatively a state space model can be used to yield a continuous evaluation of F. without the need for any cross plot.
The present invention will now be described by way of example, with reference to the accompanying drawings in which:
FIG. 1 shows a schematic view of a PDC type cutter;
FIG. 2 shows a general diagram of a logging tool in accordance with one embodiment of the invention;
FIG. 3 shows a more detailed diagram of part of the tool shown in FIG. 2;
FIG. 4 shows the cutting action of a sharp PDC cutter;
FIG. 5 shows the cutting action of a PDC cutter with a wear flat;
FIG. 6 shows the -S diagram for a single cutter with a wear flat in Berea sandstone; and
FIG. 7 shows the -S diagram for a single sharp cutter in Berea sandstone.
The action of a drag cutter such as a PDC cutter is illustrated in FIG. 1 and described in our co-pending application referenced above. The cutter is mounted on a tool as described in relation to FIG. 2 and comprises a stud 10 having a flat cutting face 12 on which a layer of hard abrasive material 14 is deposited. In the case of a PDC cutter, the material 14 is a synthetic polycrystalline diamond bonded during synthesis onto a tungsten carbide/cobalt metal support 12.
The tool shown in FIG. 2 corresponds in part to tools commonly used to measure electrical properties of formation and comprises a central main tool body 20 which can be lowered into the borehole by means of a wireline 22 which supplies power to the tool and enables data to be returned to the surface. The tool is provided with arms 24 on which are mounted sensor pads 26. The arms 24 can be operated to move the pads 26 away from the tool body 20 and urge them against the wall 28 of the borehole such that measurements can be made. In the case of measuring electrical properties, the pads 26 carry electrodes which contact the borehole wall. However, in the present case, each pad 26 carries a cutter and transducer arrangement as shown in FIG. 3. The cutter 30 is mounted on the pad 26 such that when the pad 26 is urged against the borehole wall 28 and the tool is pulled up by the wireline 22, the cutter 30 is constrained to cut a groove of a depth within certain limits, in this case typically 0.5-3 mm. A pair of displacement transducers 32, 34 is mounted one either side of the cutter 30 so as to monitor the exact depth of cut at any instant. Transducers (not shown) are also provided to measure the forces imposed on the cutter 30 normal to the direction of displacement (Fn) and parallel to the direction of displacement (FS). The data from the transducers are sampled and analysed to extract the rock properties. The pad 26 also has a scraper 36 mounted on its leading edge contacting the borehole wall 28 which serves to scrape the surface smooth of any debris, mudcake etc. in order that the cutter 30 should only encounter the resistance of the formation when cutting.
In an alternative form of tool to that shown in FIG. 3, a pair of cutters is provided. A first cutter is fixed and serves to scrape the rock smooth as the tool is moved through the borehole. The second cutter is immediately behind the first cutter and is forced to cut a groove of fixed or variable depth into the smoothed rock. The second cutter is instrumented to measure the depth of cut by measuring displacement relative to the fixed first cutter. This can be achieved using a single LVDT transducer rather than the two transducers required in the previous arrangement. Again the cutter is instrumented to measure Fn and FS as before. Since in this case, the means for measuring the depth of cut does not need to contact the rock there is no possibility that the transducers will deform or gouge the rock themselves and so give an inaccurate reading. Furthermore, both cutters should wear at approximately the same rate and so errors due to cutter wear are likely to be negligible.
In use, a typical drill bit-type PDC cutter is used. In drill bit applications, the cutters are typically run in the following conditions:
depth of cut=1 mm
linear speed of cutter=2 m/s
distance cut=200 m/vertical meter drilled, i.e. 20,000 m cut from 100 m drill bit run.
In the logging application described above, the conditions would be:
depth of cut=1 mm
linear speed of cutter=0.3 m/s
distance cut=1000 m.
The logging conditions are far less severe than drilling and so no substantial wear problems should be encountered.
The upper range for FS, which determines the overpull on the wireline cable, is of the order of FS =2 kN for a ω=10 mm cutter (values of ω down to 5 mm are suitable). In order to avoid large fluctuations of overpull on the wireline cable with change of lithology, it is best to control the depth of cut δ through a servo-control mechanism to maintain FS within optimal limits. However, some variation in the measured channels is beneficial to the accuracy of the interpretation (linear regression) and could, when needed, be introduced by imposing small amplitude fluctuations on the value of δ. The logging speed, insofar as it is not nil, need not be known to perform the interpretation.
The procedure for analysing the data obtained from the tool is given below. A perfectly sharp cutter tracing a groove of constant cross-sectional area A (A=δω) on a horizontal rock surface is shown in FIG. 4. The cutter has a vertical axis of symmetry by the backrake angle θ (contrary to the sign convention in metal cutting, θ is taken positive when the cutter is inclined forward). It is assumed that the cutter is under pure kinematic control, ie the cutter is imposed to move at a prescribed horizontal velocity with a zero vertical velocity (constant depth of cut). During the cutting, a force Fc is imparted by the cutter onto the rock; Fc s and Fc n denoting the force components that are respectively parallel and normal to the rock surface.
It is assumed that the horizontal and vertical forces on the cutter, averaged over a distance large with respect to the depth of cut, are proportional to the cross-sectional area A of the cut:
Fc s =εA (1)
Fc n =ξεA (2)
where the constant ε is defined as the intrinsic specific energy and ξ is the ratio of the vertical to the horizontal force acting on the cutting face. The specific energy ε quantifies a complex process of rock destruction and generally depends on various factor, such as rock surface, etc. The term "intrinsic specific energy" ε represents the amount of energy spent to cut a unit volume of rock by a pure cutting action. The quantity ε has the same dimensions as a stress and that a convenient unit for ε is MPa (an equivalent unit for ε is the J/cm3 which is numerically identical to the MPa).
A convenient ratio, ξ, between the vertical and the horizontal force implies that there is friction at the rock-cutter interface. Since a symmetric cut has been assumed here, no horizontal force orthogonal to the direction of the cut is expected. This is an ideal case, however, for which the vertical to horizontal force ratio, ξ, takes the particular maximum value ξ*
ξ*=tan (θ+ψ) (3)
where ψ denotes the interfacial friction angle.
Any argument about the direction of the cutting force Fc actually requires consideration of the kinematics of failed rock. Indeed, the projection of the force on the cutting face is taken to be parallel to [ν], the velocity of the failed rock relative to the cutter (principle of coaxiality). If the cross-sectional shape of the cut is symmetric (as it is usually enforced in a single cutter test) then the velocity discontinuity vector [ν], is parallel to the plane defined by the axis of symmetry and the cut direction. If symmetry is broken, as in the case of a cutter moving on an inclined surface, there is a relaxation of the constraint on the direction of [ν] leading generally to the existence of a transverse horizontal component of the cutting force.
In the case of cutter with a wear flat, see FIG. 5, the cutter force F is now decomposed into two vectorial components, Fc transmitted by the cutting face, and Ff acting across the wear flat. It is assumed that the cutting component Fc n and Fc s obey the relations (1) and (2) postulated for the perfectly sharp cutter. It is further assumed that a frictional process is taking place at the interface between the wearflat and the rock; thus the components Ff n and Ff s are related by
Ff s =μFf n (4)
where μ is a coefficient of friction.
On the basis of the fundamental equations (1), (2) and (4), a linear relation can be derived between the horizontal force components FS =Fc s +Ff s, and the vertical force component Fn =Fc n +Ff n. Indeed, using (1) and (4), the horizontal component FS can be expressed as
FS =eA=μFf n (5).
Writing Ff n as Fn -Fc n and using (2), this equation becomes
FS =(1-μξ)εA=μFn (6).
Two quantities are now introduced: the specific energy defined as ##EQU2## and the drilling strength S ##EQU3##
Both quantities and ε have the same general meaning but represents the energy spent by unit volume of rock cut, irrespective of the fact that the cutter is sharp or blunt, whereas ε is meaningful only for the cutting action.
For a perfectly sharp cutter, we have in view of the basic expression (1) and (2) and the definitions (7) and (8) that
=ε and S=ξε (9).
For a blunt cutter, the following linear relationship exist between and S, which is simply obtained by dividing both member of (6) by A:
= 0 +μS (10)
where the quantity 0 is defined as
0 =(1=μξ)ε (11).
Equation (10) actually represents a constraint on the cutting response of a PDC cutter; in other words, the specific energy and the drilling strength S are not independent of each other, but are constrained by (10) when cutting and frictional processes are taking place simultaneously. The cutting "point" defined by (9) obviously satisfies the linear relation (10) and therefore only states that are characterised by ≧ε (or alternatively by S≧ξε) are physically admissible.
A series of single cutter tests verify this procedure. These tests are performed at atmospheric pressure with a milling machine, using PDC cutter having experienced various amount of wear. The cuts are made in the top surface of a sample of Berea sandstone by moving the cutter at a constant velocity of 5.6 cm/s parallel to the rock surface (and thus imposing a constant depth of cut). The length of the cuts range from 30 to 45 cm, and the depths of cut from 0.25 to 2.5 mm. Eight different cutters (labelled A, B, C, D, E, G, I, J, K) having a backrake of 20° and a diameter of either 12.7 mm or 19.1 mm are used. Two of these cutters (J and K) are "sharp", the others having a measurable wear flat ranging from 10.3 mm2 for cutter A to 25.8 mm2 for cutter I. Table 1 summarises the relevant characteristics of the cutters used in these tests.
TABLE 1______________________________________Cutter Diameter (mm) Wearflat area (mm2)______________________________________A 12.7 10.3B 12.7 11.0C 12.7 11.0E 12.7 14.2G 19.1 20.6I 12.7 25.8J 12.7 0.K 19.1 0.______________________________________
The results of the experiments on Berea Sandstone can be plotted in an -S diagram (not shown), with each point representing the average measurement for a particular experiment. When plotted, the points appear to define a friction line characterised by μ≅0.82 and 0 ≅14 MPa. The cutting states for the two sharp cutters (J and K) are clustered near the lower left of the data cluster. The lower-left data point is taken as the best estimate of the cutting point; it is estimated here to be characterised by ε≅32 MPa and ξ≅0.8. This value of ξ implies that the interface friction angle ψ≅19°.
The most comprehensive series of tests on the Berea sandstone are performed with cutter 1; 89 measurements being available. The corresponding data points in the diagram -S are plotted in FIG. 6 where the symbols are now used to differentiate between the different depths of cut. FIG. 7 shows a similar diagram for the experimental results obtained with one of the sharp cutters (cutter J).
A further embodiment of the invention includes an optical sensor immediately behind the cutters shown as 38 in FIG. 3 which can provide optical information about the formation from the cleaned surface. This may be achieved using a fiber optic device or the like.
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|U.S. Classification||73/152.17, 73/81, 436/28, 73/78|
|Apr 26, 1993||AS||Assignment|
Owner name: SCHLUMBERGER TECHNOLOGY CORP., TEXAS
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNORS:PELTIER, BERTRAND PIERRE MARIE;DETOURNAY, EMMANUEL;BOOER, ANTHONY KEVIN;REEL/FRAME:006508/0455;SIGNING DATES FROM 19930302 TO 19930329
|Dec 19, 1997||FPAY||Fee payment|
Year of fee payment: 4
|Oct 5, 2001||FPAY||Fee payment|
Year of fee payment: 8
|Nov 22, 2005||FPAY||Fee payment|
Year of fee payment: 12