Identifying Unconventional Formations
Background
[0001] The basic principles and techniques for electromagnetic (EM) logging for earth formations are
well known. For example, induction logging to determine the resistivity (or its inverse, conductivity)
of earth formations adjacent a borehole has long been a standard and important technique in the search
for and recovery of subterranean petroleum deposits. In brief, a transmitter transmits an
electromagnetic signal that passes through formation materials around the borehole and induces a
signal in one or more receivers. The amplitude and/or phase of the receiver signals are influenced by
the formation resistivity, enabling resistivity measurements to be made. The measured signal
characteristics and/or formation properties calculated therefrom are recorded as a function of the tool's
depth or position in the borehole, yielding a formation log that can be used by analysts.
[0002] EM techniques are used in logging-while-drilling (LWD) and wireline logging. Such
techniques are used to evaluate formation parameters, including formation resistivity, formation
anisotropy, boundary position, etc.
[0003] A parameter (such as resistivity) of a given formation may be isotropic (equal in all directions)
or anisotropic (unequal in different directions). Measuring such a parameter in an unconventional
formation, containing for example fractures and/or folds, is a challenge.
Brief Description of the Drawings
[0004] Fig. 1 shows an illustrative logging while drilling environment including dipping formation
beds.
[0005] Fig. 2 shows an illustrative wireline logging environment including dipping formation beds.
[0006] Fig. 3 shows a relationship between the orientation of a borehole and a dipping formation bed.
[0007] Fig. 4 shows a hypothetical antenna arrangement for a tool having an orthogonal triaxial
transmitter and two orthogonal triaxial receivers.
[0008] Fig. 5 shows angles for defining the orientation of a tilted antenna.
[0009] Fig. 6 is a block diagram of an illustrative electronics module for an electromagnetic resistivity
tool.
[0010] Fig. 7 shows an illustrative electromagnetic resistivity logging tool having tilted transmitter and
receiver antennas.
[001 1] Fig. 8 illustrates an antenna arrangement.
[0012] Figs. 9 and 10 illustrate conventional formation models.
[0013] Fig. 11A illustrates bins.
[0014] Fig. 11B illustrates mathematical relationships between the bins and the formation from which
data is being collected.
[0015] Figs. 12 - 15, and 18 - 19 illustrate modeling responses.
[0016] Figs. 16 and 17 illustrate unconventional formation models.
[0017] Figs. 20-23 illustrate antenna arrangements.
[0018] Fig. 24 is a flow chart.
[0019] Fig. 25 illustrates an environment.
Detailed Description
[0020] The disclosed tool configurations and operations are best understood in the context of the larger
systems in which they operate. Accordingly, an illustrative logging while drilling (LWD) environment
is shown in Fig. 1. A drilling platform 2 supports a derrick 4 having a traveling block 6 for raising and
lowering a drill string 8. A kelly 10 supports the drill string 8 as it is lowered through a rotary table 12.
A drill bit 14 is driven by a downhole motor and/or rotation of the drill string 8 . As bit 14 rotates, it
creates a borehole 16 that passes through various formations 18. A pump 20 circulates drilling fluid
through a feed pipe 22 to kelly 10, downhole through the interior of drill string 8, through orifices in
drill bit 14, back to the surface via the annulus around drill string 8, and into a retention pit 24. The
drilling fluid transports cuttings from the borehole into the pit 24 and aids in maintaining the borehole
integrity.
[0021] An electromagnetic resistivity logging tool 26 is integrated into the bottom-hole assembly near
the bit 14. As the bit extends the borehole through the formations, logging tool 26 collects
measurements relating to various formation properties as well as the tool orientation and position and
various other drilling conditions. The orientation measurements may be performed using an azimuthal
orientation indicator, which may include magnetometers, inclinometers, and/or accelerometers, though
other sensor types such as gyroscopes may be used. In some embodiments, the tool includes a 3-axis
fluxgate magnetometer and a 3-axis accelerometer. The logging tool 26 may take the form of a drill
collar, i.e., a thick-walled tubular that provides weight and rigidity to aid the drilling process. A
telemetry sub 28 may be included to transfer tool measurements to a surface receiver 30 and to receive
commands from the surface receiver.
[0022] More preferably, a rotational position indicator located near the logging tool 26 or the telemetry
sub 28 may contain both a 3-axis fluxgate magnetometer and a 3-axis accelerometer. As is known in
the art, the combination of those two sensor systems enables the measurement of the toolface,
inclination, and azimuth orientation angles of the borehole. The toolface and hole inclination angles are
calculated from the accelerometer sensor output. The magnetometer sensor outputs are used to
calculate the hole azimuth. With the toolface, the hole inclination, and the hole azimuth information, a
tool in accordance with the present invention can be used to steer the bit to the desirable bed.
Specifically, the response difference or the response ratio can be used effectively to enter a desired
payzone or to stay within the payzone of interest.
[0023] At various times during the drilling process, the drill string 8 may be removed from the
borehole as shown in Fig. 2 . Once the drill string has been removed, logging operations can be
conducted using a wireline logging tool 34, i.e., a sensing instrument sonde suspended by a cable 42
having conductors for transporting power to the tool and telemetry from the tool to the surface. A
resistivity imaging portion of the logging tool 34 may have centralizing arms 36 that center the tool
within the borehole as the tool is pulled uphole. A logging facility 44 collects measurements from the
logging tool 34, and includes computing facilities for processing and storing the measurements
gathered by the logging tool.
[0024] The formations 18 shown in Fig. 1 are not perpendicular to the borehole, which may occur
naturally or due to directional drilling operations. The borehole may have a coordinate system 50
defined in accordance with the borehole's long axis (the z axis) and the north side (or alternatively, the
high side) of the hole (the x-axis). The formations 18, when characterized as a plane, may have a
coordinate system 1 defined in accordance with the normal to the plane (the z" axis) and the direction
of steepest descent (the x"-axis). As shown in Fig. 3, the two coordinate systems are related by two
rotations. Beginning with the borehole's coordinate system (x,y,z), a first rotation of angle g is made
about the z axis. The resulting coordinate system is denoted (x',y',z'). Angle g is the relative strike
angle, which indicates the direction of the formation dip relative to the borehole's coordinate system. A
second rotation of angle a is then made about the y' axis. This aligns the borehole coordinate system
with the formation coordinate system. Angle a is the relative dip angle, which is the slope angle of the
beds relative to the long axis of the borehole.
[0025] The vertical resistivity is generally found to be the resistivity as measured perpendicular to the
plane of the formation, and the horizontal resistivity is the resistivity as measured within the plane of
the formation. Determination of each of these parameters (dip angle, strike angle, vertical resistivity,
and horizontal resistivity) is desirable.
[0026] Fig. 4 shows a hypothetical antenna configuration for a multi-component electromagnetic
resistivity logging tool. The electromagnetic resistivity logging tool may be embodied as a wireline
tool and as a logging while drilling tool. A triad of transmitter coils Tc, Tg and Tz, each oriented along
a respective axis, is provided. At least one triad of similarly oriented receiver coils Rix, RIY , and iz is
also provided. For receive signal measurements relative to the amplitude and phase of the transmit
signal (sometimes called "absolute" measurements), only one receiver triad would be used. A second
triad of similarly oriented receiver coils pairs R , R2Y, and R2z may also provided when differential
measurements are desired (e.g., a signal amplitude ratio or a phase difference between receiver coils
oriented along a given axis). Differential measurements may offer increased spatial resolution.
[0027] Moran and Gianzero, in "Effects of Formation Anisotropy on Resistivity Logging
Measurements" Geophysics, Vol. 44, No. 7, p. 1266 (1979), noted that the magnetic field h in the
receiver coils can be represented in terms of the magnetic moments m at the transmitters and a
coupling matrix C:
h = Cm (1)
[0028] In express form, equation (1) is:
where M c , Mg , and M are the magnetic moments (proportional to transmit signal strength) created by
transmitters Tx , TY, and Tz , respectively. Hx , HY, Hz are the magnetic fields (proportional to receive
signal strength) at the receiver antennas Rx, Ry, and Rz, respectively.
[0029] In the antenna configuration of Fig. 4, if each transmitter is fired in turn, and signal
measurements are made at each receiver in response to each firing, nine absolute or differential
measurements are obtained. These nine measurements enable the determination of a complete coupling
matrix C. C = where I is the index for receiver Rx , RY, or Rz , J is the index for transmitter
T c, TY, or Tz, i j is a constant determined by the tool design, and v is a complex value representing
the signal amplitude and phase shift measured by receiver I in response to the firing of transmitter J.)
Knowledge of the complete coupling matrix enables the determination of dip angle, strike angle,
vertical resistivity, and horizontal resistivity. A number of techniques may be used to determine these
parameters. For example, dip and strike angle may be determined from coupling matrix values as
explained by Li Gao and Stanley Gianzero, U.S. Pat. No. 6,727,706 entitled "Virtual Steering of
Induction Tool for Determination of Formation Dip Angle". Given these angles, vertical and horizontal
resistivity can be determined in accordance with equations provided by Michael Bittar, U.S. Pat. No.
7,019,528 entitled "Electromagnetic Wave Resistivity Tool Having a Tilted Antenna for Geosteering
within a Desired Payzone" . Alternatively, a simultaneous solution for these parameters may be found
as described in the Bittar reference.
[0030] Fig. 5 shows two angles that may be used to specify the orientation of a coil antenna. The coil
antenna may be considered as residing in a plane having a normal vector. Tilt angle Qis the angle
between the longitudinal axis of the tool and the normal vector. Azimuth angle b is the angle between
the projection of the normal vector in the X-Y plane and the tool scribe line. Alternatively, in the
downhole context, azimuthal angle b may represent the angle between projection of the normal vector
in the X-Y plane and the x-axis of the borehole coordinate system.
[0031] It is noted that three transmitter antenna orientations and three receiver antenna orientations are
employed in the antenna configuration of Fig. 4. It has been discovered, as described in Michael Bittar
and Guoyu Hu, WO2008/076130, entitled "Antenna Coupling Component Measurement Tool Having
Rotating Antenna Configuration," that when tool rotation is exploited, it is possible to determine the
full coupling matrix with only one transmitter and two receiver antenna orientations (or equivalently,
one receiver and two transmitter antenna orientations). Moreover, with certain assumptions about the
configuration of the formation, one transmitter and receiver antenna orientation may be sufficient.
[0032] Before considering various tools having specific antenna configurations, the electronics
common to each tool are described. Fig. 6 shows a functional block diagram of the electronics for a
resistivity tool. The electronics include a control module 602 that is coupled to an analog switch 604.
Analog switch 604 is configured to drive any one of the transmitter coils Ti, T2, T , T4 with an
alternating current (AC) signal from a signal source 606. In some embodiments, the signal source
provides radio frequency signals. The control module 602 preferably selects a transmitter coil, pauses
long enough for transients to die out, then signals data storage/transmit module 610 to accept an
amplitude and phase sample of the signals received by each of the receivers. The control module 602
preferably repeats this process sequentially for each of the transmitters. The amplitude and phase shift
values are provided by amplitude and phase shift detector 608 which is coupled to each of the receiver
coils i and R for this purpose.
[0033] Control module 602 may process the amplitude and phase shift measurements to obtain
compensated measurements and/or measurement averages. The raw, compensated, or averaged
measurements may be transmitted to the surface for processing to determine dip and strike angles,
vertical and horizontal resistivity, and other information such as (i) distance to nearest bed boundary,
(ii) direction of nearest bed boundary, and (iii) resistivity of any nearby adjacent beds. The data
storage/transmitter module 610 may be coupled to telemetry unit 28 (Fig. 1) to transmit signal
measurements to the surface. Telemetry unit 28 can use any of several known techniques for
transmitting information to the surface, including but not limited to (1) mud pressure pulse; (2) hardwire
connection; (3) acoustic wave; and (4) electromagnetic waves.
[0034] Fig. 7 shows an electromagnetic resistivity logging tool 702 having only two receiver antenna
orientations. The tool 702 is provided with one or more regions 706 of reduced diameter. A wire coil
704 is placed in the region 706 and in some embodiments is spaced away from the surface of
subassembly 702 by a constant distance. To mechanically support and protect the coil 704, a nonconductive
filler material (not shown) such as epoxy, rubber, or ceramic may be used in the reduced
diameter regions 706. Coil 704 is a transmitter coil, and coils 710 and 712 are receiving coils. In
operation, transmitter coil 704 transmits an interrogating electromagnetic signal which propagates
through the borehole and surrounding formation. Receiver coils 710, 712 detect the interrogating
electromagnetic signal and provide a measure of the electromagnetic signal's amplitude attenuation and
phase shift. For differential measurements additional receiver coils parallel to coils 710, 712 may be
provided at an axially-spaced distance. From the absolute or differential amplitude attenuation and
phase shift measurements, the coupling matrix components can be determined and used as the basis for
determining formation parameters and as the basis for geosteering.
[0035] The transmitter coil 704 may be spaced approximately 30 inches from the receiver coils 710,
712. The transmitter and receiver coils may comprise as little as one loop of wire, although more loops
may provide additional signal power. The distance between the coils and the tool surface is preferably
in the range from 1/16 inch to 3/4 inch, but may be larger. Transmitter coil 704 and receiver coil 712
may each have a tilt angle of about 45° and aligned with the same azimuth angle, while receiver coil
710 may have a tilt angle of about 45° and an azimuth 180° apart from receiver coil 712 (or
equivalently, a tilt angle of minus 45° at the same azimuth angle as receiver coil 712).
[0036] The signal measured by a tilted receiver in response to the firing of a tilted transmitter can be
expressed in terms of the signals V that would be measured by the tool of Fig. 4. One embodiment of
an antenna configuration, illustrated in Fig. 8, includes a tilted transmitter (T) and a tilted transmitter
(R). When both the transmitter and receiver are oriented at the same azimuth angle b, the tilted receiver
signal is:
Where, 9t is the tilt angle of the transmitter relative to the z-axis (line 802 in Fig. 8), 9 is the tilt angle
of the receiver relative to the z-axis direction, v/ is a complex value representing the signal amplitude
and phase shift measured by the receiver in /-directional dipole in response to the firing of transmitter
in J-directional dipole. The tilted receiver signal v can be a measurement of a voltage or of an
electromagnetic field. Equation (3) can be also expressed as:
where:
C„ = si sin ; = v sin ¾ sin = cos sin
C , = sin 6 sin ;Cyy = sin sin 0r ;C = v cos , sin
Cx =vz
x sin cos r ; =nz sin , cos ;C = v cos 9 cos
[0037] Fig. 9 illustrates a conventional formation model where homogeneous isotropic or transversely
isotropic (TI) formation medium is considered. For a TI medium, a formation electrical property (i.e.,
formation resistivity) in the horizontal plane is different than a formation electrical property in the
vertical plane. As indicated in Fig. 9, the horizontal plane has same resistivity profile (horizontal
resistivity, ¾ ) in all horizontal directions and a vertical resistivity profile (vertical resistivity, R ) in
the vertical direction. An isotropic formation is described if R equals R¾, and an anisotropic formation
model is defined if R is not equal to .
[0038] Another conventional formation model, illustrated in Fig. 10, consists of inhomogeneous
layered formations 1002, 1004, 1006, 1008 with TI media in each layer and parallel boundaries 1010,
1012, 1014 between each layer.
[0039] During logging, in one embodiment, control module 602 sorts samples according to the
orientation of the tool when the sample was taken into N bins, such as those illustrated in Fig. 1 1A,
each bin centered at degrees relative to the high side of the tool.
[0040] With conventional formation models such as those in Figs 9 and 10, Eq. (2) can be simplified
as:
nt b )=
c s 0 _ cos6r
cos2/¾ +(C + )cos/¾ + (5)
( ) + i ½ ) +
where:
/ is azimuth angle corresponding to the bin direction in Fig. 11A,
i„g, ( ) = ( +C )cosA , and
2C + C„ +
[0041] In practice, is a tool azimuth angle relative to a tool high side direction, as illustrated in Fig.
11B. The tool's "high side" is normally a magnetic north direction determined by a magnetometer
device or as upward direction determined by a gravity-sensing device. Fig. 11B also illustrates the
relationship between a formation strike direction (i.e., a direction along a line representing an
intersection of a formation bedding plane with a horizontal plane) and the tool high side. The cosine
wave signals in equation (5) (i.e., A oubi and Asi g ) can be used to calculate strike angle bo (or relative
azimuth, the angle between the tool's high side and the formation strike direction) by examining the
azimuth shift in the tool azimuth spectrum. Further, Fig. 11B illustrates the relative dip angle defined
by the angle between the tool's drilling direction (i.e., the "z" direction) and a direction normal to the
formation bedding plane.
[0042] Equation (5) includes three types of signals with respect to tool azimuthal angle bi :
(1) a cosine wave signal with double periods ( Uble ( ) )
(2) a cosine wave signal with a single period ( Single ) ' d
(3) a constant signal ( s ) regardless of tool azimuth.
These three signals are all complex numbers consisting of a real part and an imaginary part.
Consequently, Eq. (5) indicates that both real part and imaginary part of the cosine wave should have
same shift in azimuth angle. Figs. 12 and 13 illustrate tool azimuth spectra modeling responses of an
antenna structure such as that shown in Fig. 8 (d=44inch, operation frequency of 125 kHz)
in a conventional formation model (Rh=0.62Q m, Rh=1.68Q m, relative dip angle of 20°, and strike
angle of 0°). As shown in Figs. 12 and 13, the real part and imaginary part for each type of sinusoidal
signals have the same shift in azimuth angle (that is, a peak in the real and imaginary parts of Adoubie
and a peak in the real and imaginary parts of As in g ie occurs at 0°, indicating a strike angle of 0°). Figs.
14 and 15 present the same modeling responses but with a defined formation model as in Figs. 9 or 10
with a 30° azimuth shift away from the tool. In this situation, the real part and imaginary part of each
type of sinusoidal wave present the same azimuth shift (that is, a peak in the real and imaginary parts
of Adoubie and a peak in the real and imaginary parts of As i g i occurs at 30°)(described in Eq. (5)). The
real and imaginary parts of A 0 Ubie and AS g e present the same azimuth shift in tool azimuth spectrum,
indicating the true strike angle of the formation bedding structure.
[0043] Equation (5) is not valid if the tool is located in an unconventional formation model such as
those illustrated in Figs. 16 and 17. Instead of a TI medium, Fig. 16 shows an unconventional
formation model consisting of two resistivity profiles in the horizontal plane (¾ c and R y) . The
unconventional formation 1602 illustrated in Fig. 16 has three individual resistivity profiles in triaxial
directions, where ¾ c and are located in horizontal plane in x and y direction, respectively, and R
indicating the vertical resistivity in the z direction. Such an unconventional model is defined as biaxial
anisotropic formation.
[0044] Fig. 17 illustrates an unconventional layered formation model with layers 1702 (having
resistivity profile Rhxo, Rhyo in the horizontal plane and Rvo in the vertical plane), 1704 (having
resistivity profile R x, R in the horizontal plane and R in the vertical plane), 1706 (having resistivity
profile R , hyi in the horizontal plane and R i in the vertical plane), and 1708 (having resistivity
profile R X2, R 2 in the horizontal plane and R 2 in the vertical plane) and with non-parallel boundaries
1710, 1712, 1714 between the layer.
[0045] With such unconventional formation models, such as shown in Figs. 16 and 17, equation (5)
no long valid and equation (4) can be expressed as:
T sin 6t cos bi x y z sin r cos .
,) = sin 0t sin bί v x
y v y
y vå
y sin 9r sin bί
z z z
COS t V x V y V z cos^
- + (6)
(— ) cos 2b + (- sin 2b
double
where:
. = ( " 2 o . + ( ) (7a)
( ) = (C„ + ) cos b + C y +Cy ) sin b (7b)
(7c)
[0046] Equations (7a) and 7(b) can be expressed as:
ub ) = A
DR ( - fi R ) +i ADI cos(2# - b I ) (8a)
4i„ , ( ) = cos(2 ,. + cos(2# - ) (8b)
where:
[0047] As can be seen in equations (8a), (8b) and (9), the real part and imaginary parts of each type of
sinusoidal wave has an additional azimuth shift b K,b 1 , SR , and b 51 ) caused by the unconventional
formation models. Further, the azimuth shift for the real part and the imaginary part vary on the basis
of the unconventional formation model and measured multi-components in Eq. (6). Using the same
spacing and operating frequency as Figs. 12 and 13, Figs. 18 and 19 illustrate tool azimuth spectra
modeling responses for two different formation models. Fig. 18 illustrates a plot for a conventional TI
formation model (Rh=0.25Q-m, Rv=2Q m, relative dip angle of 20° and strike angle of 0°). Fig. 19 is
a plot for an unconventional biaxial anisotropic formation model (Rhx=0.25Q-m, Rhy=lQ m,
Rv=2Q m, relative dip angle of 20° and strike angle of 0°). As shown in Fig. 19, there are angle
differences between azimuth shift in the real part as compared to the azimuth shift in the imaginary
part for sinusoidal waves in unconventional formation model, especially for 4dou l . The true formation
strike angle can be determined as described above for the azimuth spectra shown in Fig. 18. In
contrast, however, because of the angle differences between the azimuth shift in the real and azimuth
shift in the imaginary part, it is difficult to determine the true formation strike angle for the azimuth
spectra shown in Fig. 19 using the techniques described above.
[0048] In one embodiment, unconventional formation signals are decoupled and unconventional
formation model parameters are determined using the techniques described above. In one
embodiment, several antenna configurations enable an LWD system to capture and invert data to
produce unconventional formation parameters. In one embodiment, shown in Fig. 20, two sets of
transmitter-receive antenna systems are used to decouple multi-components in a conventional
formation model. In one embodiment, shown in Fig. 20, the two transmitters (Ti and T2) and the
receiver (Rx) are oriented at the same tool azimuth, the transmitters are tilted at two different angles
relative to the z-axis 2002 (Ti at tl and T2 at 2), and the receiver (Rx) is tilted relative to the z-axis
2002 (at Q) .
[0049] Under the reciprocity theorem, transmitter(s) and receiver(s) are exchangeable. Fig. 1 shows
one embodiment of an antenna structure with similar functionalities as Fig. 20. Instead of two
transmitters and one receiver as in Fig. 20, Fig. 2 1 shows two receivers (Ri and R2) and one transmitter
(Ti). In one embodiment, shown in Fig. 21, the two receivers (Ri and R2) and the transmitter (Tx) are
oriented at the same tool azimuth, the receivers are tilted at two different angles relative to the z-axis
2102 (Ri at rl and R2 at 0 2), and the transmitter (Tx) is tilted relative to the z-axis 2102 (at 6t).
[0050] While the systems shown in Figs. 20 and 2 1 are able to capture the unconventional formation
signals, the received LWD measurements with only single frequency operation are not enough to
decouple such formation parameters. Consequently, multi-frequency measurements are included with
the systems in Figs. 20 and 2 1 to allow unconventional formation determination.
[0051] Figs. 22 and 23 show antenna structures capable of capturing and decoupling unconventional
formation signals with measurements received at single operation frequency. In embodiments
illustrated Figs. 22 and 23, at least three sets of transmitter-receiver system are included where each
antenna orientation is tilted at a certain angle and oriented at a certain azimuth. With additional
introduction of different antenna azimuth, measurements from the embodiments of systems illustrated
in Fig. 22 and 23 are able to capture and invert unconventional formation parameters.
[0052] In one embodiment illustrated in Fig. 22, one transmitter (Ti) is oriented at a different azimuth
t i relative to strike angle 2202 compared to the orientation of the other two transmitters (i.e., T at
2 and T 3 at bί , b ¹ 2 and bίΐ ¹ b ) . In one embodiment, T2 and T 3 are at the same azimuth (i.e., bί2 =
b ) but at different tilt angles (i.e., t2 ¹ t3) . In one embodiment, the receiver (Rx) is tilted at angle
and is orientated at azimuth angle bG.
[0053] In one embodiment, the receivers and transmitters in Fig. 22 are exchanged.
[0054] In one embodiment illustrated in Fig. 23, every transmitter and receiver oriented at different
azimuth angle and at least one transmitter and one receiver is tilted.
[0055] In one practical embodiment using the system illustrated in Fig. 22, Rx is tilted at Q = 45° and
oriented at azimuth of b = 0° and three receivers are all tilted at l = bί2 = b = 45° but oriented at
various azimuth angles ( t i = 0°, 2 = 120°, and 3 = 240°, respectively).
[0056] In one embodiment of use, illustrated in Fig. 24, the tool 26 is rotated (block 2405). For
example, in one embodiment the tool 26 is an LWD tool and the tool 26 is rotated as part of the drilling
operation. In one embodiment, another scheme is used to rotate the tool in a wireline environment.
[0057] In one embodiment, single and/or multiple-frequency azimuthal measurements are made and
binned (block 2410). In one embodiment, the three types of signals (equations 7(a), 7(b), and 7(c)) are
decoupled using equation (6) (block 2415). In one embodiment, A doubi and/or A si g are examined for
the type of phase shift described above that indicates the samples were taken from an unconventional
formation (block 2420). If the phase shift is not present, the data is processed, for example by
applying one or more inversion techniques appropriate to conventional formations to extract formation
parameters)(block 2425). If the phase shift is present, the data is processed, for example by applying
one or more inversion techniques appropriate to unconventional formations to extract formation
parameters (block 2430).
[0058] In one embodiment, shown in Fig. 25, the control module 602 (Fig. 6) is controlled by software
in the form of a computer program on a non-transitory computer readable media 2505, such as a CD, a
DVD, a USB drive, a portable hard drive or other portable memory. In one embodiment, a processor
2510, which may be the same as or included in the control module 602, reads the computer program
from the computer readable media 2505 through an input/output device 25 15 and stores it in a memory
2520 where it is prepared for execution through compiling and linking, if necessary, and then executed.
In one embodiment, the system accepts inputs through an input/output device 2515, such as a keyboard
or keypad, mouse, touchpad, touch screen, etc., and provides outputs through an input/output device
251 , such as a monitor or printer. In one embodiment, the system stores the results of calculations in
memory 2520 or modifies such calculations that already exist in memory 2520.
[0059] In one embodiment, the results of calculations that reside in memory 2520 are made available
through a network 2525 to a remote real time operating center 2530. In one embodiment, the remote
real time operating center 2530 makes the results of calculations available through a network 2535 to
help in the planning of oil wells 2540 or in the drilling of oil wells 2540.
[0060] The word "coupled" herein means a direct connection or an indirect connection.
[0061] The text above describes one or more specific embodiments of a broader invention. The
invention also is carried out in a variety of alternate embodiments and thus is not limited to those
described here. The foregoing description of an embodiment of the invention has been presented for
the purposes of illustration and description. It is not intended to be exhaustive or to limit the invention
to the precise form disclosed. Many modifications and variations are possible in light of the above
teaching. It is intended that the scope of the invention be limited not by this detailed description, but
rather by the claims appended hereto.

What is claimed is:
1. A method comprising:
obtaining signal measurements collected by azimuthally sensitive electromagnetic logging
tool as a function of position in a borehole;
using the signal measurements to identify a type of formation model;
applying an inversion technique appropriate to the type of formation model to the set of
signal measurements to determine a geophysical property; and
using the geophysical property to make a decision regarding drilling a well.
2 . The method of claim 1, wherein obtaining signal measurements comprises obtaining at
a plurality of positions in the borehole, where bί is an azimuthal direction from which the
electromagnetic logging tool obtains the signal measurements.
3 . The method of claim 1, wherein using the signal measurements to identify a type of formation
model comprises:
decoupling a signal, having a real part that varies with azimuth and an imaginary part that
varies with azimuth, from the signal measurements;
determining that a phase shift exists between the real part of the signal and the imaginary
part of the signal and, as a result, identifying the type of formation model as an
unconventional formation model.
4 . The model of claim 3, wherein decoupling the signal comprises:
decoupling a double frequency signal; and
decoupling a single frequency signal;
wherein the double frequency signal has twice the periods of the single frequency signal in
360° of azimuth.
5 . The model of claim 3, wherein applying the inversion technique appropriate to the type of
formation model comprises:
applying an inversion technique appropriate to an unconventional formation model.
15
RECTIFIED (RULE 91) - ISA/US
6 . The model of claim 1, wherein obtaining signal measurements comprises:
equipping the electromagnetic logging tool with A tilted transmitters and B tilted receivers,
A+B = 3, the tilted transmitters and tilted receivers being oriented to a same tool
azimuth angle; and
transmitting and receiving signals having multiple frequencies through the tilted
transmitters and tilted receivers.
7 . The model of claim 1, wherein obtaining signal measurements comprises:
equipping the electromagnetic logging tool with A tilted transmitters and B tilted receivers,
A+B > 3, at least one of the tilted transmitters and tilted receivers being oriented to
a different tool azimuth angle than the tool azimuth angles to which the other tilted
transmitters and tilted receivers are oriented; and
transmitting and receiving signals having at least a single frequency through the tilted
transmitters and tilted receivers.
8. A computer program stored in a non-transitory computer readable storage medium, the program
comprising executable instructions that cause a computer to:
obtain signal measurements collected by azimuthally sensitive electromagnetic logging
tool as a function of position in a borehole;
use the signal measurements to identify a type of formation model;
apply an inversion technique appropriate to the type of formation model to the set of signal
measurements to determine a geophysical property; and
use the geophysical property to make a decision regarding drilling a well.
9 . The computer program of claim 8, wherein, when obtaining signal measurements, the computer
obtains at a plurality of positions in the borehole, where bί is an azimuthal direction from
which the electromagnetic logging tool obtains the signal measurements.
16
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10. The computer program of claim 8, wherein, when using the signal measurements to identify a
type of formation model, the computer:
decouples a signal, having a real part that varies with azimuth and an imaginary part that
varies with azimuth, from the signal measurements; and
determines that a phase shift exists between the real part of the signal and the imaginary
part of the signal and, as a result, identifies the type of formation model as an
unconventional formation model.
11. The computer program of claim 10, wherein, when decoupling the signal, the computer:
decouples a double frequency signal; and
decouples a single frequency signal;
wherein the double frequency signal has twice the periods of the single frequency signal in
360° of azimuth.
12. The computer program of claim 10, wherein, when applying the inversion technique
appropriate to the type of formation model, the computer:
applies an inversion technique appropriate to an unconventional formation model.
13. The computer program of claim 8, wherem:
the electromagnetic logging tool is equipped with A tilted transmitters and B tilted
receivers, A+B = 3, the tilted transmitters and tilted receivers being oriented to a
same tool azimuth angle, and, when obtaining signal measurements, the computer:
transmits and receives signals having multiple frequencies through the tilted
transmitters and receivers.
14. The computer program of claim 8, wherein:
the electromagnetic logging tool is equipped with A tilted transmitters and B tilted
receivers, A+B > 3, at least one of the tilted transmitters and tilted receivers being
oriented to a different tool azimuth angle than the tool azimuth angles to which the
other tilted transmitters and tilted receivers are oriented, and, when obtaining signal
measurements, the computer:
transmits and receives signals having at least a single frequency through the tilted
transmitters and receivers.
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15. An apparatus comprising:
a plurality of antennas mounted in a tool housing; and
a processor to:
obtain signal measurements collected by the plurality of antennas as a function of
position in a borehole;
use the signal measurements to identify a type of formation model;
apply an inversion technique appropriate to the type of formation model to the set
of signal measurements to determine a geophysical property; and
use the geophysical property to make a decision regarding drilling a well.
16. The apparatus of claim 15, wherein the plurality of antennas comprises:
A tilted transmitters and B tilted receivers, A+B = 3, the tilted transmitters and tilted
receivers being oriented to a same tool azimuth angle.
17. The apparatus of claim 16, further comprising:
a transmitter for transmitting multiple frequencies through the tilted transmitters; and
a receiver for receiving the multiple frequencies through the tilted receivers.
18. The apparatus of claim 1 wherein the plurality of antennas comprises:
A tilted transmitters and B tilted receivers, A+B > 3, at least one of the tilted transmitters
and tilted receivers being oriented to a different tool azimuth angle than the tool
azimuth angles to which the other tilted transmitters and tilted receivers are
oriented.
1 . The apparatus of claim 18, further comprising:
a transmitter for transmitting signals having at least a single frequency through the tilted
transmitters; and
a receiver for receiving signals having at least the single frequency through the tilted
receivers.