US 5,838,633 AGranted

Method for estimating formation in-situ stress magnitudes using a sonic borehole tool

AssigneeSchlumberger Technology Corporation

InventorBikash K. Sinha

Life of this patent

Estimating the term…

Loading patent…

Abstract

A method of estimating formation in-situ stress magnitude and nonlinear constants of an earth formation traversed by a borehole includes analyzing the flexural wave dispersions for dipole sources aligned parallel and perpendicular to the maximum far-field compressive stress direction together with the Stoneley wave dispersion derived from a monopole source. In the presence of formation and borehole stresses above and beyond those in an assumed isotropic reference state, the borehole flexural and Stoneley wave velocity dispersions are also functions of the formation stresses and nonlinear constants. A multi-frequency inversion of the flexural or Stoneley wave velocity dispersions over a selected frequency band is performed to determine the uniaxial stress magnitude S and the quantities ##EQU1## where c.sub.111, c.sub.112, and c.sub.123 are the formation non-linear constants.

Claims4

Dependent claims

A method of estimating in-situ stress magnitude of an earth formation traversed by a borehole containing borehole fluid by utilizing a sonic logging tool having a monopole source, a plurality of dipole sources, and a plurality of sonic detectors, said method comprising:

a) generating a relatively low frequency signal and a relatively high frequency signal with at least one source;
b) detecting the slow flexural, fast flexural, and Stoneley wave arrivals at the detectors for the relatively low frequency signal and the relatively high frequency signal;
c) determining the Stoneley wave velocity as a function of frequency;
d) determining the azimuthal orientation of the maximum velocity of at least one of the slow and fast flexural wave arrivals for at least one of the relatively low frequency signal and the relatively high frequency signal;
e) determining the velocities of the slow and fast flexural waves, as a function of frequency, for the relatively low frequency signal and for the relatively high frequency signal at the determined azimuthal orientation and at an orientation normal thereto;
f) associating formation anisotropy with stress in the formation if, at the determined azimuthal orientation, the velocity of the fast flexural wave for one of the relatively high frequency signal and the relatively low frequency signal is greater than the velocity of the slow flexural wave, and at the orientation normal to the determined azimuthal orientation, for the other of the relatively high frequency signal and relatively low frequency signal, the velocity of the fast flexural wave is greater than the velocity of the slow flexural wave;
and, if formation anisotropy is associated with stress in the formation;
g) selecting a reference state velocity;
h) determining a velocity change, B, due to uniaxial stress, at a plurality of discrete frequencies;
and
i) determining the stress magnitude and a plurality of non-linear formation parameters according to the equation:
A.sub.1 S+A.sub.2 Sc.sub.111 /c.sub.66 +A.sub.3 Sc.sub.112 /c.sub.66 +A.sub.4 Sc.sub.123 /c.sub.66 =B,
where A.sub.1, A.sub.2, A.sub.3, A.sub.4, and B are functions of frequency, c.sub.66 is the formation shear modulus in the reference state, and A.sub.1, A.sub.2, A.sub.3, and A.sub.4 are frequency dependent sensitivities of flexural wave velocities to S, Sc.sub.111 /c.sub.66, Sc.sub.112 /c.sub.66, and Sc.sub.123 /c.sub.66, respectively.

10 more elements

a) generating a relatively low frequency signal and a relatively high frequency signal with at least one source;
b) detecting the slow and fast flexural wave arrivals at the detectors for the relatively low frequency signal and the relatively high frequency signal;
c) determining the tube wave velocity;
d) determining the azimuthal orientation of the maximum velocity of at least one of the slow and fast flexural wave arrivals for at least one of the relatively low frequency signal and the relatively high frequency signal;
e) determining the velocities of the slow and fast flexural waves for the relatively low frequency signal and for the relatively high frequency signal at the determined azimuthal orientation and at an orientation normal thereto;
f) associating formation anisotropy with stress in the formation if, at the determined azimuthal orientation, the velocity of the fast flexural wave for one of the relatively high frequency signal and the relatively low frequency signal is greater than the velocity of the slow flexural wave, and at the orientation normal to the determined azimuthal orientation, for the other of the relatively high frequency signal and relatively low frequency signal, the velocity of the fast flexural wave is greater than the velocity of the slow flexural wave;
and, if formation anisotropy is associated with stress in the formation,
g) selecting a reference state value for a plurality of formation parameters;
h) determining the stress magnitude and a plurality of nonlinear formation parameters using the plurality of formation parameters and conducting an inversion according to AX=B where ##EQU21## where V.sub.12 is the slow flexural wave velocity, V.sub.13 is the fast flexural wave velocity, V.sub.TS is the tube wave velocity determined in step (c), and the formation parameters include at least .rho..sub.f, the borehole fluid density, .rho..sub.s, the formation mass density, V.sub.S, the shear wave speed, V.sub.T, the tube wave speed, and .sigma., the Poisson ratio.

6 more elements

Dependencies are inferred from the claim text.