Nonlinear Seismic Imaging, Inc.

Western Atlas International, Inc.

Geosource, Inc.

Other

Halliburton Geophysical Services, Inc.

Tawassul Ali Khan

Walter R Turpening

Yu Taik Chon

Sofia Khan McGuire

David F Kratochvil

Sofia Khan

B Leon Edington

Michel P Moesse

A monofrequency signal is used to record signature properties of subsurface reservoir formations. While recording conventional Vibroseis data after certain prescribed distances, the monofrequency signal is transmitted to evaluate the presence of reservoir rocks underneath that source location. When a compressional wave travels through a permeable and fluid-saturated reservoir formation, the Drag Wave travels through reservoir fluid interconnections at a slower velocity than the compressional wave in the rock matrix. Due to the Doppler Effect, a unique lower frequency is generated. This lower frequency becomes an indicator of the presence of reservoir formations. Its character depends on the tortuosity of pore interconnections, presence of pore fluids, and permeability. A transfer function is calculated to convert the swept frequency signal used for conventional seismic recording. This converted swept frequency signal is cross-correlated with the normally recorded signal. Only the presence of the reservoir formation is highlighted; non-reservoir formations are not displayed.

Direct reservoir signature using the drag wave

Permeability is one of the most important factors in influencing the commercial viability of a hydrocarbon reservoir. So far, permeability cannot be measured directly in-situ in reservoir formations. This invention relates to the field of estimating in-situ permeability of the reservoir rock formations. The measurements can be made across two wells or in a single well. Due to the morphology of their pore interconnections and the pore fluids in the rock, permeable rocks are elastically nonlinear. In a permeable rock, which is elastically nonlinear, the interactions between two elastic waves can be used in a unique way to map its physical properties. In this invention, the interaction of an elastic wave generated within the permeable rock with an externally generated seismic signal is used to determine the bulk tortuosity and bulk permeability of a reservoir rock formation.

Mapping permeable reservoir formations by measuring the elastic nonlinear interactions of a seismic wave as it propagates through the reservoir rock matrix and its pore fluids

Elastic nonlinear effects, which cause frequency spectral broadening and the effects of the presence of the Slow-Wave in the reservoir rocks, are investigated. The creation of new frequencies due to elastic nonlinearity of the reservoir rocks and their presence in the reflected seismic signals is used to map the location and extent of the reservoir formations. The large differences in the velocities of the Compressional Wave and the Slow-Wave cause changes in their reflection and refraction characteristics. The reflection due to Slow-Wave appears as a low-frequency artifact, delayed in time. The delay time of this artifact is used to calculate the Slow-Wave velocity and the tortuosity of the reservoir rocks. Based on the tortuosity and the wellbore data, permeability can be estimated.

Mapping reservoir rocks using frequency spectral broadening and the presence of the slow-wave

A method for determining the location and the orientation of the open natural fractures in an earth formation from the interaction of the two seismic signals, one signal transmitted into the formation from one wellbore and the second signal transmitted from the surface of the earth, the interaction of the two seismic signals as they simultaneously propagate through the fractured space is recorded in the second wellbore. The seismic signal transmitted from the surface is a lower frequency acoustic pulse of large amplitude identified as 'modulation' wave and the signal transmitted from the wellbore is a higher discrete frequency seismic signal, identified as 'carrier' wave. The interaction of the &lsquo;carrier&rsquo; wave during the compression and rarefaction cycles of the &lsquo;modulation&rsquo; signal is recorded. By subtracting the &lsquo;carrier&rsquo; from the interaction signal, the &lsquo;modulation-pulse&rsquo;, which represents the arrival time of the surface generated acoustic pulse, from the surface source to the subsurface fractures is extracted. By plotting the arrival times and the relative amplitudes of the &lsquo;modulation-pulse&rsquo;, the orientation and the location of the open fractures is determined.

Mapping subsurface open fractures in a reservoir using a surface impulse and a downhole vibratory source

This invention relates to mapping the open fractures in the reservoir subsurface formations. To map these open fractures, the elastically nonlinear interaction of the two surface generated seismic waves, as they propagate through the open fractures and are reflected back from the subsurface boundaries, is recorded using conventional 3-D seismic receiver configurations. Recorded data are processed for standard 3-D reflection imaging and additionally for mapping the location and orientation of the subsurface open fractures.

Mapping subsurface open fractures using elastically nonlinear interaction of two surface-generated waves

This invention relates to mapping the hydrocarbon reservoir characteristics by mapping the reservoir formations that display dynamic elastic nonlinearity responses to the seismic signals. The main reason of this nonlinear behavior in the reservoir rocks is their bulk rock property: the porosity, fractures, differential pressure and pore saturation. To map these bulk rock properties, the interaction of the two seismic waves as they propagate through elastically nonlinear rocks is recorded. Two compressional seismic signals are transmitted from the surface. Seismic reflection data using surface or borehole detectors are recorded. One of the transmitted signals is a conventional swept frequency and the other is a mono-frequency signal. During the propagation of these two signals through the elastically nonlinear reservoir rocks, there is an interaction between the two signals. The sum and difference frequencies of the two primary seismic signals that were transmitted from the surface are created. These new frequencies constitute an 'interaction' wave that travels along with the two primary waves. In this invention, the 'interaction' signal created by the two seismic waves as they propagate through the reservoir rocks is separated from the primary signals and used to map the reservoir rocks that exhibit elastic nonlinearity due their bulk rock properties. The cross-correlation of the recorded data with the swept frequency signal provides a conventional seismic data set that is used for normal 2-D or 3-D seismic processing. The cross-correlation of the recorded data with the summed and differenced signals provides two sets of data that represent the seismic reflected image from the subsurface nonlinear formations.

Mapping reservoir characteristics using earth's nonlinearity as a seismic attribute

This invention relates to using elastically nonlinear seismic imaging methods, to identify the bypassed hydrocarbons and the movement of the reservoir fluids in the reservoir due to injection and production processes. Time-lapse seismic recording is used to monitor the changes in the hysteretic nonlinear behavior of the pore fluids in the reservoir rocks. Since the nonlinear hysteretic behavior of the saturated reservoir rock generates harmonics of the primary seismic signal that propagates through it, the measurement of these harmonics is used to determine the changes in the reservoir fluids due to hydrocarbon production over time.

Time-lapse seismic using nonlinear seismic imaging

This Patent describes a method for determining the location and orientation of the open natural fractures in an earth formation by analyzing the interaction of the two seismic signals. One is a low frequency signal transmitted from the earth's surface and the other a high frequency signal transmitted from a wellbore. The compressional and the rarefaction cycles of the lower frequency signal are used to modulate the width of the open fractures, which changes their transmission characteristics. As a result, the amplitude of the high frequency signal gets modulated as it propagates through the open fractures. The result of the interaction of the high and low frequency seismic signals is recorded in another wellbore. The spectral analysis of the modulated signal that is recorded during compression and rarefaction cycles of the lower frequency surface generated signal is used to determine the location and the orientation of the open natural fractures.

Mapping subsurface fractures using nonlinearity measurements

A method for determining a degree of acoustic non-linearity of an earth formation from seismic signals transmitted into the formation from within one wellbore and received from the formation in another wellbore. The seismic signals include two selected discrete frequencies. The method includes spectrally analyzing the received signals, determining from the spectral analysis the presence of a frequency representing a sum of the two selected frequencies, and determining a relative amplitude of the sum frequency with respect to the amplitudes of the two selected discrete frequencies. In a particular embodiment, the method includes determining the presence of a frequency in the spectrally analyzed signals representing the difference between the selected discrete frequencies, and determining the presence of harmonic multiples of one of the two selected discrete frequencies.

Cross-well seismic mapping method for determining non-linear properties of earth formations between wellbores

A method of determining the continuity of earth formations between wellbores by analyzing seismic energy imparted to the formations. The energy is imparted to the formations at a plurality of depths in one wellbore and is received at a plurality of depths in another wellbore. Compressional and shear components of the seismic energy received in the other wellbore are separated. A frequency spectrum is determined for the compressional component and the shear component of the seismic energy at each selected depth. Common imparted depth stacks of the compressional components and shear components are assembled at the depths at which the seismic energy is imparted. Common received depth stacks of the compressional components and the shear components are assembled at the selected depths at which the energy is received. The assembled common imparted depth stacks of the compressional components and the shear components are plotted and the assembled common received depth stacks of the compressional components and shear components are plotted. Formations having related frequency spectra of the compressional components and formations having related frequency spectra of the shear components may be detected.

Cross-well connectivity mapping including separation of compressional

A method is provided for significantly reducing the distortion and crossfeed from any selected order harmonic for any number of vibratory seismic sources operated concurrently, at the same time providing for separation of the signals from the different sources and for improving the signal-to-noise ratio. After determining the highest order harmonic likely to cause distortion, a number of sweeps of each source in each position is selected. This number depends upon the number of sources and the highest order harmonic to be suppressed. Initial phase angles for each sweep of each source are then selected to permit signal separation while suppressing harmonics up to and including that highest order harmonic.

Method of source coding and harmonic cancellation for vibrational

A method of seismic exploration and a system which provides the capability for increasing the number of depth points from which seismic data are acquired are disclosed. This increase in data is realized without increasing the number of recording channels or the number of geophone stations employed in the system. A higher common depth point multiplicity is achieved by separating energy sources in relation to geophone stations. The recording system is capable of automatically sorting out the data from different energy sources and storing it in different blocks of a memory. Since substantially all available recording time is fully utilized by using energy sources to their optimum efficiency, higher common-depth-point multiplicity can be achieved with minimum field costs.

Weight-drop seismic exploration system

Apparatus is provided for determining the conformity of an energy pulse generated by a weight drop seismic source to a defined energy pulse characteristic in order that reflections associated with a non-conforming energy pulse can be rejected. The apparatus operates to compare the signature of a weight drop with a signature standard. Incoming seismic data is rejected and not recorded if the difference between the incoming signature pulse shape and the standard signature pulse shape is too great. The pulse shape of the incoming signature is analyzed by comparing a sample of the incoming signature amplitude to upper and lower rejection limits derived from a time correlated amplitude sample of the standard signature. The upper and lower rejection limits against which an incoming signature sample is compared are proportional to the amplitude of the time correlated standard signature sample. Each pair of upper and lower rejection limits is produced by multiplying each standard signature sample by a multiplier that is less than one for the lower limit and greater than one for the upper limit. The multiplication function is implemented by a sequential weighted adder. After a prescribed number of incoming signature samples have fallen outside the rejection limits, an indication that the energy pulse is bad is indicated.

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Cypress, TX, United States of America

Tawassul Ali Khan