Baker Hughes Oilfield Operations LLC

Baker Hughes, a Ge Compnay, LLC

Baoyan Li

Marc Stephen Ramirez

Elan Yogeswaren

Hasan Kesserwan

Joseph Olaiya

Guodong Jin

Alberto Mezzatesta

Julio Roberto Arro

Freddy Mendez

Douglas J Patterson

Roger Steinsiek

Holger Thern

Sushant Dutta

John F Priest

Wei Han

Peng Yuan

Sebastien Kamgang

Muhammad Abrar Manzar

Dalila Balmaceda

In at least one embodiment, a well inspection method and system is disclosed. The method includes transmitting an acoustic signal from a well inspection tool into a casing structure, receiving return signals from the casing structure to the well inspection tool, performing, using at least one processor associated with the well inspection tool, a Fast Fourier Transform (FFT) on a plurality of frequencies of the return signals to generate spectrogram data, determining entropy spectra from the spectrogram data, and determining casing loadings associated with the casing structure based at least in part on the entropy spectra.

Characterization system and method for casing loading using entropy analysis

A method and system to be used in well inspection. An acoustic signal is transmitted from a well inspection tool into a well structure and one or more return signals is detected using at least one receiver. At least one processor is used to generate variable density log (VDL) data that includes multiple waveforms in a time domain from the one or more return signals. A number of independent components to be used based on variances in the VDL data is determined and the multiple waveforms are decomposed into multiple components associated with one or more local structure variances of the well structure using independent component analysis (ICA) and the number of independent components. Characteristics of the well structure is determined based in part on patterns or features associated with one or more independent components from the multiple components.

System and method for diagnosing borehole structure variances using independent component analysis

Methods for determining properties of a media on an exterior of a casing in downhole systems are described. The methods include conveying a logging tool through a casing in a downhole formation, stimulating shear waves and flexural waves in the casing, obtaining a shear attenuation rate measurement and a flexural attenuation rate measurement within the casing responsive to the media on the exterior of the casing, comparing the measured shear attenuation rate and the measured flexural attenuation rate against a plurality of respective division boundary values, and determining one or more properties of the media on the exterior of the casing based on the comparison of the measured shear attenuation rate and the measured flexural attenuation rate against the plurality of respective interfaces.

Methodology for annular solids and fluids differentiation through integration of shear and flexural ultrasonic acoustic waves

In at least one embodiment, a well inspection method and system enables transmission of an acoustic signal from a well inspection tool into a well structure and reception of return signals from the well structure at an array of receivers on the well inspection tool. The method and system enable performing of Short-Term Fourier Transform (STFT) on the return signals to generate spectrogram data that is used to determine short-term power spectra of the return signals. Time-dependent frequency response and location-dependent waveform propagation patterns are identified from the short-term power spectra. Cement bonding conditions is determined based on pattern matching using the time-dependent frequency response patterns and using the location-dependent waveform propagation patterns.

Systems and methods for cement evaluation through tubing using short-term frequency responses

A method for determining a tubing deviation from nuclear measurement data includes acquiring neutron measurement data from a wellbore. The method also includes identifying one or more features from the neutron measurement data. The method further includes determining, based at least in part on a pattern matching algorithm, that the one or more features are indicative of a tubular deviation. The method also includes determining, based at least in part on a comparison between the one or more features, a deviation amount.

Systems and methods for determining tubing deviations

A method for characterizing a bond between a first tubular disposed in a borehole and a structure outside of the tubular, the method includes transmitting a signal into and through the first tubular using a signal transmitter conveyed through the borehole and detecting a return signal using a return signal receiver conveyed through the borehole to provide return signal information in a time domain. The method also includes transforming the return signal information in the time domain to return signal information in a frequency domain using a transform and determining a difference between the return signal information in the frequency domain and reference frequency domain return signal information. The method further includes characterizing the bond of the first tubular to the structure outside of the first tubular using the difference to provide a characterization of the bond.

Quantifying cement bonding quality of cased-hole wells using a quality index based on frequency spectra

A method of estimating a wettability characteristic of a rock material includes acquiring a plurality of T2 distributions based on nuclear magnetic resonance (NMR) measurements of a rock material under a plurality of fluid saturated rock conditions, constructing a measurement matrix based on the plurality of T2 distributions, and performing non-negative factorization of the measurement matrix to determine feature components. The method also includes reconstructing the plurality of T2 distributions based on the feature components, and extracting a first set of T2 distributions associated with mobile water under a wetting condition and a second set of T2 distributions associated with mobile water under a non-wetting condition based on the feature components, and calculating a wettability index (WI) based on the first extracted set of T2 distributions and the second extracted set of T2 distributions.

Wettability estimation using T2 distributions of water in wetting and non-wetting phases

A method of estimating properties of a resource bearing formation includes receiving, by a processor, a measured echo train generated by a nuclear magnetic resonance (NMR) measurement device deployed in a region of interest, and a measured noise of the measured echo train, and calculating a Tdistribution subject to a nonlinear equality constraint, the nonlinear equality constraint dependent on the measured noise and a fitting error between the measured echo train and a modeled echo train. Calculating the Tdistribution includes estimating a solution for the Tdistribution that is closest to satisfying the nonlinear equality constraint.

Inversion of NMR echo trains using a supplementary nonlinear equality constraint

A method for transforming an earth formation and/or production equipment based on correcting nuclear magnetic resonance (NMR) data to account for partially water-saturated rock includes: receiving NMR logging data having echo-trains for an earth formation; inverting the echo-trains to provide transverse relaxation time constant (T) distributions for various components of fluid in the earth formation; substituting a Tdistribution for mobile water of fully water-saturated rock for a Tdistribution for mobile water of partially water-saturated rock based on values of the mobile water Tdistribution of partially water-saturated rock and a total porosity constraint; summing the Tdistribution for mobile water of fully water-saturated rock and a Tdistribution for an immobile water component of the fluid to provide a T, distribution for fully water-saturated rock; and transforming the earth formation and/or the production equipment based on a parameter derived from the Tdistribution for fully water-saturated rock.

Fluid substitution method for T2 distributions of reservoir rocks

A method for estimating liquid and vapor molar fraction of components, liquid mole fraction, vapor mole fraction, liquid saturation, and vapor saturation of a mixture of hydrocarbons in nano-pores in an earth formation includes: constructing an equation of state (EOS) representing the mixture hydrocarbons in the nano-pores in the earth formation; the EOS having a term accounting for capillary pressure in the nano-pores. The method further includes inputting a composition of the mixture of hydrocarbons, a phase pressure of the hydrocarbons and a pore size distribution of the earth formation into the EOS and solving the EOS and to estimate the liquid and vapor molar fraction of components, liquid mole fraction, vapor mole fraction, liquid saturation, and vapor saturation of the mixture of hydrocarbons in the nano-pores in the earth formation.

Method to estimate the influence of pore-size distribution on phase equilibrium of multi-component hydrocarbon systems in unconventional shale gas and oil reservoirs

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Tomball, TX, United States of America

Baoyan Li