Elastic Impedance Research Articles

Shale rocks brittleness index prediction method using extended elastic impedance inversion

In unconventional shale oil and gas exploration, the brittleness characteristics of rock not only greatly affect the fracturing effect of horizontal wells, but also one of the important evaluation parameters for shale oil and gas “sweet spots” prediction. However for pre-stack seismic inversion, due to the poor reliability of large offset seismic data, the reliability of inverted density parameter is lower.At the same time, it is difficult to establish an accurate initial model of seismic attributes. Both of the aspects above limits the wide application of pre-stack seismic inversion methods for the brittleness prediction at the beginning of the exploration. The Extended Elastic Impedance (EEI) inversion method is developed on the basis of conventional AVO theory. This method can make full use of the information of pre-stack seismic data, and also there is no need to establish an initial model of the elastic parameters. It can directly invert the rock elastic parameters such as acoustic impedance, P-velocity to S-velocity ratio, rock density, Poisson's ratio and Young's modulus. This method also has great application potential for the prediction of rock brittleness index. This paper first introduces the EEI inversion method and key technologies. And the feasibility of applying EEI to predict rock brittleness index is analyzed. Then it was applied to the evaluation of the brittleness of the shale reservoir of the Songliao Basin and the prediction is consistent with the actual drilling results.

Characterizing complex slope channel reservoirs applying extended elastic impedance, Saffron gas field, offshore Nile Delta, Egypt

In a complex reservoir with a significant degree of heterogeneity, it is a challenge to characterize the reservoir using different seismic attributes based on available data within certain time constraints. Prestack seismic inversion and amplitude variation with offset are among the techniques that give excellent results, particularly for gas-bearing clastic reservoir delineation because of the remarkable contrast between the latter and the surrounding rocks. Challenges arise when a shortage of seismic or well data presents an obstacle in applying these techniques. A further challenge arises if it is necessary to predict water saturation (Sw) using the seismic data because of the independent nonlinear relationship between Sw and seismic attributes and inversion products. Prediction of Sw is necessary not only for characterizing pay from nonpay reservoirs but also for economic reasons. Therefore, extended elastic impedance has been performed to produce a 3D volume of Sw over the reservoir interval. Then, a 3D sweetness volume and spectral decomposition volumes were used to grasp the geometry of the sand bodies that have been charged with gas in addition to their connectivity. This could help illustrate the different stages in the evolution of the Saffron channel system and the sand bodies distribution, both vertically and spatially, and consequently increase production and decrease development risk.

Amplitude Variation with Angle Inversion for New Parameterized Porosity and Fluid Bulk Modulus

Estimating porosity and fluid bulk modulus is an important goal of reservoir characterization. Based on the model of fluid substitution, we first propose a simplified bulk modulus of a saturated rock as a function of bulk moduli of minerals and fluids, in which we employ an empirical relationship to replace the bulk modulus of dry rock with that of minerals and a new parameterized porosity. Using the simplified bulk modulus, we derive a PP-wave reflection coefficient in terms of the new parameterized porosity and fluid bulk modulus. Focusing on reservoirs embedded in rocks whose lithologies are similar, we further simplify the derived reflection coefficient and present elastic impedance that is related to porosity and fluid bulk modulus. Based on the presented elastic impedance, we establish an approach of employing seismic amplitude variation with offset/angle to estimate density, new parameterized porosity, and fluid bulk modulus. We finally employ noisy synthetic seismic data and real datasets to verify the stability and reliability of the proposed inversion approach. Test on synthetic seismic data illustrates that the proposed inversion approach can produce stable inversion results in the case of signal-to-noise ratio (SNR) of 2, and applying the approach to real datasets, we conclude that reliably results of porosity and fluid bulk modulus are obtained, which is useful for fluid identification and reservoir characterization.

Nonlocal thermodynamic response of thermal insulation layer–substrate wall system considering the temperature-dependent thermal material properties

Changes of the insulation performance and deformation characteristics caused by temperature in the external thermal insulation system (ETICS) have a significant influence on its energy-saving effect. In this paper taking into account the temperature-dependence thermal material properties, the thermal contact resistance at the interface, and the elastic wave impedance, a bilayered structure model for insulation layer and the wall was established to study the nonlocal thermodynamic response. Based on the fractional order generalized thermoelasticity theory and introduced nonlocal dimension parameters, the solutions for insulation layer surface under harmonic temperature load were obtained. The effects of thermal contact resistance, nonlocal factor and fractional order parameter on the temperature, stress and displacement of the ETICS were analyzed. The results can provide theoretical support for solving the problem of deformation of the interface between the insulation layer and the wall.

Seismic reservoir characterization of Bentheimer sandstone, Emlichheim oil field, Lower Saxony, Germany

Even in mature oil and gas provinces, unexpected subsurface complexity may challenge budgeted seismic reservoir characterization workflows to become adapted to a higher degree of customization during data preconditioning. In the process of providing a trend cube of sandstone porosity and automatic fault extraction to populate the property distribution and structural framework of a static model over the mature Emlichheim oil field, northwest Germany, many unforeseen data quality issues are encountered that necessitate rigorous well log and seismic data conditioning prior to analysis and interpretation. Specifically, insufficient noise suppression, ambiguous wireline log responses, missing curve log data, noncompliant amplitude-versus-angle gathers, and inadequate compensation of velocity anisotropy need to be addressed. These topics pose serious challenges to automatic fault extraction, seismic attribute analysis, machine learning, artificial neural network technology, the selected inversion method, Bayesian lithology prediction, and fuzzy math to transform elastic impedances into reservoir porosity. Application of multiple inversion methods generates the individual components of new earth models (sand geobodies, alternative elasticity-to-porosity transforms, etc.) that are used for advanced porosity modeling. This new information allows to update the existing static models of a mature oil field.

Estimation of subsurface rock properties from seismic inversion and geo-statistical methods over F3-block, Netherland

Seismic inversion methods are routinely used to estimate attributes such as P-impedance, S-impedance, density, P-wave and S-wave velocity, and elastic impedances from seismic and well log data. These attributes help to understand subsurface lithology and fluid content. There are several types of seismic inversion methods available in which model-based inversion has got more attention. In the present study, the model-based inversion and geostatistical methods namely probabilistic neural network (PNN), multi-layer feed-forward neural network (MLFN) and radial basis function neural network (RBFNN) are implemented to estimate acoustic impedance, porosity, density, gamma-ray volume and P-wave velocity in the inter-well region of the F-3 block, Netherlands. The aim of the study is to predict a number of petrophysical parameters and demonstrate how they can be used to interpret seismic reflection data. A comparative study is also performed to estimate the best suitable method to predict various petrophysical parameters. The assessment of inverted results demonstrates that the impedance in the region varies from 2550 m/s*g/cc to 6150 m/s/*g/cc, which is relatively low and indicates the presence of loose formation in the area. The correlation between synthetic seismic trace and initial seismic trace is estimated to be 0.98, and the synthetic relative error as 0.19, indicating excellent algorithm output. Further, the assessment of the geostatistical methods is carried out to predict petrophysical parameters in conjunction with Multi-Attribute Transform Analysis. The analysis shows that among the geostatistical methods, the PNN provides slightly better results. The petrophysical parameters that are estimated in this study are porosity, density, gamma-ray, and P-wave velocity volumes. These parameters reinforce the interpretation of seismic data, which is a significant step in any project of exploration and production. The technique is first implemented to the composite traces near to the well location, and the findings are analysed with well log data. Second, the entire seismic section is inverted for porosity, density, gamma-ray, and P-wave velocity after achieving satisfactory outcomes in the first step. The assessment demonstrates very high-resolution subsurface petrophysical parameters which strengthen the seismic data interpretation.

Reservoir characterization of gas saturated sandstone using Extended Elastic Impedance (EEI), Poisson Impedance (PI) and Curved Pseudo Elastic Impedance (CPEI)

The WR field in this study is a gas hydrocarbon proven field with high saturation rate and reservoir character in tight sandstone. There are prestack 3D seismic data and three well data that have P-wave velocity (Vp) and S-wave velocity (Vs). In its development there are three kind of methods using Vp, Vs, and angle function constants that is Extended Elastic Impedance (EEI), Poisson Impedance (PI), and Curved Pseudo Elastic Impedance (CPEI). By using correlation coefficient concept between two kinds of variable, we can look for the angle function constants which used in those three methods. The results obtained from those three methods correlated with lithology log data (Gamma ray (GR)) at the range of angle (-90° to 90°) is EEI = 30°, PI = 59° and CPEI = -69°, whereas with fluid log target (Water Saturation (SW)) obtained angle values correlated with EEI = 20°, PI = 51° and CPEI = -60°. The highest correlation to the target lithology (GR) and fluid (SW) log data of the three methods is CPEI with correlation 0.881 for lithology and 0.604 for fluid. The vertical of the three methods shows a good reservoir character with high saturation rate of gas. The result of the lateral distribution of the three methods shows the character of the depositional environment in the target reservoir located in the estuarine environment in upper shoreface facies for Reservoir A and transition facies for Reservoir B. The direction trend of the source of the sedimentary sediment is the south-east direction, and this result fits with the regional geological concept in the WR field.

Identifying Gas-bearing Carbonate Reservoir Using Extended Elastic Impedance

It is difficult to identify the carbonate reservoirs by using conventional seismic reflection data, especially in cases where the reflection coefficient of the gas-bearing zone is close to that of the carbonate background. In such cases, the extended elastic impedance (EEI) as a seismic reconnaissance attribute with the ability to predict fluids and lithology can be used. It allows for a better distinction between seismic anomaly caused by lithology and the one caused by the fluid content. The EEI attribute extends the available reflection angles and applies different weights to the intercept and gradient values so as to extract the petrophysical properties of the rock at a specific incident angle. Using the EEI attribute, we can estimate the elastic parameters such as shear impedance; the ratio of the compressional velocity to shear velocity; Poisson’s ratio; and bulk, Lame, and shear moduli, and petrophysical properties, including porosity, clay content, and water saturation. The known reservoirs in the study area are three oil-bearing formations namely, Surmeh (Arab), Gadvan (Buwaib), and Dariyan (Shuaiba), and three gas-bearing formations, including Kangan, Dalan, and Faraghan. The Dehram group is composed of Kangan (Triassic), Dalan, and Faraghan (Permian) formations. Permian carbonates of Kangan–Dalan and its equivalent Khuff have regionally been developed as a thick carbonate sequence in the southern Persian Gulf region. In this paper, parameters 𝜆𝑝 and 𝜇𝜌 extracted from the EEI method are used to characterize a carbonate reservoir. Our results show that the EEI can highlight the difference between the reservoir and non-reservoir formation to identify the gas-bearing areas.

Quantitative Reservoir Characterization of Tight Sandstone Using Extended Elastic Impedance

Quantitative inversion of reservoir properties plays a crucial role in the efficient development of tight sandstone reservoirs. Based on the theories of statistical rock physics and extended elastic impedance (EEI), a complete workflow for quantitative prediction of reservoir properties is developed and the key steps thereof are provided here. The square of S-velocity to P-velocity ratio (K), which is consistent with geological setting of a study area, is obtained from statistics of well data, the value of angle $$\chi$$ most relevant to lithology and porosity is produced automatically by evaluating correlations of reservoir parameters with EEI, and the formulas that fit EEI with clay volume and with porosity are obtained. Then, angle $$\chi$$ is applied to relevant EEI reflection coefficient data from amplitude variation with offset attribute cubes, the EEI related to clay volume and porosity is obtained through model-based constrained inversion on these data cubes, fitting formulas from well analysis are used to convert EEI data cubes to clay volume and porosity data cubes, and finally, the parameters of a tight sandstone reservoir are predicted quantitatively. The prediction results are consistent with production data from existing wells, indicating that the method proposed here is reliable.

Seismic Frequency Component Inversion for Elastic Parameters and Maximum Inverse Quality Factor Driven by Attenuating Rock Physics Models

Attenuation exists in seismic wave propagation in subsurface layers, and relatively high attenuation occurs in oil-bearing reservoirs. Inversion of frequency components of observed seismic data generates values of attenuation factor 1/Q, which produces potential results for determining oil-bearing reservoirs. Beginning with expressions of seismic wave velocity in attenuating media, we involve P-wave maximum attenuation factor to rewrite P-wave velocity driven by an attenuating rock physics model, and we also employ an empirical relationship between P-wave attenuation factor and S-wave attenuation factor to express S-wave velocity in terms of P-wave maximum attenuation factor. Using the derived P- and S-wave velocities, we extend Zoeppritz equations to compute reflection coefficient for an interface separating two attenuating media. Under the assumption that contrasts in elastic properties of two media across the interface are small and the background attenuation is weak, we propose a linearized reflection coefficient of PP-wave as a function of contrasts in elastic parameters (i.e., P-wave velocity, S-wave velocity and density) and attenuation factor, and expression of elastic impedance (EI) is also presented. Based on the EI, we demonstrate an approach of estimating elastic parameters and attenuation factor from frequency components of partially incidence-stacked seismic data, which is implemented as a two-step inversion involving the prediction of EI datasets using a model-based damping least-squares algorithm and nonlinear inversion for elastic parameters and attenuation factor. Noisy synthetic seismic data generated using the extended Zoeppritz equations are employed to verify the robustness and stability of the proposed inversion approach. Applying the proposed approach to a real dataset acquired over an oil-bearing reservoir, we obtain convincing results of P-wave velocity, S-wave velocity, density and attenuation factor, which can reasonably match corresponding well log data.

Inversion of differences in frequency components of azimuthal seismic data for indicators of oil-bearing fractured reservoirs based on an attenuative cracked model

Based on a model of attenuative cracked rock, we have derived a simplified and frequency-dependent stiffness matrix associated with (1) a rock volume containing aligned and partially saturated cracks and (2) a new indicator of oil-bearing fractured reservoirs, which is related to pressure relaxation in cracked rocks and influenced by fluid viscosity and saturation. Starting from the mathematical form of a perturbation in this stiffness matrix across a reflecting interface separating two attenuative cracked media, we set up a linearized P-wave to P-wave reflection coefficient as an azimuthally and frequency-dependent function of dry rock elastic properties, dry fracture weaknesses, and the new indicator. By varying this reflection coefficient with azimuthal angle, we derive a further expression referred to as the quasidifference in elastic impedance, or [Formula: see text], which is primarily affected by the dry fracture weaknesses and the new indicator. An inversion approach is established to use differences in frequency components of seismic amplitudes to estimate these weaknesses and the indicator based on the derived [Formula: see text]. In synthetic inversion tests, we determine that the approach produces interpretable parameter estimates in the presence of data with a moderate signal-to-noise ratio (S/N). Testing on a real data set suggests that reliable fracture weakness and indicator are generated by the approach; fractured and oil-bearing reservoirs are identified through a combination of the dry fracture weakness and the new indicator.

Nonlinear inversion of seismic amplitude variation with offset for an effective stress parameter

Effective stress estimates play important roles in reservoir characterization, for instance, in guiding the selection of fracturing areas in unconventional reservoirs. Based on Gassmann’s fluid substitution model, we have set up a workflow for nonlinear inversion of seismic data for dry rock moduli, fluid factors, and a stress-sensitive parameter. We first make an approximation within the fluid substitution equation, replacing the porosity term with a stress-sensitive parameter. We then derive a linearized reflection coefficient as a function of a stress-parameter reflectivity and reexpress it in terms of elastic impedance (EI). An amplitude-variation-with-offset (AVO) inversion workflow is set up, in which the seismic data are transformed to EI, after stacking within five incidence angle ranges; these are then inverted to determine the stress-sensitive parameter. The two-step process involves two inversions with significantly different properties. The first is a model-based least-squares inversion to estimate EI; the second is a more complex nonlinear inversion of the EI for a set of unknowns including the stress-sensitive parameter. Motivated by an interest in hybridizing AVO and full-waveform inversion (FWI), we set the latter step up to resemble some features of a published AVO-FWI formulation. The approach is subjected to synthetic validation, which permits us to analyze the response and test the stability of the workflow. We finally apply the workflow to real data acquired over a gas-bearing reservoir, which reveals that the approach generates potential indicators of fluid presence and stress prediction.

The influence of metal cover plates on ballistic performance of silicon carbide subjected to large-scale tungsten projectile

Confined silicon carbide (SiC) plates covered with aluminium alloy, mild steel, and copper alloy materials of different elastic impedances were subjected to normal impact by blunt tungsten-heavy-alloy projectile of 16 mm diameter and 40 mm length, at a nominal striking velocity of 1.25 km/s. Failure analysis of the armour modules and penetration weight calculated by the measured residual penetration were applied to characterize ballistic performance of the ceramic armour modules. A simulation calculation was employed to investigate the inner impact process and the results corresponded well with the experimental ones. The damage initiation and propagation in ceramic, and the stress field distribution in the projectile were presented and analysed. The results showed that the cover plate can effectively reduce the damage of the target due to the extension of a dwell period compared with a ‘no cover’ structure. Low- elastic impedance material covers promote the impact stress distribution in ceramic leading to great improvement in ceramic ballistic performance. Moreover, the effect of cover material properties and energy dissipation at different impact periods was discussed.

Size-dependent mechanical-diffusion responses of multilayered composite nanoplates

ABSTRACT Multi-cell storage devices (e.g. lithium-ion batteries (LIBs)) stand as one of the most important components which are widely used in battery energy storage technology for renewable energy power system, hybrid electric vehicles and portable electronic devices due to its high energy density and low manufacturing cost. In recent years, there has been an explosion of developing new and multifunctional nanomaterials with particular interest to electrode nanomaterials (nano-MnO2, nano-LiMn2O4, etc.). In such case, size-dependent mechanical-diffusion responses analysis of multilayered composite nanostructure under non-uniform concentration in-service environment will become significantly important. To address the problem, a multilayered composite nanoplates account for diffusion impedance and elastic wave impedance at the interface is considered in this research. Governing equations involving with size-dependent characteristic lengths and material constant ratio of each two adjacent layers are formulated, and then, a semi-analytical approach via the Laplace transformation is applied. Then, the obtained solutions are applied to bilayered composite nanoplates, and the influences of size effects and material constants ratio on structural responses are emphatically discussed to provide guidelines on and new insights into the optimal design and management of mechanical responses and vibration control of nano-sized multi-cell storage devices under non-uniform concentration environment, especially for the nano-coating.

Characterization of sandstone reservoir field “Q” sub-basin Jambi using the extended elastic impedance seismic inversion method

The extended elastic impedance (EEI) inversion method is a seismic inversion technique that can optimally predict the character of a hydrocarbon reservoir using expansion of the incident angle from -90° to +90°. In the study of Field “Q” Sub–Basin Jambi, EEI was used to characterize a sandstone reservoir and predict the existence of gas or oil using the parameters Vp/Vs ratio, lambda–rho, and mu–rho. EEI was performed to determine the maximum correlation value at the optimum chi (χ) angle for each parameter specified by the correlation between the target logs and the EEI logs. The optimum chi (χ) angle was used to create a scaled volume reflectivity that was then used to make an initial model, which was required in the inversion process. Inversion was performed using a post–stack inversion–based model. The inversion results were then used to determine the spread of the reservoir, with the results indicating the possibility of a reservoir containing gas and oil. In this study, the Vp/Vs ratio ranged between 16 and 18, the mu–rho values ranged between 25 and 35 GPa*(g/cc), and the lambda–rho values ranged between 20 and 22 GPa*(g/cc) for gas and between 25 and 27 GPa*(g/cc) for oil.

Elastic-Impedance-Based Fluid/Porosity Term and Fracture Weaknesses Inversion in Transversely Isotropic Media with a Tilted Axis of Symmetry

The rock containing a set of tilted fractures is equivalent to a transversely isotropic (TTI) medium with a tilted axis of symmetry. To implement fluid identification and tilted fracture detection, we propose an inversion approach of utilizing seismic data to simultaneously estimate parameters that are sensitive to fluids and tilted fractures. We first derive a PP-wave reflection coefficient and elastic impedance (EI) in terms of the dip angle, fluid/porosity term, shear modulus, density, and fracture weaknesses, and we present numerical examples to demonstrate how the PP-wave reflection coefficient and EI vary with the dip angle. Based on the information of dip angle of fractures provided by geologic and well data, we propose a two-step inversion approach of utilizing azimuthal seismic data to estimate unknown parameters involving the fluid/porosity term and fracture weaknesses: (1) the constrained sparse spike inversion (CSSI) for azimuthally anisotropic EI data and (2) the estimation of unknown parameters with the low-frequency constrained regularization term. Synthetic and real data demonstrate that fluid and fracture parameters are reasonably estimated, which may help fluid identification and fracture characterization.

ANALISIS AMPLITUDE VERSUS OFFSET (AVO) MENGGUNAKAN PARAMETER PETROFISIKA LAMBDA MU RHO (LMR) DAN EXTENDED ELASTIC IMPEDANCE (EEI) UNTUK KARAKTERISASI RESERVOAR KARBONAT

The research that refers to the characterization of carbonate reservoir to identify lithology and fluid had been done to the Baturaja Formation in South Sumatera Basin. The method used is analyzed of Amplitude Versus Offset (AVO) by utilizing the petrophysics parameter of Lambda Mu Rho (LMR) and Extended Elastic Impedance (EEI). The goal of the research is to find out the comparison of the application of petrophysics parameter LMR and EEI to characterization carbonate reservoir, besides finding a prospect location or proposed well. The result of data analysis of Al-Fatah well shows that the carbonate reservoir position with liquefied gas is located deeper around 350 meters with a thickness of around 7.62 meters. Interpretation of seismic from inversion result by using the petrophysics parameter of LMR and EEI shows the presence of a prospect location to the CDP 4253 up to 4301, which is carbonate reservoir with fluid accumulation (gas).

Matrix-fluid-fracture decoupled-based elastic impedance variation with angle and azimuth inversion for fluid modulus and fracture weaknesses

The ratio of normal-to-shear fracture compliances, approximate to the product of two ratios of shear-to-compressional (S-to-P) wave velocity and normal-to-tangential fracture weakness, has been treated as an indicator of fluid content for an oil-bearing reservoir with aligned fractures. However, this indicator depends on both fluid saturation and fracturing strength of rocks, while the effective fluid bulk modulus as a sensitive indicator decouples the double effects of rock porosity and pore fluid. Moreover, an incorrect value of S- and P-wave velocity ratio may have a significant effect on the estimation of normal-to-shear fracture compliances. Based on the anisotropic poroelasticity amplitude variation with offset and azimuth (AVOAz) theory, we use the Born formalism and a first-order perturbation assumption to derive a matrix-fluid-fracture decoupled-based linearized PP-wave reflection coefficient in an oil-bearing fractured porous medium. Our derived formula reveals that the combined effects of background matrix, pore fluids and fracture strength on seismic amplitudes are separated, more applicable to implement the fluid identification and fracture detection in a liquid-filled porous reservoir with aligned fractures. Following a Bayesian framework, we develop a Bayesian inversion method to reasonably obtain the fluid modulus and saturated fracture weaknesses. The implementation methodology includes two steps: a model-based least-squares inversion for azimuthal elastic impedances and an iterative Bayesian seismic inversion for model parameters. Tests on synthetic data corrupted with moderate random noise indicate that these model parameters can be estimated reasonably and accurately when the oil-saturated rock is permeated with a single fracture system. Test on a real data set validates that the reliable estimates of fluid and fracture parameters can be used to realize the fluid identification and fracture detection in an oil-bearing fractured porous reservoir in a more direct manner than previous approach.

Azimuthal elastic impedance-based Fourier coefficient variation with angle inversion for fracture weakness

Quantitative inversion of fracture weakness plays an important role in fracture prediction. Considering reservoirs with a set of vertical fractures as horizontal transversely isotropic media, the logarithmic normalized azimuthal elastic impedance (EI) is rewritten in terms of Fourier coefficients (FCs), the 90° ambiguity in the azimuth estimation of the symmetry axis is resolved by judging the sign of the second FC, and we choose the FCs with the highest sensitivity to fracture weakness and present a feasible inversion workflow for fracture weakness, which involves: (1) the inversion for azimuthal EI datasets from observed azimuthal angle gathers; (2) the prediction for the second FCs and azimuth of the symmetry axis from the estimated azimuthal EI datasets; and (3) the estimation of fracture weakness combining the extracted second FCs and azimuth of the symmetry axis iteratively, which is constrained utilizing the Cauchy sparse regularization and the low-frequency regularization in a Bayesian framework. Tests on synthetic and field data demonstrate that the 90° ambiguity in the azimuth estimation of the symmetry axis has been removed, and reliable fracture weakness can be obtained when the estimated azimuth of the symmetry axis deviates less than 30°, which can guide the prediction of fractured reservoirs.

Nonlocal thermo-viscoelasticity and its application in size-dependent responses of bi-layered composite viscoelastic nanoplate under nonuniform temperature for vibration control

Viscoelastic nanomaterials (e.g., ethylene glycol-Al2O3, ethylene glycol-ZnO, etc.) have become one of the most promising candidates for nanodevices/nanocomposites, which are widely used as high-efficient nano colloidal dampers, nano-sensors, and nano-actuators in nanoengineering due to their excellent mechanical, thermal, and chemical properties. Present study aims to develop a complete size-dependent thermo-viscoelastic coupling model accounting for two fundamentally distinct size-dependent models which govern the nonlocal feature of heat transport and viscoelastic deformation, respectively. The proposed model is applied to investigate the transient responses of a bi-layered composite viscoelastic nanoplate with nonidealized interfacial conditions of thermal contact resistance and elastic wave impedance.