Modest improve in temperature at the production wellhead is because of
Modest boost in temperature in the production wellhead is due to the sudden drop inside the production wellhead stress. The contribution inside the fluid flow is due to the first pressure shock with the injection that comes in the faulted zones which are located at the bottom with the technique having a larger temperature. As time proceeds, the contribution from the matrix plus the leakage zone increases and reduces the temperature some days right after the starting on the injection. To calculate the initial temperature in the wellhead, it truly is assumed that there is a steady state flow from the combination of your matrix and the fault zones. This initial temperature is slightly lower than that in the unsteady situation in the early time period. The fluid using the decrease viscosity shows a delay in the development with the pressure shock MNITMT web resulting from the cold fluid injection. Hence, the contribution from the matrix as well as the leakage zone for the fluid together with the temperature 40 C takes place later and also the major fluid flow from the faulted zone in the bottom on the system lasts for a longer time. In addition, the temperature improve in situation B is higher in comparison to that of situation A because of the reality that scenario B includes a larger production rate than situation A which reduces the time for exchanging heat in the wellbore. Figure ten shows the comparison of temperature distribution inside the fractures and along the wellbore for scenarios A and B. The higher production rate leads to slightly faster thermal drawdown in the production well bottom for situation B than scenario A. No thermal breakthrough was observed in the production well bottom even soon after 100 years of operation, as shown in Figure 10e,f. 3.4. Uncertainties There are several uncertainties within this model. We thought of the wellbore as a line supply for the heat flow. The faulted zone is formulated applying a fracture. Each of these assumptions are trustworthy mainly because the size from the wellbore as well as the fault zone is negligible in comparison towards the all round size of your reservoir. Information validation for the quick operational period for production confirms this behavior. The matrix zone is regarded as as homogeneous and isotropic. Because the permeability of matrix is reduce than faulted zone, its contribution to the heat and mass flux is smaller. Thus, this assumption holds true. As we usually do not know the precise point of the leakage zone alongside the casing area, we viewed as a homogeneous leakage and attempted to compensate for the achievable errors by performing a trial-and-error approach to seek out an appropriate lumped parameter that defines the wellbore heat exchange effect. Additionally, due to the unavailability of your geomechanical and geochemical data, we mostly focused on the hydrothermal behavior with the JPH203 Purity geothermal technique. Short-term validation of this TH model offers an insight regarding the precise method characterization, like the permeability and porosity distribution, fault placement and its contribution to the overall flow, the wellbore effect on the all round heat exchange, and fluid and rock properties. Therefore, it builds a basis for future THM or THMC (thermo-hydro-mechanical-chemical) simulations. Our expectation regarding the THM behavior is that permeability around the injection would raise (resulting in the localized thermoelastic tension reorientation and elevated pore stress). Therefore, the enhanced permeability will likely be favorable within the energy extraction. Based on this un-Geosciences 2021, 11,This initial.