Shear wave velocity is an important feature in the seismic exploration that could be utilized in reservoir development strategy and characterization. Its vital applications in petrophysics, seismic, and geomechanics to predict rock elastic and inelastic properties are essential elements of good stability and fracturing orientation, identification of matrix mineral and gas-bearing formations. However, the shear wave velocity that is usually obtained from core analysis which is an expensive and time-consuming process and dipole sonic imager tool is not commonly available in all wells. In this study, a statistical method is presented to predict shear wave velocity from wireline log data. The model concentrated to predict shear wave velocity from petrophysical parameters and any pair of compressional wave velocity, porosity and density in carbonate rocks. The established method can estimate shear wave velocity in carbonate rocks with a correlation coefficient of close to unity.

Shear and compressional wave velocities, coupled with other petrophysical data, are vital in determining the dynamic modules magnitude in geomechanical studies and hydrocarbon reservoir characterization. But, due to field practices and high running cost, shear wave velocity may not available in all wells. In this paper, a statistical multivariate regression method is presented to predict the shear wave velocity for Khasib formation - Amara oil fields located in South- East of Iraq using well log compressional wave velocity, neutron porosity and density. The accuracy of the proposed correlation have been compared to other correlations. The results show that, the presented model provides accurate estimates of shear wave velocity with correlation coefficient of about unity than other currently available methods.

Viscosity is one of the most important governing parameters of the fluid flow, either in the porous media or in pipelines. So it is important to use an accurate method to calculate the oil viscosity at various operating conditions. In the literature, several empirical correlations have been proposed for predicting crude oil viscosity. However, these correlations are limited to predict the oil viscosity at specified conditions. In the present work, an extensive experimental data of oil viscosities collected from different samples of Iraqi oil reservoirs was applied to develop a new correlation to calculate the oil viscosity at various operating conditions either for dead, saturated or under saturated reservoir. Validity and accuracy of the new correlation was confirmed by comparing the obtained results of this correlation and other ones, with experimental data for Iraqi oil samples. It was observed that the new correlation gave the most accurate agreement with the experimental data.

Amara is situated south east of the city of Missan. The structure of Amara field is approximately about 9 Km long and 5 km width. This field is produced from three producing reservoirs Khasib, Mishrif and Nahr Umar. Most of the wells in this field that are producing from the main pay zone (Nahr Omar) suffer from sand production problem that was led to completely shut-in the wells due to accumulated sands in the wellbore.     The objective of this study is to investigate re-entry horizontal wells as a solution that may lead to minimize the well problems especially that is concern with sand problem, keeping into consideration the increasing wells productivity.  The production of horizontal wells can dramatically be improved by providing a greater contact of reservoir to the wellbore. Horizontal wells may also offer other advantages such as decreasing pressure drop, fluid velocities around the wellbore, minimizing water and gas coning as well as accelerated production. This may be extended to include the elimination of sand production problem from unconsolidated sand formations. Additionally, the design of horizontal wells must also includes the sand screens and/or gravel pack completion.  Due to limited geological and reservoir data of Amara oil field, advance analytical software was used to analyze the production history for two vertical wells AM/2 and AM/3. These wells are completely shut-in due to sand accumulation in the wellbore. The analytical solution converts the vertical well geometry into horizontal well model using same reservoir and fluid characteristics to estimate horizontal wells productivity increment for different pressure drawdowns and stimulation process.  The results showed that well AM/3 has greater response for production increment against the applied reservoir pressure drawdowns and stimulation activity than (well AM/2). This conclusion may led to select (well AM/3) to be much superior than (well AM/2) for eliminating sand control production.

Unconfined compressive strength (UCS) of rock is the most critical geomechanical property widely used as input parameters for designing fractures, analyzing wellbore stability, drilling programming and carrying out various petroleum engineering projects. The USC regulates rock deformation by measuring its strength and load-bearing capacity. The determination of UCS in the laboratory is a time-consuming and costly process. The current study aims to develop empirical equations to predict UCS using regression analysis by JMP software for the Khasib Formation in the Buzurgan oil fields, in southeastern Iraq using well-log data. The proposed equation accuracy was tested using the coefficient of determination (R²), the average absolute relative error (AARE%) and the standard deviation error (SD%). It has been found that the developed equation is reliable and capable of predicting the UCS with an acceptable degree of confidence R², AARE% and SD% are 0.8549, 2.619%, and 0.0569%, respectively when compared with field data. Furthermore, when compared to other known correlations, showed better prediction results.