Journal of Petroleum Research & Studies

Permeability is the property that permits the passage of fluids through the interconnected pores of a rock. It is one of the most important, most spatially variable, most uncertain, and hence least predictable transport properties of porous formations. This paper represents a method to predict permeability of Khasib Formation in two wells (Am-1,Am-2) of Amara field using Multilinear regression (MLR) technique and various empirical models, such as Tixier’s, Timur’s and Coates and Dumanoir equations, are used to quantify permeability from well log calculations of porosity and irreducible water saturation. Measured porosity and permeability data from plugs of the available core intervals were used for validation of the predicated data from the logs. The calculated permeability values were compared with the laboratory measurements of core samples to those estimated from different empirical approaches, such as Tixier, Timur, Coates and Dumanoir models, as well as multilinear regression technique by using the statistical correlation coefficient (R2). The present study indicates that Multilinear regression (MLR) technique is the best method and the most validity to estimate permeability from well logs data.

The aim of this project is to remove or eliminate the effect of the highly toxic gas of H2S on the health of personal, environment, drilling fluid reology, and drilling equipment materials by adding an economic mixture of sulphide scavengers to the contaminated drilling fluid. In this research mixture of 14.7 gm/l of iron oxide in the form of magnetite (Fe3O4) and 14.7 gm/l of ferrous oxalate Fe(C2O4), which cost is 1.3 US$ per 1kg of mixture, was used to remove the all forms of soluble sulphides (H2S, HS-, S2-) from water-base drilling fluid. The Fe3O4 reacts with dissolved H2S and the reaction carry on fast at pH below 8, while Fe(C2O4) reacts with HS-, S2- and this reaction proceed at high rate at pH above 8. Both reactions produce insoluble iron sulphides. The chemical analysis showed that the soluble species of sulphides in the drilling fluid, which its pH was 7.9, were present as dissolved H2S gas and as bisulphide ions (HS-). The analysis also explained that the total concentration of these sulphides in the drilling fluid was 3000 ppm.
The results of treatment of contaminated fluid showed that all forms of sulphides were removed from drilling fluid after adding the mixture of scavengers to the contaminated fluid. The results also explained that the drilling fluid reology recovered after removing the soluble sulphides, which were the main factors that effect on the drilling fluid reology, from the drilling fluid.

Accurate estimation of relative permeability is essential for reliable reservoir history matching and decision-making, and effective reservoir management. This information is also critical for the design, implementation, and monitoring of enhanced oil recovery processes.
This study presents an effective method for acquiring the relative permeability data directly from the well production data in oil reservoirs where water acts as the fluid phase displacing oil. The methodology presented in this study provides convenient interpretation formulae which are applicable to unsteady-state, two-phase, immiscible, and incompressible fluids. The total mobility and the mobility ratio of the immiscible fluids are related to the characteristic parameters of the displacement process and the cumulative injected fluid pore volume following [1] et al. These parameters are then incorporated into a general correlation function which allows for analytically estimation of the relative permeability functions. The present approach produces unique estimation of the relative permeability functions and is more practical than the previous approaches which rely on computationally complicated history matching procedures, often suffer from the non uniqueness issue of the obtained relative permeability data.
This study demonstrated that the fluid viscosity have significant effects on determined relative permeability curves using Toth et. [1]. Method for radial flow The Toth et al. method works satisfactorily even for heterogeneous reservoirs. The effect of heterogeneities on the relative permeability curves is negligible using Toth method. However, the effect becomes significant when there are channels.

Iraq has huge oil and gas resources in terms of hydrocarbon reserves and high levels of expected production and export capabilities. Since 2003, dramatic political and economic changes have occurred, and these changes have affected the nature of, and trends within the Iraqi economy, mainly the petroleum industry which is the backbone of the Iraqi economy. There has been a radical shift in economic philosophy, to encourage new petroleum investment trends whereby the role of government is reduced and that of International Companies is enhanced, with the adoption of new investment patterns in upstream and downstream activities. These changes have occurred over a transition period for the institutional – legal framework after 2003, and have introduced unprecedented patterns in most Iraqi petroleum activities.
The subject of this paper is the fundamental changes in investment in relation to the Iraqi petroleum industry. The purpose of this paper is to examine the current and expected patterns of petroleum investment in Iraq into upstream and downstream activities during the period of 2003 – 2012.

Corrosion is an international problem with more structures and materials buried in the soil. The most common and applicable technique to overcome this problem is cathodic protection. In this work a Carbone steel pipe of length 100 cm is buried in a wooden box submerged by soil and Impressed Current Cathodic Protection system was applied using power supply and close circuit, several important factors has been studied, like Anode position (distance and depth), soil resistivity (wet and dry), condition the pipe (coated and un-coated), distribution of potential and currents along the pipe (cathode), the amount of current required to achieve cathodic protection. A mathematical model was developed to simulate the ranges of parameters and factors affecting Impressed Current Cathodic Protection (ICCP). Regression of this model to data and results yielded parameter values vary depending on the effect of the same factor

Tanks and pressurized vessels are one of the main equipments in the gas and oil refinery industry. Every petroleum industry has a lot of tanks. Gas and oil are corrosive materials, therefore the corrosion losses cost large amount of money and time every year. The severity of corrosion depends on various working parameters such as H2S level, partial pressure of CO2, temperature, chloride concentration, surface films and oxide contents.