72397289-Reservoir-Engineering.ppt
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This document discusses key concepts in reservoir engineering. It defines a reservoir as rock containing hydrocarbons and outlines important reservoir properties like porosity and permeability. It also covers fluid properties such as viscosity and formation volume factor. Finally, it lists several types of drive mechanisms that can produce oil and gas from a reservoir such as water drive, gas cap drive, and expansion drive mechanisms.
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Properties of reservoir rocks
The document discusses key properties of reservoir rocks including porosity, permeability, and fluid saturation. It defines porosity as the ratio of pore space volume to total rock volume and describes different types of porosity such as primary, secondary, and effective porosity. It also defines permeability as the ability of rocks to transmit fluids and discusses how it is affected by factors like grain size. Additionally, it explains concepts such as critical oil saturation and critical water saturation which refer to saturation levels above which fluids will flow.
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The document discusses relative permeability, which describes the ability of fluids to flow through porous media in the presence of other fluids. It covers factors that affect relative permeability like fluid saturations, rock properties, wettability, and pressure. Different wettability types can impact relative permeability curves and residual saturations. Mobility ratios also influence waterflood performance. Proper representation and measurement of relative permeability is important for reservoir evaluation and optimization.
Reservoir rock & fluid
- The document discusses reservoir characteristics including rock and fluid properties that are important to understand for optimal hydrocarbon recovery. Techniques like seismic data, well logging, and testing provide valuable data to build reservoir models.
- Key rock properties that impact hydrocarbon storage and flow include porosity, permeability, and wettability. Core analysis in the lab and well logs provide data on these properties.
- Understanding fluid properties like phase behavior under reservoir conditions of pressure and temperature is also important for predicting production performance and fluid composition.
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This document discusses reservoir characteristics, rock and fluid properties, and drive mechanisms. It provides information on:
1) Techniques like seismic data, well logging, core analysis, and well testing that are used to understand the reservoir and develop an accurate reservoir model.
2) Reservoir characteristics including rock type, porosity, permeability, and factors that allow hydrocarbon accumulation like sufficient pore space and traps.
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4) Fluid properties including phase behavior under varying pressures and temperatures, properties of different fluid types, and sampling techniques.
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This document provides an overview of a reservoir engineering course focused on fundamental rock properties. It discusses key topics like porosity, saturation, wettability, capillary pressure, and how they are determined through laboratory core analysis. Porosity refers to the pore space available to hold fluids and is classified as absolute or effective porosity. Saturation represents the fraction of pore space occupied by a fluid. Capillary pressure describes the pressure differential between immiscible fluids based on interface curvature. Laboratory tests on core samples are used to characterize these important rock properties.
reservoir engineering
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- A pressure-temperature diagram is used to classify reservoirs and describe the phase behavior of reservoir fluids, delineating the liquid, gas, and two-phase regions.
- Based on the diagram, reservoirs are classified as oil reservoirs if the temperature is below the critical temperature, and gas reservoirs if above the critical temperature.
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- A pressure-temperature diagram is used to classify reservoirs and describe the phase behavior of reservoir fluids, delineating the liquid, gas, and two-phase regions.
- Based on the diagram, reservoirs are classified as oil reservoirs if the temperature is below the critical temperature, and gas reservoirs if above the critical temperature.
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72397289-Reservoir-Engineering.ppt
- 2. Any thing which can contain any type of reserve in it, is called Reservoir. In The Petroleum Engineering, the Reservoir is the rock that contains the amount hydrocarbons in it.
- 3. Reservoir properties Porosity. Porosity is the property of reservoir rock, which is the ratio of pore volume of the rock to the bulk volume of the rock. Porosity is measured in %age, and it is represented by Ø Phai.
- 4. Permeability. It is the interconnection between pore spaces, through which the fluid can move or flow. The unit of permeability is Darcy or mili darcy.
- 5. Fluid Properties Viscosity. Viscosity is the property of a fluid which resists the fluid to flow. The unit of viscosity is cent poise.
- 6. Formation Volume factor. Formation volume factor is the ratio of volume of fluid at the reservoir condition to the volume of fluid at the standard conditions. Standard conditions are 14.7 psi pressure and 60F temperature.
- 7. Solution Gas Oil Ratio. It is the no. of standard cubic feet of the gas, dissolved in a stock tank barrel of oil. Under the reservoir conditions, the gas is dissolved in oil.
- 8. Bubble Point Pressure. This is the pressure at which the first bubble of gas is liberated from oil. When the reservoir pressure is reduced, the dissolved gas starts to escape from oil.
- 9. Drive Mechanisms 1, water drive Mechanism 2, Gas Cap Drive Mechanism 3, Expansion Drive Mechanism 4, Combination Drive Mechanism 5, Rock expansion Mechanism