CGE588 Reservoir Engineering II UITM Assignment Sample Malaysia

CGE588 Reservoir Engineering II is a course offered at Universiti Teknologi MARA (UiTM). This course is designed to provide students with a comprehensive understanding of advanced topics in reservoir engineering, building upon the foundational knowledge gained in Reservoir Engineering I.

In this course, students will learn about the principles and practices of reservoir simulation, which is an essential tool for reservoir engineers in predicting reservoir behavior and optimizing production. The course will cover various topics including numerical methods for solving partial differential equations, material balance equations, and various techniques for history matching and uncertainty analysis.

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In this section, we will describe some assignment briefs. These are:

Assignment Brief 1: Describe the concepts of fluid flow in porous media to appraise reservoir flow behavior.

Fluid flow in porous media is a complex phenomenon that occurs when a fluid, such as oil or gas, moves through a network of interconnected pores and channels within a porous rock. Understanding the behavior of fluid flow in porous media is crucial for appraising the reservoir flow behavior.

The basic concepts involved in fluid flow in porous media include:

  1. Porosity: Porosity is the ratio of the void space in a rock to the total volume of the rock. It determines the amount of fluid that a rock can store and how easily the fluid can flow through it.
  2. Permeability: Permeability is the ability of a rock to allow fluids to flow through it. It is a measure of the ease with which fluids can move through the pore space in a rock.
  3. Darcy’s law: Darcy’s law describes the relationship between the fluid flow rate, the pressure gradient, and the permeability of the porous media. It states that the flow rate is proportional to the pressure gradient and the permeability.
  4. Fluid properties: Fluid properties, such as viscosity, density, and compressibility, also play an important role in fluid flow in porous media. These properties determine how the fluid will behave as it moves through the pore space in a rock.
  5. Relative permeability: Relative permeability is a measure of the effective permeability of a rock to a particular fluid, such as oil or gas, in the presence of another fluid, such as water. It is a function of the saturation of each fluid.
  6. Capillary pressure: Capillary pressure is the pressure difference between two fluids at the interface between them in a porous medium. It determines how fluids are distributed within the pore space in a rock.

By taking these concepts into consideration, reservoir engineers can build mathematical models to simulate fluid flow in porous media and make predictions about reservoir behavior, such as the amount of oil or gas that can be produced and the rate at which it can be produced.

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Assignment Brief 2: Analyse oil and gas material balance concepts for reserve and recovery factor estimation.

Oil and gas material balance is a concept used in the petroleum industry to estimate the amount of recoverable hydrocarbons in a reservoir. The method is based on the law of conservation of mass, which states that the total mass of any material in a closed system remains constant over time.

The material balance equation for a reservoir can be written as follows:

Original oil in place (OOIP) = cumulative oil production + remaining oil in place

The concept of reserve factor and recovery factor are important in oil and gas material balance analysis. Reserve factor is defined as the ratio of recoverable reserves to the total hydrocarbon content of the reservoir. Recovery factor, on the other hand, is the ratio of the cumulative production of hydrocarbons to the initial hydrocarbon content of the reservoir.

The material balance equation can be rearranged to estimate the reserve and recovery factors as follows:

Reserve Factor = (Cumulative Oil Production + Remaining Oil in Place) / Original Oil in Place

Recovery Factor = Cumulative Oil Production / Original Oil in Place

The original oil in place (OOIP) can be estimated using geological and geophysical data, such as well logs and seismic surveys. The cumulative oil production can be calculated by monitoring the production rates over time. The remaining oil in place can be estimated by analyzing the pressure data from the reservoir.

The material balance method is a powerful tool for estimating the recoverable reserves and recovery factors of a reservoir. However, it is important to note that the accuracy of the estimates depends on the quality of the input data and the assumptions made in the analysis. Therefore, it is important to use multiple methods and cross-check the results to ensure accuracy.

Assignment Brief 3: Evaluate the fundamentals of reservoir engineering for prudent development of oil and gas fields.

Reservoir engineering is a crucial aspect of the oil and gas industry that focuses on the evaluation and management of subsurface reservoirs to optimize hydrocarbon production. The following are some of the fundamentals of reservoir engineering that are important for the prudent development of oil and gas fields:

  1. Reservoir characterization: This involves the collection, analysis, and interpretation of geological and geophysical data to understand the subsurface reservoir’s properties and behavior. The reservoir engineer uses this information to determine the size, shape, and location of the reservoir, the nature and quality of the hydrocarbon resource, and the fluid and rock properties that control the flow of hydrocarbons.
  2. Fluid flow and transport: Reservoir engineers use mathematical models to simulate the flow of hydrocarbons in the subsurface, taking into account factors such as fluid properties, reservoir permeability, and well placement. These models help to predict the reservoir’s performance and estimate the ultimate recovery of hydrocarbons.
  3. Well testing and monitoring: Reservoir engineers use various techniques to measure the pressure and flow rates in wells, which provide critical data for evaluating the reservoir’s behavior and performance. These tests help to optimize the production strategy, identify production problems, and estimate the reservoir’s ultimate recovery.
  4. Enhanced oil recovery (EOR) techniques: These are methods used to increase the amount of oil that can be recovered from a reservoir beyond the primary production phase. Reservoir engineers evaluate and design EOR processes, such as gas injection, water flooding, and chemical injection, to optimize hydrocarbon recovery.
  5. Reservoir management: This involves the continuous monitoring and management of the reservoir over its productive life to maximize hydrocarbon recovery while minimizing costs and risks. Reservoir engineers work closely with other disciplines, such as geology, drilling, and production, to implement effective reservoir management strategies.

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