Questions and Answers
Live oil viscosity can be estimated using the equation µo = µob + δp µo ( p − ______)
pb
The value of δpμo for the oil viscosity shown in Figure 3.6 is approximately ______ cp/psi for pressures greater than BP pressure.
8 × 10−5
Oil viscosity μo at pressure p above BP pressure pb can be estimated using equation ______.
3.24
Oil viscosity increases because of compression of the oil above ______ pressure.
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The plot in Figure 3.6 shows results for the correlation of Equations 3.20 through ______.
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Formation Volume Factor refers to the properties of ______ in geologic formations.
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The value of the slope δpμo is ______ since oil viscosity increases as pressure increases.
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The change in oil viscosity above BP pressure due to increasing pressure is represented as ______.
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Rs varies from near 0 up to ______ SCF/STB.
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Live oil viscosity at BP pressure is represented as ______.
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Study Notes
Copyright Information
- Copyright © 2017 by John Wiley & Sons, Inc., all rights reserved.
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- Simultaneously published in Canada.
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Book Details
- Title: Introduction to Petroleum Engineering
- Authors: John R. Fanchi and Richard L. Christiansen
- Published by: John Wiley & Sons, Inc.
- ISBN:
- 9781119193449 (cloth)
- 9781119193647 (epdf)
- 9781119193616 (epub)
- Library of Congress Classification: LCC TN870.F327 2017; DDC 622/.3382–dc23
Chapter Content Overview
-
Introduction to Petroleum Engineering:
- Covers alternative energy opportunities and production performance ratios.
- Discusses the life cycle and management of a reservoir, emphasizing recovery efficiency and petroleum economics.
-
Future of Energy:
- Outlines global oil and gas production, resources and reserves, peak oil concepts, and future energy options.
-
Reservoir Fluids and Rocks:
- Explores properties of fluids including gas, oil, and water, and discusses classification systems.
- Examines rock properties such as porosity, permeability, and reservoir heterogeneity.
-
Multiphase Flow:
- Addresses concepts of interfacial tension, wettability, relative permeability, and their impact on well productivity.
-
Petroleum Geology:
- Covers geologic history, sedimentary basins, hydrocarbon formation, and volumetric analysis related to recovery factors.
-
Reservoir Geophysics:
- Discusses seismic waves, data acquisition, processing, and interpretation techniques for exploring reservoirs.
-
Drilling Processes:
- Describes rotary drilling rigs, the planning and execution of the drilling process, and types of wells, including directional and extended reach drilling.
-
Well Logging:
- Introduces different types of logging such as lithology, porosity, and resistivity logs emphasizing their importance in formation evaluation.
-
Well Completions and Upstream Facilities:
- Outlines procedures for well completion, including acidizing and hydraulic fracturing, and details on onshore and offshore facilities.
-
Transient Well Testing and Production Performance:
- Details pressure transient testing techniques and decline curve analysis for assessing well performance.
-
Reservoir Performance:
- Discusses reservoir flow simulators, recovery mechanisms, and performance metrics for both conventional and unconventional reservoirs.
-
Midstream and Downstream Operations:
- Explains the midstream sector's role in transportation and the downstream sector's processes including refining and gas processing.
Appendices and Resources
- Unit conversion factors are provided in the appendix.
- Activities throughout the book include further readings, true/false assessments, and exercises for hands-on learning.### Oil and Gas Phase Behavior
- Gas solubility in oil increases with rising pressure until a saturation point is reached, known as bubble-point pressure (BP pressure).
- BP pressure indicates the highest pressure at which gas can coexist with oil; beyond this, the oil is considered undersaturated.
Bubble-Point Pressure Calculation
-
BP pressure (Pbp) is calculated using the correlation formula:
pb = 18.2 (A - 1.4) -
Variable A is determined by gas dissolved in oil (Rs in SCF/STB), gas gravity (γg), temperature (T in °F), and API gravity (°API):
- A = (Rs / γg) ^ 0.83 * (10^(0.00091T - 0.0125 * °API))
Example Calculation: Bubble-Point Pressure
- For a reservoir temperature of 220°F, oil gravity of 35°API, gas gravity of 0.68, and 350 SCF/STB of dissolved gas, the oil's formation volume factor (Bob) at BP pressure can be found using:
- Bob = 0.98 + 0.00012 A^1.2, where A is calculated from Rs and γg.
Oil Formation Volume Factor Calculation
-
Convert API gravity to specific gravity:
- γo = 141.5 / (°API + 131.5) → yields γo = 0.85 for 35°API.
-
Compute variable A for Bob using:
- A = (350 SCF/STB) * (γg / γo) ^ 0.5 + 1.25 * T → A = 588 for the given values.
-
Substitute into the Bob equation:
- Bob = 0.98 + 0.00012 * (588)^1.2 → results in a formation volume factor of approximately 1.23 RB/STB.
Effects of Pressure on Oil Properties
- Oil formation volume factor decreases due to oil compression above bubble-point pressure.
- Oil viscosity increases under pressure above bubble-point pressure; viscosity can be calculated:
- µo = µob + δpµo * (p - pb).
Viscosity Change with Pressure
- Initial viscosity at BP pressure is denoted µob. The change in oil viscosity with increasing pressure is represented by δpµo, approximately 8 × 10^-5 cp/psi for pressures above BP pressure.
- Higher pressure correlates with increased oil viscosity.
Water Properties in Geologic Formations
- Consideration of water properties is essential in the analysis of geologic formations containing water.
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