Porosity Assignment Help
Porosity
Fluid retaining capacity of reservoir rocks is called porosity. Mathematically it is ratio of void space in the rock to the bulk volume of the rock. In reservoir rocks there exist basically two types of porosity, expressed as …
- Original porosity and
- Induced porosity.
Porosity evolved through depositional environment is called original porosity, while Induced porosity is change form of original porosity due to geological changes basic structure of rocks. Following are the classifications of rock and its different porosity…
| Rock | Original Porosity | Induced Porosity |
| Sandstone | Intergranular | Fracture development |
| Limestone | Intercrystalline and oolitic | Vugs and solution cavity |
Rock having original porosity is more uniform in their characteristics than those rocks in which a large part of the porosity is induced. The porosity for the cubical packing arrangements is 47.6% and that of rhombohedral is 25.96%. In fact porosity of reservoir rock does not depend upon the grain size. Sometimes cementing material may seal off a part of the pore space, so we have to define porosity in some other words …
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Total Porosity: It is the ratio of total void space in the rock to the bulk volumes of the rock.
Effective Porosity: It is the ratio of the interconnected pore void space in the rock to the bulk volume of the rock. Effective porosity is more important for reservoir engineering point of view. For tightly cemented material there is significant difference between effective porosity and total porosity. One important application of the effective porosity is its use in determining the original hydrocarbon volume in place. Consider a reservoir with an areal extent of A acres and an average thickness of h feet. The total bulk volume of the reservoir can be determined from the following expressions:
Bulk volume = 43,560 Ah, ft3
Or
Bulk volume = 7,758 Ah, bbl
Where A = areal extent, acres
h = average thickness
The reservoir pore volume PV can then be determined by combining
Expressing the reservoir pore volume in
Cubic feet give:
PV = 43,560 Ahf, ft3
Expressing the reservoir pore volume in barrels gives:
PV = 7,758 Ahf, bbl
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Following are some of the topics in General Composition Of Petroleum in which we provide help:
- General Composition Of Petroleum
- Physical Properties Of Hydrocarbons
- Origin of Petroleum
- Fundamental properties Of Fluid Permeated Rocks
- Porosity
- Permeability
- The Klinkenberg Effect
- Saturation
- Wettability
- Capillary Pressure
- Relative Permeability
- Drainage Process
- Three phase Relative Permeability
- Rock Compressibility
- Fundamentals Of Reservoir Fluid Behavior
- Classification Of Reservoir And Reservoir Fluids
- Gas Reservoirs
- Fundamentals Of Reservoir Fluid Flow
- Types Of Fluids
- Properties Of natural Gases
- Behavior Of Ideal Gases
- Behavior of Real Gases
- Compressibility Of Natural Gases
- Properties Of Crude Oil Systems
- Gas Solubility
- Determination And Application of Reservoir Fluid Properties
- Composition Of The Reservoir Fluid
- Differential Liberation Test
- Separator Tests
- Fluid Analysis Data On Gas
- Constant-Volume Depletion
- Oil Recovery mechanisms And The material Balance Equation
- Primary Recovery Mechanisms
- The Depletion Drive Mechanism
- Gas Cap Drive
- The Water Drive Mechanism
- Water Production
- The Gravity-Drainage-Drive Mechanism
- The Combination-Drive Mechanism
- The Material Balance Equation
- Change in Pore Volume Due to Initial Water and Rock Expansion
- Gas Reservoirs Help
- The Volumetric Method
- The material Balance Method
