By Faruk Civan
Reservoir Formation harm, 3rd variation, provides the newest info at the fiscal difficulties which can happen in the course of a variety of stages of oil and fuel restoration from subsurface reservoirs, together with construction, drilling, hydraulic fracturing, and workover operations.
The textual content is helping readers higher comprehend the strategies inflicting formation harm and the criteria which may bring about diminished stream potency in near-wellbore formation throughout the a variety of levels of oil and gasoline construction.
The 3rd version within the sequence offers the main all-encompassing quantity to this point, including new fabric on conformance and water keep watch over, hydraulic fracturing, specified tactics for unconventional reservoirs, box purposes layout, and value review for harm regulate measures and techniques.
- Understand correct formation harm procedures by way of laboratory and box testing
- Develop theories and mathematical expressions for description of the basic mechanisms and processes
- Predict and simulate the results and situations of many of the forms of formation harm techniques encountered in petroleum reservoirs
- Develop methodologies and optimum thoughts for formation harm keep an eye on and remediation
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Additional resources for Reservoir formation damage : fundamentals, modeling, assessment, and mitigation
5 g/cm3. 6. Prepare a plot of areosity versus porosity using Eqs. 12) in the range of 0 # φ # 1:0. 48 CHAPTER 3 PETROGRAPHIC CHARACTERISTICS 7. Prepare a plot of tortuosity versus porosity using Eqs. 15) in the range of 0 # φ # 1:0. 8. Prepare bimodal β-distribution charts (fractional and cumulative types) based on Eqs. 22). Try several sets of properly selected parameter values and observe their effect on the results. 9. Prepare bimodal fractal distribution charts (fractional and cumulative types) based on Eqs.
1995, credit Kelkar, 1991, 1993 for this information): 1. Microscopic a. 9 CLASSIFICATION OF ROCK 25 À Pore-throat radius À Rock lithology 2. Macroscopic a. Core-scale data À Permeability À Porosity À Saturation À Wettability 3. Megascopic a. Simulator grid block-scale data À Wireline logs À Seismic data 4. Gigascopic a. Reservoir-scale data À Pressure transient tests À Geologic model Kelkar et al. (2002) described the geostatistical approaches required to reservoir characterization. 10 by Kelkar (2000) explains the incorporation of the realizations of reservoir geology and petrophysical properties into building an adequate reservoir model.
49) in which, the subscripts o and N indicate the initial and terminal porosity and permeability values, α12α8 are empirical parameters, and peff denotes effective overburden stress, given according to Nieto et al. 50) in which α is Biot’s constant, and pob and ppf are overburden stress and pore fluid pressure, respectively. Civan (2000b) verified these equations by using data from Nieto et al. (1994) and Bustin (1997). 4 EFFECT OF TEMPERATURE AND FORMATION DAMAGE Gupta and Civan (1994a) and then Civan (2000b) formulated the variations in porosity and permeability caused by temperature.