JNTU
JNTU B.Tech IV RESERVOIR STIMULATION Previous Question Paper (May - 2019 - R15)
Note: This question paper contains two parts A and B. Part A is compulsory which carries 25 marks. Answer all questions in Part A. Part B consists of 5 Units. Answer any one full question from each unit. Each question carries 10 marks and may have a, b, c as sub questions.
Part A
Define permeability anisotropy.
Answer
Permeability anisotropy refers to the condition where the permeability of a rock formation is not uniform in all directions, typically resulting in different values for horizontal and vertical permeability due to sedimentary deposition or stress orientation.
What are the pertinent rock properties?
Answer
The pertinent rock properties include porosity (the void space volume), permeability (the ability to transmit fluids), compressive strength (resistance to deformation), Young's modulus, Poisson's ratio, and in-situ stress state.
What are the oil base fluids?
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Define acid fracturing.
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Compare the interrelation of pre- and after-closure pressure analyses.
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Distinguish the linear, transitional and radial flow pressure responses.
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What are the parameters involved in selection of proppant?
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Classify the names of matrix stimulation techniques.
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Estimate the potential problems during diversion treatment.
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Write a short note on Diverting agents.
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Part B
Explain the inflow performance relationship (IPR) for pseudo steady state for an oil well.
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Give a detail note on the layered reservoir testing.
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Demonstrate the pressure decline analysis with the Carter leak off model.
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Classify the major steps involves in the interpretation of transient test data.
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Derivation of the Khristianovich–Geertsma–de Klerk model.
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What are the applications of three-dimensional and pseudo three-dimensional models?
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Estimate the reaction stoichiometry and energy balance during acid fracturing.
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Establish the planar three-dimensional models.
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Discriminate the various number of parameters controlling of fluid loss to the formation during a fracturing treatment is a filtration process.
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Define the formation pressure capacity. Explain the formation pressure capacity for PKN-type fracture.
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Estimate the diagnosis of periods of controlled fracture height growth.
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Calculation of reduction in apparent fracture conductivity resulting from non-Darcy fracture flow. A vertically fractured gas well has hf = 100 ft and w = 0.25 in. The fracture is propped with 20/40-mesh Hickory fracture sand and has kf = 85,000 md at reservoir confining conditions. The well is produced at 10 MMscf/D, and γg = 0.6. Determine the percent apparent fracture conductivity reduction resulting from non-Darcy fracture flow for the reservoir.
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Discriminate the geometry modeling with the help of neat diagram.
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Give the general guideline for fracturing fluid selection in oil and gas wells.
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Establish the design process of sandstone acidizing treatment with neat flow sheet.
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Explain the process of the treatment response diagnosis.
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Demonstrate the guidelines of methods used to control the precipitates caused by acidizing are proper acid staging, lower acid concentrations.
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