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New model improves gas migration velocity estimates in shut-in wells
The Oil & gas journal, 1993-11, Vol.91 (46), p.55-60
Copyright PennWell Publishing Company Nov 15, 1993 ;ISSN: 0030-1388 ;EISSN: 1944-9151 ;CODEN: OIGJAV
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Title:
New model improves gas migration velocity estimates in shut-in wells
Author:
JOHNSON, A
;
TARVIN, J
Subjects:
03 NATURAL GAS
;
Applied sciences
;
CALCULATION METHODS
;
Completion equipments and methods. Casing. Cementing. Tests and measurements in wells
;
COMPRESSIBILITY
;
Crude oil, natural gas and petroleum products
;
Drilling
;
DRILLING FLUIDS
;
Drilling. Casing. Preparing wells for production
;
ELASTICITY
;
Energy
;
ENERGY SOURCES
;
ENGINEERING
;
ENVIRONMENTAL TRANSPORT
;
Equipment testing
;
Estimates
;
Exact sciences and technology
;
Experiments
;
Exploration
;
FLUIDS
;
FOSSIL FUELS
;
FUEL GAS
;
FUELS
;
GAS FUELS
;
Gas industry
;
GASES
;
GEOLOGIC DEPOSITS
;
Improvements
;
MASS TRANSFER
;
MATHEMATICAL MODELS
;
MECHANICAL PROPERTIES
;
MINERAL RESOURCES
;
NATURAL GAS
;
NATURAL GAS DEPOSITS
;
Natural gas distribution
;
NATURAL GAS FIELDS
;
NATURAL GAS WELLS
;
Permeability
;
PRESSURIZATION
;
Prospecting and production of crude oil, natural gas, oil shales and tar sands
;
RESERVOIR ENGINEERING
;
RESOURCES
;
TENSILE PROPERTIES
;
TESTING
;
Velocity
;
Wells
;
WELLS 030300 -- Natural Gas-- Drilling, Production, & Processing
Is Part Of:
The Oil & gas journal, 1993-11, Vol.91 (46), p.55-60
Description:
Incorrect estimates of gas migration can lead to additional problems during well control. Direct measurements of gas migration velocities in laboratory experiments and full-scale tests have shown that gas can migrate up a well bore at approximately 6,000 ft/hr. Typical estimates of the gas migration velocity are 1,000 ft/hr or less. These estimates are derived from the rate of increase of surface pressures during shut in and are in error because they rely on a conventional hydrostatic model that neglects several important factors, such as mud compressibility, well bore elasticity, and fluid loss. In a new model, typical values for elasticity and fluid loss are derived from formation integrity tests for a real well. With these values, the new model calculates rates of pressure rise that are consistent with those observed in the field, even though the gas migration velocity is as large as that measured in the experiments. The model shows that conventional field practices that neglect these effects can underestimate the gas migration velocity by a factor of 10 or more.
Publisher:
Tulsa, OK: Pennwell
Language:
English
Identifier:
ISSN: 0030-1388
EISSN: 1944-9151
CODEN: OIGJAV
Source:
ProQuest Central
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