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A simple and reliable method for gas well deliverability determinationYussefabad, Arman G. January 2007 (has links)
Thesis (M.S.)--West Virginia University, 2007. / Title from document title page. Document formatted into pages; contains xi, 79 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 42-47).
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Development of a successful chemical treatment of gas wells with condensate or water blocking damageBang, Vishal, January 1900 (has links)
Thesis (Ph. D.)--University of Texas at Austin, 2007. / Vita. Includes bibliographical references.
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An economical method for the numerical solution of the behavior of a gas well with a vertical fracture /Crafton, James W. January 1975 (has links)
Thesis (Ph.D.)--University of Tulsa, 1975. / Bibliography: l. 45-48.
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Production decline analysis of horizontal well in gas shale reservoirsAdekoya, Folarin. January 1900 (has links)
Thesis (M.S.)--West Virginia University, 2009. / Title from document title page. Document formatted into pages; contains xi, 68 p. : ill. (some col.), col. maps. Includes abstract. Includes bibliographical references (p. 66-68).
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Modeling well performance in compartmentalized gas reservoirsYusuf, Nurudeen 15 May 2009 (has links)
Predicting the performance of wells in compartmentalized reservoirs can be quite
challenging to most conventional reservoir engineering tools. The purpose of this
research is to develop a Compartmentalized Gas Depletion Model that applies not only
to conventional consolidated reservoirs (with constant formation compressibility) but
also to unconsolidated reservoirs (with variable formation compressibility) by including
geomechanics, permeability deterioration and compartmentalization to estimate the
OGIP and performance characteristics of each compartment in such reservoirs given
production data.
A geomechanics model was developed using available correlation in the industry
to estimate variable pore volume compressibility, reservoir compaction and permeability
reduction. The geomechanics calculations were combined with gas material balance
equation and pseudo-steady state equation and the model was used to predict well
performance.
Simulated production data from a conventional gas Simulator was used for
consolidated reservoir cases while synthetic data (generated by the model using known parameters) was used for unconsolidated reservoir cases. In both cases, the
Compartmentalized Depletion Model was used to analyze data, and estimate the OGIP
and Jg of each compartment in a compartmentalized gas reservoir and predict the
subsequent reservoir performance. The analysis was done by history-matching gas rate
with the model using an optimization technique.
The model gave satisfactory results with both consolidated and unconsolidated
reservoirs for single and multiple reservoir layers. It was demonstrated that for
unconsolidated reservoirs, reduction in permeability and reservoir compaction could be
very significant especially for unconsolidated gas reservoirs with large pay thickness and
large depletion pressure.
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Field application of an interpretation method of downhole temperature and pressure data for detecting water entry in horizontal/highly inclined gas wellsAchinivu, Ochi I. 15 May 2009 (has links)
In the oil and gas industry today, continuous wellbore data can be obtained with high
precision. This accurate and reliable downhole data acquisition is made possible by
advancements in permanent monitoring systems such as downhole pressure and
temperature gauges and fiber optic sensors. The monitoring instruments are increasingly
incorporated as part of the intelligent completion in oil wells where they provide
bottomhole temperature, pressure and sometimes volumetric flow rate along the
wellbore - offering the promise of revolutionary changes in the way these wells are
operated. However, to fully realize the value of these intelligent completions, there is a
need for a systematic data analysis process to interpret accurately and efficiently the raw
data being acquired. This process will improve our understanding of the reservoir and
production conditions and enable us make decisions for well control and well
performance optimization.
In this study, we evaluated the practical application of an interpretation model,
developed in a previous research work, to field data. To achieve the objectives, we developed a simple and detailed analysis procedure and built Excel user interface for
data entry, data update and data output, including diagnostic charts and graphs. By
applying our interpretation procedure to the acquired field data we predicted temperature
and pressure along the wellbore. Based on the predicted data, we used an inversion
method to infer the flow profile - demonstrating how the monitored raw downhole
temperature and pressure can be converted into useful knowledge of the phase flow
profiles and fluid entry along the wellbore. Finally, we illustrated the sensitivity of
reservoir parameters on accuracy of interpretation, and generated practical guidelines on
how to initialize the inverse process. Field production logging data were used for
validation and application purposes.
From the analysis, we obtained the production profile along the wellbore; the fluid
entry location i.e. the productive and non-productive locations along the wellbore; and
identified the fluid type i.e. gas or water being produced along the wellbore. These
results show that temperature and pressure profiles could provide sufficient information
for fluid identity and inflow distribution in gas wells.
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Modeling well performance in compartmentalized gas reservoirsYusuf, Nurudeen 10 October 2008 (has links)
Predicting the performance of wells in compartmentalized reservoirs can be quite
challenging to most conventional reservoir engineering tools. The purpose of this
research is to develop a Compartmentalized Gas Depletion Model that applies not only
to conventional consolidated reservoirs (with constant formation compressibility) but
also to unconsolidated reservoirs (with variable formation compressibility) by including
geomechanics, permeability deterioration and compartmentalization to estimate the
OGIP and performance characteristics of each compartment in such reservoirs given
production data.
A geomechanics model was developed using available correlation in the industry
to estimate variable pore volume compressibility, reservoir compaction and permeability
reduction. The geomechanics calculations were combined with gas material balance
equation and pseudo-steady state equation and the model was used to predict well
performance.
Simulated production data from a conventional gas Simulator was used for
consolidated reservoir cases while synthetic data (generated by the model using known parameters) was used for unconsolidated reservoir cases. In both cases, the
Compartmentalized Depletion Model was used to analyze data, and estimate the OGIP
and Jg of each compartment in a compartmentalized gas reservoir and predict the
subsequent reservoir performance. The analysis was done by history-matching gas rate
with the model using an optimization technique.
The model gave satisfactory results with both consolidated and unconsolidated
reservoirs for single and multiple reservoir layers. It was demonstrated that for
unconsolidated reservoirs, reduction in permeability and reservoir compaction could be
very significant especially for unconsolidated gas reservoirs with large pay thickness and
large depletion pressure.
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Development of a successful chemical treatment of gas wells with condensate or water blocking damageBang, Vishal, 1980- 29 August 2008 (has links)
During production from gas condensate reservoirs, significant productivity loss occurs after the pressure near the production wells drops below the dew point of the hydrocarbon fluid. Several methods such as gas recycling, hydraulic fracturing and solvent injection have been tried to restore gas production rates after a decline in well productivity owing to condensate and/or water blocking. These methods of well stimulation offer only temporary productivity restoration and cannot always be used for a variety of reasons. Significant advances have been made during this study to develop and extend a chemical treatment to reduce the damage caused by liquid (condensate + water) blocking in gas condensate reservoirs. The chemical treatment alters the wettability of water-wet sandstone rocks to neutral wet, and thus reduces the residual liquid saturations and increases gas relative permeability. The treatment also increases the mobility and recovery of condensate from the reservoir. A nonionic polymeric fluoro-surfactant in a glycol-alcohol solvent mixture improved the gas and condensate relative permeabilities by a factor of about 2 on various outcrop and reservoir sandstone rocks. The improvement in relative permeability after chemical treatment was quantified by performing high pressure and high temperature coreflood experiments on outcrop and reservoir cores using synthetic gas mixtures at reservoir conditions. The durability of the chemical treatment has been tested by flowing a large volume of gas-condensate fluids for a long period of time. Solvents used to dissolve and deliver the surfactant play an important part in the treatment, especially in the presence of high water saturation or high salinity brine. A screening test based on phase behavior studies of treatment solutions and brines has been used to select appropriate mixtures of solvents based on reservoir conditions. The adsorption of the surfactant on the rock surface has been measured by measuring the concentration of the surfactant in the effluent. Wettability of treated and untreated reservoir rocks has been analyzed by measuring the USBM and Amott-Harvey wettability indices to evaluate the effect of chemical treatment on wettability. For the first time, chemical treatments have also been shown to remove the damage caused by water blocking in gas wells and for increasing the fracture conductivity and thus productivity of fractured gas-condensate wells. Core flood experiments done on propped fractures show significant improvement in gas and condensate relative permeability due to surface modification of proppants by chemical reatment. Relative permeability measurements have been done on sandstone and limestone cores over a wide range of conditions including high velocities typical of high rate gas wells and corresponding to both high capillary numbers and non-Darcy flow. A new approach has been presented to express relative permeability as a function three non-dimensionless terms; capillary number, modified Reynolds Number and PVT ratio. Numerical simulations using a compositional simulator have been done to better understand and design well treatments as a function of treatment volume and other parameters. Injection of treatment solution and chase gas and the flow back of solvents were simulated. These simulations show that chemical treatments have the potential to greatly increase production with relatively small treatment volumes since only the near-well region blocked by condensate and/or water needs to be treated.
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A study of the effects of well and fracture design in a typical Marcellus shale wellSchweitzer, Ross T. January 1900 (has links)
Thesis (M.S.)--West Virginia University, 2009. / Title from document title page. Document formatted into pages; contains ix, 100 p. : ill. (some col.), col. maps. Includes abstract. Includes bibliographical references (p. 72-73).
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Acoustical signal during hydraulic fracturingKing, Jeremy Scott, January 1999 (has links)
Thesis (M.S.)--West Virginia University, 1999. / Title from document title page. Document formatted into pages; contains x, 82 p. : ill. (some col.) Vita. Includes abstract. Includes bibliographical references (p. 42).
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