Spelling suggestions: "subject:"gas cells""
41 |
[en] TOTAL ANALYSIS METHODOLOGY FOR THE DEVELOPMENT OF A NATURAL GAS FIELD / [pt] METODOLOGIA DE ANÁLISE GLOBAL PARA O DESENVOLVIMENTO DE UM CAMPO DE GÁS NATURALOSCAR HERNAN JALIL GUITERAS 22 October 2003 (has links)
[pt] Para que ocorra o fluxo de fluidos em um sistema de
produção é necessário que a energia dos fluidos no
reservatório seja capaz de superar as perdas de carga nos
diversos componentes do sistema. Os fluidos têm que escoar
do reservatório aos separadores na superfície, passando
pelas tubulações de produção dos poços, pelos equipamentos
de cabeça de poço e pelas linhas de surgência. O projeto de
um sistema de produção não deve ser executado considerando
independentemente o desempenho do reservatório e o cálculo
do fluxo nas tubulações de produção e nas linhas e
equipamentos de superfície. A avaliação do desempenho de um
sistema de produção de gás requer a aplicação de um
método de análise total que considere simultaneamente o
escoamento nos diversos segmentos do sistema. A análise
total de um sistema de produção, pode ser efetuada por
um método gráfico - analítico a ser empregado no desenho de
completação de poços de gás e petróleo com ou sem
levantamento artificial. Em termos de conceito de análise
total, um sistema de produção é constituído basicamente
pelos elementos: reservatório, tubo de produção vertical,
linhas de fluxo horizontal e separador, incluindo válvulas
de fundo de poço e choke superficiais, onde ocorrem uma
certa perda de pressão relacionada com a vazão. O
comportamento de fluxo de cada elemento do sistema total
de produção é representado por uma equação que relaciona a
pressão num nó selecionado e a vazão de produção. O cálculo
seqüencial das pressões nos diferentes nós dos diversos
elementos do sistema permite que a vazão de produção do
poço seja determinada. Para calcular a relação da vazão com
as mudanças de pressão que ocorrem durante o transporte do
fluido à superfície e conseqüente variação das propriedades
físicas do fluido, efetuou-se uma revisão dos conceitos de
engenharia de reservatório, correlações de fluxo em
tubulações verticais, horizontais e restrições. Finalmente,
realizou-se uma análise de sensibilidade da metodologia ao
emprego das diferentes relações de performance de fluxo e
dos métodos de cálculo de fluxo em poços e linhas. / [en] For the flow of fluids to occur in a production system, the
fluids energy in the reservoir must be capable of
overcoming load losses along various system components.
Fluids must flow from the reservoir to the surface
separators through the wells tubing, wellhead equipment
and flowing lines. The production system design must not be
executed by considering separately the performance of the
reservoir and the flow calculation across the tubing,
surface equipment and lines. The evaluation of a gas
production system performance requires applying a total
analysis method that considers the drainage at various
system segments simultaneously. The total analysis of a
production system can be effected through a graphical-
analytical method to be used for the completion design of
oil and gas wells with or without artificial lift. In terms
of total analysis concept, a production system is basically
comprised of the following components: reservoir, vertical
tubing, horizontal flow lines and separator, including
bottom-hole valves and surface choke, where some pressure
loss occurs in relation to the flow rate. The flow behavior
of each component in a total production system is
represented by an equation that relates the pressure at one
selected node and the production flow rate. The sequential
pressure calculation at the different nodes of various
system components allows determining the well s production
flow rate. In order to calculate the relationship between
the flow rate and the pressure changes that occur during
fluid transportation to the surface, with the resulting
variation of the fluid s engineering, flow correlations in
vertical and horizontal tubing, and restrictions. Finally,
we proceeded to analyze the methodology s sensitivity to
the use of different flow performance relations and flow
calculation methods in wells and lines.
|
42 |
The Mist gas field, N.W. Oregon : source rock characterization and stable isotope (C,H,N) geochemistryStormberg, Gregory J. 28 June 1991 (has links)
Graduation date: 1992
|
43 |
A coupled wellbore/reservoir simulator to model multiphase flow and temperature distributionPourafshary, Peyman, 1979- 29 August 2008 (has links)
Hydrocarbon reserves are generally produced through wells drilled into reservoir pay zones. During production, gas liberation from the oil phase occurs due to pressure decline in the wellbore. Thus, we expect multiphase flow in some sections of the wellbore. As a multi-phase/multi-component gas-oil mixture flows from the reservoir to the surface, pressure, temperature, composition, and liquid holdup distributions are interrelated. Modeling these multiphase flow parameters is important to design production strategies such as artificial lift procedures. A wellbore fluid flow model can also be used for pressure transient test analysis and interpretation. Considering heat exchange in the wellbore is important to compute fluid flow parameters accurately. Modeling multiphase fluid flow in the wellbore becomes more complicated due to heat transfer between the wellbore fluids and the surrounding formations. Due to mass, momentum, and energy exchange between the wellbore and the reservoir, the wellbore model should be coupled with a numerical reservoir model to simulate fluid flow accurately. This model should be non-isothermal to consider the effect of temperature. Our research shows that, in some cases, ignoring compositional effects may lead to errors in pressure profile prediction for the wellbore. Nearly all multiphase wellbore simulations are currently performed using the "black oil" approach. The primary objective of this study was to develop a non-isothermal wellbore simulator to model transient fluid flow and temperature and couple the model to a reservoir simulator called General Purpose Adaptive Simulator (GPAS). The coupled wellbore/reservoir simulator can be applied to steady state problems, such as production from, or injection to a reservoir as well as during transient phenomena such as well tests to accurately model wellbore effects. Fluid flow in the wellbore may be modeled either using the blackoil approach or the compositional approach, as required by the complexity of the fluids. The simulation results of the new model were compared with field data for pressure gradients and temperature distribution obtained from wireline conveyed pressure recorder and acoustic fluid level measurements for a gas/oil producer well during a buildup test. The model results are in good agreement with the field data. Our simulator gave us further insights into the wellbore dynamics that occur during transient problems such as phase segregation and counter-current multiphase flow. We show that neglecting these multiphase flow dynamics would lead to unreliable results in well testing analysis.
|
44 |
Defining Correlation Between Radon, Uranium Deposits, and Oil and Gas Wells Using GIS Regression MethodsBandreddy, Naga Abhiram 04 September 2019 (has links)
No description available.
|
45 |
Simulation and design of energized hydraulic fracturesFriehauf, Kyle Eugene 23 October 2009 (has links)
Hydraulic fracturing is essential for producing gas and oil at an economic rate from low permeability sands. Most fracturing treatments use water and polymers with a gelling agent as a fracturing fluid. The water is held in the small pore spaces by capillary pressure and is not recovered when drawdown pressures are low. The un-recovered water leaves a water saturated zone around the fracture face that stops the flow of gas into the fracture. This is a particularly acute problem in low permeability formations where capillary pressures are high. Depletion (lower reservoir pressures) causes a limitation on the drawdown pressure that can be applied. A hydraulic fracturing process can be energized by the addition of a compressible, sometimes soluble, gas phase into the treatment fluid. When the well is produced, the energized fluid expands and gas comes out of solution. Energizing the fluid creates high gas saturation in the invaded zone, thereby facilitating gas flowback. A new compositional hydraulic fracturing model has been created (EFRAC). This is the first model to include changes in composition, temperature, and phase behavior of the fluid inside the fracture. An equation of state is used to evaluate the phase behavior of the fluid. These compositional effects are coupled with the fluid rheology, proppant transport, and mechanics of fracture growth to create a general model for fracture creation when energized fluids are used. In addition to the fracture propagation model, we have also introduced another new model for hydraulically fractured well productivity. This is the first and only model that takes into account both finite fracture conductivity and damage in the invaded zone in a simple analytical way. EFRAC was successfully used to simulate several fracture treatments in a gas field in South Texas. Based on production estimates, energized fluids may be required when drawdown pressures are smaller than the capillary forces in the formation. For this field, the minimum CO2 gas quality (volume % of gas) recommended is 30% for moderate differences between fracture and reservoir pressures (2900 psi reservoir, 5300 psi fracture). The minimum quality is reduced to 20% when the difference between pressures is larger, resulting in additional gas expansion in the invaded zone. Inlet fluid temperature, flowrate, and base viscosity did not have a large impact on fracture production. Finally, every stage of the fracturing treatment should be energized with a gas component to ensure high gas saturation in the invaded zone. A second, more general, sensitivity study was conducted. Simulations show that CO2 outperforms N2 as a fluid component because it has higher solubility in water at fracturing temperatures and pressures. In fact, all gas components with higher solubility in water will increase the fluid’s ability to reduce damage in the invaded zone. Adding methanol to the fracturing solution can increase the solubility of CO2. N2 should only be used if the gas leaks-off either during the creation of the fracture or during closure, resulting in gas going into the invaded zone. Experimental data is needed to determine if the gas phase leaks-off during the creation of the fracture. Simulations show that the bubbles in a fluid traveling across the face of a porous medium are not likely to attach to the surface of the rock, the filter cake, or penetrate far into the porous medium. In summary, this research has created the first compositional fracturing simulator, a useful tool to aid in energized fracture design. We have made several important and original conclusions about the best practices when using energized fluids in tight gas sands. The models and tools presented here may be used in the future to predict behavior of any multi-phase or multi-component fracturing fluid system. / text
|
46 |
The Landscape Legacies of Gas Drilling in North TexasSakinejad, Michael Cyrus 05 1900 (has links)
In North Texas, the Barnett Shale underlies large areas of the Dallas-Fort Worth Metroplex (DFW), which magnifies debates about the externalities of shale gas development (SGD). Continued demand for natural gas and expansive urbanization in DFW will cause more people to come in contact with drilling rigs, gas transport, and other urban shale gas landscapes. Thousands of gas wells within the DFW region occupy a large, yet scattered land surface area. DFW city planners, elected officials, and other stakeholders must deal with current and future urban growth and the surface impacts that are associated with gas development. This research examines how shale gas landscapes affect urban land uses, landscapes, and patterns of development in DFW. The study focuses on multiple fast growing DFW municipalities that also have high numbers of gas well pad sites. This study asks what are the spatial characteristics of gas well production sites in DFW and how do these sites vary across the region; how do gas well production sites affect urban growth and development; and how are city governments and surface developers responding to gas well production sites, and what are the dominant themes of contestation arising around gas well production sites and suburban growth?
|
47 |
Assessment of Soil Properties in Proximity to Abandoned Oil Wells usingRemote Sensing and Clay X-ray Analysis, Wood County, OhioMagdic, Matthew James 21 July 2016 (has links)
No description available.
|
48 |
Estimation of Air Emissions During Production Phase from Active Oil and Gas Wells in the Barnett Shale Basin: 2010-2013Dohde, Farhan A. 05 1900 (has links)
The Barnett shale basin, the largest onshore gas field in the state of Texas, mainly produces natural gas. The basin’s oil and gas productions have dramatically increased over the past two decades with the enhancement via shale fracturing (fracking) technology. However, recent studies suggest that air emissions from shale fracking have significantly contributed to the growing air pollution problem in North Texas. In this study, air emissions from the Barnett shale basin during the production phase of the oil and gas activities (once the product is collected from the wells) are quantified. Oil and gas production data were acquired from the Texas Railroad Commission for the baseline years of 2010 through 2013. Methodology from prior studies on shale basins approved by the Texas Commission on Environmental Quality was employed in this study and the emission inventories from the production phase sources were quantified. Accordingly, the counties with the most gas operations in the basin, Tarrant, Johnson, Denton and Wise, were found to be the highest emitters of air pollutants. Tarrant County was responsible for the highest emitted NOx (42,566 tons) and CO (17,698 tons) in the basin, while Montague County released the maximum VOC emissions (87,601 tons) during the study period. Amongst the concerned emitted pollutants, VOC was the largest emitted pollutant during the study period (417,804 tons), followed by NOx (126,691 tons) and CO (47,884 tons). Significant Sources of air emissions include: storage tanks, wellhead compressor engines, and pneumatic devices. Storage tanks and pneumatic devices contributed to about 62% and 28% of the total VOC emissions, respectively. Whereas, wellhead compressor engines are primarily responsible for about 97% of the total NOx emissions. Finally, in Tarrant, Wise and Denton counties, the emissions increased during the study period due to increase in the oil and gas production, while Johnson County’s emission contribution declined throughout the study period.
|
49 |
Ozone Pollution of Shale Gas Activities in North TexasAhmadi, Mahdi 05 1900 (has links)
The effect of shale gas activities on ground-level ozone pollution in the Dallas-Fort Worth area is studied in detail here. Ozone is a highly reactive species with harmful effects on human and environment. Shale gas development, or fracking, involves activities such as hydraulic fracturing, drilling, fluid mixing, and trucks idling that are sources of nitrogen oxides (NOX) and volatile organic compounds (VOC), two of the most important precursors of ozone. In this study two independent approaches have been applied in evaluating the influences on ozone concentrations. In the first approach, the influence of meteorology were removed from ozone time series through the application of Kolmogorov-Zurbenko low-pass filter, logarithmic transformation, and subsequent multi-linear regression. Ozone measurement data were acquired from Texas Commission on Environmental Quality (TCEQ) monitoring stations for 14 years. The comparison between ozone trends in non-shale gas region and shale gas region shows increasing ozone trends at the monitoring stations in close proximity to the Barnett Shale activities. In the second approach, the CAMx photochemical model was used to assess the sensitivity of ozone to the NOX and VOC sources associated with shale oil and gas activities. Brute force method was applied on Barnett Shale and Haynesville Shale emission sources to generate four hypothetical scenarios. Ozone sensitivity analysis was performed for a future year of 2018 and it was based on the photochemical simulation that TCEQ had developed for demonstrating ozone attainment under the State Implementation Plan (SIP). Results showed various level of ozone impact at different locations within the DFW region attributed to area and point sources of emissions in the shale region. Maximum ozone impact due to shale gas activities is expected to be in the order of several parts per billion, while lower impacts on design values were predicted. The results from the photochemical modeling can be used for health impact assessment and air quality management purposes. Both studies in this research show that the impact of shale gas development on local and regional level of ozone is significant, and therefore, it should be considered in the implementation of effective air quality strategies.
|
50 |
Maximal Proposition, Environmental Melodrama, and the Rhetoric of Local Movements: A Study of The Anti-Fracking Movement in Denton, TexasHensley, Colton Dwayne 12 1900 (has links)
The environmental problems associated with the boom in hydraulic fracturing or "fracking," such as anthropogenic earthquakes and groundwater contamination, have motivated some citizens living in affected areas such as Denton, Texas to form movements with the goal of imposing greater regulation on the industry. As responses to an environmental threat that is localized and yet mobile, these anti-fracking movements must construct rhetorical appeals with complicated relationships to place. In this thesis, I examine the anti-fracking movement in Denton, Texas in a series of three rhetorical analyses. In the first, I compared fracking bans used by Frack Free Denton and State College, Pennsylvania to distinguish the argumentative claims that are dependent on the politics of place, and affect strategies localities must use in resisting natural gas extraction. In the second, I compare campaign strategies that use local identity as a way of invoking legitimacy, which reinforces narrative frameworks of environmental risk. In the third, I conduct and analyze interviews with anti-fracking leaders who described the narrative of their movement, which highlighted tensions in the rhetorical construction of a movement as local. Altogether, this thesis traces the rhetorical conception of place across the rhetoric of the anti-fracking movement in Denton, Texas, while seeking to demonstrate the value of combining rhetorical criticism with rhetorical field methods.
|
Page generated in 0.0663 seconds