Relevant bibliographies by topics / Gas reservoirs. Gas wells. Shale

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'Gas reservoirs. Gas wells. Shale'

Author: Grafiati
Published: 4 June 2021
Last updated: 12 February 2022

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Journal articles on the topic "Gas reservoirs. Gas wells. Shale"

1

Tao, Hong Hua, Li Jun Cheng, Jun Feng Liu, and Zhao Hui Lu. "Pressure Transient Analysis for Partial Open Fractured Wells in Shale Gas Reservoirs." Applied Mechanics and Materials 535 (February 2014): 75–83. http://dx.doi.org/10.4028/www.scientific.net/amm.535.75.

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Shale gas has been paid much attention for its great potential as the unconventional energy all over the world. The great success in North America shale gas exploration and development has stimulated the exploration and development of shale gas in China. Shale gas is much different from conventional gas reservoir with its highly difficult in exploration, high technical requirements and expensive costs, so the mechanism study, characterization study and development technology of shale gas are much more important than ever before.Therefore, according to the characteristic of desorption, diffusion and seepage, a seepage model of partial open fractured wells in shale gas reservoirs has been established. The plots of pressure characteristic curves are drawn.The flowing phases are divided in the pressure characteristic curves.The factors which affect the pressure dynamic characteristics are discussed. The results can help people to understand the flow mechanism of fractured wells in shale gas reservoirs and provide the theoretical support for the high-efficiency development of shale gas reservoirs using fractured wells.
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Li, Lei, Guanglong Sheng, and Yuliang Su. "Water-Gas Two-Phase Flow Behavior of Multi-Fractured Horizontal Wells in Shale Gas Reservoirs." Processes 7, no. 10 (September 27, 2019): 664. http://dx.doi.org/10.3390/pr7100664.

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Hydraulic fracturing is a necessary method to develop shale gas reservoirs effectively and economically. However, the flow behavior in multi-porosity fractured reservoirs is difficult to characterize by conventional methods. In this paper, combined with apparent porosity/permeability model of organic matter, inorganic matter and induced fractures, considering the water film in unstimulated reservoir volume (USRV) region water and bulk water in effectively stimulated reservoir volume (ESRV) region, a multi-media water-gas two-phase flow model was established. The finite difference is used to solve the model and the water-gas two-phase flow behavior of multi-fractured horizontal wells is obtained. Mass transfer between different-scale media, the effects of pore pressure on reservoirs and fluid properties at different production stages were considered in this model. The influence of the dynamic reservoir physical parameters on flow behavior and gas production in multi-fractured horizontal wells is studied. The results show that the properties of the total organic content (TOC) and the inherent porosity of the organic matter affect gas production after 40 days. With the gradual increase of production time, the gas production rate decreases rapidly compared with the water production rate, and the gas saturation in the inorganic matter of the ESRV region gradually decreases. The ignorance of stress sensitivity would cause the gas production increase, and the ignorance of organic matter shrinkage decrease the gas production gradually. The water film mainly affects gas production after 100 days, while the bulk water has a greater impact on gas production throughout the whole period. The research provides a new method to accurately describe the two-phase fluid flow behavior in different scale media of fractured shale gas reservoirs.
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Diwu, Peng Xiang, Rui Liu, Tong Jing Liu, and Bin Jia. "Productivity Evaluation Study of Shale Gas Reservoirs." Advanced Materials Research 1073-1076 (December 2014): 2296–99. http://dx.doi.org/10.4028/www.scientific.net/amr.1073-1076.2296.

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The seepage mechanism of unconventional gas is very complex, and has a unique seepage mechanism and dynamic flow characteristics. It is difficult to use conventional gas production capacity to predict recoverable reserves. In this paper, starting from fluid mechanics, based on reservoir characteristics of the shale gas fracturing, a composite model of shale gas reservoirs was established, and stable production time was determined. We analyzed the effects of inside and outside zone permeability, the radius, pressure gradient, desorption influence of the compression factor and reservoir thickness, etc., and the established a shale gas well productivity equation refer to Vogel equation. The results show that: area permeability, penetration outside the area, zone radius, reservoir thickness and desorption compression factor were sensitive to shale gas production capacity; skin factor and the pressure gradient is not sensitive factor; through reliability analysis, the productivity formula which was referred to Vogel equation can determine the production capacity of shale gas wells quickly and accurately.
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Zhan, Jie, Zhihao Niu, Mengmeng Li, Ying Zhang, Xianlin Ma, Chao Fan, and Ruifei Wang. "Numerical Simulation and Modeling on CO2 Sequestration Coupled with Enhanced Gas Recovery in Shale Gas Reservoirs." Geofluids 2021 (August 4, 2021): 1–15. http://dx.doi.org/10.1155/2021/9975296.

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CO2 geological sequestration in shale is a promising method to mitigate global warming caused by greenhouse gas emissions as well as to enhance the gas recovery to some degree, which effectively addresses the problems related to energy demand and climate change. With the data from the New Albany Shale in the Illinois Basin in the United States, the CMG-GEM simulator is applied to establish a numerical model to evaluate the feasibility of CO2 sequestration in shale gas reservoirs with potential enhanced gas recovery (EGR). To represent the matrix, natural fractures, and hydraulic fractures in shale gas reservoirs, a multicontinua porous medium model will be developed. Darcy’s and Forchheimer’s models and desorption-adsorption models with a mixing rule will be incorporated into the multicontinua numerical model to depict the three-stage flow mechanism, including convective gas flow mainly in fractures, dispersive gas transport in macropores, and CH4-CO2 competitive sorption phenomenon in micropores. With the established shale reservoir model, different CO2 injection schemes (continuous injection vs. pulse injection) for CO2 sequestration in shale gas reservoirs are investigated. Meanwhile, a sensitivity analysis of the reservoir permeability between the hydraulic fractures of production and injection wells is conducted to quantify its influence on reservoir performance. The permeability multipliers are 10, 100, and 1,000 for the sensitivity study. The results indicate that CO2 can be effectively sequestered in shale reservoirs. But the EGR of both injection schemes does not perform well as expected. In the field application, it is necessary to take the efficiency of supplemental energy utilization, the CO2 sequestration ratio, and the effect of injected CO2 on the purity of produced methane into consideration to design an optimal execution plan. The case with a permeability multiplier of 1,000 meets the demand for both CO2 sequestration and EGR, which indicates that a moderate secondary stimulation zone needs to be formed between the primary hydraulic fractures of injection and production wells to facilitate the efficient energy transfer between interwell as well as to prevent CO2 from channeling. To meet the demand for CO2 sequestration in shale gas reservoirs with EGR, advanced and effective fracking is essential.
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Shang, Xiaofei, Huawei Zhao, Shengxiang Long, and Taizhong Duan. "A Workflow for Integrated Geological Modeling for Shale Gas Reservoirs: A Case Study of the Fuling Shale Gas Reservoir in the Sichuan Basin, China." Geofluids 2021 (August 25, 2021): 1–22. http://dx.doi.org/10.1155/2021/6504831.

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Shale gas reservoir evaluation and production optimization both require geological models. However, currently, shale gas modeling remains relatively conventional and does not reflect the unique characteristics of shale gas reservoirs. Based on a case study of the Fuling shale gas reservoir in China, an integrated geological modeling workflow for shale gas reservoirs is proposed to facilitate its popularization and application and well improved quality and comparability. This workflow involves four types of models: a structure-stratigraphic model, reservoir (matrix) parameter model, natural fracture (NF) model, and hydraulic fracture (HF) model. The modeling strategies used for the four types of models vary due to the uniqueness of shale gas reservoirs. A horizontal-well lithofacies sublayer calibration-based method is employed to build the structure-stratigraphic model. The key to building the reservoir parameter model lies in the joint characterization of shale gas “sweet spots.” The NF models are built at various scales using various methods. Based on the NF models, the HF models are built by extended simulation and microseismic inversion. In the entire workflow, various types of models are built in a certain sequence and mutually constrain one another. In addition, the workflow contains and effectively integrates multisource data. Moreover, the workflow involves multiple model integration processes, which is the key to model quality. The selection and optimization of modeling methods, the innovation and development of modeling algorithms, and the evaluation techniques for model uncertainty are areas where breakthroughs may be possible in the geological modeling of shale gas reservoirs. The workflow allows the complex process of geological modeling of shale gas reservoirs to be more systematic. It is of great significance for a dynamic analysis of reservoir development, from individual wells to the entire gas field, and for optimizing both development schemes and production systems.
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Li, Jun, Yuetian Liu, and Kecong Ma. "Numerical Investigation of Multistage Fractured Horizontal Wells considering Multiphase Flow and Geomechanical Effects." Geofluids 2021 (May 3, 2021): 1–13. http://dx.doi.org/10.1155/2021/5522282.

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Hydraulic fracturing is a key technology in unconventional reservoir production, yet many simulators only consider the single-phase flow of shale gas, ignoring the two-phase flow process caused by the retained fracturing fluid in the early stage of production. In this study, a three-dimensional fluid–gas–solid coupling reservoir model is proposed, and the governing equations which involve the early injection water phenomenon and stress-sensitive characteristics of shale gas reservoirs are established. The finite element–finite difference method was used for discretisation of stress and strain equations and the equations of flow balances. Further, a sensitivity analysis was conducted to analyse fracture deformation changes in the production. Fracture characteristics under different rock mechanics coefficients were simulated, and the influence of rock mechanics parameters on productivity was further characterised. The stimulated reservoir volume zone permeability could determine the retrofitting effect, the permeability increased from 0.02 to 0.1 mD, and cumulative gas production increased from 18.08 to 26.42 million m3, thus showing an increase of 8.34 million m3, or 46%. The effect of Young’s modulus on the yield was smaller than Poisson’s ratio and the width and length of the fractures. Production was most sensitive to the length of the fractures. The length of the fracture increased from 200 to 400 m, and the cumulative gas production increased from 26.44 to 38.34 million m3, showing an increase of 11.9 million m3, or 45%. This study deepens the understanding of the production process of shale gas reservoirs and has significance for the fluid–gas–solid coupling of shale gas reservoirs.
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SHENG, GUANGLONG, YULIANG SU, WENDONG WANG, FARZAM JAVADPOUR, and MEIRONG TANG. "APPLICATION OF FRACTAL GEOMETRY IN EVALUATION OF EFFECTIVE STIMULATED RESERVOIR VOLUME IN SHALE GAS RESERVOIRS." Fractals 25, no. 04 (July 25, 2017): 1740007. http://dx.doi.org/10.1142/s0218348x17400072.

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According to hydraulic-fracturing practices conducted in shale reservoirs, effective stimulated reservoir volume (ESRV) significantly affects the production of hydraulic fractured well. Therefore, estimating ESRV is an important prerequisite for confirming the success of hydraulic fracturing and predicting the production of hydraulic fracturing wells in shale reservoirs. However, ESRV calculation remains a longstanding challenge in hydraulic-fracturing operation. In considering fractal characteristics of the fracture network in stimulated reservoir volume (SRV), this paper introduces a fractal random-fracture-network algorithm for converting the microseismic data into fractal geometry. Five key parameters, including bifurcation direction, generating length ([Formula: see text]), deviation angle ([Formula: see text]), iteration times ([Formula: see text]) and generating rules, are proposed to quantitatively characterize fracture geometry. Furthermore, we introduce an orthogonal-fractures coupled dual-porosity-media representation elementary volume (REV) flow model to predict the volumetric flux of gas in shale reservoirs. On the basis of the migration of adsorbed gas in porous kerogen of REV with different fracture spaces, an ESRV criterion for shale reservoirs with SRV is proposed. Eventually, combining the ESRV criterion and fractal characteristic of a fracture network, we propose a new approach for evaluating ESRV in shale reservoirs. The approach has been used in the Eagle Ford shale gas reservoir, and results show that the fracture space has a measurable influence on migration of adsorbed gas. The fracture network can contribute to enhancement of the absorbed gas recovery ratio when the fracture space is less than 0.2 m. ESRV is evaluated in this paper, and results indicate that the ESRV accounts for 27.87% of the total SRV in shale gas reservoirs. This work is important and timely for evaluating fracturing effect and predicting production of hydraulic fracturing wells in shale reservoirs.
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Kou, Hui Hui, Wei Dong Liu, Dong Dong Hou, and Ling Hui Sun. "Recognition of Fracturing by Stimulated Reservoir Volume (SRV) in Shale Gas Wells." Advanced Materials Research 361-363 (October 2011): 349–52. http://dx.doi.org/10.4028/www.scientific.net/amr.361-363.349.

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Ultra-low permeability shale reservoir require a large fracture network to maximal well performance. In conventional reservoirs and tight gas sands, single fracture length and conductivity are the key drivers for stimulation performance. In shale reservoirs, where complex fracture network are created, single fracture length and conductivity are insufficient to stimulate. This is the reason for the concept of using stimulated reservoir volume as a correlation parameter for well performance. This paper mainly illustrates perforation with interlaced row well pattern and multi-fracture fracturing technology and refracturing applied in vertical wells. Moreover, it establishes the seepage differential equation of multi-fracture.
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Zhang, Bo-ning, Xiao-gang Li, Yu-long Zhao, Cheng Chang, and Jian Zheng. "A Review of Gas Flow and Its Mathematical Models in Shale Gas Reservoirs." Geofluids 2020 (November 30, 2020): 1–19. http://dx.doi.org/10.1155/2020/8877777.

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The application of horizontal wells with multistage hydraulic fracturing technologies has made the development of shale gas reservoirs become a worldwide economical hotspot in recent years. The gas transport mechanisms in shale gas reservoirs are complicated, due to the multiple types of pores with complex pore structure and special process of gas accumulation and transport. Although there have been many attempts to come up with a suitable and practical mathematical model to characterize the shale gas flow process, no unified model has yet been accepted by academia. In this paper, a comprehensive literature review on the mathematical models developed in recent years for describing gas flow in shale gas reservoirs is summarized. Five models incorporating different transport mechanisms are reviewed, including gas viscous flow in natural fractures or macropores, gas ad-desorption on shale organic, gas slippage, diffusion (Knudsen diffusion, Fick diffusion, and surface diffusion), stress dependence, real gas effect, and adsorption layer effect in the nanoshale matrix system, which is quite different from conventional gas reservoir. This review is very helpful to understand the complex gas flow behaviors in shale gas reservoirs and guide the efficient development of shale gas. In addition to the model description, we depicted the type curves of fractured horizontal well with different seepage models. From the review, it can be found that there is some misunderstanding about the essence of Knudsen/Fick diffusion and slippage, which makes different scholars adopt different weighting methods to consider them. Besides, the contribution of each mechanism on the transport mechanisms is still controversial, which needs further in-depth study in the future.
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Mu, Song Ru, and Shi Cheng Zhang. "Numerical Simulation of Shale Gas Production." Advanced Materials Research 402 (November 2011): 804–7. http://dx.doi.org/10.4028/www.scientific.net/amr.402.804.

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Shale gas reservoirs require a large fracture network to maximize well performance. Microseismic fracture mapping has shown that large fracture networks can be generated in many shale reservoirs. The application of microseismic fracture mapping measurements requires estimation of the structure of the complex hydraulic fracture or the volume of the reservoir that has been stimulated by the fracture treatment. There are three primary approaches used to incorporate microseismic measurements into reservoir simulation models: discrete modeling of the complex fracture network, wire-mesh model, and dual porosity model. This paper discuss the different simulation model, the results provided insights into effective stimulation designs and flow mechanism for shale gas reservoirs.
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Dissertations / Theses on the topic "Gas reservoirs. Gas wells. Shale"

1

Kalantari-Dahaghi, Amirmasoud. "Reservoir modeling of New Albany Shale." Morgantown, W. Va. : [West Virginia University Libraries], 2010. http://hdl.handle.net/10450/11022.

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Thesis (M.S.)--West Virginia University, 2010.
Title from document title page. Document formatted into pages; contains xii, 81 p. : ill. (some col.), col. maps. Includes abstract. Includes bibliographical references (p. 68-69).
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Erturk, Mehmet Cihan. "Production Performance Analysis Of Coal Bed Methane, Shale Gas, Andtight Gas Reservoirs With Different Well Trajectories And Completiontechniques." Master's thesis, METU, 2013. http://etd.lib.metu.edu.tr/upload/12615510/index.pdf.

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The large amount of produced oil and gas come from conventional resources all over the world and these resources are being depleted rapidly. This fact and the increasing oil and gas prices force the producing countries to find and search for new methods to recover more oil and gas. In order to meet the demand, the oil and gas industry has been turning towards to unconventional oil and gas reservoirs which become more popular every passing day. In recent years, they are seriously considered as supplementary to the conventional resources although these reservoirs cannot be produced at an economic rate or cannot produce economic volumes of oil and gas without assistance from massive stimulation treatments, special recovery processes or advanced technologies. The vast increase in demand for petroleum and gas has encouraged the new technological development and implementation. A wide range of technologies have been developed and deployed since 1980. With the wellbore technology, it is possible to make use of highly deviated wellbores, extended reach drilling, horizontal wells, multilateral wells and so on. All of the new technologies and a large number of new innovations have allowed development of increasingly complex economically marginal fields where shale gas and coal bed methane are found. In this study, primary target is to compare different production methods in order to obtain better well performance and improved production from different types of reservoirs. It is also be given some technical information regarding the challenges such as hydraulic fracturing and multilateral well configuration of the unconventional gas reservoir modeling and simulation. With the help of advances in algorithms, computer power, and integrated software, it is possible to apply and analyze the effect of the different well trajectories such as vertical, horizontal, and multilateral well on the future production performance of coal bed methane, shale gas, and tight gas reservoirs. A commercial simulator will be used to run the simulations and achieve the best-case scenarios. The study will lead the determination of optimum production methods for three different reservoirs that are explained above under the various circumstances and the understanding the production characteristic and profile of unconventional gas systems.
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Labed, Ismail. "Gas-condensate flow modelling for shale gas reservoirs." Thesis, Robert Gordon University, 2016. http://hdl.handle.net/10059/2144.

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In the last decade, shale reservoirs emerged as one of the fast growing hydrocarbon resources in the world unlocking vast reserves and reshaping the landscape of the oil and gas global market. Gas-condensate reservoirs represent an important part of these resources. The key feature of these reservoirs is the condensate banking which reduces significantly the well deliverability when the condensate forms in the reservoir below the dew point pressure. Although the condensate banking is a well-known problem in conventional reservoirs, the very low permeability of shale matrix and unavailability of proven pressure maintenance techniques make it more challenging in shale reservoirs. The nanoscale range of the pore size in the shale matrix affects the gas flow which deviates from laminar Darcy flow to Knudsen flow resulting in enhanced gas permeability. Furthermore, the phase behaviour of gas-condensate fluids is affected by the high capillary pressure in the matrix causing higher condensate saturation than in bulk conditions. A good understanding and an accurate evaluation of how the condensate builds up in the reservoir and how it affects the gas flow is very important to manage successfully the development of these high-cost hydrocarbon resources. This work investigates the gas Knudsen flow under condensate saturation effect and phase behaviour deviation under capillary pressure of gas-condensate fluids in shale matrix with pore size distribution; and evaluates their effect on well productivity. Supplementary MATLAB codes are provided elsewhere on OpenAIR: http://hdl.handle.net/10059/2145.
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Knudsen, Brage Rugstad. "Production Optimization in Shale Gas Reservoirs." Thesis, Norwegian University of Science and Technology, Department of Engineering Cybernetics, 2010. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-10035.

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Natural gas from organic rich shales has become an important part of the supply of natural gas in the United States. Modern drilling and stimulation techniques have increased the potential and profitability of shale gas reserves that earlier were regarded as unprofitable resources of natural gas. The most prominent property of shale gas reservoirs is the low permeability. This is also the reason why recovery from shale gas wells is challenging and clarifies the need for stimulation with hydraulic fracturing. Shale gas wells typically exhibit a high initial peak in the production rate with a successive rapid decline followed by low production rates. Liquid accumulation is common in shale wells and is detrimental on the production rates. Shut-ins of shale gas wells is used as a means to prevent liquid loading and boost the production. This strategy is used in a model-based production optimization of one and multiple shale gas well with the objective of maximizing the production and long-term recovery. The optimization problem is formulated using a simultaneous implementation of the reservoir model and the optimization problem, with binary variables to model on/off valves and an imposed minimal production rate to prevent liquid loading. A reformulation of the nonlinear well model is applied to transform the problem from a mixed integer nonlinear program to a mixed integer linear program. Four numerical examples are presented to review the potential of using model-based optimization on shale gas wells. The use of shut-ins with variable duration is observed to result in minimal loss of cumulative production on the long term recovery. For short term production planning, a set of optimal production settings are solved for multiple wells with global constraints on the production rate and on the switching capacity. The reformulation to a mixed integer linear program is shown to be effective on the formulated optimization problems and allows for assessment of the error bounds of the solution.

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Hartigan, David Anthony. "The petrophysical properties of shale gas reservoirs." Thesis, University of Leicester, 2015. http://hdl.handle.net/2381/32213.

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A significant challenge to the petrophysical evaluation of shale gas systems can be attributed to the conductivity behaviour of clay minerals. This is compounded by centimetre to sub-millimetre vertical and lateral heterogeneity in formation geological and therefore petrophysical properties. Despite this however, we remain reliant on Archie based methods for determining water saturation (Sw), and hence the free gas saturation (1-Sg) in shale gas systems. There is however significant uncertainty in both how resistivity methods are applied and the saturation estimates they produce, due largely as Archie parameter inputs (e.g. a, m, n, and Rw) are difficult to determine in shale gas systems, where obtaining a water sample, or carrying out laboratory experiments on recovered core is often technically impractical. This research assesses the geological implications for, and controls on, variations in pseudo Archie parameters in the Bossier and Haynesville Shale Formations in the northern Gulf of Mexico basin. Investigation has particularly focused on the numerical analysis and systematic modification of Archie parameter values to minimise the error between core SW (Dean Stark analysis) and computed Sw values. Results show that the use of optimised Archie parameters can be effective in predicting SW, particularly in the Haynesville formation, but identifies systematic bias in generated Archie parameters that precludes their accurate physical interpretation. Analysis also suggests that variability in the resistivity (Rt) log response is the principal source of error in Sw estimates in the Bossier Shale. Moreover, results suggest that where clay volume exceeds 28%, the resistivity response becomes increasingly variable and elevated, indicating an apparent clay associated ‘excess resistivity’. This is explained by a geologically consistent model that links increasing clay volume to bulk pore water freshening, supported by empirical adaptations that allow for improved Archie parameter selection and a further reduction in the error of Sw estimates.
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Serra, Kelsen Valente. "Well testing for solution gas drive reservoirs /." Access abstract and link to full text, 1988. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/8811978.

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Yusuf, Nurudeen. "Modeling well performance in compartmentalized gas reservoirs." [College Station, Tex. : Texas A&M University, 2007. http://hdl.handle.net/1969.1/ETD-TAMU-2107.

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Adeyeye, Adedeji Ayoola. "Gas condensate damage in hydraulically fractured wells." Texas A&M University, 2003. http://hdl.handle.net/1969.1/213.

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This project is a research into the effect of gas condensate damage in hydraulically fractured wells. It is the result of a problem encountered in producing a low permeability formation from a well in South Texas owned by the El Paso Production Company. The well was producing a gas condensate reservoir and questions were raised about how much drop in flowing bottomhole pressure below dewpoint would be appropriate. Condensate damage in the hydraulic fracture was expected to be of significant effect. Previous attempts to answer these questions have been from the perspective of a radial model. Condensate builds up in the reservoir as the reservoir pressure drops below the dewpoint pressure. As a result, the gas moving to the wellbore becomes leaner. With respect to the study by El-Banbi and McCain, the gas production rate may stabilize, or possibly increase, after the period of initial decline. This is controlled primarily by the condensate saturation near the wellbore. This current work has a totally different approach. The effects of reservoir depletion are minimized by introduction of an injector well with fluid composition the same as the original reservoir fluid. It also assumes an infinite conductivity hydraulic fracture and uses a linear model. During the research, gas condensate simulations were performed using a commercial simulator (CMG). The results of this research are a step forward in helping to improve the management of gas condensate reservoirs by understanding the mechanics of liquid build-up. It also provides methodology for quantifying the condensate damage that impairs linear flow of gas into the hydraulic fracture.
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Yussefabad, Arman G. "A simple and reliable method for gas well deliverability determination." Morgantown, W. Va. : [West Virginia University Libraries], 2007. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=5280.

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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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Eljack, Hassan Daffalla. "Combine gas deliverability equation for reservoir and well." Morgantown, W. Va. : [West Virginia University Libraries], 2007. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=5285.

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Thesis (M.S.)--West Virginia University, 2007.
Title from document title page. Document formatted into pages; contains viii, 56 p. : ill. (some col.). Vita. Includes abstract. Includes bibliographical references (p. 45-46).
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Books on the topic "Gas reservoirs. Gas wells. Shale"

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Schamel, Steven. Shale gas resources of Utah: Assessment of previously undeveloped gas discoveries. Salt Lake City, Utah: Utah Geological Survey, 2006.

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Rezaee, Reza, ed. Fundamentals of Gas Shale Reservoirs. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.

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Lee, Kun Sang, and Tae Hong Kim. Integrative Understanding of Shale Gas Reservoirs. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-29296-0.

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Nash, Katelyn M. Shale gas development. New York: Nova Science Publishers, 2010.

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Navarro, Gabriel L. Marcellus shale and shale gas: Facts and considerations. Hauppauge, N.Y: Nova Science Publishers, 2011.

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Schamel, Steven. Shale gas reservoirs of Utah: Survey of an unexploited potential energy resource. Salt Lake City]: Utah Geological Survey, 2005.

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Breyer, John Albert. Shale reservoirs: Giant resources for the 21st century. Tulsa, OK: American Association of Petroleum Geologists, 2012.

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Gholinezhad, Jebraeel, John Senam Fianu, and Mohamed Galal Hassan. Challenges in Modelling and Simulation of Shale Gas Reservoirs. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-70769-3.

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Chernykh, V. A. Matematicheskai︠a︡ gidrogeomekhanika plastov i skvazhin: Mathematical hydrogeomechanics of the reservoirs and wells. Moskva: Neftʹ i gaz, 2012.

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Zibert, G. K. Perspektivnye tekhnologii i oborudovanie dli︠a︡ podgotovki i perepodgotovki uglevodorodnykh gazov i kondensata: Prospective Tecnologies and Equipment for Preparation and Processing Hydrocarbon Gases and Condensate. Moskva: Nedra, 2005.

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Book chapters on the topic "Gas reservoirs. Gas wells. Shale"

1

Ahmad, Abualksim, and Reza Rezaee. "Pore Pressure Prediction for Shale Formations Using Well Log Data." In Fundamentals of Gas Shale Reservoirs, 139–67. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch7.

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Qian, Qi, Weiyao Zhu, and Jia Deng. "Production Forecasting of Fractured Wells in Shale Gas Reservoirs with Discontinuous Micro-Fractures." In Acid Gas Extraction for Disposal and Related Topics, 259–79. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2016. http://dx.doi.org/10.1002/9781118938652.ch18.

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Rezaee, Reza, and Mark Rothwell. "Gas Shale." In Fundamentals of Gas Shale Reservoirs, 1–19. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch1.

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Dehghanpour, Hassan, Mingxiang Xu, and Ali Habibi. "Wettability of Gas Shale Reservoirs." In Fundamentals of Gas Shale Reservoirs, 341–59. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch16.

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Rasouli, Vamegh. "Geomechanics of Gas Shales." In Fundamentals of Gas Shale Reservoirs, 169–90. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch8.

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Lee, Kun Sang, and Tae Hong Kim. "Characteristics of Shale Reservoirs." In Integrative Understanding of Shale Gas Reservoirs, 21–41. Cham: Springer International Publishing, 2016. http://dx.doi.org/10.1007/978-3-319-29296-0_2.

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Javadpour, Farzam, and Amin Ettehadtavakkol. "Gas Transport Processes in Shale." In Fundamentals of Gas Shale Reservoirs, 245–66. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch11.

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Kazemi, Hossein, Ilkay Eker, Mehmet A. Torcuk, and Basak Kurtoglu. "Performance Analysis of Unconventional Shale Reservoirs." In Fundamentals of Gas Shale Reservoirs, 283–300. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch13.

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Dong, Zhenzhen, Stephen A. Holditch, and W. John Lee. "Resource Estimation for Shale Gas Reservoirs." In Fundamentals of Gas Shale Reservoirs, 301–23. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch14.

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Trabucho-Alexandre, João. "Organic Matter-Rich Shale Depositional Environments." In Fundamentals of Gas Shale Reservoirs, 21–45. Hoboken, NJ: John Wiley & Sons, Inc, 2015. http://dx.doi.org/10.1002/9781119039228.ch2.

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Conference papers on the topic "Gas reservoirs. Gas wells. Shale"

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Guo, Jianchun, Jie Zeng, Xiangzeng Wang, and Fanhua Zeng. "Analytical Model for Multifractured Horizontal Wells in Heterogeneous Shale Reservoirs." In SPE Asia Pacific Oil & Gas Conference and Exhibition. Society of Petroleum Engineers, 2016. http://dx.doi.org/10.2118/182422-ms.

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Cely, Alexandra, Andrei Zaostrovski, Tao Yang, Knut Uleberg, and Margarete Kopal. "Well GOR Prediction from Surface Gas Composition in Shale Reservoirs." In SPE Annual Technical Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205842-ms.

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Abstract There are increased development activities in shale reservoirs with ultra-low permeability thanks to the advances in drilling and fracking technology. However, representative reservoir fluid samples are still difficult to acquire. The challenge leads to limited reservoir fluid data and large uncertainties for shale play evaluation, field development, and production optimization. In this work, we built a large unconventional reservoir fluid database with more than 2400 samples from shale reservoirs in Canada, Argentina, and the USA, comprising early production surface gas data and traditional PVT data from selected shale assets. A machine learning approach was applied to the database to predict gas to oil ratio (GOR) in shale reservoirs. To enhance regional correlations and obtain a more accurate GOR prediction, we developed a machine learning model focused on Canada shale plays data, intended for wells with limited reservoir fluid data available and located within the same region. Both surface gas compositional data and well location and are input features to this model. In addition, we developed an additional machine learning model for the objective of a generic GOR prediction model without shale dependency. The database includes Canada shale data and Argentina and USA shale data. The GOR predictions obtained from both models are good. The machine learning model circumscribed to the Canada shale reservoirs has a mean percentage error (MAPE) of 4.31. In contrast, the generic machine learning model, which includes additional data from Argentina and USA shale assets, has a MAPE of 4.86. The better accuracy of the circumscribed Canada model is due to the introduction of the geospatial well location to the model features. This study confirms that early production surface gas data can be used to predict well GOR in shale reservoirs, providing an economical alternative for the sampling challenges during early field development. Furthermore, the GOR prediction offers access to a complete set of reservoir fluid properties which assists the decision-making process for shale play evaluation, completion concept selection, and production optimization.
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Croce, Daniel David, and Luis Eduardo Zerpa. "Intermittent Gas Lift for Liquid Loaded Horizontal Wells in Tight Gas Shale Reservoirs." In SPE Artificial Lift Conference and Exhibition - Americas. Society of Petroleum Engineers, 2020. http://dx.doi.org/10.2118/201153-ms.

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Cipolla, C. L., E. P. Lolon, J. C. Erdle, and V. Tathed. "Modeling Well Performance in Shale-Gas Reservoirs." In SPE/EAGE Reservoir Characterization & Simulation Conference. European Association of Geoscientists & Engineers, 2009. http://dx.doi.org/10.3997/2214-4609-pdb.170.spe125532.

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Cipolla, Craig L., Elyezer Lolon, Jim Erdle, and Vinit Santosh Tathed. "Modeling Well Performance in Shale-Gas Reservoirs." In SPE/EAGE Reservoir Characterization and Simulation Conference. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/125532-ms.

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Nobakht, Morteza, and Christopher R. Clarkson. "Multiwell Analysis of Multifractured Horizontal Wells in Tight/Shale Gas Reservoirs." In SPE Canadian Unconventional Resources Conference. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/162831-ms.

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Bartoletti, Viola, and Carolina Coll. "Numerical Modelling of Multiple Fractured Horizontal Wells in Shale gas Reservoirs." In SPE Europec featured at 80th EAGE Conference and Exhibition. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/190851-ms.

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Zhang, Fengyuan, and Hamid Emami-Meybodi. "Flowback Fracture Closure of Multifractured Horizontal Wells in Shale Gas Reservoirs." In SPE/AAPG Eastern Regional Meeting. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/191817-18erm-ms.

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Song, Bo, Michael John Economides, and Christine A. Ehlig-Economides. "Design of Multiple Transverse Fracture Horizontal Wells in Shale Gas Reservoirs." In SPE Hydraulic Fracturing Technology Conference. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/140555-ms.

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Gai, Shaohua, Ailin Jia, and Yunsheng Wei. "Reservoir Modelling in the Shale Gas Reservoirs Based on Horizontal Wells and Seismic Inversion." In Abu Dhabi International Petroleum Exhibition & Conference. Society of Petroleum Engineers, 2019. http://dx.doi.org/10.2118/197330-ms.

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Reports on the topic "Gas reservoirs. Gas wells. Shale"

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Sheng, James, Lei Li, Yang Yu, Xingbang Meng, Sharanya Sharma, Siyuan Huang, Ziqi Shen, et al. Maximize Liquid Oil Production from Shale Oil and Gas Condensate Reservoirs by Cyclic Gas Injection. Office of Scientific and Technical Information (OSTI), November 2017. http://dx.doi.org/10.2172/1427584.

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Veil, J. A. Trip report for field visit to Fayetteville Shale gas wells. Office of Scientific and Technical Information (OSTI), September 2007. http://dx.doi.org/10.2172/924689.

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Heath, Jason E., Kristopher L. Kuhlman, David G. Robinson, Stephen J. Bauer, and William Payton Gardner. Appraisal of transport and deformation in shale reservoirs using natural noble gas tracers. Office of Scientific and Technical Information (OSTI), September 2015. http://dx.doi.org/10.2172/1222657.

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Grace, Rashmi, and Jack Pashin. Geologic Assessment of the Carbon Sequestration Potential of Paleozoic Shale Gas Reservoirs in Alabama (Final Report). Office of Scientific and Technical Information (OSTI), July 2010. http://dx.doi.org/10.2172/1814011.

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Ingraham, Mathew Duffy, Dan Stefan Bolintineanu, Rekha R. Rao, Lisa Ann Mondy, Jeremy B. Lechman, Enrico C. Quintana, and Stephen J. Bauer. Final Report for LDRD: The Effect of Proppant Placement on Closure of Fractured Shale Gas Wells. Office of Scientific and Technical Information (OSTI), September 2016. http://dx.doi.org/10.2172/1601327.

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Cheng, A. M. Development of general inflow performance relationships (IPR's) for slanted and horizontal wells producing heterogeneous solution-gas drive reservoirs. Office of Scientific and Technical Information (OSTI), April 1992. http://dx.doi.org/10.2172/5596773.

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Cheng, A. M. Development of general inflow performance relationships (IPR`s) for slanted and horizontal wells producing heterogeneous solution-gas drive reservoirs. Office of Scientific and Technical Information (OSTI), April 1992. http://dx.doi.org/10.2172/10137825.

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Koperna, George. The Coal-Seq III Consortium. Advancing the Science of CO2 Sequestration in Coal Seam and Gas Shale Reservoirs. Office of Scientific and Technical Information (OSTI), March 2014. http://dx.doi.org/10.2172/1253143.

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