Relevant bibliographies by topics / Gas wells

Academic literature on the topic 'Gas wells'

Author: Grafiati
Published: 4 June 2021
Last updated: 1 August 2024

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Journal articles on the topic "Gas wells"

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Pinchuk, Sofiya, Galina Galchenko, Aleksey Simonov, Ludmila Masakovskaya, and Irina Roslyk. "Complex Corrosion Protection of Tubing in Gas Wells." Chemistry & Chemical Technology 12, no. 4 (December 10, 2018): 529–32. http://dx.doi.org/10.23939/chcht12.04.529.

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Sarsenbaevna, Batirova Uldaykhan, Tajetdinova Gulnora Abatbay qizi, and Karjaubayev Marat Ospanovich. "THE PROCESS OF DRILLING OIL AND GAS WELLS." American Journal of Applied Sciences 6, no. 6 (June 1, 2024): 49–52. http://dx.doi.org/10.37547/tajas/volume06issue06-08.

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The process of drilling oil and gas wells is a critical component of the energy industry, playing an important role in the extraction of vital natural resources. This article provides an in-depth exploration of the intricate procedures and technologies involved in drilling operations. From initial site preparation to the complexities of directional drilling, this article aims to shed light on the multifaceted process of extracting oil and gas from beneath the Earth's surface. Throughout this exploration, we will delve into the fundamental principles, safety considerations, environmental impacts, and innovative advancements that shape the modern landscape of drilling operations.
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Chu, Hongyang, Tianbi Ma, Zhen Chen, Wenchao Liu, and Yubao Gao. "Well Testing Methodology for Multiple Vertical Wells with Well Interference and Radially Composite Structure during Underground Gas Storage." Energies 15, no. 22 (November 10, 2022): 8403. http://dx.doi.org/10.3390/en15228403.

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To achieve the goal of decarbonized energy and greenhouse gas reduction, underground gas storage (UGS) has proven to be an important source for energy storage and regulation of natural gas supply. The special working conditions in UGS cause offset vertical wells to easily interfere with target vertical wells. The current well testing methodology assumes that there is only one well, and the interference from offset wells is ignored. This paper proposes a solution and analysis method for the interference from adjacent vertical wells to target vertical wells by analytical theory. The model solution is obtained by the solution with a constant rate and the Laplace transform method. The pressure superposition is used to deal with the interference from adjacent vertical wells. The model reliability in the gas injection and production stages is verified by commercial software. Pressure analysis shows that the heterogeneity and interference in the gas storage are caused by long-term gas injection and production. As both the adjacent well and the target well are in the gas production stage, the pressure derivative value in radial flow is related to production rate, mobility ratio, and 0.5. Gas injection from offset wells will cause the pressure derivative to drop later. Multiple vertical wells from the Hutubi UGS are used to illustrate the properties of vertical wells and the formation.
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Lin, Jiajing, and Ding Zhu. "Modeling well performance for fractured horizontal gas wells." Journal of Natural Gas Science and Engineering 18 (May 2014): 180–93. http://dx.doi.org/10.1016/j.jngse.2014.02.011.

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McCain, W. D., and R. A. Alexander. "Sampling Gas-Condensate Wells." SPE Reservoir Engineering 7, no. 03 (August 1, 1992): 358–62. http://dx.doi.org/10.2118/19729-pa.

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Marusin, A., and I. E. Marusin. "AUTOMATION OF GAS WELLS." Международный студенческий научный вестник (International Student Scientific Herald), no. 3 2023 (2023): 19. http://dx.doi.org/10.17513/msnv.21302.

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Karnaukhov, M. L., and O. N. Pavelyeva. "WELL TESTING HORIZONTALGAS-CONDENSATE WELLS." Oil and Gas Studies, no. 3 (July 1, 2017): 56–61. http://dx.doi.org/10.31660/0445-0108-2017-3-56-61.

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The well testing of gas-condensate horizontal wells are discussed in the article and the comparative analysis of borehole flow capacity, depending on the mode of it’s operation is presented. Extra attention is focused on the issue of timely identification of the reasons for the reduction of fluid withdrawal from the reservoir. The presence of high skin effect is proved, which confirms the existence of low-permeability of bottomhole formation zone related to condensation in the immediate area of the horizontal wellbore.
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Carpenter, Chris. "Expertise in Complex-Well Construction Leveraged for Geothermal Wells." Journal of Petroleum Technology 75, no. 05 (May 1, 2023): 87–89. http://dx.doi.org/10.2118/0523-0087-jpt.

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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 204097, “Constructing Deep Closed-Loop Geothermal Wells for Globally Scalable Energy Production by Leveraging Oil and Gas Extended-Reach Drilling and High-Pressure/High-Temperature Well-Construction Expertise,” by Eric van Oort, SPE, Dongmei Chen, SPE, and Pradeepkumar Ashok, SPE, The University of Texas at Austin, et al. The paper has not been peer reviewed. _ In the complete paper, deep closed-loop geothermal systems (DCLGS) are introduced as an alternative to traditional enhanced geothermal systems (EGS) for green energy production that is globally scalable and dispatchable. The authors demonstrate that DCLGS wells can generate power on a scale comparable to that of EGS. They also highlight technology gaps and needs that still exist for economically drilling DCLGS wells, writing that it is possible to extend oil and gas technology, expertise, and experience in extended-reach drilling (ERD) and high-pressure/high-temperature (HP/HT) drilling to construct complex DCLGS wells. Introduction CLGS is considered a subset of EGS, but the authors write that it is a distinct entity. EGS mostly involves well designs that rely on fractures for heat extraction. Such systems are different from CLGS wells in that the latter use closed conduits for thermal fluid circulation and heating. CLGS relies on fluids pumped through a closed loop. The authors treat CLGS systems as being different from EGS systems, with the understanding that drilling technologies discussed in the paper as enablers for CLGS wells apply equally to EGS wells. In the geothermal (GT) domain, the majority of attention and funding currently is assigned to EGS projects. A case is made in the complete paper to continue to develop DCLGS technology because of its favorable risk profile compared with EGS. Part I of the complete paper introduces a hydraulic model coupled with a thermal model suitable for calculating the power generation of DCLGS wells. This synopsis concentrates instead on Part II of the complete paper, in which technology gaps and needs of DCLGS drilling and well construction are highlighted and opportunities identified where oil and gas experience and technology can be directly applied and leveraged. Similarities and Differences of Deep GT and Oil and Gas HP/HT Wells - GT wells generally use larger production hole sizes than typical land wells. - Casing-cement annuli typically are cemented back to surface. - GT wells can be drilled in more-forgiving pore-pressure fracture gradient (PPFG) environments with wider drilling margins than geopressured HP/HT wells in hydrocarbon systems. - Severe lost circulation appears to be a universal problem in deep GT wells. - Drilling costs can account for 50% or more of the total capital costs for a GT energy project. - Data sets on GT wells are much smaller than those for oil and gas wells.
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Khudjaev, M., and A. Rakhimov. "Gas flow modeling in wells." Journal of Physics: Conference Series 2131, no. 5 (December 1, 2021): 052075. http://dx.doi.org/10.1088/1742-6596/2131/5/052075.

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Abstract The topic of research is gas flow modeling in wells. The subject of the study is to determine the dynamic parameters of gas in a gas well, taking into account changes in the ambient temperature and gravity. Mathematical and numerical modeling of gas flow in a gas well is performed; a numerical algorithm to determine gas pressure in a gas well is built. This algorithm allows studying the state of production and injection wells with varying conditions at the wellhead and at the lower end of the well. Research methods are based on the energy equations of the transported gas; the mass conservation equation, which are the basic equations of gas flow; the methods of numerical and mathematical modeling. In the article, numerical and mathematical models of gas flow in a gas well are obtained, taking into account changes in the ambient temperature and gravity. A numerical algorithm and a program were built to determine the gas-dynamic characteristics of wells. The computational process was based on the “cycle in cycle” principle. Provisions were made to study the state of production and injection wells with varying conditions at the wellhead and at the bottom end of the well.
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Mahadevan, Jagannathan, Mukul Mani Sharma, and Yannis C. Yortsos. "Capillary Wicking in Gas Wells." SPE Journal 12, no. 04 (December 1, 2007): 429–37. http://dx.doi.org/10.2118/103229-pa.

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Summary Gas expansion near the wellbore during production causes the evaporation of connate water. When the reservoir permeability is low, capillarity is controlling, causing liquid movement to the near-wellbore region, where drying rates are higher. In tight-gas sands or in shale gas formations, where capillarity is high, the gas production itself can cause depletion of the water saturation below residual values because of such evaporation. In this work, we present a study of the fundamental processes involved during the flow of a gas in a liquid-saturated porous medium. We have modeled evaporation by accounting for the capillary driven film flow, or "wicking," of saline liquid to the wellbore or the near-fracture region and the effect of gas expansion. It is shown that, for gas reservoirs with connate water saturation, large pressure drawdowns lead to a drying front that develops at the formation face and propagates into the reservoir. When pressure drops are lower, water rapidly redistributes because of capillarity-induced movement of liquid from high- to low-saturation regions. This phase redistribution causes higher drying rates near the wellbore. The results show, for the first time, the effect of both capillarity- induced film flow and gas compressibility on the rate of drying in gas wells. The model can be used to help maximize gas production under conditions such as water blocking by optimizing the operating conditions. Additionally, it can be used to obtain a better understanding of the impact of capillarity on evaporation and consequent processes, such as salt precipitation. Introduction Problems involving gas flow past trapped liquids in porous media are encountered in a variety of contexts, such as water block removal in gas wells, evaporation of volatile oils, and recovery of residual oil. In the case of a binary system, such as gas and water, the thermodynamic phase equilibrium can be represented by a simple linear law and gas injection that reduces to a drying problem in which the remaining liquid is evaporated by the flowing gas. Drying of wetting liquids in porous media has been studied by several authors. These studies mainly focused on pass-over drying, in which gas is passed over a porous medium saturated with the wetting liquid. This form of drying is controlled by the gas flow rate. However, when the liquid recedes into the porous medium, drying is controlled by the rate of diffusion of the components in the liquid phase in the pore spaces. Early in 1949, Allerton et al. studied through-drying of packed beds of crushed quartz and other porous materials by convection of dry gas. The study, however, did not consider the effect of gas compressibility or capillarity. Whitaker developed a diffusion theory of drying using volume averaging methods with constant pressure in the gas phase. This eliminated the effect of compressibility of gas on the drying rates and therefore is useful only in a pass-over drying context. Experimental and simulation studies of gas injection (Dullien et al. 1989; Holditch 1979; Kamath and Laroche 2003) showed that trapped water is first removed by a viscous displacement followed by a long period of evaporation. These studies showed that higher pressure drop, permeability, and temperatures caused greater rates of evaporation and faster progression of saturation drying fronts in both fractured and unfractured wells.
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Dissertations / Theses on the topic "Gas wells"

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Al, Mutairi Fahad M. "Evaluation of skin factor from single-rate gas well test." Morgantown, W. Va. : [West Virginia University Libraries], 2008. https://eidr.wvu.edu/etd/documentdata.eTD?documentid=6047.

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Thesis (M.S.)--West Virginia University, 2008.
Title from document title page. Document formatted into pages; contains viii, 75 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 38-43).
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Shi, Chunmei. "Flow behavior of gas-condensate wells /." May be available electronically:, 2009. http://proquest.umi.com/login?COPT=REJTPTU1MTUmSU5UPTAmVkVSPTI=&clientId=12498.

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Liao, Tianlu. "Mechanistic modeling of intermittent gas lift /." Access abstract and link to full text, 1991. http://0-wwwlib.umi.com.library.utulsa.edu/dissertations/fullcit/9210710.

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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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Reza, Rostami Ravari. "Gas condensate damage in hydraulically fractured wells." Texas A&M University, 2004. http://hdl.handle.net/1969.1/1100.

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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 from a gas condensate reservoir. Questions were raised about whether flowing bottomhole pressure below dewpoint would be appropriate. Condensate damage in the hydraulic fracture was expected to be of significant effect. In the most recent work done by Adedeji Ayoola Adeyeye, this subject was studied when the effects of reservoir depletion were minimized by introduction of an injector well with fluid composition the same as the original reservoir fluid. He also used an infinite conductivity hydraulic fracture along with a linear model as an adequate analogy. He concluded that the skin due to liquid build-up is not enough to prevent lower flowing bottomhole pressures from producing more gas. This current study investigated the condensate damage at the face of the hydraulic fracture in transient and boundary dominated periods when the effects of reservoir depletion are taken into account. As a first step, simulation of liquid flow into the fracture was performed using a 2D 1-phase simulator in order to help us to better understand the results of gas condensate simulation. Then during the research, gas condensate models with various gas compositions were simulated 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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Juell, Aleksander. "Production Optimization of Remotely Operated Gas Wells." Doctoral thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-15934.

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Foss, Matthew. "Operating costs at the well level for natural gas wells in Alberta." Thesis, National Library of Canada = Bibliothèque nationale du Canada, 2001. http://www.collectionscanada.ca/obj/s4/f2/dsk3/ftp05/MQ64912.pdf.

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Tesfaslasie, Samson. "Automatic type curve matching for predicting gas wells production." Morgantown, W. Va. : [West Virginia University Libraries], 1999. http://etd.wvu.edu/templates/showETD.cfm?recnum=916.

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Thesis (M.S.)--West Virginia University, 1999.
Title from document title page. Document formatted into pages; contains xv, 113 p. : ill. (some col.). Includes abstract. Includes bibliographical references (p. 67-68).
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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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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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Books on the topic "Gas wells"

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Limited, Shell Canada. A report on an application by Shell Canada Limited to drill a critical sour well in the Jutland (Castle River South) Area. Calgary: Energy Resources Conservation Board, 1986.

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Lea, James Fletcher. Gas well deliquification. 2nd ed. Amsterdam: Gulf Professional Pub./Elsevier, 2008.

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Lea, James Fletcher. Gas well deliquification. 2nd ed. Amsterdam: Gulf Professional Pub./Elsevier, 2008.

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Bill, Dockery, and United States. Minerals Management Service. Gulf of Mexico OCS Region, eds. Investigation of gas well blowout, Brazos Area Block A-23, May 30, 1990: Gulf of Mexico offshore Texas. New Orleans: U.S. Dept. of the Interior, Minerals Management Service, Gulf of Mexico OCS Regional Office, 1992.

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(Denmark), Formidlingsrådet, ed. Olie/gas-efterforskning: Høring september 1986. København: Industriministeriet, Teknologistyrelsen, Formidlingsrådet, 1987.

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Sullivan, Dan M. Natural gas fields of Indiana. Bloomington, Ind: Indiana University, Indiana Geological Survey, 1995.

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Ontario. Ministry of Agriculture and Food. On-Farm Natural Gas Wells. S.l: s.n, 1985.

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Skiba, A. K. Modelirovanie i optimizat︠s︡ii︠a︡ strategiĭ razrabotki gruppy gazovykh mestorozhdeniĭ. Moskva: Vychislitelʹnyĭ T︠S︡entr im. A.A. Dorodnit︠s︡yna Rossiĭskoĭ akademii nauk, 2012.

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Saroi︠a︡n, A. E. Obsadnai︠a︡ kolonna dli︠a︡ nefti︠a︡nykh i gazovykh skvazhin =: Casing for oil and gas wells. San Francisco: [s.n.], 2007.

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Chernykh, V. A. Kont︠s︡ept︠s︡ii gazovoĭ dinamiki plastov i skvazhin. Moskva: Izd-vo "Neftʹ i gaz", 2012.

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Book chapters on the topic "Gas wells"

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Ershaghi, Iraj. "Gas Wells." In Solved Problems in Well Testing, 51–55. Cham: Springer International Publishing, 2023. http://dx.doi.org/10.1007/978-3-031-47299-2_5.

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Jordaan, Sarah Marie. "Natural Gas as a Bridge Fuel?" In Wells to Wire, 103–11. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-71971-5_7.

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Panish, Morton B., and Henryk Temkin. "Optical Properties of Quantum Wells." In Gas Source Molecular Beam Epitaxy, 200–250. Berlin, Heidelberg: Springer Berlin Heidelberg, 1993. http://dx.doi.org/10.1007/978-3-642-78127-8_7.

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Jordaan, Sarah Marie. "Global Markets and Competitiveness of Gas-Fired Power." In Wells to Wire, 67–84. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-71971-5_5.

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Jordaan, Sarah Marie. "The Denominator: Natural Gas Production, Throughput, and Electricity Generation." In Wells to Wire, 31–44. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-71971-5_3.

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Jordaan, Sarah Marie. "Tackling Uncertainty Across the Life Cycle of Gas-Fired Power." In Wells to Wire, 85–102. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-71971-5_6.

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Panish, Morton B., and Henryk Temkin. "Carrier Transport Across Quantum Wells and Superlattices." In Gas Source Molecular Beam Epitaxy, 251–78. Berlin, Heidelberg: Springer Berlin Heidelberg, 1993. http://dx.doi.org/10.1007/978-3-642-78127-8_8.

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Spreux, Alain, and André Jourdan. "Horizontal Wells and Reservoir Management Strategy." In The European Oil and Gas Conference, 14–22. Dordrecht: Springer Netherlands, 1991. http://dx.doi.org/10.1007/978-94-010-9844-1_5.

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Jordaan, Sarah Marie. "An Introduction to Life Cycle Assessment of Natural Gas-Fired Electricity." In Wells to Wire, 1–11. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-71971-5_1.

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Cai, M., P. G. Ma, J. Q. Wang, W. H. Ma, C. G. Wang, Z. P. Yang, J. L. Li, and N. Li. "Studies on Improving Drainage Gas Recovery Efficiency of Gas Wells." In Springer Series in Geomechanics and Geoengineering, 800–806. Singapore: Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-10-7560-5_74.

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Conference papers on the topic "Gas wells"

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Podchuvalova, Y. A., I. L. Chameev, E. A. Sherstoboev, E. P. Borisov, and V. N. Grischuk. "Gas-dynamic methods of well research as a tool for complex improvement of the efficiency of gas re-injection into the gas cap of the Novoportovskoe Oil and Gas Condensate Field." In Horizontal Wells 2021. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.202154062.

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Sokhoshko, S. K., and M. A. Rojas-Mikheeva. "Features of Gas Inflow Into the Slanted Gas Wells." In Horizontal Wells 2019 Challenges and Opportunities. European Association of Geoscientists & Engineers, 2019. http://dx.doi.org/10.3997/2214-4609.201901849.

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Salamy, S. P., K. Aminian, G. J. Koperna, and C. D. Locke. "Analysis of Well Test Results From Horizontal Gas Shale Wells." In SPE Gas Technology Symposium. Society of Petroleum Engineers, 1991. http://dx.doi.org/10.2118/21498-ms.

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Jatmiko, W., and T. S. Daltaban. "A New Pressure Transient Well Testing Method for Gas Condensate Wells." In SPE Gas Technology Symposium. Society of Petroleum Engineers, 1998. http://dx.doi.org/10.2118/39967-ms.

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Ibrahim, Mazher. "Development of New Well Index Equation for Fracture Wells." In SPE Unconventional Gas Conference and Exhibition. Society of Petroleum Engineers, 2013. http://dx.doi.org/10.2118/164017-ms.

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Yeager, V. J., and C. E. Shuchart. "Acidizing Gas Storage Wells." In SPE Eastern Regional Meeting. Society of Petroleum Engineers, 1997. http://dx.doi.org/10.2118/39225-ms.

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Lin, Jiajing, and Ding Zhu. "Modeling Well Performance for Fractured Horizontal Gas Wells." In International Oil and Gas Conference and Exhibition in China. Society of Petroleum Engineers, 2010. http://dx.doi.org/10.2118/130794-ms.

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Apasov, G. T., D. A. Borisov, E. V. Voevoda, M. Y. Gvozdev, V. A. Gribanov, A. V. Yelesin, D. S. Loginova, and D. A. Reshetnikov. "Management of the development of the Tazovsky oil and gas condensate field with a thin oil rim of high-viscosity oil with a massive gas cap." In Horizontal Wells 2021. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.202154064.

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Noskevich, V. V., and V. Y. Gorshkov. "Investigation of state of the gas pipeline part under the Vym River." In Horizontal Wells 2021. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.202154010.

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Dash, T., D. W. Scott, and C. K. Kwok. "Using Type Wells to Economically Schedule DUC Well Completions." In SPE Oklahoma City Oil and Gas Symposium. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/185109-ms.

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Reports on the topic "Gas wells"

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Kasten, Ansas Matthias, John Scott Price, Sarah L. Katz, Frederick W. Wheeler, William R. Ross, Edward J. Nieters, Adrian Ivan, Sergei Dolinsky, Brian Jurczyk, and Aaron Krites. NXIS - Well integrity inspection in unconventional gas wells. Office of Scientific and Technical Information (OSTI), June 2017. http://dx.doi.org/10.2172/1375716.

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Joel L. Morrison and Sharon L. Elder. Consortium for Petroleum & Natural Gas Stripper Wells. Office of Scientific and Technical Information (OSTI), December 2006. http://dx.doi.org/10.2172/901289.

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Joel L. Morrison and Sharon L. Elder. Consortium for Petroleum & Natural Gas Stripper Wells. Office of Scientific and Technical Information (OSTI), March 2007. http://dx.doi.org/10.2172/909265.

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Joel L. Morrison and Sharon L. Elder. Consortium for Petroleum & Natural Gas Stripper Wells. Office of Scientific and Technical Information (OSTI), September 2006. http://dx.doi.org/10.2172/895862.

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Morrison, Joel. Consortium for Petroleum & Natural Gas Stripper Wells. Office of Scientific and Technical Information (OSTI), December 2011. http://dx.doi.org/10.2172/1174138.

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Brown, Zyglowicz, and Frantz. K83XPSQ Modeling of Damage in Gas Storage Wells. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), January 2003. http://dx.doi.org/10.55274/r0011218.

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The primary aim of this study is to addresses this specific question. In addition, this study also establishes techniques to conduct cost-benefit analyses on deliverability enhancement treatments, quantitatively determine the impact of operational changes on deliverability, and conduct comprehensive damage surveillance less expensively and therefore more frequently. The zip file contains the final report, the associated data that the analysis was performed on, and spreadsheets to analyze/graph the results.
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Maurer, William, and Gregory Deskins. GRl-91-0204 Gas Reservoir Wellbore Orientation - Sensitivity Analysis of Parameters Affecting Production. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), June 1991. http://dx.doi.org/10.55274/r0011162.

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A parametric study was performed to investigate the effects of numerous well and reservoir parameters on gas well productivity. GMODl, an analytical model for gas production in homogeneous reservoirs, was used to calculate production data for more than 250 sets of reservoir/wellbore parameters. Vertical, horizontal, slant and fractured wells were investigated. Several conclusions were reached as a result of parametric sensitivity analyses. In the right applications, horizontal gas wells produce 3 to 6 times more than vertical wells. At angles above about 60�, slant wells have significantly increased production rates over vertical wells due to increased wellbore exposure. Additionally, horizontal wells intersecting multiple natural fractures can produce significantly more gas than vertical wells intersecting a single fracture.
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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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Weiss. L52296 Smart Gas Using Chemicals To Improve Gas Deliverability Phase II. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), March 2009. http://dx.doi.org/10.55274/r0010658.

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The objective of this effort was to demonstrate in the field the new wettability altering technology developed in the laboratory during Phase 1. Reservoir cores from three gas storage facilities including sandstone and dolomite reservoirs were used to evaluate the two surfactants. The imbibition and core flood tests showed that gas deliverability was improved in surfactant-treated sandstone cores. It was concluded that the aquifer storage facilities are candidates for field testing. Results from Phase I provided the foundation for this Phase II project. The Waverly Storage Facility operated by Southern Union/Panhandle Energy was selected as the site for a field test of the surfactant process. Waverly is an 1800-ft sandstone aquifer gas storage reservoir located near Springfield, lllinois. Expansion and contraction of a spherical gas bubble provided pressure support as gas was injected and withdrawn from 37 individual wells. Three wells were selected for treatment with 1000 bbl of ~4% surfactant solution. An additional three nearby wells were selected as control wells. A field mixing procedure similar to that used in the laboratory to avoid phase separation of the microemulsion was developed and successfully used during the third week of October 2007 when the wells were treated. Rates and pressures were measured at the wellhead; fluid levels were not recorded. Since the initial rate-pressure data collected during the project year including the well treatments were sparse, it was decided to extend the project to the end of 2008 to acquire more field data.
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Bass, R. L., and E. B. Bowles. PR-15-627-R01 Subsurface Safety Valves in Gas Storage Wells. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), May 1987. http://dx.doi.org/10.55274/r0011881.

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