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Author: Arron A. Tchouka Singhe
Publisher: Cuvillier Verlag
ISBN: 3736944055
Category : Technology & Engineering
Languages : en
Pages : 240
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Book Description
Injection into geological formations is seen by many as a short to medium term measure to reduce emissions of CO2 to the environment and as such to slowdown the pace of global warming. The injection process requires that the fluid flows effectively into the host formation. To this end it is very important to accurately predict the pressure and temperature of the fluid along the well and especially at the bottom of the hole. In the present dissertation a rigorous procedure to estimate fluid pressure and temperature along CO2 injection wells has been developed based on analytical modeling. The procedure accommodates wellbores of varying diameter, varying deviation angles, non-uniform tubing strings and layered formations with different thermal properties and varying geothermal gradients. To test the models, computer codes have been written with Visual Basic.Net language on the Microsoft Visual Studio Platform. The codes are encapsulated in a user-friendly Graphical User Interface. The simulated results are compared with field observed data from a shallow aquifer injection vertical well in Germany (Ketzin) and that from a relatively deeper offshore aquifer injection slanted well in Norway (Snøhvit). The maximum deviation is around 2% for pressure and around 10% for temperature.
Author: Arron A. Tchouka Singhe
Publisher: Cuvillier Verlag
ISBN: 3736944055
Category : Technology & Engineering
Languages : en
Pages : 240
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Book Description
Injection into geological formations is seen by many as a short to medium term measure to reduce emissions of CO2 to the environment and as such to slowdown the pace of global warming. The injection process requires that the fluid flows effectively into the host formation. To this end it is very important to accurately predict the pressure and temperature of the fluid along the well and especially at the bottom of the hole. In the present dissertation a rigorous procedure to estimate fluid pressure and temperature along CO2 injection wells has been developed based on analytical modeling. The procedure accommodates wellbores of varying diameter, varying deviation angles, non-uniform tubing strings and layered formations with different thermal properties and varying geothermal gradients. To test the models, computer codes have been written with Visual Basic.Net language on the Microsoft Visual Studio Platform. The codes are encapsulated in a user-friendly Graphical User Interface. The simulated results are compared with field observed data from a shallow aquifer injection vertical well in Germany (Ketzin) and that from a relatively deeper offshore aquifer injection slanted well in Norway (Snøhvit). The maximum deviation is around 2% for pressure and around 10% for temperature.
Author: Arron A. Tchouka Singhe
Publisher:
ISBN:
Category :
Languages : en
Pages : 202
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Book Description
Author: Zhiyuan Luo
Publisher:
ISBN:
Category :
Languages : en
Pages : 358
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Book Description
Large-scale geologic CO2 storage is a technically feasible way to reduce anthropogenic emission of green house gas to atmosphere by human beings. In large-scale geologic CO2 sequestration, high injection rate is required to satisfy economics and operational considerations. During the injection phase, temperature and pressure of the storage aquifers may vary significantly with the introduced CO2. These changes would re-distribute the in-situ stresses in formations and induce fracture initiation or even propagation. If fractures are not permitted by regulators, then the injection operation strategies must be supervised and designed to prevent fracture initiation, and the storage formations should be screened for risk of fracturing. In more flexible regulatory environment, if fractures are allowed, fractures would strongly influence the CO2 migration profile and storage site usage efficiency depending on fracture length and growth rate. In this dissertation, we built analytical heat transfer models for vertical and horizontal injection wells. The models account for the dependency of overall heat transfer coefficient on injection rate to more accurately predict the borehole temperature. Based on these models, we can calculate temperature change in formation surrounding wellbores and thus evaluate thermo-elastic stress around borehole as well as its impact on fracture initiation pressure. By considering the impact of thermo-elastic effect on fracturing pressure, we predicted maximum injection rate avoiding fracture initiation and provided injection and storage strategies to increase the maximum safe injection rate. The results show that thermo-elastic stress significantly limits maximum injection rate for no-fractured injection scenario, especially for horizontal injectors. To improve injection rate, partial perforation and pre-heating CO2 before injection have been designed, and results shows that these strategies can strongly negate thermo-elastic influence for various injection scenarios. On the other hand, the model provides parametric analysis on geological and operational conditions of CO2 storage project for site screening work. In the case of permitting fracture occurrence, a semi-analytical model was built to quantitatively describe fracture propagation and injected fluid migration profile of a fractured vertical injector for storage systems with various boundary conditions. We examined the correlation between fracture growth and CO2 migration in various injection scenarios. Two-phase fractional flow model of Buckley-Leverett theory has been extended to account for the CO2-brine three-region flow system (dry CO2, CO2-brine, and brine) from a fractured injector. In the sensitivity study, fracture growth and fluid migration greatly depend on Young's modulus of the formation rock and storage site boundary conditions. Consequently, the results show that fast growing, long fractures may yield a flooding pattern with large aspect ratio, as well as early breakthrough at the drainage boundary; in contrast, slow growing short fractures provides high injectivity without changing flooded area shape. We studied the physics for issues related to injection induced fractures in geologic CO2 sequestration in saline aquifers, assessed risk associated to them and developed low cost and quick analytical models. These models could easily provide predictions on maximum injection rate in no-fracture regulation CO2 storage projects as well as estimate fracture growth and injected fluid migration under fracture allowable scenarios. "Preferred storage aquifers" have following properties: larger permeability, deep formation, no over pressure, low Young's modulus and low Poisson's ratio and open boundaries. In many practical cases, however, injection strategies have to be designed if some properties of formation are out of ideal range. Besides applications in CO2 storage, the approach and model we developed can also be applied into any injection induced fracture topics, namely water/CO2 flooding and wasted water re-injection.
Author: Zhiyuan Wang
Publisher: Frontiers Media SA
ISBN: 2832516866
Category : Science
Languages : en
Pages : 143
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Author: Aleksandar Kondinski
Publisher: Frontiers Media SA
ISBN: 283254343X
Category : Science
Languages : en
Pages : 148
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Author: Revelation Jacob Samuel
Publisher:
ISBN:
Category :
Languages : en
Pages : 249
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Book Description
The internationally agreed global climate deal reached at the Paris Climate Conference in 2015 is intended to limit the increase in global average temperatures to "well below" 2°C above pre-industrial levels. This comes in addition to the European Union ambition for 80% to 95% reduction in the 1990 greenhouse gas emissions by 2050 in order to avoid dangerous climate change. Most scenario studies indicate that Carbon Capture and Storage (CCS) is essential for achieving such ambitious reductions. In CCS operations, depleted gas fields represent prime targets for large-scale storage of the captured CO2. Considering the relatively low wellhead pressure of such fields, the uncontrolled injection of the high-pressure dense phase CO2 will result in its rapid, quasi-adiabatic Joule-Thomson expansion leading to significant temperature drops. This could pose several risks, including blockage due to hydrate and ice formation following contact of the cold sub-zero CO2 with the interstitial water around the wellbore and the formation water in the perforations at the near well zone, thermal stress shocking and fracture of the wellbore casing steel and over-pressurisation accompanied by CO2 backflow into the injection system due to the violent evaporation of the superheated liquid CO2 upon entry into the wellbore. In order to minimise the above risks and develop best-practice guidelines for the injection of CO2, the accurate prediction of the CO2 pressure and temperature along the well during the injection process is of paramount importance. This thesis deals with the development and verification of a Homogeneous Equilibrium Mixture (HEM) model and a Homogenous Equilibrium Relaxation Mixture (HERM) model for simulating the transient flow phenomena taking place during the injection of dense phase CO2 into depleted gas fields. The HEM model assumes instantaneous interface mass, momentum and energy exchange between the constituent CO2 liquid and vapour phases. As such they remain at the same pressure, temperature and velocity, whence the corresponding fluid-flow may be described using a single set of mass, momentum and energy conservation equations. The HERM on the other hand presents an additional equation which accounts for the thermodynamic non-equilibrium thorough the introduction of a relaxation time. It also accounts for phase and flow dependent fluid/wall friction and heat transfer, variable well cross sectional area as well as deviation of the well from the vertical. At the well inlet, the opening of the upstream flow regulator valve is modelled as an isenthalpic expansion process; whilst at the well outlet, a formation-specific pressure-mass flow rate correlation is adopted to characterise the storage site injectivity. The testing of the models is based on their application to CO2 injection into the depleted 2582 m deep Goldeneye Gas Reservoir at Hewett field in the North Sea for which the required design and operational data are publically available. Varying injection scenarios involving the rapid (5 mins), medium (30 mins) and slow (2 hrs) linear ramping up of the injected CO2 flow rate to the peak nominal value of 33.5 kg/s are simulated. In each case, the simulated pressure and temperature transients at the top and bottom of the well are used to ascertain the risks of well-bore thermal shocking or interstitial ice formation leading to well blockage due to the rapid cooling of the CO2. Detailed sensitivity analysis of the most important parameters affecting the CO2 in-well flow behaviour, including the wellbore diameter variations, well inclination, upstream temperature, pressure and time variant injection mass flow rate are conducted. The simulation results obtained for a slow (2 hrs) flowrate ramp-up case using the HEM model produce a minimum wellhead temperature of - 11 oC. The corresponding minimum temperature using the HERM model on the other hand is - 21 oC, demonstrating the importance of accounting for non-equilibrium effects and the model"s usefulness as a tool for the development of optimal injection strategies for minimising the risks associated with the injection of CO2 into depleted gas fields.
Author: Jia'en Lin
Publisher: Springer Nature
ISBN: 9811508607
Category : Technology & Engineering
Languages : en
Pages : 501
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Book Description
This book is a compilation of selected papers from the 3rd International Petroleum and Petrochemical Technology Conference (IPPTC 2019). The work focuses on petroleum & petrochemical technologies and practical challenges in the field. It creates a platform to bridge the knowledge gap between China and the world. The conference not only provides a platform to exchanges experience but also promotes the development of scientific research in petroleum & petrochemical technologies. The book will benefit a broad readership, including industry experts, researchers, educators, senior engineers and managers.
Author: Kingshuk Srivastava
Publisher: CRC Press
ISBN: 1000995119
Category : Technology & Engineering
Languages : en
Pages : 187
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Book Description
This book covers aspects of data science and predictive analytics used in the oil and gas industry by looking into the challenges of data processing and data modelling unique to this industry. It includes upstream management, intelligent/digital wells, value chain integration, crude basket forecasting, and so forth. It further discusses theoretical, methodological, well-established, and validated empirical work dealing with various related topics. Special focus has been given to experimental topics with various case studies. Features: Provides an understanding of the basics of IT technologies applied in the oil and gas sector Includes deep comparison between different artificial intelligence techniques Analyzes different simulators in the oil and gas sector as well as discussion of AI applications Focuses on in-depth experimental and applied topics Details different case studies for upstream and downstream This book is aimed at professionals and graduate students in petroleum engineering, upstream industry, data analytics, and digital transformation process in oil and gas.
Author: Jia'en Lin
Publisher: Springer Nature
ISBN: 9819702682
Category :
Languages : en
Pages : 965
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Book Description
Author: Abdolhossein Hemmati-Sarapardeh
Publisher: Gulf Professional Publishing
ISBN: 0128219343
Category : Science
Languages : en
Pages : 462
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Book Description
Thermal Methods, Volume Two, the latest release in the Enhanced Oil Recovery series, helps engineers focus on the latest developments in this fast-growing area. In the book, different techniques are described in addition to the latest technologies in data mining and hybrid processes. Supported field case studies are included to illustrate a bridge between research and practical applications, making it useful for both academics and practicing engineers. Structured to start with thermal concepts and steam flooding, the book's editors then advance to more complex content, guiding engineers into areas such as hybrid thermal methods and edgier technologies that bridge solar and nuclear energy. Supported by a full spectrum of contributors, this book gives petroleum engineers and researchers the latest research developments and field applications to drive innovation for the future of energy. Presents the latest understanding surrounding the updated research and practical applications specific to thermal enhanced oil recovery methods Provides an analysis of editors’ research on available technology, including hybrid thermal-solvent processes and dual pipe configurations Teaches about additional methods, such as data mining applications, and economic and environmental considerations
