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With offshore development migrating into ever-deeper waters, the industry is relying on subsea technology to facilitate increased oil and gas recovery while lowering costs and improving safety and operating efficiencies. The deepwater reservoirs being developed today also are becoming more challenging, with greater subsurface depths, higher pressures and temperatures, and more complex fluid systems. Given these trends, the need has never been greater to understand flow assurance risks and design effective strategies to mitigate those risks. Flow assurance can be expressed as the coupling of multiphase flow and fluid phase behavior. It requires understanding both steady-state and transient multiphase flows, as well as fluid properties, fluid compositions, pressure volume temperature (PVT) characteristics, and other fluid phase behaviors from the reservoir to the topsides process equipment throughout the life of field to prevent upset conditions. Flow assurance strategies are on the critical path to reducing overall development costs and ensuring safe and reliable subsea production operations. Since it has such a significant impact on field development and production system design, it is important to establish at an early phase of project planning whether flow assurance is needed. From the earliest stages onward, flow assurance operating philosophy should permeate each phase of field development engineering and project execution revealed as flow assurance design requirements. System modeling helps identify design limits and potential production issues. For full videos you can visit this link : https://drive.google.com/file/d/1nwRUKplF_QSMR6dvHeY49n51y1WxaTTx/view?usp=sharing https://bit.ly/3H9WlL3 and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1t4hcQ3eEwT_3GOSXxyZif5nEoSA0RQwU/view?usp=sharing

Flow assurance in subsea systems focuses on preventing solid deposits from blocking the flow path. The principle solids of concern are wax and hydrates. Sometimes scale and asphaltenes are also a concern. For a given reservoir fluid these solids precipitate at certain combinations of pressure and temperature. Precipitated solids are often carried downstream slurried in the fluid; however precipitated solids can also deposit on the walls of the production equipment, which ultimately causes plugging and flow stoppage. Control of this blockage is the essence of "flow assurance". Solids control strategies involve keeping the system pressure and temperature in a region where the solids are unstable (thermodynamic control) or controlling the conditions of solids formation so that deposits do not form (kinetic control) or allowing solids to deposit, then periodically removing them (mechanical control). For full videos you can visit this link : https://drive.google.com/file/d/1YV2GDH-jDQbTfsJfguWD0i73KH3fNkD_/view?usp=sharing https://bit.ly/3H0qM6q and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1KPzK-VYl8mq1bhzg2xdkHdgCYw5vtVWn/view?usp=sharing

PIPESIM is a flow simulation software program that is used for modeling both steady-state and transient multiphase flows. Mid-sized and large companies in both the oil and gas industry use PIPESIM to understand the behavior of fluids in their systems under various operating conditions. As part of normal use, PIPESIM can optimize production, diagnose operational challenges, and simulate pipeline design scenarios using its computational fluid dynamics (CFD) capabilities. For full videos you can visit this link : https://drive.google.com/file/d/196Z4RV0HQX4BRM0LY0toY3aUo5MtrZrJ/view?usp=sharing https://bit.ly/3TKdAKz and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1JYJZCKeqAtWnjQ56zPzs8AU7fCT_kpKF/view?usp=sharing

Erosion in multiphase flows, with entrained sand, is a more complex phenomenon than erosion in single-phase flow because of the different flow regimes possible. Earlier predictive models for erosion in multiphase flow were primarily based on empirical data and the accuracy of those models was limited to the flow conditions of the experiments. A mechanistic model has been developed for predicting erosion in elbows in multiphase flow considering the effects of particle velocities in gas and liquid phases upstream of the elbow. Local fluid velocities in multiphase flow are used to calculate erosion rates in multiphase flow using particle tracking and erosion equations. Because the mechanistic model is based on the physics of multiphase flow and the erosion phenomenon, it is expected to be more general than the previous empirical models. Erosion experiments were conducted on two-inch and three-inch elbows in a large scale multiphase flow loop with gas, liquid and sand for gas and liquid velocities producing slug and annular flows. The annular flow experiments were primarily performed in the upward vertical orientation but a few experiments were performed in the horizontal orientation. All the slug flow experiments were performed in the horizontal orientation. Based on the experiments, the mechanistic model has been improved to predict erosion in several different multiphase flow regimes considering the effects of sand particle distribution and particle velocities in gas-liquid flows. For full videos you can visit this link : https://drive.google.com/file/d/1RqTJYyt3SQmsE6uf0KUWEWLBIA16BF1P/view?usp=sharing https://bit.ly/41Muryb and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1OjSyW8eINMgDRmc2uBWNqYQVE44sCaKE/view?usp=sharing

Natural gas hydrate formation in subsea pipelines is a major problem in the upstream petroleum industry. Gas hydrates are formed at high pressures and low temperatures when water lattice with cavities trap gas molecules such as methane. Hydrates are solid deposits that clog subsea flowlinesand increase pressure drops across the pipeline, and under severe conditions can completely stop flow through pipelines resulting in tremendous production losses. This course briefly explain the structure and mechanism of gas hydrate formation and provide the audience with an overview of various gas hydrate prevention and mitigation technology used in the upstream petroleum industry. The manuscript discusses important methods used in the industry, such as chemical injection, depressurization, thermal stimulation, and mechanical removal by summarizing work from over hundred reports. Relative merits and demerits of these methods are also discussed. In addition, some interesting research results are also reviewed. This course conclude by providing a tables howing the relative technology readiness level for each method. Also, potential areas of future research are discussed For full videos you can visit this link : https://drive.google.com/file/d/1cRTRO3N_O9znpojv5rv5zgCIrO1ImZS2/view?usp=sharing https://bit.ly/3tw9zyD and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/13jgKJSJS6Ro1YU-ytUiFLe1_GMeGnzpZ/view?usp=sharing

Pipeline–riser transportation systems are frequently used in the offshore oil industry and are the main approach to transport oil and gas from oil wells to offshore platforms. In general, a pipeline–riser system has two key components: the sinuous pipelines on the seabed covering about 10 km from the wellhead to the pipeline manifold, and the risers connecting the manifold to the processing equipment on the platform and having various configurations according to the depth of the sea. From the point of view of flow assurance, the production fluid in a pipeline–riser transportation system must be operated in a safe, efficient, and reliable way throughout the design life of the platform. However, during the exploitation process, oil and gas multiphase mixtures transported in the system have various flow patterns that are more complicated than the flow patterns of multiphase flows in the horizontal or the vertical pipes. Some of the flow patterns may lead to equipment damage or reduction in oil production. Therefore, the flow patterns in oil transmission systems must be carefully controlled to ensure production safety. The most important tasks are to identify the flow patterns to be avoided and to determine their flow mechanisms. Such a flow pattern is commonly known as severe slugging flow. It is observed to occur only at low flow rates as well as in the downward inclined pipelines, where it fosters the formation of stratified flow. In this situation, the gas from the well will be easily blocked in the pipeline and prevented from entering the riser, while the liquid accumulates at the riser base until the liquid level reaches the riser top. The trapped gas then pushes the liquid slug out of the pipeline and penetrates the riser once it reaches the riser base. The nature of the severe slugging process is unique, with extreme long liquid slug ranging from one to several riser heights and large pressure fluctuations in the pipelines together with long periods of intermittent liquid and gas production. It presents a challenge not only to the capacity of the separator processing the long liquid slug but also to the impact resistance of the facilities. As a result, severe slugging flow differs from normal slug flow and is expected to be clearly distinguished from other flow patterns. For full videos you can visit this link : https://drive.google.com/file/d/1bV2qkcvDcGgrY6aUw30E5eki4xRftvVx/view?usp=sharing https://bit.ly/47apekU and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1_o6MFjxS7YnLY37wZlcXhkWC-8eJ76UG/view?usp=sharing

One way in analyzing multiphase flow is to calculate the pressure drop along the pipe or the wellbore. The pressure drop is the difference in pressure between two points in the flow direction. It is caused by several factors, such as the friction, the gravity, the acceleration, and the momentum changes of the phases. The pressure drop affects the flow performance and the operational costs of multiphase flow systems. The calculation of the pressure drop can be done by using empirical correlations, such as the Beggs and Brill, the Duns and Ros, and the Hagedorn and Brown correlations, or by using mechanistic models, such as the homogeneous, the separated, and the drift flux models. The flow regime affects the pressure drop in two ways: directly and indirectly. Directly, the flow regime determines the phase distribution and the interfacial phenomena, which are the main factors that influence the pressure drop. For example, a stratified flow regime has a low interfacial area and a low interfacial shear stress, which result in a low frictional pressure drop. Conversely, an annular flow regime has a high interfacial area and a high interfacial shear stress, which result in a high frictional pressure drop. Indirectly, the flow regime affects the pressure drop by changing the fluid properties, such as the density, the viscosity, and the surface tension, which also influence the pressure drop. For example, a bubbly flow regime has a higher gas density and a lower gas viscosity than a slug flow regime, which affect the gravity and the acceleration pressure drops. For full videos you can visit this link : https://drive.google.com/file/d/1ahLWJl11PQR_nPzc1R84NgNxYpIMj2VE/view?usp=sharing https://bit.ly/3RGCYhv and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/19CZqVJP27g9oI_GDxuGCciDhB3U6zN4V/view?usp=sharing

A phase is any homogeneous and physically distinct region that is separated from another such region by a distinct boundary. The most relevant phases in the oil industry are liquids (water & oil), gases (or vapors), and to a lesser extent, solids. As the conditions of pressure and temperature vary, the phases in which hydrocarbons exist, and the composition of the phases may change. It is important to understand the initial condition of fluids to be able to calculate surface volumes represented by subsurface hydrocarbons. It is also necessary to be able to predict phase changes as the temperature and pressure vary both in the reservoir and as the fluids pass through the surface facilities, so that the appropriate subsurface and surface development plans can be made. Phase behaviour describes the phase or phases in which a mass of fluid exists at given conditions of pressure, volume and temperature (PVT). These relationships are frequently shown graphically as phase diagrams. Phase behavior for single component systems are simple but as more components are added to the system, it becomes complex. A brief look at the phase behaviour of single component fluids or pure substances will foster an understanding of more complex systems. For full videos you can visit this link : https://drive.google.com/file/d/16O7O_6Ri5AZXY6yQ3SrmRcOT-3IPt9tN/view?usp=sharing https://bit.ly/4az5vhI and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1sqoq3FPnBt3_5XCyVDUDxlm5PJ7tjU6e/view?usp=sharing

Heat management systems is a practice of maintaining the fluid temperature inside the flowline well above the Hydrates Formation Temperature and WAT. The heat management system is regarded as very valuable in flow assurance solutions due to its cost-effectiveness. As the oil and gas fields progress into deep water, there is an increasing demand for a heat management system to stop the formation of hydrate sand wax in the subsea systems. Therefore, a good heat management plan is selected based on the needed cooldown time, water depth, U-value, and temperature range. The heat management systems consist of active heating and passive insulation. The active heating system uses external heat sources like hot water, direct electrical, and electrically heat-traced flowline to warm the produced fluid while the passive insulation system utilizes material like Mineral wool and Polyurethane with a low thermal conductivity to lower heat loss to the environment. For full videos you can visit this link : https://drive.google.com/file/d/1kC0ILm92SzztzCCmYQmFBV3TU2Pos97T/view?usp=sharing https://bit.ly/47Xr8Xf and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1d2TULJ1tgSdWTgRnCCZoZVWLrAbWisSw/view?usp=drive_link

Flow assurance deals with all issues that may arise in flowline and can cause the flow not to happen properly. It deals with issues like slugging, hydrate formation, flow of waxy fluids, multiphase flow prediction, etc. Flow assurance studies can be categorized to steady-state studies and transient studies. Steady-state flow assurance studies helps to draw a clear picture of the flowing system. Steady-state studies results helps to understand phase behavior, operational limitations, etc. For example, knowing what happens in turndown operation, winter and summer conditions, different feed characteristics helps to predict the borderlines of safe operational area. Steady-state hydraulic model is used to determine pipeline size. Criteria for line sizing is pressure constraints, erosion velocity limits and flow regime. All steady-state prediction models assume that pressure, temperature and physical properties of the fluid remains constant with time. But in the real world they change with time. However, single-phase pipeline sizing by steady-state hydraulic modeling usually leads us to acceptable results. For full videos you can visit this link : https://drive.google.com/file/d/1KGL6xTsRxPuYOMLZTu8iKDr7dp3oV2gC/view?usp=sharing https://bit.ly/3NA9MYf and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/14FY_YyebQqhEiMYsVUzM2OfUJ9Ufq7WF/view?usp=sharing

Flow assurance is an engineering analysis process that is used to ensure that hydrocarbon fluids are transmitted economically from the reservoir to the end user over the life of a project in any environment. Flow assurance analysis is a recognized critical part of the design and operation of subsea oil/gas systems. Flow assurance challenges focus mainly on the prevention and control of solid deposits that could potentially block the flow of product. The solids of concern generally are hydrates, wax, and asphaltenes. Sometimes scale and sand are also included. Flow assurance has become more challenging in recent years in subsea field developments involving long-distance tie-backs and deepwater. The challenges include a combination of low temperature, high hydrostatic pressure for deepwater and economic reasons for long offsets. The solutions to solids deposition problems in subsea systems are different for gas versus oil systems. Flow assurance is only successful when the operations generate a reliable, manageable, and profitable flow of hydrocarbon fluids from the reservoir to the end user. For full videos you can visit this link : https://drive.google.com/file/d/19sS9xoeJZOxPEAnSS9_lKiPZ-70NsMNK/view?usp=sharing https://bit.ly/41peDBl and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1NnGUk9DynDAF3l6xZ0mVUiD8A7OPrH4Q/view?usp=sharing

The course presents the application of the finite segment method to the analysis of coupled bending torsional vibrations of risers. The method is formulated by means of joint coordinates using multibody methods for kinematics and dynamics. A new approach to calculating bending and torsion moments is presented. The mathematical model and computer program enable us to analyze both free and forced vibrations of risers caused by the motion of the base (vessel or platform) as well as hydrodynamic forces. The model is validated by comparing frequencies of free and forced vibrations calculated from the authors’ own models with the results presented by other researchers. Natural frequencies are also compared with analytical solutions. The influence of sea currents and of the initial twisting of the riser on its natural and forced vibrations is analyzed. For full videos you can visit this link : https://drive.google.com/file/d/1Jwph32HCq0NZM7WU5xH1F6g1PAkgC0Q_/view?usp=sharing https://bit.ly/3TnDzr2 and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1vSvHiKdCM7--YCE_fFFmsKPCBKApHLIc/view?usp=drive_link

With a global track record spanning almost 40 years, Wood’s proprietary software Flexcom is a simulator for dynamic offshore structures and has delivered advanced engineering solutions to major operators, EPC contractors, equipment suppliers and engineering consultancy firms. This all-round software is suitable for a variety of scenarios, ranging from FEED studies, detailed engineering design, fatigue life assessment, structural installation and decommissioning. It is highly versatile, readily lending itself to applications in growing sectors such as marine renewable energy and floating offshore wind. The name Flexcom derives from its origins as a computational software simulating flexible risers, befitting the emerging oil production technology of the North Sea in the early 1980s. By contrast, the most recent edition has been developed to focus on floating offshore wind. The tool’s evolution is a classic example of an innovative solution provider adapting to ever-changing industry requirements. From humble beginnings of just one client back in 1983, Flexcom now has a global user base of over 300. So, what makes Flexcom unique? Fundamentally, Flexcom is a finite element analysis (FEA) tool that uses an industry-proven finite element formulation, widely acknowledged as best-in-class. Offshore structures undergo significant motions when subjected to ocean waves, therefore, unlike some other FEA solvers, Flexcom uses a convected coordinate technique to cater for large-scale displacements. For full videos you can visit this link : https://drive.google.com/file/d/1aCV1Z7urXbEZ6Jsl86fnMyrYbdzVvTSH/view?usp=sharing https://bit.ly/3Tki4Hn and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/145UKmf7U7oQ-rITkHYxMLikMiDRCRz24/view?usp=sharing

Flexible riser design is an engineering process based on complex assumptions about the product, environment, and the specific application. To compound this challenge, flexible pipe is a complex product with unique design and construction issues, particularly as water depths increase. Even with industry experience, failures do occur, and the attendant cost of such failures and the problems they induce, are enormous. Flexible riser integrity management systems are available to reduce the problem. These systems can include hardware monitoring, data acquisition, and data interpretation to reduce the probability and severity of failures. It also can lead to more accurately tailored maintenance and intervention plans. Once flexible pipe risers are installed, a number of problems can affect their performance and field life. External damage can arise from pipe contact with platform braces, bend stiffener contact with the I-tube, localized compression in the bellmouth, and sharp corners inside the bellmouth helmet. Accelerated armor wire failure can result from fatigue at the I-tube and as a result of corrosion after external sheath damage and sour annulus environment. For full videos you can visit this link : https://drive.google.com/file/d/1Bk7NmgqGpxKHx54zUtlIbadjR6JXTVBt/view?usp=sharing https://bit.ly/49KLa8J and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1F8bQ1_szh9ZG94W8gs-f8O1VHsJaeXSD/view?usp=drive_link

The amount of energy in a wave is related to its amplitude and its frequency. Large-amplitude earthquakes produce large ground displacements. Loud sounds have high-pressure amplitudes and come from larger-amplitude source vibrations than soft sounds. Large ocean breakers churn up the shore more than small ones. Consider the example of the seagull and the water wave, work is done on the seagull by the wave as the seagull is moved up, changing its potential energy. The larger the amplitude, the higher the seagull is lifted by the wave and the larger the change in potential energy. The energy of the wave depends on both the amplitude and the frequency. If the energy of each wavelength is considered to be a discrete packet of energy, a high-frequency wave will deliver more of these packets per unit time than a low-frequency wave. We will see that the average rate of energy transfer in mechanical waves is proportional to both the square of the amplitude and the square of the frequency. If two mechanical waves have equal amplitudes, but one wave has a frequency equal to twice the frequency of the other, the higher-frequency wave will have a rate of energy transfer a factor of four times as great as the rate of energy transfer of the lower-frequency wave. For full videos you can visit this link : https://drive.google.com/file/d/1TKU6mKAZ2LLf_tR6s_xM4VHnpNrewX1N/view?usp=drive_link https://bit.ly/3MUyORB and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1CxCxno70xG1o_ydTK2Ekv25YQedQ5YaE/view?usp=drive_link

Mooring system design has been a subject of research spanning beyond the scope of offshore floating platforms, including wave energy converters and fish vessels. Some of the major components of floating offshore structures consist of the mooring line and risers, and although they perform entirely different functions and are guided by different design requirements, the two components, together with the floating platform, constitute an interacting dynamic system that responds jointly to the influence of environmental loadings. This interaction has over the years been acknowledged as a critical design consideration, especially in deep-water operations. As a result, an integrated mooring-riser design methodology is proven to be crucial, where the risers, moorings, and the floaters are analyzed simultaneously to produce SAFOP and offset diagrams for the riser and moorings line respectively. The inclusion of risers in the analysis procedure affects the natural periods, damping, as well as the slow drift response of the vessel. Considerations of risers are reported to have a significant effect on the surge/sway coupling with consequent influence on low-frequency motion response. For full videos you can visit this link : https://drive.google.com/file/d/1-W-5S9kKlZFMESK4IyOYYU8vF1vIKKhY/view?usp=sharing https://bit.ly/3SNRBBV and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1E-jh4oBj7ShRIr9EfBuoLoGSDC7wuKNT/view?usp=drive_link

A riser system is essentially conductor pipes connecting floaters on the surface and the wellheads at the seabed. There are essentially two kinds of risers, namely rigid risers and flexible risers. A hybrid riser is the combination of these two. The riser system must be arranged so that the external loading is kept within acceptable limits with regard to: Stress and sectional forces, VIV and suppression, Wave fatigue, and Interference. The riser should be as short as possible in order to reduce material and installation costs, but it must have sufficient flexibility to allow for large excursions of the floater. The riser system of a production unit is to perform multiple functions, both in the drilling and production phases. The functions performed by a riser system include: Production/injection, export/import or circulate fluids, drilling, and completion & workover. A typical riser system is mainly composed of: Conduit (riser body), interface with floater and wellhead, components, and auxiliary For full videos you can visit this link : https://drive.google.com/file/d/19yDQBb9tz4TiSDec8lUfq9lf2PQd63_J/view?usp=sharing https://bit.ly/40PmeJ0 and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1VZqwXBSF7IaWvNdkmMjFNG3ZhDTe-HIF/view?usp=drive_link

Pipe stress analysis is a crucial operation in both pipe design and maintenance operations. As pipe failures might lead to critical situations, the performance of correct pipe stress calculations becomes essential to ensure maximum safety and efficiency while verifying pipe design has been correct in order to extend the product’s life cycle. Pipe stress analysis is a testing method that examines a piping system’s behavior under different loading situations. As such, it’s able to analyze how the material responds to pressure, temperatures, fluid and supports, thus helping engineers: • Observe the pipe’s flexibility and stiffness • Determine values such as maximum stresses, forces, displacements and restraints • Monitor the limits of stress in piping components and their correspondence to applicable standards • Decide on the right support systems to ensure their loads and movements are correct and safe avoiding unsuitable materials that do not support the necessary loads and pressures • Notice potential disengagements from support structures and pipes • Foresee how mechanical vibrations, seismic loads or acoustic vibrations might influence pipe operations • Guarantee pipes are leak-proof to prevent leakage • Select appropriate materials that meet strength and durability requirements All in all, the main reason to perform pipe stress analysis is to guarantee maximum safety wherever pipe systems are installed, so that pipe failures can be minimized. The right pipe analysis can also extend the pipe’s life cycle and ensure the quality and integrity of the transported product. For full videos you can visit this link : https://drive.google.com/file/d/1q2psPp2DIHTWkB_5lS7s1XAJD3-jK63z/view?usp=sharing https://bit.ly/3SQCZBC and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/16sHVvYfGkz6DdoHYdIODufaiFWwsuaSJ/view?usp=drive_link

Pipe stress analysis is a crucial operation in both pipe design and maintenance operations. As pipe failures might lead to critical situations, the performance of correct pipe stress calculations becomes essential to ensure maximum safety and efficiency while verifying pipe design has been correct in order to extend the product’s life cycle. Pipe stress analysis is a testing method that examines a piping system’s behavior under different loading situations. As such, it’s able to analyze how the material responds to pressure, temperatures, fluid and supports, thus helping engineers: • Observe the pipe’s flexibility and stiffness • Determine values such as maximum stresses, forces, displacements and restraints • Monitor the limits of stress in piping components and their correspondence to applicable standards • Decide on the right support systems to ensure their loads and movements are correct and safe avoiding unsuitable materials that do not support the necessary loads and pressures • Notice potential disengagements from support structures and pipes • Foresee how mechanical vibrations, seismic loads or acoustic vibrations might influence pipe operations • Guarantee pipes are leak-proof to prevent leakage • Select appropriate materials that meet strength and durability requirements All in all, the main reason to perform pipe stress analysis is to guarantee maximum safety wherever pipe systems are installed, so that pipe failures can be minimized. The right pipe analysis can also extend the pipe’s life cycle and ensure the quality and integrity of the transported product. For full videos you can visit this link : https://drive.google.com/file/d/18K7CC7DeIpAtu5pRV_loogo-N2PStO4M/view?usp=sharing https://bit.ly/3SUD734 and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1iEsiB2ydT4bl8LpyHDLbc9rApj8C0DIS/view?usp=drive_link

Pipeline ancillary equipment are components of the pipeline system other than the physical pipeline. In reality there is a wide range of components that make up the pipeline system, each of which performs an important role. We will take a look at the most significant of these components, including: flanges, end fittings, connectors, bulkheads,coatings, insulation, anodes, protection, manifolds, valves, flow meters, controls equipment, tie-in spools. For full videos you can visit this link : https://drive.google.com/file/d/1uTGw6KlUdl3srB3D5HoYVBjPxrWaYoWb/view?usp=sharing https://bit.ly/46oM73K and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1p_XjOFAkrZ2DlGNe4kemOAA-Jtd09Fxm/view?usp=drive_link

This course gives an elementary introduction to linear wave theory. Linear wave theory is the core theory of ocean surface waves used in ocean and coastal engineering and naval architecture. The treatment is kept at a level that should be accessible to first year undergraduate students and does not require more than elementary calculus, probability and statistics. It will cover the linear theory of regular gravity waves on the surface of a fluid, in our case, the surface of water. For gravity waves, gravitation constitutes the restoration force, that is the force that keep the waves going. This applies to waves with wave lengths larger than a few centimeters. For shorter surface waves, capillary forces come into action. Later, this course covers basic wave motion and applies to all kind of waves. We briefly discuss the equations and boundary conditions which lead to water waves. Plane waves are treated in detail and simple superposition is also mentioned. We then proceed to three dimensional waves. The notes are rather short in the sense that they discuss the equations rather than the applications. For full videos you can visit this link : https://drive.google.com/file/d/13BSChnGh2Z_eIvfsoHO_JsOy5r6T_uPj/view?usp=drive_link https://bit.ly/3GcCD0U and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/16WAdY87zdYCx3cth1twipLZzUxh4Q71A/view?usp=drive_link

TTRs are long circular cylinders used to link the seabed to a floating platform. These risers are subject to steady currents with varying intensities and oscillatory wave flows. The risers are provided with tensioners at the top to maintain the angles at the top and bottom under the environmental loading. The tension requirements for production risers are generally lower than those for drilling risers. The risers often appear in a group arranged in a rectangular or circular array. TTRs rely on a top tensioner in excess of their apparent weight for stability. TTRs are commonly used on a tension leg platform or spar dry tree production platform (spar). At the surface, the riser is supported from the platform by hydropneumatic tensioners, which allow the riser to move axially or stroke, relative to the platform. TTRs were designed for shallow-water use, but as the water depths grew, so did the need for new designs. In shallow water it has been practice using top tensioned risers, but as design for larger water depth is accounted the need for new design practice has increased. The ordinary Top Tensioned riser is very sensitive to the heave movements due to wave and current loads because the rotation at the top and bottom connections is limited. The heave movement also requires top tension equipment to compensate for the lack of tension. If the top tension is reduced it will cause larger bending moment along the riser especially if the riser is located an environment with strong current. If the effective tension becomes negative (i.e. compression) then Euler buckling will occur. For full videos you can visit this link : https://drive.google.com/file/d/1nZQOEUNlX1kUR09H-eXPAbAF1qBsx-jG/view?usp=sharing https://bit.ly/41cpHSo and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1_17wEvPc26LgC-I3Zjidc8WXqXt_ouKZ/view?usp=sharing

The top tensioning system is used to pull at the top of the drilling riser to support the weight of the riser, its components, and the fluid inside the riser; and it is also used to control the shape of the riser when subjected to environmentally-induced load effects. The tensioning system is normally composed of a number of “tensioners”. The number and rating of the tensioner units will determine the total capacity of the tensioning system. There are two types of tensioner designs (i.e., wireline tensioners and direct-acting tensioners). A wireline tensioner unit uses a hydraulic ram with a large volume air-filled accumulator to maintain near constant tension on the tensioner wires. One end of the wire is attached at the tensioner and the other is attached to the outer barrel of the telescopic joint through sheaves underneath the drill floor. A direct-acting tensioner has a hydraulic rod and piston assembly, which are attached directly to the drill floor structure and the outer barrel of the telescopic joint. Riser Stability Calculation The stability calculation is to calculate the minimum required top tension to verify that the tensioning system has sufficient capacity for the structural stability of the riser string with anticipated mud weight and possible of loss of one or two tensioners. Besides the minimum top tension requirements, maximum allowable top tension of the riser string is often limited by factors other than the tensioning capacity. These factors include the following: The structural capacity of the drill floor which supports the tensioning system. The tension rating of the riser joints and couplings. For full videos you can visit this link : https://drive.google.com/file/d/1E1eLUJrs50g3dUTXmDkGNZClNabi-rJ9/view?usp=sharing https://bit.ly/3uMJWtC and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1PReH8DZkvE_UfaLkBvIqrI-e8pIQbcms/view?usp=sharing

As the computing capacity increases, the use of finite element methods has become the most commonly used technique and the riser’s dynamics are now coupled with the dynamics of the vessel which are also simulated and controlled under dynamic positioning systems. Nowadays, dynamic analyses are performed not only in order to study the response under fluctuating loads but also to design controllers that can accurately regulate the horizontal displacement of the risers to prevent collision with other offshore structures. For full videos you can visit this link : https://drive.google.com/file/d/1wyb_ojcZySnrD4-aEWldbRiMP5SQHbrj/view?usp=sharing https://bit.ly/47QpvKn and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1aDDva82FUFtgBPxyKxtjPxdpLpgW9tg5/view?usp=sharing

As the computing capacity increases, the use of finite element methods has become the most commonly used technique and the riser’s dynamics are now coupled with the dynamics of the vessel which are also simulated and controlled under dynamic positioning systems. Nowadays, dynamic analyses are performed not only in order to study the response under fluctuating loads but also to design controllers that can accurately regulate the horizontal displacement of the risers to prevent collision with other offshore structures. For full videos you can visit this link : https://drive.google.com/file/d/10OfLMVjSRN0X8ayZfx0oSGP7GUSO6bi3/view?usp=sharing https://bit.ly/47x76m3 and you will be directed to a google drive link where you can download all files of this course https://drive.google.com/file/d/1ZEMJS5slLWNgTpoHGhHnZOrtZiSJCgKA/view?usp=sharing