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Abstract An onboard, autonomous power system was required to supply electricity to a floating LNG (FLNG) plant anchored offshore the state of Sarawak in Malaysia. The power system together with its ancillaries were designed to be reliable and robust enough to operate an LNG plant located 180km offshore while sustaining a crew of 140 people. The design of the power system started by estimating the amount of power required by the plant. The distribution of loads was then decided and system voltages were selected. The voltage of power generators was then matched with the selected system voltage either through direct connection or via unit transformers. This resulted in different design options which when combined with a plant constrained by limited space and weight as in the case of FLNG, presented unique design challenges. System studies were carried out together with protection coordination to ensure system stability. The results concluded that the power system will remain stable during a three-phase fault at the highest system voltage. In the event of a total power outage, the electrical system was designed to safely shutdown the plant and then restart it to resume production. The power generation system at the topside was installed on the floater at the dockyard. All electrical systems were tested prior to sail-away. The load-testing of the GTG's at the dockyard would have incurred substantial cost in terms of the fuel, load bank rental and supporting services. After careful consideration, it was decided to carry out the load tests offshore at the production location. The unique design of the electrical system for the Floating LNG plant will provide a reference for future, similar projects. The lessons learned will serve to improve future designs in this niche technology.
Abstract This paper will examine the benefits of using integrated power management systems for automatic load shedding and generation control at oil and gas facilities. Many oil and gas facilities today, such as refineries, offshore installations, pipelines, and well pads located in remote areas operate their own autonomous or partially autonomous power networks to ensure that an adequate amount of electricity is available to run critical equipment in the event of a loss of the utility grid. Load shedding is an important procedure whereby non-essential loads, such as cooling and air conditioning units, motors, furnaces, compressors, pumps, and lighting systems are shut down in a strategic manner in order to ensure that the facility's core processes remain running and costly downtime is avoided if there is a generation failure or disturbance either onsite or within the public utility grid. To achieve this, many operators today use separate independent systems, which shed load in accordance with a predefined priority list. However, because these systems are often deployed in addition to an energy automation system, they have their own hardware, wiring, and maintenance requirements, which lead to inefficiencies, overlap between equipment, and higher lifecycle costs. This paper will discuss the advantages of embedding applications in existing substation automation infrastructure and combining energy automation and power management applications like load shedding and automatic generation control (AGC). Doing so enables facilities to achieve substantial cost savings and improve the reliability of their onsite power networks. A case study will be presented on a major crude oil pipeline, where the use of an integrated power management solution helped an operator reduce CAPEX and OPEX, improve critical process uptime, and enhance safety by allowing personnel to control systems remotely. The paper will also discuss how enterprises can use integrated power management systems for operator training and grid simulation purposes.
Abstract In the last decades the importance of LNG (liquid natural gas) has been increasing continuously. Worldwide a large number of plants have been erected using classical compressor technology driven by direct-coupled gas turbines. This approach limits the availability due to maintenance restrictions and the missing spinning redundancy. Modern concepts are based on large full electrical compressors which allow controlling the process with reduced energy consumption. The corresponding maintenance concept improves the LNG plant availability significantly. LNG plants generally have no grid connection, i.e. the LNG plant must be supplied under island conditions. Guarantee a high availability of the electrical and steam generation is however necessary. Therefore it is primarily important not only to provide a suitable system design, but also to investigate its ability to dynamically withstand heavy events, taking into account the mutual interaction of electrical output of the steam turbine and the variation of the steam demand, the boiler capacity and the dynamics of the supplementary firing. Aim of this paper is to illustrate an integrated approach for the steady-state and dynamic study of LNG plants, in which both the electrical and the steam system are completely modeled and interfaced. After separate design, both systems are simulated with the same simulation tool, so operations and events are immediately incorporated and the two systems show the reciprocal interaction. Thus more realistic and significant system responses to events are obtained, with increase in the project efficiency and reduction of investment costs. To validate the approach, a typical LNG plant is modeled, including all relevant equipment and controllers, as well as process system units, with PSSยฎNETOMAC. The simulation of severe outage cases allows to optimize the basic electrical and steam control concept and to design the load or generation shedding sequences, depending on the outage severity. 1 Introduction In the oil and gas industries (O&G) energy is used differently along the O&G value chain. In the upstream 75 % is used in rotating equipment like compression and pumping, in the midstream 99 % for compression and pumping transportation and in the down stream more than 90 % for heat transfer. O&G is one of the most energy intensive industries with a high CO2 emission (O&G consumes about 20 % of its products in its own process and emits 12 % of the global energy related CO2 per year). The O&G industry will play a major role in the climate debate in the next years. In addition fuel costs and CO2 emission can take different pathways which allow using efficiency technology to reduce the costs and the CO2 emission. In the last years the importance of LNG (liquefied natural gas) has been increasing and this development is expected to continue. Depending on the size of one liquefaction train, the power demand is 300 to 450 MW, mainly used for coolant compression. World wide a large number of LNG-plants have been erected using classical compression technology with compressors driven by gas turbines directly coupled on a single shaft. This approach is limited in availability and flexibility through high maintenance restrictions and missing spinning redundancy. In addition the energy efficiency is relatively low and therefore CO2 emission and fuel consumption is relatively high. A modern concept is based on large electrical driven compressor units, supplied by a set of generators, based on combined cycle plants (E-LNG). Fig. 1 shows the different plant concepts.
Abstract Electrifying industries is an emerging trend that aims to replace traditional fossil-fuel-based energy sources with renewable electricity in various sectors. Several industrial installations around the world, offshore and onshore, are abandoning reliance on fossil-fuel based power generators by connecting to the public grid directly or through power from shore interconnection. In many cases those installations are and lead to an island network configuration or what is commonly known as micro grid constituted of the load, the renewable generator plant and the transmission system. The objective of this work is to investigate frequency regulation in this configuration. In the presence of classical power generators based on synchronous machines an island grid caters for the power system stability among others, frequency regulation, through the inherit characteristics of the synchronous machines. In the absence of synchronous generators- based power plants, frequency stability becomes more critical as the entire power system inertia is reduced due to the absence of rotating machines both on the generation, especially in the case of solar generation, and load side, i.e. power electronics connected motors. The power system frequency regulation has to be achieved through careful coordination and cooperation of the different power electronic devices controllers such as solar generation converters, battery energy storage systems (BESS) converters and HVDC converters, in case present. This investigation is achieved by the means of RMS based dynamic system simulations. The investigation shows that the ability of the synchronous machine prime mover to regulate the power system frequency through its governor action and avoid critical frequency excursions through inherit kinetic inertia is significantly reduced due to renewable energy displacement of synchronous machine power generation. Additionally, the speed of measurement and response to frequency events of the power electronics-based devices is detrimental to system survival. The investigation shows that the coordination of the solar generation and BESS along with their respective droops and coordination with other power electronic devices in the power system, such as HVDC transmission with grid forming functionalities, is essential. Frequency regulation in lower inertia power systems is essential to maintain system and process operation and reliability. The investigation gives an outlook into realizing industrial installation in remote locations without connection to an existing public grid relying solely on sustainable sources of power generation.
- Machinery > Industrial Machinery (1.00)
- Energy > Renewable > Solar (1.00)
- Energy > Power Industry (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract The oil and gas industry would never have imagined that the full electrification of floating, production, storage, and offloading (FPSO) units would be plausible one day. Fast forward to today, we are currently progressing towards an era that will inaugurate full electrification of an FPSO in the Brazilian waters by the end of this decade. The idea is to challenge the norm of replacing all gigantic gas turbines with electric motors and power the entire FPSO, a big step towards decarbonising the FPSOs. However, the industry needs immediate solutions towards optimising fuel efficiency and curbing emissions as the full electrification method was not viable previously due to several reasons such as limits from local regulations on power plant sizing. Therefore, rather than solely focusing on the conceptual design of full electrification, several recently contracted FPSOs had incorporated a partial electrification concept that maximise electricity usage to reduce emissions, resulting in the first proven concept for the partial electrification of FPSOs. The main goal of this paper is two-fold; First, to discuss the main features of a Partial-Electric FPSO currently contracted to operate in the pre-salt region of Brazilian waters that turns conventional loads into motorised loads. Several decarbonisation efforts implemented via reduced emissions and advanced monitoring tools will also be discussed for the Partial-Electric FPSO that is under construction in the shipyard at the point of this paper being published. Second, to present the new technologies and concepts that the next generation of FPSOs can adopt in the process of transitioning into the full electrification of FPSOs, which mainly focus on the combined cycle power generation (CCPG). With the implementation of partial electrifications and new technologies like CCPG, this will prepare the FPSO industry ahead of the 1.5-degree target, and at the same time paving the way for the development of greener FPSOs.
- South America > Brazil (0.29)
- North America > United States > Texas (0.28)