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BP has acquired UK-based digital energy business Open Energi. The company's digital platform uses real-time data to optimize the performance of energy assets. It connects customers to power markets with the goal of providing flexibility at times of low renewable-energy generation and during price peaks. The share of primary energy from renewables is projected to increase from around 5% in 2018 to 60% by 2050 in the net-zero scenario set out in BP's Energy Outlook. However, because generation from these sources depends on weather conditions, the growth will also bring increased market and price volatility.
The required power for the oil field is either generated on site by engine- or turbine-driven generator sets or purchased from a local utility company. The engines or turbines may use diesel or natural gas as a fuel. Some units are dual-fueled, using natural gas and diesel. Natural-gas-fueled prime movers are most practical for normal power generation for most applications. Diesel is used where natural gas is unavailable and for units that provide black-start and emergency power.
Electricity systems around the world are changing, with the Paris Agreement of 2015 a catalyst for much current change. The Australian government ratified the agreement by committing to 26–28% emissions reductions below 2005 levels by 2030. Reduction in emissions from electricity generation has become the focus of these targets. To decarbonize the grid to meet targets while building firm, dispatchable generation capacity to support the system, a new metric is required to measure success. The complete paper explores the outputs of the model of energy and grid services (MEGS), illustrating outcomes if a single technology group is favored.
Energy demand is expected to grow during the next century as more countries seek a better quality of life for their citizens. Increasing trends in population and consumption, price volatility, supply instability, and environmental concerns are changing the energy mix and energy strategies in the 21st century. The energy mix is the set of energy sources that are used to meet energy demand. Energy demand will be met by a global energy mix that is transitioning from a mix dominated by fossil fuels to a more balanced energy portfolio. The emerging energy mix will rely on clean energy. Clean energy refers to energy that has little or no detrimental impact on the environment.
One of the options for gas monetization is gas to power (GTP), sometimes called gas to wire (GTW). Electric power can be an intermediate product, such as in the case of mineral refining in which electricity is used to refine bauxite into aluminum; or it can be an end product that is distributed into a large utility power grid. This page focuses on electricity as the end product. The primary issues related to GTP are the relative positions of the resource and the end market and transmission methods. The scale or volume of gas and/or power to be transported influences each of these issues.
Two of the world's wealthiest men have put their vast resources behind what the nuclear industry calls small modular reactors (SMRs) in the quest for the perfect carbon-free energy source. TerraPower, founded by Bill Gates, and PacifiCorp, owned by Warren Buffett's Berkshire Hathaway, are sponsors of the project. The first SMR from TerraPower, the Natrium reactor project, will be built in Wyoming--the nation's primary coal producer--at the very location that once housed a coal station, where the infrastructure for a steam-cycle power plant and distribution to the electrical grid already exist. Last year, the state legislature passed a law authorizing utilities to replace coal or natural gas generation with small nuclear reactors and the US Department of Energy awarded TerraPower $80 million in initial funding to demonstrate Natrium technology; the department has committed additional funding subject to congressional approvals. Just ask anyone in Texas where a combination of frozen wind turbines and unprecedented demand last winter darkened the state for days.
Natural gas may be facing an uphill battle in proving itself as a suitable bridging fuel between conventional hydrocarbons and renewable energy sources, especially in Europe where urgency over climate change has ramped up and the call for a quicker path to decarbonization grows louder. As a result, natural gas plant projects across the region are having a harder time finding financing as lenders are pressured to ratchet up the emissions criteria required for funding. Utility providers across Europe have already predicted the potential of supply issues as they work to phase out aging infrastructure, including coal-powered and nuclear plants. Producers have felt for years that gas would be the natural feedstock for new power generation as scientists played catchup in the world of green energy. However, with the cost of renewable energy falling and the promise of new breakthroughs in hydrogen technologies coupled with the drive for a zero-emission future, the natural gas "bridge" may be bypassed altogether.
Carreño, Ignacio Losada (Arizona State University) | Scaglione, Anna (Arizona State University) | Giacomoni, Anthony (PJM Interconnection) | Sundar, Kaarthik (Los Alamos National Laboratory) | Deka, Deepjyoti (Los Alamos National Laboratory) | Zlotnik, Anatoly (Los Alamos National Laboratory)
Abstract We propose a modeling framework and computational method to examine the impacts of operational contingencies on a pipeline system’s capacity to transport natural gas, and study the resulting effect on the reliability of an electric power transmission system that relies on that pipeline for generation fuel. A stochastic model is used to simulate the prevalence of unplanned events that lead to outages that decrease transport capacity, and that may cause curtailments to gas-fired generators that do not hold firm pipeline transportation contracts. We use a transient optimal gas flow as an integrated model that serves as a proxy for pipeline financial and physical operations that involve human-in-loop decisions including compressor setpoint changes. The resulting effects on energy delivery by both the electric power and natural gas sectors is evaluated using transient pipeline simulation and power flow analysis. We consider contingencies occurring during normal operations and collect statistics related to pipeline performance. The proposed approach can be used to discover system vulnerabilities and could ultimately guide development of reliability standards. Introduction Many electric power systems throughout the world now heavily rely on natural gas pipeline networks to supply fuel for gas-fired generation . This has led to growing demand for natural gas transportation in large-scale pipelines, but also increased variability and intermittence in high volume gas flows to dispatched gas-fired generators, which result from operational decision making for the power grid. Although the wholesale power and gas delivery sectors have taken actions to improve market efficiency and implement formal coordination mechanisms , , it is becoming increasingly problematic for power generation asset managers to procure natural gas during periods of pipeline congestion for both base load and ancillary services , which may lead to load curtailments  such as during the recent cold weather event in Texas.
Abstract The integration of Renewable Energy Sources (RES) into the electric power system and the demand for efficient, clean and reliable production, transport and distribution of energy is connected with an increased coupling between the individual energy systems. The interdependency between natural gas and electric power systems, for instance, is increasing and expected to increase further in the near future, mainly due to the growing demand for flexible backup generation and the need for short- and long-term energy storage options to balance the fluctuations of variable and intermittent RES. The need for flexible backup power can be covered by Gas Fired Power Plants, while the demand for seasonal storage can be met by Power-To-Gas facilities. In this paper, we show how curtailment of RES can be reduced by operating Power-To-Gas facilities. Introduction To meet future decarbonization targets power system planners and operators have to integrate more variable renewable energy sources into their electric power systems. The stable and reliable operation of the power system, however, requires a balance between power generation and demand, since electric energy cannot be efficiently and economically stored in existing power system networks. Due to the uncertainty and variability in the generation from Renewable Energy Sources (RES) and at the same time the lack of energy storage, power system planners and operators must find new flexibility and storage options, which typically lie at the interface between different energy networks, such as natural gas, heat & power networks. Natural gas networks, for instance, have relatively large energy storage capacities (linepack, underground gas storage, LNG storage tanks), which can be leveraged by electricity networks to tackle the flexibility and energy storage challenges. The connection between the gas and electric power system can exist at Gas-To-Power plants (G2P) as Gas fired Power Plants (GPP), electric driven gas compressor stations (Power-To-Pressure - P2P) as well as Power-To-Gas facilities (P2G). G2P facilities have relatively short start-up and shut-down times, making them well suited as back-up generation sources in case of lack of wind and solar generation. P2G facilities, on the other hand, can be used to convert excess power generation from renewable sources into hydrogen (H2) and/or synthetic natural gas (SNG), which in turn can be injected into the natural gas pipeline network and/or underground gas storage reservoirs.