Natural Gas Production Research Articles

Process Reduces Carbon Emissions From Natural Gas Compression and Production

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 214974,“New Technology Reduces Carbon Emissions From Natural Gas Compression and Production Facilities,” by John Guoynes, SPE, David Stiles, SPE, and Cory Vail, Axip Energy Services, et al. The paper has not been peer reviewed. _ A chemical-free process has been developed to capture exhaust from natural gas drive compressors and supporting gas-fueled production equipment while featuring a small footprint. The process separates CO2 and nitrogen from exhaust, allowing the CO2 to be discharged at high pressure for transport, sequestration, or enhanced oil recovery. Introduction Over 50,000 compressors move natural gas in North America. Most are driven by either internal combustion engines or turbines. These compressors produce am estimate of more than 30 million tonnes of CO2 equivalent yearly, according to the US Environmental Protection Agency’s Greenhouse Gas (GHG) Reporting Program. The significance of GHG reduction policies has heightened with the passing of the Inflation Reduction Act, which provides support for companies investing in future carbon capture use and storage, along with methane reduction. Process Modeling Modeling and analysis of an exhaust-gas carbon capture system, and the design and optimization of a supercritical CO2 (sCO2) waste-heat-recovery power cycle, was performed. This cycle was chosen for its high efficiency and relatively compact design compared with competitive waste-heat-recovery technologies. The preliminary process-flow diagram was provided based on conditions for 30,000-hp large reciprocating gas engines. Several process configurations were investigated; these iterations are detailed in the complete paper. A summary of this development shows that Iterations 1 through 3 showed improvements in power through improving the sCO2 power-cycle efficiency. However, this came at the increase in high-pressure sCO2 components. A simplification of components returned the sCO2 cycle to a single cascaded cycle in Iterations 4 through 5. Temperature selection in the sCO2 cycle also improved its efficiency. Moving to Iteration 4 improved the system power requirement by 20.7%. Iteration 5 showed moderately reduced performance over Iteration 4. This was the result of shifting more duty to the ammonia chillers and a moderate worsening of performance in the gas compressor. Iteration 5 did not improve the power requirement of the system. Ultimately, Iteration 4 was the most-efficient cycle evaluated with the overall lowest power requirement. Exhaust-Capture Decarbonization System The system developed captures exhaust from compression and other internal combustion equipment commonly used in gas transmission, oil and gas production, and midstream applications. The system works with a chemical-free, cryogenic design with a small modular footprint to capture large volumes of exhaust gas at atmospheric pressure. This technology separates CO2 and nitrogen, generates enough power from waste heat to run the equipment, and discharges captured CO2 under high pressure at supercritical conditions for compressor stations of 5,000 to 20,000 hp. The design is fully self-contained and mounts on a compact skid package capable of handling up to 70 million scf/D of exhaust while extracting liquid CO2 from rich-burn driven compressors, lean-burn driven compressors, or turbines.

Development, challenges and strategies of natural gas industry under carbon neutral target in China

In the mid-21st century, natural gas will enter its golden age, and the era of natural gas is arriving. This paper reviews the development stages of global natural gas industry and the enlightenment of American shale gas revolution, summarizes the development history and achievements of the natural gas industry in China, analyzes the status and challenges of natural gas in the green and low-carbon energy transition, and puts forward the natural gas industry development strategies under carbon neutral target in China. The natural gas industry in China has experienced three periods: start, growth, and leap forward. At present, China has become the fourth largest natural gas producer and third largest natural gas consumer in the world, and has made great achievements in natural gas exploration and development theory and technology, providing important support for the growth of production and reserves. China has set its goal of carbon neutrality to promote green and sustainable development, which brings opportunities and challenges for natural gas industry. Natural gas has significant low-carbon advantages, and gas-electric peak shaving boosts new energy development; the difficulty and cost of development are more prominent. For the national energy security and harmonious development between economy and ecology under the carbon neutral goal, based on the principle of “comprehensive planning, technological innovation, multi-energy complementarity, diversified integration, flexibility and efficiency, optimization and upgrading”, the construction of the production-supply- storage-marketing system has to be improved so as to boost the development of the natural gas industry. First, it is necessary to strengthen efforts in the exploration and development of natural gas, making projects and arrangement in key exploration and development areas, meanwhile, it is urgent to make breakthroughs in key science theories and technologies, so as to increase reserve and production. Second, it should promote green and innovative development of the natural gas by developing new techniques, expanding new fields and integrating with new energy. Third, there is a demand to realize transformation and upgrading of the supply and demand structure of natural gas by strengthening the layout of pipeline gas, liquefied natural gas and the construction of underground gas storage, establishing reserve system for improving abilities of emergency response and adjustment, raising the proportion of natural gas in the primary energy consumption and contributing to the transformation of energy consumption structure, realizing low-carbon resources utilization and clean energy consumption.

Assessing the role of LNG in global carbon neutrality efforts: A project management review

This paper review explores the role of LNG in the context of global carbon neutrality efforts. It examines various aspects such as the current state of LNG usage, its environmental impacts, technological advancements, regulatory frameworks, and the challenges and opportunities associated with its integration into the energy mix. Through a comprehensive analysis, this review aims to provide insights into how project management principles can facilitate the effective implementation of LNG projects to support the transition towards a carbon-neutral future. The transition to a carbon-neutral global economy is an imperative challenge of the 21st century, necessitating a profound shift in energy systems and practices. At the forefront of this transition, liquefied natural gas (LNG) has emerged as a potential bridge fuel, offering a pathway towards decarburization. This project management review delves into the multifaceted role of LNG within the context of global carbon neutrality efforts, examining its current usage, environmental implications, technological advancements, regulatory frameworks, and the associated challenges and opportunities. Through a comprehensive analysis, this review aims to shed light on how project management principles can effectively facilitate the implementation of LNG projects to support the transition towards a carbon-neutral future. LNG's emergence as a potential bridge fuel stems from its relatively lower carbon intensity compared to other fossil fuels. As nations strive to reduce greenhouse gas emissions and meet their commitments under the Paris Agreement, LNG presents an opportunity to mitigate climate change while addressing energy security and economic development objectives. However, a nuanced understanding of LNG's role requires a thorough examination of various dimensions. Firstly, the current state of LNG usage underscores its growing significance in the global energy landscape. With LNG trade reaching record highs in recent years, countries are increasingly turning to LNG to meet their energy needs. Major LNG-producing nations such as Qatar, Australia, and the United States have invested in liquefaction infrastructure, enabling the export of LNG to markets around the world. Additionally, LNG is utilized across diverse sectors, including power generation, industrial processes, transportation, and residential heating, highlighting its versatility and applicability. Despite its potential benefits, LNG is not without environmental impacts. The extraction, production, and transportation of natural gas, the primary component of LNG, can result in methane emissions, a potent greenhouse gas. In conclusion, LNG has emerged as a potential bridge fuel in the transition towards a carbon-neutral global economy. Its relatively lower carbon intensity, versatility, and scalability make it a viable option for reducing greenhouse gas emissions while meeting energy demand. However, realizing the full potential of LNG requires careful consideration of its environmental impacts, technological advancements, regulatory frameworks, and associated challenges. By applying project management principles, stakeholders can effectively navigate the complexities of LNG projects and contribute to the achievement of global carbon neutrality goals.

Integration assessment of turquoise hydrogen in the European energy sector

Turquoise hydrogen from natural gas pyrolysis has recently emerged as a promising alternative for low-carbon hydrogen production with a high-value pure carbon by-product. However, the implications of this technology on the broader energy system are not well understood at present. To close this literature gap, this study presents an assessment of the integration of natural gas pyrolysis into a simplified European energy system. The energy system model minimizes the cost by optimizing investment and hourly dispatch of a broad range of electricity and fuel production, transmission, and storage technologies, as well as imports/exports on the global market. Norway is included as a major natural gas producer, and Germany as a major energy importer. Results reveal that pyrolysis is economically attractive at modest market shares where the carbon by-product can be sold into high-value markets for 400 €/ton. However, pyrolysis-dominated scenarios that employ methane as a hydrogen carrier also hold promise as they facilitate deep decarbonization without the need for vast expansions of international electricity, hydrogen, and CO2 transmission networks. The simplicity and security benefits of such pyrolysis-led decarbonization pathways justify the modest 11 % cost premium involved for an energy system where natural gas is the only energy trade vector. In conclusion, there is a strong case for turquoise hydrogen in future energy systems and further efforts for commercialization of natural gas pyrolysis are recommended.

Downstream Analysis of Strategic Investment in Natural Gas Commodities in Increasing the Value of Indonesian Natural Gas Products

Downstream Analysis of Strategic Investment in Natural Gas Commodities in Increasing the Value of Indonesian Natural Gas Products

Drilling Down for Answers: Unmasking the Impact of Oil and Natural Gas Activity on Crime Rates in Texas

This article delves into the impact of oil and natural gas (ONG) production on the incidence of Part I violent crimes in Texas. Texas holds a prominent position in the energy industry, contributing to 43% of the nation's crude oil production and 26% of its natural gas production (EIA, 2021). However, alongside ONG operations come significant societal changes, including a rise in various social issues, including criminal activities. While prior research has explored the consequences of ONG-related transformations on crime rates through perceptual and economic studies, there is a scarcity of studies that investigate the intricate relationship between ONG activities and crime patterns, particularly in the Texan context. To bridge this research gap, this study employs residual change scores and multiple linear regression techniques to scrutinize county-level shifts in ONG activity and Part I violent crime incidents during the period spanning 2009 to 2019 across Texas ONG-producing counties. The findings derived from this investigation unveil a noteworthy association between six dynamic ONG measures and the alteration in specific known Part I violent crimes. This study makes a noteworthy contribution to the existing body of knowledge concerning rural crime and boomtown dynamics as it stands as the inaugural examination utilizing residual change score analysis to determine whether ONG activity indeed contributes to any variations in known Part I violent crime rates. By scrutinizing the intricate connection between energy production and crime, this research aids in fostering a better understanding of the social implications of ONG activities in resource-rich regions, particularly within Texas.

An Economic Analysis of In-Situ Hydrogen Production from Natural Gas Wells with Subsurface Carbon Retention

Summary An economic analysis for a wellbore methodology that promotes sustainable natural gas conversion to hydrogen is presented. The methodology uses at-source, wellbore gasification of methane for hydrogen production, incorporating the simultaneous in-situ sequestration of carbon for both climate and economic benefit. The proposal is for a wellbore completion tool, to take natural gas (methane) production from the reservoir and perform gasification within the wellbore tool (not within the reservoir). This would not interfere with reservoir management, allowing standard reservoir management practices to be used. The proposed process is for natural gas fields and not for use in the gasification of heavy oils (which is covered by other “combustion type” reservoir management processes performed deep within the reservoir geology). The proposed methane gasification tool, when located deep within the wellbore, takes maximum advantage of the “free” energy provided by the elevated temperatures and pressures of the surrounding fluid-connected geology. The combination of surface-injected fluids and geofluids, mixed inside the wellbore gasification tool at depth, significantly reduces the excess process energy input from the surface and lessens feedstock consumption for power. The proposed system is neither electricity cost dependent nor fuel cost dependent, as both are provided in situ and through heat recovery and reserves. There are therefore several process steps and significant energy and cost savings to be gained by this method when compared with surface-based methane reformation facilities, as well as infrastructure longevity benefits. In addition, CO2 life cycle climate savings are made, as zero carbon is produced to the surface, eliminating the harm greenhouse gases (GHGs: CH4 and CO2) do while transitioning through the environment. The proposed methodology therefore avoids the expense and energy consumption of the subsequent, only partial, downstream recapture of the CO2 released from the combustion of this same methane. To help maintain consistency and ensure comparability for hydrogen production types, the standardized H2A template of the National Renewable Energy Laboratory (NREL) of the U.S. Department of Energy was used in our analysis. This economic template contains several cost model scenarios used to illustrate the possible magnitudes of economic advantages using this wellbore methodology. Based on the model’s comparative cost analyses, such a proposed system could produce hydrogen from natural gas wells consistently below 1 USD/kg H2, leading to cost-competitive wellbore hydrogen production when compared with surface-based steam methane reformation facilities. Using several scenarios for cost analysis, we found that the cost cannot be higher than 2 USD/kg H2. In our uncertainty quantification, we included the effects of the number of wells that can be used as well as mixing H2 with CH4 (v/v%).

Carbon-neutral cement: The role of green hydrogen

Business-as-usual (BAU) cement production is associated with a linear model that contributes significantly to global warming and is dependent on volatile energy markets. A novel circular model is proposed, by adding three power-to-gas system components to current production systems: a calcium-looping (CaL) CO2 capture unit; water electrolysis for hydrogen and oxygen generation; and a methanation unit for synthetic natural gas (SNG) production. The paper presents the first analysis of the combined industrial-scale operation of these components in a closed loop, where the SNG fuels the cement kiln and the CaL unit, while the O2 produced feeds it. The circular, hybrid, and BAU models are compared in three feasibility scenarios. It is concluded that the circular model outperforms the other alternatives environmentally, opening a potential pathway for the cement industry to achieve near net-zero CO2 emissions, reduce energy dependence and improve economic efficiency.

Modelling spatial & temporal variability of air pollution in an area of unconventional natural gas operations

Despite the growing unconventional natural gas production industry in northeastern British Columbia, Canada, few studies have explored the air quality implications on human health in nearby communities. Researchers who have worked with pregnant women in this area have found higher levels of volatile organic compounds (VOCs) in the indoor air of their homes associated with higher density and closer proximity to gas wells. To inform ongoing exposure assessments, this study develops land use regression (LUR) models to predict ambient air pollution at the homes of pregnant women by using natural gas production activities as predictor variables. Using the existing monitoring network, the models were developed for three temporal scales for 12 air pollutants. The models predicting monthly, bi-annual, and annual mean concentrations explained 23%–94%, 54%–94%, and 73%–91% of the variability in air pollutant concentrations, respectively. These models can be used to investigate associations between prenatal exposure to air pollutants associated with natural gas production and adverse health outcomes in northeastern British Columbia.

US oil and gas system emissions from nearly one million aerial site measurements.

As airborne methane surveys of oil and gas systems continue to discover large emissions that are missing from official estimates1-4, the true scope of methane emissions from energy production has yet to be quantified. We integrate approximately one million aerial site measurements into regional emissions inventories for six regions in the USA, comprising 52% of onshore oil and 29% of gas production over 15 aerial campaigns. We construct complete emissions distributions for each, employing empirically grounded simulations to estimate small emissions. Total estimated emissions range from 0.75% (95% confidence interval (CI) 0.65%, 0.84%) of covered natural gas production in a high-productivity, gas-rich region to 9.63% (95% CI 9.04%, 10.39%) in a rapidly expanding, oil-focused region. The six-region weighted average is 2.95% (95% CI 2.79%, 3.14%), or roughly three times the national government inventory estimate5. Only 0.05-1.66% of well sites contribute the majority (50-79%) of well site emissions in 11 outof 15 surveys. Ancillary midstream facilities, including pipelines, contribute 18-57% of estimated regional emissions, similarly concentrated in a small number of point sources. Together, the emissions quantified here represent an annual loss of roughly US$1 billion in commercial gas value and a US$9.3 billion annual social cost6. Repeated, comprehensive, regional remote-sensing surveys offer a path to detect these low-frequency, high-consequence emissions for rapid mitigation, incorporation into official emissions inventories and a clear-eyed assessment of the most effective emission-finding technologies for a given region.

Opportunities and challenges for gas coproduction from coal measure gas reservoirs with coal‐shale‐tight sandstone layers: A review

AbstractThe extraction of coal measure gas has been shifted toward thin gas reservoirs due to the depletion of medium‐thick gas reservoirs. The coproduction of coalbed gas, shale gas, and tight sandstone gas (called a multisuperposed gas system) is a key low‐cost technology for the enhancement of natural gas production from thin gas reservoirs in coal measure. As an emerging engineering exploitation technology at its early stage of development, gas coproduction confronts various engineering challenges in hydraulic fracturing, bottom‐hole pressure regulation, well network arrangement, and extraction sequence. The current understanding of the opportunities and challenges in the gas coproduction from the multisuperposed gas system is not comprehensive enough. In this case, the previous achievements in the field of gas coproduction should be urgently reviewed to provide valuable guidance and recommendations for further development. This review first discusses the regional and spatial distribution characteristics and possible reservoir combinations of gas reservoirs in coal measure. Then, the basic properties of different reservoirs, engineering challenges, and interlayer interference are comparatively analyzed and discussed. The current simulation models for gas coproduction and potential future research directions are further explored. The results indicate that the coupling effects of reservoir heterogeneity, interwell interference, and geological structure for increasing coproduction prediction accuracy should be included in future simulation models for gas coproduction. Careful investigation is required to explore the mechanisms and their further quantifications on the effects of interlayer interference in gas coproduction. The fractal dimension as a scale can play an important role in the characterization of the gas and water transport in different reservoirs. The machine learning methods have tremendous potential to provide accurate and fast predictions for gas coproduction and interlayer interference.

3D modeling of cryogenic cracking by liquid nitrogen in coal under true triaxial stresses

Coalbed methane (CBM) plays an indispensable role in total natural gas production and consumption, and for the bottlenecks encountered in stimulating CBM reservoirs by conventional fracturing methods, studying more environment-friendly and efficient stimulation methods is imperative. Cryogenic fracturing using liquid nitrogen has been trialed for the development of coalbed methane, demonstrating great significance as more and more research corroborated. This study extended our previous coupled thermo-mechanical-damage (TMD) numerical procedure to investigate the cryogenic fracturing or damage process in 3D coal cubes. The cryogenic fractures on concrete cubes along with analytical solutions of temperature and first principle stress distributions for the borehole cooling process were first employed to verify the correctness and feasibility of this method, which incorporates the boundary conditions affected by the Leidenfrost effect at the initial stage. Then sensitivity analyses of cryogenic fracture generation including the maximum fracture cross-sectional area and the fractured volume were carried out. Results show that the coal rock with a high modulus of elasticity and coefficient of thermal expansion is more prone to be damaged in terms of the cross-sectional area and volume than other parameters within the parameter range analyzed. Damage cross-sectional area and damage volume expand with both the increasing coefficient of thermal expansion and the increasing modulus of elasticity, while they shrink with increasing heat capacity and coal density. Cryogenic fractures are relatively less sensitive to the thermal conductivity, density, and heat capacity of coal. This 3D modeling study provides a technical route and a panorama of the cryogenic fracturing process under varied conditions in opaque coal rocks.

Citizens Awareness and Perception in Food Waste Management in some Metropolitan Cities in India

Food Waste is a global issue with implications for the health of society, economics, and the environment. It is a major issue in urbanized societies/ metropolitan cities as compared to rural areas and village populations in India. Food Waste its utilization in the natural gas production units and farm compost units which are lacking in metropolitan cities.

A fusion gas load prediction model with three-way residual error amendment

Accurately predicting gas load is crucial for optimal planning and scheduling of natural gas production. Existing machine learning or deep learning-based prediction methods primarily aim to improve accuracy. However, these methods face challenges such as overlapped features, significant background noise, and residual errors. In response to these challenges, we proposed a fusion prediction model, known as the Double Temporal Convolutional Network (TCN) and Light Gradient Boosting Machine (LightGBM) with Three-way Residual Error Amendment (DT-LGBM-3WREA). To address the overlapped feature issue in time series data, we utilize the STL module for data decomposition. To handle background noise, the network incorporates a double TCN module specifically designed for trend and seasonal components. Thus, it can better avoid the transmission of noise between modules. To address residual error, we introduce three-way decision methodology and develop the 3WREA module, which aims to avoid local optima and random factors from perturbing the prediction accuracy. This approach mitigates the influence of remainder item on overall prediction performance. Experimental results demonstrate that the DT-LGBM-3WREA model excels in gas load prediction scenarios, surpassing state-of-the-art methods.

Natural Gas Production

Current data on natural gas production, as well as a breakdown of production by country. Updated on a monthly basis.

Europe’s independence from Russian natural gas — Effects of import restrictions on energy system development

With the Russian invasion on Ukraine in 2022 and the following disruption of Russian natural gas imports, Europe’s energy reliance on Russia has become more apparent than ever. To tackle the resulting challenges of a limited supply of fossil fuels from Russia and especially its effects on energy system development, short and long-term effects need to be investigated thoroughly. This paper aims to quantitatively analyze the impact of reduced natural gas availability from Russia on the European energy system, both in the coming years, as well as in the future. Using the Global Energy System Model (GENeSYS-MOD), three scenarios with varying amounts of Russian natural gas and further impacts of reduced fossil fuel imports from Russia are calculated. Results show that strong effects are mostly observed in the short to medium-term, but an overall earlier phase-out of fossil fuels can be achieved in the long-term. The reduction of natural gas imports is tackled by an increase in LNG imports and domestic natural gas production to overcome the supply gap. Strong reactions are seen in the levelized costs of electricity generation between 2022 and 2025, with higher costs in scenarios with restrictions on Russian natural gas imports, but with a negligible difference in the long-term. Most importantly, lower emissions in scenarios with reduced natural gas supply from Russia highlight the positive effect of an early reduction in fossil fuels and investment in renewable technologies, resulting in a near 100% emission-free energy system by 2045, 5 years before the Base scenario with unrestricted Russian gas imports. The results find that a limitation of Russian fossil imports does not pose a long-term threat to the European energy system or its required transition away from fossil fuels, but can rather accelerate its decarbonization and energy demand reductions.

Research on the influence mechanism of fluid control valve on the production of segmented horizontal wells and the balanced gas production control model: A case analysis of Sichuan basin natural gas

The existing research on the multiple fluid control valves to control the balanced exploitation of natural gas in horizontal wells lacks theoretical model support. On this basis, this paper established a flow rate and pressure model of the segmented horizontal well based on the fluid control valve. The model considers the throttling performance, installation position and opening adjustment step size of the fluid control valve for the first time. Next, systematically analyzed the mechanism of mutual influence of the opening and the position on the flow rate and pressure based on multiple fluid control valves. In addition, a novel method of using the dichotomy model to adjust the production of different production segments was proposed to analyze the horizontal wells of 15 production segments in Sichuan. It was found that when the opening adjustment step size is less than 5%, the natural gas production shows irregular changes, which makes it hard to effectively control the production of each segment. When the step size is 5%, the maximum production variation is 2.7%, which will have a more significant and meaningful effect on the exploitation of natural gas. Through seven iterations, the maximum production errors of high and low production segments are 1.3 % and 1.1 % respectively, both less than 2.7%. The research results verified the correctness of the theoretical model of segmented horizontal wells based on multiple fluid control valves. This research provided a theoretical basis for the opening control of multiple fluid control valves based on different production segments of horizontal wells.

Electricity sector impacts of water taxation for natural gas supply under high renewable generation

The future of energy development could be soon restrained by water scarcity. Shale gas, which is highly water-consuming in its extraction, is even more vulnerable. Thus, understanding the power system’s response to water constraints considering uncertainties from variable renewable energy generation becomes critical. This study presents a multi-stage stochastic Mixed Complementarity Problem for the energy sector, considering renewables variability and water scarcity’s impact on natural gas extraction. The power and natural gas sectors were modeled with hourly and daily resolution, respectively. Results demonstrate that stochastic planning enables smoother natural gas production and storage strategies, ensuring consistent operations with a narrower production range. Water taxation affects gas production and the generation mix, leading to electricity price changes. Gas-based electricity generation varies up to 16.2% based on water taxation and wind availability. Furthermore, water taxation of up to 20% can raise gas prices by up to 21.1%. This study underscores the need to integrate water scarcity considerations into energy planning, offering insights into sustainable decision-making, water resource management, reliable electricity generation, and price stability amidst evolving renewable portfolios.

Improvement energy performance for GHG mitigation - a case of FPSO vessel platform in Oil & Gas offshore production

This study offers an in-depth review of specific facets of the oil and gas industry, emphasizing the role of Floating Production, Storage, and Offloading (FPSO) vessels. It delves into diverse topics, highlighting potential opportunities, a solid research methodology for emissions quantification, and the pivotal challenge of reducing GHG emissions. Among the multitude of opportunities analyzed within the industry's value chain, the upstream sector - encompassing both exploration and production of oil and natural gas - receives considerable focus. This sector can be further divided into key segments characterized by high energy consumption and consequent significant emissions. Notably, the combustion of natural gas for power generation stands out, contributing a substantial 68% of CO2 emissions at related facilities. This process is a primary target for mitigation and energy efficiency enhancements. The intricate interplay between energy generation and CO2 emissions stands at the forefront of current research, emphasizing the need for improving vessel energy efficiency. This paper employs a case-based methodology, evaluating the effectiveness of energy efficiency measures within an FPSO setting and their resulting impact on GHG emissions. Central to this inquiry is a detailed examination of the FPSO Fluminense, strategically located within Brazil's Campos Basin, with the study meticulously examining the relationship between advancements in energy efficiency and emission reductions. While translating these insights into practical applications poses challenges, the momentum generated by rigorous research, combined with policy recommendations addressing GHG emissions in the oil sector, can indeed chart a path toward a more robust, sustainable, and integrated energy future.

Coordinated operation and optimal sizing strategy of P2G—CNG trucks scheme on wind farm for participating in retail gas market

The increase in wind penetration and the stochastic nature of wind can cause some wind power to be curtailed, leading to a loss of revenue. Wind farm owners can invest in power to gas (P2G)—compressed natural gas (CNG) truck systems to utilize the curtailed wind power that would otherwise have been wasted. This paper proposes a coordinated operation and optimal sizing strategy of P2G and CNG trucks. P2G derives its power from curtailed wind power and also purchases electricity at low prices to facilitate methane (natural gas) production. The methane is directly stored in CNG trucks, which are used as temporary storage and as a means of transporting the gas, thereby reducing costs by eliminating storage tank. Firstly, a coordinated operation strategy for P2G and CNG trucks considering curtailed wind power and electricity purchased from the grid is presented. Secondly, an optimal sizing optimization model to determine the capacity of P2G and the number of CNG trucks using particle swarm optimization is presented, considering the coordinated operation strategy and operation constraints to maximize profit when the proposed system participates in the retail gas market. Finally, case studies were conducted to verify the viability of the proposed strategy using curtailed wind power data, electricity price data, and gas price data. Result show that optimal capacity of the P2G plant is 9.9 MW, and the optimal number of CNG trucks is 2. There is a 19.8% cost reduction with a payback period of 5.728 years compared to the conventional strategy with a payback period of 8.52 years. 89.74% of curtailed wind power is utilized, while only 10.26% of curtailed wind power is unutilized. Higher utilization of curtailed wind power that would otherwise have been wasted is achieved. The system earns a profit by selling the produced natural gas to a retail gas market.