scholarly journals Petroleum and Natural Gas in New York State

1887 ◽  
Vol 16 (01) ◽  
pp. 906-959
Author(s):  
Charles A. Ashburner
Energies ◽  
2021 ◽  
Vol 14 (13) ◽  
pp. 3834
Author(s):  
Stephanie Taboada ◽  
Lori Clark ◽  
Jake Lindberg ◽  
David J Tonjes ◽  
Devinder Mahajan

Public attention to climate change challenges our locked-in fossil fuel-dependent energy sector. Natural gas is replacing other fossil fuels in our energy mix. One way to reduce the greenhouse gas (GHG) impact of fossil natural gas is to replace it with renewable natural gas (RNG). The benefits of utilizing RNG are that it has no climate change impact when combusted and utilized in the same applications as fossil natural gas. RNG can be injected into the gas grid, used as a transportation fuel, or used for heating and electricity generation. Less common applications include utilizing RNG to produce chemicals, such as methanol, dimethyl ether, and ammonia. The GHG impact should be quantified before committing to RNG. This study quantifies the potential production of biogas (i.e., the precursor to RNG) and RNG from agricultural and waste sources in New York State (NYS). It is unique because it is the first study to provide this analysis. The results showed that only about 10% of the state’s resources are used to generate biogas, of which a small fraction is processed to RNG on the only two operational RNG facilities in the state. The impact of incorporating a second renewable substitute for fossil natural gas, “green” hydrogen, is also analyzed. It revealed that injecting RNG and “green” hydrogen gas into the pipeline system can reduce up to 20% of the state’s carbon emissions resulting from fossil natural gas usage, which is a significant GHG reduction. Policy analysis for NYS shows that several state and federal policies support RNG production. However, the value of RNG can be increased 10-fold by applying a similar incentive policy to California’s Low Carbon Fuel Standard (LCFS).


Author(s):  
Masroor Hasan ◽  
Charles Neill

A conceptual framework and modeling approach are presented for assessing pipeline adequacy to meet existing and future demands for natural gas in electricity generation after gas demands for traditional end users have been met. Transportation logistics and economics issues are identified that natural gas (and electric) suppliers face in trying to meet traditional and electricity generation gas demands. An integrated electric and gas modeling approach is used for this purpose. The approach uses separate models for electric and gas systems. Consistent equilibrium solutions are obtained by iterating between the two models. The economic decisions and logistical issues facing the gas and electric industries are quite stark. The incentives of the two industries need to be realigned to achieve greater electric efficiency, reliable generation, and better air quality at a reasonable cost. As a detailed case study of the modeling approach, results are presented from an analysis of the ability of the natural gas delivery system to meet future electricity generation requirements in New York State. The analysis integrates the modeling of the gas demands of New York State electric generators with the modeling of available gas supply and delivery capacity to the state. Although the analysis indicates that the gas and electric systems in New York can reliably meet their future loads under a range of electricity generation and gas pipeline expansion scenarios, oil use by electric generators remains a key substitute for gas during times of peak gas demands (e.g., cold winter days).


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