scholarly journals Low carbon renewable natural gas production from coalbeds and implications for carbon capture and storage

2017 ◽  
Vol 8 (1) ◽  
Author(s):  
Zaixing Huang ◽  
Christine Sednek ◽  
Michael A. Urynowicz ◽  
Hongguang Guo ◽  
Qiurong Wang ◽  
...  
Keyword(s):  
Natural Gas ◽  
Carbon Capture ◽  
Carbon Capture And Storage ◽  
Gas Production ◽  
Low Carbon ◽  
Natural Gas Production ◽  
Renewable Natural Gas ◽  
And Storage

Reducing cost of CCUS associated with natural gas production by improving monitoring technologies

2020 ◽  
Vol 60 (1) ◽  
pp. 1
Author(s):  
Mohammad Bagheri ◽  
Scott Ryan ◽  
David Byers ◽  
Matthias Raab
Keyword(s):  
Natural Gas ◽  
Carbon Capture ◽  
Cost Model ◽  
Gas Production ◽  
Department Of Energy ◽  
Monitoring Cost ◽  
Natural Gas Production ◽  
Monitoring Technologies ◽  
The Cost ◽  
And Storage

This paper examines how we can reduce the cost of carbon capture, utilisation and storage (CCUS). The CO2CRC research and demonstration projects during the last 15 years and the upcoming Otway Stage 3 Project aim to reduce the cost of CCUS. The CO2CRC Otway Stage 3 Project will develop subsurface monitoring technologies which can significantly reduce the cost of the surveillance. The CCUS associated with natural gas processing carries the lowest cost compared to other industries because production of concentrated CO2 streams is already part of the gas production process. Transport and storage remain the highest cost components of CCUS for natural gas production. Ranges of storage and transportation costs based on different publicly available data are ~US$2–40/tCO2 and ~US$2–10/tCO2 respectively. Further, the US Department of Energy cost model identifies 40–60% of storage cost as relating to recurring monitoring. This is highly dependent on project specifications, regulatory requirements and geographical considerations. The application of Otway Stage 3 subsurface technologies show preliminary long-term monitoring cost savings estimates for a large Australian project of up to 75% compared to conventional surface seismic-based methodologies. Depending on total injection mass, this would equate to an estimated cost saving of up to AU$12/tonne of CO2 injected for such a project. Reduced monitoring costs could be applied to all CCUS projects but would be of most interest to gas projects because storage is likely to be the biggest contributor to overall CCUS cost.

scholarly journals Life Cycle Assessment of Direct Air Carbon Capture and Storage with Low-Carbon Energy Sources

2021 ◽  
Author(s):  
Tom Terlouw ◽  
Karin Treyer ◽  
christian bauer ◽  
Marco Mazzotti
Keyword(s):  
Life Cycle Assessment ◽  
Life Cycle ◽  
Carbon Capture ◽  
Large Scale ◽  
Carbon Capture And Storage ◽  
Low Carbon ◽  
Solid Sorbent ◽  
Low Carbon Energy ◽  
And Storage ◽  
Limited Scope

Prospective energy scenarios usually rely on Carbon Dioxide Removal (CDR) technologies to achieve the climate goals of the Paris Agreement. CDR technologies aim at removing CO2 from the atmosphere in a permanent way. However, the implementation of CDR technologies typically comes along with unintended environmental side-effects such as land transformation or water consumption. These need to be quantified before large-scale implementation of any CDR option by means of Life Cycle Assessment (LCA). Direct Air Carbon Capture and Storage (DACCS) is considered to be among the CDR technologies closest to large-scale implementation, since first pilot and demonstration units have been installed and interactions with the environment are less complex than for biomass related CDR options. However, only very few LCA studies - with limited scope - have been conducted so far to determine the overall life-cycle environmental performance of DACCS. We provide a comprehensive LCA of different low temperature DACCS configurations - pertaining to solid sorbent-based technology - including a global and prospective analysis.

Distribution and estimates of Australia's identified energy commodity resources

2021 ◽  
Vol 61 (2) ◽  
pp. 325
Author(s):  
Barry E. Bradshaw ◽  
Meredith L. Orr ◽  
Tom Bernecker
Keyword(s):  
Natural Gas ◽  
Carbon Capture ◽  
Coal Gasification ◽  
Carbon Capture And Storage ◽  
Energy Resource ◽  
Gas Production ◽  
Renewable Energy Resources ◽  
North West ◽  
The North ◽  
Energy Provider

Australia is endowed with abundant, high-quality energy commodity resources, which provide reliable energy for domestic use and underpin our status as a major global energy provider. Australia has the world’s largest economic uranium resources, the third largest coal resources and substantial conventional and unconventional natural gas resources. Since 2015, Australia’s gas production has grown rapidly. This growth has been driven by a series of new liquefied natural gas (LNG) projects on the North West Shelf, together with established coal seam gas projects in Queensland. Results from Geoscience Australia’s 2021 edition of Australia’s energy commodity resources assessment highlight Australia’s endowment with abundant and widely distributed energy commodity resources. Knowledge of Australia’s existing and untapped energy resource potential provides industry and policy makers with a trusted source of data to compare and understand the value of these key energy commodities to domestic and world markets. A key component of Australia’s low emissions future will be the development of a hydrogen industry, with hydrogen being produced either through electrolysis of water using renewable energy resources (‘green’ hydrogen), or manufactured from natural gas or coal gasification, with carbon capture and storage of the co-produced carbon dioxide (‘blue’ hydrogen). Australia’s endowment with abundant natural gas resources will be a key enabler for our transition to a low emissions future through providing economically competitive feedstock for ‘blue’ hydrogen.

Assessment of Future Sustainable Power Technologies with Carbon Capture and Storage

2008 ◽  
Vol 9 (1) ◽  
Author(s):  
Ioannis Hadjipaschalis ◽  
Costas Christou ◽  
Andreas Poullikkas
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Carbon Capture ◽  
Unit Cost ◽  
Carbon Capture And Storage ◽  
Combined Cycle ◽  
Major Power ◽  
Natural Gas Combined Cycle ◽  
And Storage ◽  
Avoidance Cost

In this work, a technical, economic and environmental analysis concerning the use of three major power generation plant types including pulverized coal, integrated gasification combined cycle (IGCC) and natural gas combined cycle, with or without carbon dioxide (CO2) capture and storage (CCS) integration, is carried out. For the analysis, the IPP optimization software is used in which the electricity unit cost and the CO2 avoidance cost from the various candidate power generation technologies is calculated. The analysis indicates that the electricity unit cost of IGCC technology with CCS integration is the least cost option with the lowest CO2 avoidance cost of all candidate technologies with CCS integration. Further investigation concerning the effect of the loan interest rate on the economic performance of the candidate plants revealed that up to a value of loan interest of approximately 5.7%, the IGCC plant with CCS retains the lowest electricity unit cost. Above this level, the natural gas combined cycle plant with post-combustion CCS becomes more economically attractive.

scholarly journals Review of Energy Efficiency of the Gas Production Technologies From Gas Hydrate-Bearing Sediments

2021 ◽  
Vol 9 ◽  
Author(s):  
Koji Yamamoto ◽  
Sadao Nagakubo
Keyword(s):  
Natural Gas ◽  
Energy Conversion ◽  
Energy Demand ◽  
Carbon Capture ◽  
Carbon Dioxide Emission ◽  
Carbon Capture And Storage ◽  
Gas Production ◽  
Energy Return On Investment ◽  
Production Technologies ◽  
Project Life

Even in the carbon-neutral age, natural gas will be valuable as environment-friendly fuel that can fulfill the gap between the energy demand and supply from the renewable energies. Marine gas hydrates are a potential natural gas source, but gas production from deposits requires additional heat input owing to the endothermic nature of their dissociation. The amount of fuel needed to produce a unit of energy is important to evaluate energy from economic and environmental perspectives. Using the depressurization method, the value of the energy return on investment or invested (EROI) can be increased to more than 100 for the dissociation process and to approximately 10 or more for the project life cycle that is comparable to liquefied natural gas (LNG) import. Gas transportation through an offshore pipeline from the offshore production facility can give higher EROI than floating LNG; however, the latter has an advantage of market accessibility. If the energy conversion from methane to hydrogen or ammonia at the offshore facility and carbon capture and storage (CCS) can be done at the production site, problems of carbon dioxide emission and market accessibility can be solved, and energy consumption for energy conversion and CCS should be counted to estimate the value of the hydrate resources.

Sign in / Sign up

Export Citation Format

Share Document