Investigation of high temperature, high pressure, scaling and dissolution effects for Carbon Capture and Storage at a high CO2 content carbonate gas field offshore Malaysia

Oxy-fuel combustion is an effective technology for carbon capture and storage (CCS). Oxy-combustion for coal-fired power stations is a promising technology by which to diminish CO2 emissions. Unfortunately, little attention has been paid to the oxy-combustion characteristics affected by the combustion atmosphere. This paper is aimed at investigating the oxy-fuel combustion characteristics of Australian coal in a 0.3 MWth furnace. In particular, the influences of various oxygen flow rates and recirculated flue gas (RFG) on heating performance and pollutant emissions are examined in O2/RFG environments. The results show that with increases in the secondary RFG flow rate, the temperatures in the radiative and convective sections decrease and increase, respectively. At a lower oxygen flow rate, burning Australian coal emits lower residual oxygen and NO concentrations. In the flue gas, a high CO2 concentration of up to 94.8% can be achieved. Compared to air combustion, NO emissions are dramatically reduced up to 74% for Australian coal under oxy-combustion. Note that the high CO2 concentrations in the flue gas under oxy-coal combustions suggest great potential for reducing CO2 emissions through carbon capture and storage.

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Modelling ruptures of buried high-pressure dense-phase CO 2 pipelines in carbon capture and storage applications – Part II. A full-scale rupture

International Journal of Greenhouse Gas Control ◽

10.1016/j.ijggc.2015.08.020 ◽

2015 ◽

Vol 42 ◽

pp. 712-728 ◽

Cited By ~ 5

Author(s):

Christopher J. Wareing ◽

Michael Fairweather ◽

Samuel A.E.G. Falle ◽

Robert M. Woolley

Keyword(s):

High Pressure ◽

Carbon Capture ◽

Carbon Capture And Storage ◽

Full Scale ◽

Dense Phase ◽

And Storage

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Microfluidic mass transfer of CO2 at elevated pressures: implications for carbon storage in deep saline aquifers

Lab on a Chip ◽

10.1039/d1lc00106j ◽

2021 ◽

Vol 21 (20) ◽

pp. 3942-3951

Author(s):

Tsai-Hsing Martin Ho ◽

Junyi Yang ◽

Peichun Amy Tsai

Keyword(s):

Mass Transfer ◽

High Pressure ◽

Carbon Storage ◽

Carbon Capture ◽

Carbon Capture And Storage ◽

Saline Aquifers ◽

Elevated Pressures ◽

Reservoir Conditions ◽

Deep Saline Aquifers ◽

And Storage

Carbon capture and storage in deep saline aquifers is a promising technology to mitigate anthropologically emitted CO2. Our high-pressure microfluidics can help assess the relevant time-scale and CO2 mass transfer in different reservoir conditions.

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Materials for use in calcium looping technology for CCS – corrosion processes in high-temperature CO2

Koroze a ochrana materialu ◽

10.1515/kom-2017-0017 ◽

2017 ◽

Vol 61 (4) ◽

pp. 143-148 ◽

Cited By ~ 1

Author(s):

J. Poláčková ◽

J. Petrů ◽

M. Janák ◽

J. Berka ◽

A. Krausová

Keyword(s):

High Temperature ◽

Carbon Capture ◽

Carbon Capture And Storage ◽

Special Device ◽

Temperature Oxidation ◽

Aisi 304 ◽

Gaseous Environment ◽

Calcium Looping ◽

Ccs Technologies ◽

And Storage

Abstract Carbon Capture and Storage (CCS) technologies are a perspective solution to reduce the amount of CO2 emissions. One of promising methods is Ca-looping, which is based on carbonation and calcination reactions. During both of these processes, especially calcination, high temperatures (650-950°C) are required. This means high demands on the corrosion resistance of equipment materials. Therefore, we carried out a study to suggest materials with suitable properties for calciner construction, which have to be particularly heat resistant: stainless steels (AISI 304, AISI 316L and AISI 316Ti) and nickel alloys (Inconel 713, Inconel 738, Incoloy 800H). A special device simulating calciner environment was built for this purpose. Chosen materials were tested in temperature 900°C, atmospheric pressure and gaseous environment with composition that can be possible in a calciner. The surfaces of materials were evaluated to determine composition and properties of formed oxide layers. High temperature oxidation was observed on all tested materials and oxide exfoliation occurred on some of tested materials (304, 316L).

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Demonstrating geosequestration in Australia: the CO2CRC Otway Project

The APPEA Journal ◽

10.1071/aj08074 ◽

2009 ◽

Vol 49 (2) ◽

pp. 601

Author(s):

Sandeep Sharma ◽

Peter Cook ◽

Charles Jenkins

Keyword(s):

Carbon Capture ◽

Carbon Capture And Storage ◽

Regulatory Regime ◽

Atmospheric Conditions ◽

Gas Field ◽

Near Surface ◽

Long Term Storage ◽

And Storage ◽

Baseline State

The CO2CRC has a demonstration storage project underway in the Otway Basin of southwest Victoria. The aim of the project is to demonstrate that carbon capture and storage (CCS) can be performed under Australian conditions. The project involves extracting CO2 rich gas from an existing field and injecting it into a nearby depleted natural gas field for long-term storage. Injection commenced in April 2008, and approximately 100,000 tonnes of CO2 are planned to be injected through a new injection well drilled in 2007. A multi-disciplinary monitoring and verification (M&V) program has been in place from late 2005 and a baseline state of the subsurface, near surface and atmospheric conditions has been comprehensively defined prior to the commencement of injection. The project has also been instrumental in unravelling the legislative overlaps between jurisdictions and has helped shape the regulatory regime being developed by the Victorian Government. At the present time over 35,000 tonnes of CO2 has been injected and a variety of monitoring data collected. This paper aims to provide an update on the holistic project and how some of the findings may lead to expediting commercial uptake of CCS in Australia.

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Feasibility Study of Offshore Hybrid Technology for High CO2 Gas Field Monetization

10.2523/iptc-21220-ms ◽

2021 ◽

Author(s):

M. Faizan Ahmad Zuhdi ◽

F. Hadana Rahman ◽

Hamid Shahjavan ◽

M. Azlan Mas’od ◽

R. Suhaib Salihuddin ◽

...

Keyword(s):

Carbon Capture ◽

Oil And Gas ◽

Carbon Capture And Storage ◽

Oil And Gas Industry ◽

Liquid Form ◽

Gas Field ◽

Co2 Gas ◽

High Co2 ◽

Field Development ◽

Gas Removal

Abstract The CO2 capture technology is well understood in the oil and gas industry. However, to unlock the Hydrocarbon from an ultra-high CO2 offshore field (more than 70% mol), special attention is needed to capture CO2 for a field development to be economically attractive. Therefore, the current technology inventory needs to be studied to achieve project goals and at the same time achieving Carbon Capture and Storage (CCS) requirements. A hybrid of multiple carbon capture technology will help to improve the hydrocarbon (HC) loss, reduce both operational and capital cost and minimize overall auto consumption. The hybrid of cryogenic distillation (CryoD), membrane and supersonic gas separation (SGS) was studied to explore its feasibility. To enable ease of CO2 transport and handling, CO2 is preferred to be in liquid form. In order to achieve this, CryoD technology is the preferred solution for bulk removal. CryoD is also able to cater to the feed gas fluctuation and becomes a robust candidate for high variance feedstock. However, being dependant on sub zero working temperatures, the system will require larger equipment footprint and tonnage. The focus of the study is to evaluate the sensitivity impact of an operating condition on the Hybrid configuration of CryoD + membrane (CM) and CryoD + SGS (CS. Areas of focus will be equipment tonnage and footprint, power consumption and eventually cost (CAPEX & OPEX). The monetization of ultra-high CO2 gas field is then made feasible by using hybrid Acid Gas Removal Unit (AGRU) to meet sales gas specification. The CryoD + membrane technology is the preferred solution for offshore system.

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Modelling ruptures of buried high pressure dense phase CO 2 pipelines in carbon capture and storage applications—Part I. Validation

International Journal of Greenhouse Gas Control ◽

10.1016/j.ijggc.2015.01.020 ◽

2015 ◽

Vol 42 ◽

pp. 701-711 ◽

Cited By ~ 8

Author(s):

Christopher J. Wareing ◽

Michael Fairweather ◽

Samuel A.E.G. Falle ◽

Robert M. Woolley

Keyword(s):

High Pressure ◽

Carbon Capture ◽

Carbon Capture And Storage ◽

Dense Phase ◽

And Storage

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Techno-Economic Analysis of CO2 Capture Technologies in Offshore Natural Gas Field: Implications to Carbon Capture and Storage in Malaysia

Processes ◽

10.3390/pr8030350 ◽

2020 ◽

Vol 8 (3) ◽

pp. 350

Author(s):

Norhasyima Rahmad Sukor ◽

Abd Halim Shamsuddin ◽

Teuku Meurah Indra Mahlia ◽

Md Faudzi Mat Isa

Keyword(s):

Natural Gas ◽

Economic Analysis ◽

Co2 Capture ◽

Carbon Capture ◽

Net Present Value ◽

Market Price ◽

Carbon Capture And Storage ◽

Gas Field ◽

Physical Absorption ◽

And Storage

Growing concern on global warming directly related to CO2 emissions is steering the implementation of carbon capture and storage (CCS). With Malaysia having an estimated 37 Tscfd (Trillion standard cubic feet) of natural gas remains undeveloped in CO2 containing natural gas fields, there is a need to assess the viability of CCS implementation. This study performs a techno-economic analysis for CCS at an offshore natural gas field in Malaysia. The framework includes a gas field model, revenue model, and cost model. A techno-economic spreadsheet consisting of Net Present Value (NPV), Payback Period (PBP), and Internal Rate of Return (IRR) is developed over the gas field’s production life of 15 years for four distinctive CO2 capture technologies, which are membrane, chemical absorption, physical absorption, and cryogenics. Results predict that physical absorption solvent (Selexol) as CO2 capture technology is most feasible with IRR of 15% and PBP of 7.94 years. The output from the techno-economic model and associated risks of the CCS project are quantified by employing sensitivity analysis (SA), which indicated that the project NPV is exceptionally sensitive to gas price. On this basis, the economic performance of the project is reliant on revenues from gas sales, which is dictated by gas market price uncertainties.

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