scholarly journals Helium in the Australian liquefied natural gas economy

2018 ◽  
Vol 58 (1) ◽  
pp. 209 ◽  
Author(s):  
Christopher J. Boreham ◽  
Dianne S. Edwards ◽  
Robert J. Poreda ◽  
Thomas H. Darrah ◽  
Ron Zhu ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Economic Value ◽  
Industrial Process ◽  
Sedimentary Basins ◽  
Liquefied Natural Gas ◽  
Hydrocarbon Gases ◽  
Apparent Loss ◽  
Argon Isotopes ◽  
Northern Carnarvon Basin

Australia is about to become the premier global exporter of liquefied natural gas (LNG), bringing increased opportunities for helium extraction. Processing of natural gas to LNG necessitates the exclusion and disposal of non-hydrocarbon components, principally carbon dioxide and nitrogen. Minor to trace hydrogen, helium and higher noble gases in the LNG feed-in gas become concentrated with nitrogen in the non-condensable LNG tail gas. Helium is commercially extracted worldwide from this LNG tail gas. Australia has one helium plant in Darwin where gas (containing 0.1% He) from the Bayu-Undan accumulation in the Bonaparte Basin is processed for LNG and the tail gas, enriched in helium (3%), is the feedstock for helium extraction. With current and proposed LNG facilities across Australia, it is timely to determine whether the development of other accumulations offers similar potential. Geoscience Australia has obtained helium contents in ~800 Australian natural gases covering all hydrocarbon-producing sedimentary basins. Additionally, the origin of helium has been investigated using the integration of helium, neon and argon isotopes, as well as the stable carbon (13C/12C) isotopes of carbon dioxide and hydrocarbon gases and isotopes (15N/14N) of nitrogen. With no apparent loss of helium and nitrogen throughout the LNG industrial process, together with the estimated remaining resources of gas accumulations, a helium volumetric seriatim results in the Greater Sunrise (Bonaparte Basin) > Ichthys (Browse Basin) > Goodwyn–North Rankin (Northern Carnarvon Basin) accumulations having considerably more untapped economic value in helium extraction than the commercial Bayu-Undan LNG development.

Study on solidification of carbon dioxide using cold energy of liquefied natural gas

2000 ◽  
Vol 29 (4) ◽  
pp. 249-268 ◽  
Author(s):  
Yoshiyuki Takeuchi ◽  
Shogo Hironaka ◽  
Yutaka Shimada ◽  
Kenji Tokumasa
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Liquefied Natural Gas ◽  
Cold Energy

scholarly journals Effects of the rate of natural gas production on the recovery factor during carbon dioxide injection at the initial gas-water contact

2021 ◽  
Vol 1 (3(57)) ◽  
pp. 6-11
Author(s):  
Serhii Matkivskyi
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Gas Production ◽  
Gas Condensate ◽  
Recovery Factor ◽  
Formation Water ◽  
Hydrocarbon Gases ◽  
Water Contact ◽  
Natural Gas Production ◽  
Gas Recovery

The object of research is gas condensate reservoirs, which is being developed under the conditions of the manifestation of the water drive of development and the negative effect of formation water on the process of natural gas production. The results of the performed theoretical and experimental studies show that a promising direction for increasing hydrocarbon recovery from fields at the final stage of development is the displacement of natural gas to producing wells by injection non-hydrocarbon gases into productive reservoirs. The final gas recovery factor according to the results of laboratory studies in the case of injection of non-hydrocarbon gases into productive reservoirs depends on the type of displacing agent and the level heterogeneity of reservoir. With the purpose update the existing technologies for the development of fields in conditions of the showing of water drive, the technology of injection carbon dioxide into productive reservoirs at the boundary of the gas-water contact was studied using a digital three-dimensional model of a gas condensate deposit. The study was carried out for various values of the rate of natural gas production. The production well rate for calculations is taken at the level of 30, 40, 50, 60, 70, 80 thousand m3/day. Based on the data obtained, it has been established that an increase in the rate of natural gas production has a positive effect on the development of a productive reservoir and leads to an increase in the gas recovery factor. Based on the results of statistical processing of the calculated data, the optimal value of the rate of natural gas production was determined when carbon dioxide is injected into the productive reservoir at the boundary of the gas-water contact is 55.93 thousand m3/day. The final gas recovery factor for the optimal natural gas production rate is 64.99 %. The results of the studies carried out indicate the technological efficiency of injecting carbon dioxide into productive reservoirs at the boundary of the gas-water contact in order to slow down the movement of formation water into productive reservoirs and increase the final gas recovery factor.

scholarly journals USES OF A HLADOPOTENTSIAL OF THE LIQUEFIED NATURAL GAS FOR DECREASE IN EMISSIONS OF CARBON DIOXIDE HEAT POWER INSTALLATIONS

2016 ◽  
Vol 3 (37) ◽  
pp. 143-155 ◽  
Author(s):  
Oleg Konstantinovich Bezyukov ◽  
◽  
Valentin Leonidovich Erofeyev ◽  
Alexander Sergeyevich Pryakhin ◽  
◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Liquefied Natural Gas ◽  
Heat Power ◽  
Power Installations

scholarly journals Study on Solidification of Carbon Dioxide using Cold Energy of Liquefied Natural Gas.

1997 ◽  
Vol 63 (606) ◽  
pp. 654-659 ◽  
Author(s):  
Yoshiyuki TAKEUCHI ◽  
Haruyoshi FUJITA ◽  
Yutaka SHIMADA ◽  
Kenji TOKUMASA
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Liquefied Natural Gas ◽  
Cold Energy

Low-Permeable Reservoirs as High Potential Assets for EGR

2021 ◽  
Author(s):  
Nazarii Hedzyk ◽  
Oleksandr Kondrat
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Adsorption Capacity ◽  
Injection Pressure ◽  
Reservoir Pressure ◽  
Hydrocarbon Gases ◽  
Gas Recovery ◽  
Adsorbed Gas ◽  
Reservoir Permeability ◽  
Gas Fields

Abstract Natural gas fields that are being developed in Ukraine, mainly relate to the high and medium permeability reservoirs, most of which are at the final stage of field life. In this situation one of the main sources of additional gas production is unconventional fields. This paper presents the analysis of challenges concerning development of low-permeable reservoirs and experimental results of conducted research, which provide the opportunity to establish technologies for enhance gas recovery factor. For this purpose, a series of laboratory experiments were carried out on the sand packed models of gas field with different permeability (from 9.7 to 93 mD) using natural gas. The pressure in the experiments varied from 1 to 10 MPa, temperature – 22-60 °C. According to the features of low-permeable gas fields development the research of displacement desorption with carbon dioxide and inert gas stripping by nitrogen was conducted. These studies also revealed the influence of pressure, temperature, reservoir permeability and non-hydrocarbon gases injection rate on the course of adsorption-desorption processes and their impact on the gas recovery factor. According to the experimental results of relative adsorption capacity determination it can be concluded that the carbon dioxide usage as the displacement agent can lead to producing adsorbed gas by more than 30% than by using nitrogen. To remove the adsorbed gas just reservoir pressure lowering is not enough due to the nature of adsorption isotherms. Particularly at pressure decreasing by 8-10 times compared to initial reservoir pressure only about 30-40% of the total amount of initially adsorbed gas is desorbed. And at considerable reservoir pressure reduction the further deposit development is not economically profitable. According to the results it was found that in the case of nitrogen usage the most effective method is full voidage replacement at injection pressure of 0.8 of the initial reservoir pressure, and in case of carbon dioxide usage - full voidage replacement method at pressure of 0.6 of the initial reservoir pressure. Taking into account availability of N2 and CO2, N2injection is recommended for further implementation. The influence of displacement agent injection pressure on gas recovery was experimentally proved. The physical sense of the processes taking place during natural gas desorption stimulation by non-hydrocarbon gases was justified. The effect of temperature, pressure and reservoir permeability on methane adsorption capacity were determined. The mathematical model for estimating adsorbed gas amount depending on the reservoir parameters was developed. Obtained results were summarized and recommendations for practical implementation of elaborated technological solutions were suggested.

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