FUTURE OF SYNTHETIC LIQUID HYDROCARBONS IN AUSTRALIA

1975 ◽  
Vol 15 (1) ◽  
pp. 159
Author(s):  
G. N. Keith
Keyword(s):  
Natural Gas ◽  
Liquid Hydrocarbon ◽  
Liquid Hydrocarbons ◽  
Synthetic Fuels ◽  
Conservation Of Energy ◽  
Self Sufficiency ◽  
Current Production ◽  
Low Efficiency ◽  
Capital Intensive ◽  
Synthetic Liquid Hydrocarbons

Australia's currently known reserves of fossil fuel indicate that we have 250 years supply of black coal at current production rates, 400 years of brown coal, 170 years of natural gas, but only 16 years of crude oil (20 years if natural gas liquids figures are included). While we are presently supplying about 65% of our liquid hydrocarbon requirements, this will drop to about 10% by 1990 unless significant new discoveries are made. While it may be technically possible to replace the petroleum based industrial fuels with either coal or natural gas, there is no currently developed alternative for transport fuels. If Australia wishes to pursue the objective of energy self-sufficiency, then these transport fuels produced from indigenous crude, even with the maximum of secondary processing, will have to be supplemented with synthetic fuels made from coal, natural gas or L.P.G.There is considerable activity world wide in perfecting the technology of coal liquefaction, but it seems certain that the process will be highly capital intensive and there will need to be some guaranteed minimum price for the products to protect the venture from fluctuations in the world price of natural crude oil.Converting LPG to gasoline is technically feasible but whether it is sound from an economic standpoint or whether it is justified when considering conservation of energy is a matter for debate.Natural gas can be converted to gasoline but again with a relatively low efficiency of energy conservation. However, it could be attractive where gas is available far in excess of conventional demands and can be supplied to the process at a reasonable price.

scholarly journals New Insight into the Kinetics of Deep Liquid Hydrocarbon Cracking and Its Significance

Geofluids ◽  
2017 ◽  
Vol 2017 ◽  
pp. 1-11 ◽  
Author(s):  
Wenzhi Zhao ◽  
Shuichang Zhang ◽  
Bin Zhang ◽  
Kun He ◽  
Xiaomei Wang
Keyword(s):  
Natural Gas ◽  
Liquid Hydrocarbon ◽  
Numerical Calculations ◽  
Source Rocks ◽  
Generation Model ◽  
Liquid Hydrocarbons ◽  
Gas Generation ◽  
Hydrocarbon Cracking ◽  
Kinetic Calculations ◽  
Total Oil

The deep marine natural gas accumulations in China are mainly derived from the cracking of liquid hydrocarbons with different occurrence states. Besides accumulated oil in reservoir, the dispersed liquid hydrocarbon in and outside source also is important source for cracking gas generation or relayed gas generation in deep formations. In this study, nonisothermal gold tube pyrolysis and numerical calculations as well as geochemical analysis were conducted to ascertain the expulsion efficiency of source rocks and the kinetics for oil cracking. By determination of light liquid hydrocarbons and numerical calculations, it is concluded that the residual bitumen or hydrocarbons within source rocks can occupy about 50 wt.% of total oil generated at oil generation peak. This implies that considerable amounts of natural gas can be derived from residual hydrocarbon cracking and contribute significantly to the accumulation of shale gas. Based on pyrolysis experiments and kinetic calculations, we established a model for the cracking of oil and its different components. In addition, a quantitative gas generation model was also established to address the contribution of the cracking of residual oil and expulsed oil for natural gas accumulations in deep formations. These models may provide us with guidance for gas resource evaluation and future gas exploration in deep formations.

scholarly journals An empirical analysis on the operational profile of liquefied natural gas carriers with steam propulsion plants

2020 ◽  
pp. 1-20
Author(s):  
Carlos González Gutiérrez ◽  
Santiago Suárez de la Fuente ◽  
Jean-Marc Bonello ◽  
Richard Bucknall
Keyword(s):  
Natural Gas ◽  
Greenhouse Gases ◽  
Empirical Analysis ◽  
Continuous Monitoring ◽  
Simulation Models ◽  
Energy Performance ◽  
Liquefied Natural Gas ◽  
Liquid Hydrocarbons ◽  
Operational Profile ◽  
Emission Studies

Abstract Liquefied natural gas (LNG) offers negligible NOx and SOx emissions as well as reductions in CO2 compared with other liquid hydrocarbons. LNG is a significant player in the global energy mix, with a projection of 40% increase in demand for the next two decades. It is anticipated that the expected rise in demand will cause the fleet of LNG carriers (LNGC) to expand. This work concentrates on steam-powered LNGC, which accounted for 47% of the LNGC fleet in 2018. It performs an empirical analysis of continuous monitoring data that provide high levels of accuracy and transparency. The analysis is done on data collected from 40 LNGCs for over a year to estimate the fleet's operational profile, fuel mix and energy performance. The findings of this work are relevant for bottom-up analysis and simulation models that depend on technical assumptions, but also for emission studies such as the upcoming Fourth International Maritime Organization Greenhouse Gases study.

EQUILIBRIA IN TWO-PHASE, GAS-LIQUID HYDROCARBON SYSTEMS: IV. METHANE AND HEPTANE

1938 ◽  
Vol 16b (11) ◽  
pp. 396-410 ◽  
Author(s):  
E. H. Boomer ◽  
C. A. Johnson ◽  
A. G. A. Piercey
Keyword(s):  
Natural Gas ◽  
Liquid Hydrocarbon ◽  
Two Phase ◽  
Complete Miscibility ◽  
Solubility Equilibrium

The densities and compositions of both phases in the methane-n-heptane solubility equilibrium have been determined at 25°, 55°, and 85 °C. at total pressures from 35 to 250 atm. The critical pressures of complete miscibility were found, and the properties of the system are discussed. The nitrogen-n-heptane system was investigated similarly at 100.9 atm. and temperatures from 25° to 115 °C. The system composed of Viking natural gas and impure heptanes was also investigated at 25 °C. The three systems, methane-pentane, -hexane, and -heptane are compared and discussed.

Chemical Deliquification of Unconventional Gas Wells

2014 ◽  
Author(s):  
K.. Francis-LaCroix ◽  
D.. Seetaram
Keyword(s):  
Natural Gas ◽  
Best Practice ◽  
Oil And Gas ◽  
Large Deviation ◽  
Cost Effective ◽  
Gas Production ◽  
Lessons Learned ◽  
Offshore Platforms ◽  
Gas Wells ◽  
Current Production

Abstract Trinidad and Tobago offshore platforms have been producing oil and natural gas for over a century. Current production of over 1500 Bcf of natural gas per year (Administration, 2013) is due to extensive reserves in oil and gas. More than eighteen of these wells are high-producing wells, producing in excess of 150 MMcf per day. Due to their large production rates, these wells utilize unconventionally large tubulars 5- and 7-in. Furthermore, as is inherent with producing gas, there are many challenges with the production. One major challenge occurs when wells become liquid loaded. As gas wells age, they produce more liquids, namely brine and condensate. Depending on flow conditions, the produced liquids can accumulate and induce a hydrostatic head pressure that is too high to be overcome by the flowing gas rates. Applying surfactants that generate foam can facilitate the unloading of these wells and restore gas production. Although the foaming process is very cost effective, its application to high-producing gas wells in Trinidad has always been problematic for the following reasons: Some of these producers are horizontal wells, or wells with large deviation angles.They were completed without pre-installed capillary strings.They are completed with large tubing diameters (5.75 in., 7 in.). Recognizing that the above three factors posed challenges to successful foam applications, major emphasis and research was directed toward this endeavor to realize the buried revenue, i.e., the recovery of the well's potential to produce natural gas. This research can also lead to the application of learnings from the first success to develop treatment for additional wells, which translates to a revenue boost to the client and the Trinidad economy. Successful treatments can also be used as correlations to establish an industry best practice for the treatment of similarly completed wells. This paper will highlight the successes realized from the treatment of three wells. It will also highlight the anomalies encountered during the treatment process, as well as the lessons learned from this treatment.

scholarly journals Impact of basin evolution, depositional environment, pore water evolution and diagenesis on reservoir-quality of Lower Paleozoic Haima Supergroup sandstones, Sultanate of Oman

GeoArabia ◽  
2004 ◽  
Vol 9 (4) ◽  
pp. 107-138
Author(s):  
Karl Ramseyer ◽  
Joachim E. Amthor ◽  
Christoph Spötl ◽  
Jos M.J. Terken ◽  
Albert Matter ◽  
...  
Keyword(s):  
Pore Water ◽  
Depositional Environment ◽  
Liquid Hydrocarbon ◽  
Gas Condensate ◽  
Reservoir Quality ◽  
Liquid Hydrocarbons ◽  
Eastern Flank ◽  
Oman Mountains ◽  
Hydrocarbon Charge

ABSTRACT Sandstones of the Early Paleozoic Miqrat Formation and Barik Sandstone Member (Haima Supergroup) are the most prolific gas/condensate containing units in the northern part of the Interior Oman Sedimentary Basin (IOSB). The reservoir-quality of these sandstones, buried to depths exceeding 5 km, is critically related to the depositional environment, burial-related diagenetic reactions, the timing of liquid hydrocarbon charge and the replacement of liquid hydrocarbon by gas/condensate. The depositional environment of the sandstones controls the net-sand distribution which results in poorer reservoir properties northwards parallel to the axis of the Ghaba Salt Basin. The sandy delta deposits of the Barik Sandstone Member have a complex diagenetic history, with early dolomite cementation, followed by compaction, chlorite formation, hydrocarbon charge, quartz and anhydrite precipitation and the formation of pore-filling and pore-lining bitumen. In the Miqrat Formation sandstone, which is comprised of inland sabkha deposits, similar authigenic minerals occur, but with higher abundances of dolomite and anhydrite, and less quartz cement. The deduced pore water evolution from deposition to recent, in both the Miqrat Formation and the Barik Sandstone Member, reflects an early addition of saline continental waters and hydrocarbon-burial related mineral reactions with the likely influx of lower-saline waters during the obduction of the Oman Mountains. Four structural provinces are recognized in the IOSB based on regional differences in the subsidence/uplift history: the Eastern Flank, the Ghaba and Fahud Salt Basins and the Mabrouk-Makarem High. In the Fahud Salt Basin, biodegradation of an early oil charge during Late Paleozoic uplift resulted in reservoir-quality degradation by bitumen clogging of the pore space. On the Eastern Flank and the Mabrouk-Makarem High, however, the early oil bypassed the area. In contrast, post-Carboniferous liquid hydrocarbons were trapped in the Mabrouk-Makarem High, whereas on the Eastern Flank surface water infiltration and loss of hydrocarbons or biodegradation to pore occluding bitumen occurred. In the Ghaba Salt Basin, post-Carboniferous hydrocarbon charge induced a redox reaction to form porosity/permeability preserving chlorite in the reservoirs. The liquid hydrocarbons were replaced since the obduction of the Oman Mountains by gas/condensate which prevented the deep parts (>5,000 m) of the Ghaba Salt Basin from pore occluding pyrobitumen and thus deterioration of the reservoir quality.

scholarly journals Methane Conversion to Liquid Hydrocarbons over W-ZSM-5 and W Loaded Cu/HZSM-5

2006 ◽  
Vol 6 (2) ◽  
pp. 58 ◽  
Author(s):  
Didi Dwi Anggoro ◽  
Nor Aishah Saidina Amin
Keyword(s):  
Methane Conversion ◽  
Principal Component ◽  
Acid Catalyst ◽  
Liquid Hydrocarbon ◽  
Direct Conversion ◽  
Catalytic Performance ◽  
Liquid Hydrocarbons ◽  
Oxidation Of Methane ◽  
Highly Active ◽  
To Come

The direct conversion of natural gas-in particular, its principal component, methane into useful products has been the subject of intense study over the past decades. However, commercialization of this process is still not viable because its conversion and selectivity potentials remain low. Thus, the search continues to come up with a suitable catalyst that allows methane to be oxidized in a controlled environment to yield a high percentage of higher hydrocarbons. ZSM-5 zeolite has been known to be a suitable catalyst for olefin oligomerization. Previous studies, however, have indicated that ZSM-5 zeolites are not resistant to high temperatures. In this work, ZSM-5 was modified with copper and tungsten to develop a highly active and heat-resistant bifunctional oxidative acid catalyst. The oxidation of methane was performed over W/Cu/HZSM-5 catalyst and the results compared with the catalytic performance of W/ HZSM-5 and HZSM-5 catalysts. The metal oxide on the catalyst surface led to enhanced conversion of Hz and CO to CZ-3 ydrocarbons and, hence, reduced HzO selectivity. Inh the liquid hydrocarbons, Cs+ selectivity increased with increasing amount of surface Bn1Jnstedacid sites. The experimental results indicated higher methane conversion and liquid hydrocarbon selectivity than that of W/3.0Cu/HZSM-5 catalyst.

Microwave Discharge in Liquid Hydrocarbons: Study of a Liquid Hydrocarbon after Exciting the Discharge

2018 ◽  
Vol 52 (4) ◽  
pp. 324-329 ◽  
Author(s):  
Yu. A. Lebedev ◽  
K. A. Averin ◽  
R. S. Borisov ◽  
A. R. Garifullin ◽  
E. S. Bobkova ◽  
...  
Keyword(s):  
Microwave Discharge ◽  
Liquid Hydrocarbon ◽  
Liquid Hydrocarbons ◽  
Microwave Discharge In Liquid

Enhancing Liquid Hydrocarbon Pipeline Leak Detection Using Instrumented Aerial Surveillance

2014 ◽  
Author(s):  
Adrian Banica ◽  
Doug Waslen ◽  
Boyd T. Tolton
Keyword(s):  
Natural Gas ◽  
New Technology ◽  
Field Tests ◽  
Ground Level ◽  
Leak Detection ◽  
Liquid Hydrocarbon ◽  
Aerial Surveillance ◽  
Natural Gas Pipelines ◽  
Test Methodology ◽  
Detection Technology

Suncor Energy Inc. contacted Synodon as part of an effort to enhance pipeline leak detection. Ideally, Suncor needed a technology that could detect natural gas as well as liquid hydrocarbon releases. Synodon’s new technology is an aircraft mounted gas remote sensing instrument that has been used for detecting leaks from natural gas pipelines for over four (4) years and was expanding their capability to include liquid hydrocarbons. This paper will describe the steps that Suncor and Synodon have taken over the last two years to develop and validate this detection technology. Synodon completed a number of studies including laboratory and field tests that demonstrated the ability of Synodon’s technology to remotely detect ground-level plumes of vapours released from a liquid hydrocarbon pipeline. Synodon conducted full atmospheric analytic modeling followed by laboratory measurements to determine the level of sensitivity of its instrument measurement to both methane and various liquid hydrocarbon vapors including gasoline, condensates and synthetic crude oil. Suncor participated in the development of test methodology and field execution in order to witness and validate the results. Based on this work, Suncor has determined an optimum inspection frequency based on theoretical spill size, SCADA leak detection thresholds and conventional aerial patrol constraints. The results and conclusions of this work will be presented.

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