Comparison of isotopic compositions of hydrocarbon gas in shallow groundwater and a deep oil and natural gas reservoir in southeastern New Brunswick, Canada

2020 ◽  
Vol 56 ◽  
pp. 207-229
Author(s):  
Diana B. Loomer ◽  
Kerry T.B. MacQuarrie ◽  
Tom A. Al
Keyword(s):  
Natural Gas ◽  
New Brunswick ◽  
Shallow Groundwater ◽  
Isotopic Signature ◽  
Oil Field ◽  
Hydrocarbon Gases ◽  
Gas Field ◽  
Isotopic Analyses ◽  
Oil And Natural Gas ◽  
Hydrocarbon Gas

Isotopic analyses of natural gas from the Stoney Creek oil field in New Brunswick indicate carbon (δ13C) and hydrogen (δ2H) values in methane (C1) of -42.4 ± 0.7‰ VPDB and -220.9 ± 3.2‰ VSMOW, respectively. Isotopic data and a gas molecular ratio of 12 ± 1 indicate a wet thermogenic gas formed with oil near the onset of the oil-gas transition zone. The isotopic profiles of the C1–C5 hydrocarbon gases are consistent with kinetic isotope effect models. The Albert Formation of the Horton Group hosts the Stoney Creek oil field (SCOF) and the McCully gas field (MCGF) the only other gas-producing field in the province. Both are thermogenic in origin; however, the SCOF gas has a lower thermal maturity than the MCGS. Hydrocarbon gas composition in shallow aquifers across southeastern New Brunswick was also evaluated. Gas source interpretations based on δ13C and δ2H values are uncertain; oxidation and biogenic overprinting are common and complicate interpretation. The effect of oxidation on δ13C and δ2H values was apparent when C1 concentrations were ≤1 mg/L. In some samples with C1 concentrations >5 mg/L, isotopic discrimination methods point to a biogenic origin. However, the molecular ratios <75 and the presence of >C3 fractions, indicate a thermogenic origin. This suggests a thermogenic isotopic signature has been overprinted by biological activity.

scholarly journals Hydrocarbon gas accumulations in Greece and their origin

2001 ◽  
Vol 34 (3) ◽  
pp. 1265 ◽  
Author(s):  
N. RIGAKIS ◽  
N. ROUSSOS ◽  
E. KAMBERIS ◽  
P. PROEDROU
Keyword(s):  
Sedimentary Basins ◽  
Oil Field ◽  
Hydrocarbon Gases ◽  
Gas Field ◽  
Water Wells ◽  
Clastic Sediments ◽  
Hydrocarbon Gas ◽  
Gas Fields ◽  
Of Greece ◽  
Gas Seeps

In the sedimentary basins of Greece are found a lot of hydrocarbon gases that can be distinguished in four categories. Surface gas seeps, gas shows in shallow water-wells, gases in exploration wells and hydrocarbon gas fields. The main gas shows are mainly located inside recent clastic sediments. Hydrocarbon amount varies between a few ppm and several units percent. Gases are classified in the biogenic gases of Katakolo onshore gas-field, the most surface gas seeps and the gases at shallow depths of exploration wells. Catagenetic are the gases of Katakolo oil field, the Epanomi and South Kavala gas fields, and a lot of gases found in great depths of exploration wells. Metagenetic gases have been identified in Delta Evros and West Thermaikos.

THE GIPPSLAND OIL AND GAS FIELDS—FOUR YEARS OF PRODUCTION AND UTILISATION

1973 ◽  
Vol 13 (1) ◽  
pp. 166
Author(s):  
M. A. Stratton
Keyword(s):  
Natural Gas ◽  
Social Life ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Petroleum Products ◽  
The State ◽  
Oil Field ◽  
Oil Fields ◽  
Gas Field ◽  
Paper Mills

The discovery by the partnership of Esso Exploration and Production Australia Inc. and Hematite Petroleum Pty Ltd during the past eight years of the natural gas and crude oil fields off the east Victorian coast has often been compared to that of gold in the State in the 1850's in its impact .on the economic, industrial and social life of the community.To date the amount spent in the State on the discovery and overall development of these fields is approximately $600 million. The value of oil and gas recovered over the period of nearly four years since production commenced in 1969 and distributed and utilised by various means to 31 December 1972, amounts to about $500 million. In addition the value of refined products from Victoria's three refineries and items produced by industrial processes through the use of natural gas and petroleum products as fuels, amount to many more millions of dollars. The total impact on Victoria in one form or another could, if measured in monetary value, he equivalent to about $1200 million-all in the course of about eight years.Other States have also benefited. The building of tankers, barges, tugs and work boats and the modification of refineries in New South Wales and Queensland, have probably cost in the region of $200 million whilst indirectly the success of the Gippsland oil and gas discoveries has spurred other explorers to step up the search in many areas and, as far as natural gas is concerned, with considerable success.The speed and efficiency with which the four gas and oil fields developed to date were brought into production, the necessary treatment plants erected, the pipelines laid and distribution facilities organised; and with which the gas industry changed over to the new fuel and refineries modified their processes to use indigenous crudes have, by world standards, been exceptional. From the time the first gas field-Barracouta, was found in February 1965 until the last oil field in the program -Kingfish came fully on stream late in 1971, less than seven years elapsed.During that time Victorian fuel patterns underwent vast changes. Today over 95% of all gas consumers are using natural gas and about 70% of crude processed by local refineries comes from the Gippsland Basin. The significance of natural gas in particular is demonstrated by a 41% increase in gas sales in Victoria in 1971/72 over the previous twelve months and this trend is expected to accelerate as a result of recent arrangements for the supply of large volumes of this fuel to industrial plants including paper mills, cement works and an alumina smelter.Also of major significance to the State has been the development of the port of Western Port where the loading of tankers and LPG carriers has resulted in it becoming the State's second busiest port. Of less immediate impact but still of great value in the long term, has been the building of better roads and facilities needed to service the installations and the emergence of many valuable skills in the petroleum industry which will make easier the task of future development of new fields and facilities in Victoria and other parts of Australia.

scholarly journals Identification of Hydrocarbon Gas and Discriminate CO2 Using Lame Parameter and Batzle-Wang Model

2019 ◽  
Vol 125 ◽  
pp. 15003
Author(s):  
Alvian Yogi Pamungkas ◽  
Mohammad Syamsu Rosid ◽  
Mochammad Wahdanadi Haidar
Keyword(s):  
Natural Gas ◽  
Saturated Hydrocarbon ◽  
Environmental Problems ◽  
Hydrocarbon Gases ◽  
Co2 Gas ◽  
Fluid Content ◽  
Success Ratio ◽  
Hydrocarbon Fluid ◽  
Gas Identification ◽  
Hydrocarbon Gas

Drilling activities in 2016 were carried out at 34 points with only achieving a success ratio of 26%. It affects the decreasing in natural gas reserves. In addition, the presence of CO2 raises problems during production and environmental problems. So, it is necessary to identify hydrocarbon gas and to discriminate CO2. The method used for gas identification is the Lame parameter where the parameters can distinguish the effects caused by lithology and fluid. The Batzle-Wang model is applied to distinguish between hydrocarbon gases and CO2 gas by estimating the fluid’s properties of CO2 gas. Based on the analysis of result the parameters Lambda-Rho and Mu-Rho, both parameters can distinguish the lithology and identify the hydrocarbon fluid content. The area around the C4 is indicated hydrocarbon in 9930 - 10000 ft depth with Lambda-Rho 30 – 31.79 GPa*g/cc and Mu-Rho 27 – 43 GPa*g/cc. Based on the Batzle-Wang Vp analysis, saturated CO2 gas is vulnerable at 16000-17000 ft/s where it is still in range Vp saturated hydrocarbon gas and distributed around the C4 well based on LMR analysis.

scholarly journals Spectrometric measurements of atmospheric propane (C<sub>3</sub>H<sub>8</sub>)

2021 ◽  
Vol 21 (13) ◽  
pp. 10727-10743
Author(s):  
Geoffrey C. Toon ◽  
Jean-Francois L. Blavier ◽  
Keeyoon Sung ◽  
Katelyn Yu
Keyword(s):  
New Mexico ◽  
Natural Gas ◽  
Absorption Feature ◽  
Strongly Correlated ◽  
Permian Basin ◽  
Gas Field ◽  
Solar Absorption ◽  
Back Trajectories ◽  
Oil And Natural Gas ◽  
Gas Fields

Abstract. We report measurements of atmospheric C3H8 from analysis of ground-based solar absorption spectra from the Jet Propulsion Laboratory (JPL) MkIV interferometer. Using the strong Q-branch absorption feature at 2967 cm−1, we can measure C3H8 in locations where its abundance is enhanced by proximity to sources (e.g., large natural gas fields, megacities). A case study of MkIV C3H8 measurements from Fort Sumner, New Mexico, shows that amounts are strongly correlated with ethane (C2H6) and with back-trajectories from SE New Mexico and western Texas, where the Permian Basin oil and natural gas field is located. Measurements from JPL, California, also show large C3H8 enhancements on certain days but more correlated with CO than C2H6. From high-altitude balloon-borne MkIV solar occultation measurements, C3H8 was not detected at any altitude (5–40 km) in any of the 25 flights.

scholarly journals Spectrometric measurements of atmospheric propane (C<sub>3</sub>H<sub>8</sub>)

2020 ◽  
Author(s):  
Geoffrey C. Toon ◽  
Jean-Francois L. Blavier ◽  
Keeyoon Sung ◽  
Katelyn Yu
Keyword(s):  
New Mexico ◽  
Natural Gas ◽  
Absorption Feature ◽  
Strongly Correlated ◽  
Permian Basin ◽  
Gas Field ◽  
Solar Absorption ◽  
Back Trajectories ◽  
Oil And Natural Gas ◽  
Gas Fields

Abstract. We report measurements of atmospheric C3H8 from analysis of ground-based, solar absorption spectra from the JPL MkIV interferometer. Using the strong Q-branch absorption feature at 2967 cm−1, we can measure C3H8 in locations where its abundance is enhanced by proximity to sources (e.g., large natural gas fields, mega-cities). A case study of MkIV C3H8 measurements from Ft. Sumner, New Mexico, show large variations that are strongly correlated with ethane (C2H6) amounts and with back-trajectories from SE New Mexico and West Texas, where the Permian Basin oil and natural gas field is located. Measurements from JPL, California, also show large C3H8 enhancements on certain days, but more correlated with CO than C2H6. From MKIV solar occultation measurements from balloon, C3H8 was not detected at any altitude in any flight.

DEVELOPMENT OF NEW METHODS FOR DETECTION OF LEAKS OF HYDROCARBON GAS

2019 ◽  
pp. 60-64
Author(s):  
R. A. Eminov ◽  
N. Z. Mursalov
Keyword(s):  
Wind Speed ◽  
Natural Gas ◽  
Hydrocarbon Gases ◽  
New Methods ◽  
Gas Leak ◽  
Hydrocarbon Gas ◽  
Remote Determination ◽  
A Site ◽  
Gas Leaks

The paper is devoted to development of new methods for detection of leaks of hydrocarbon gas. It is determined that the wellknown fact on inverse interrelation of concentration of oxygen and such gases as N2 and CH4 can be used for remote determination of leaks of hydrocarbon gases. The gradient method for detection of leaks of natural gas composed of determination of two directions with minimum value of gradient of concentration of O2 in two fixed points and characterization of the point of crossing of them as a site of leak is suggested. The method of circles for detection of natural gases leaks site providing for determination of three points in supposed zone of leak and drawing up the circles around these points with growing radius with defined regularity is suggested. The point of crossing of all circles in some cycle of radiuses increase is presented as the gas leaks site. The carried out experimental researches held in various amounts of wind speed shown that when the wind speed surpass the fixed value location of gas leak site would be impossible due to effect of wind on spatial distribution and concentration of natural gas. Thus the proposed method is not designated for cases when a heavy wind occurs.

scholarly journals Reduced methane recovery at high pressure due to methane trapping in shale nanopores

2020 ◽  
Vol 1 (1) ◽  
Author(s):  
Chelsea W. Neil ◽  
Mohamed Mehana ◽  
Rex P. Hjelm ◽  
Marilyn E. Hawley ◽  
Erik B. Watkins ◽  
...  
Keyword(s):  
High Pressure ◽  
Natural Gas ◽  
Marcellus Shale ◽  
Management Strategies ◽  
The United States ◽  
Gas Production ◽  
Methane Recovery ◽  
Gas Field ◽  
Gas Recovery ◽  
Hydrocarbon Gas

Abstract By 2050, shale gas production is expected to exceed three-quarters of total US natural gas production. However, current unconventional hydrocarbon gas recovery rates are only around 20%. Maximizing production of this natural resource thus necessitates improved understanding of the fundamental mechanisms underlying hydrocarbon retention within the nanoporous shale matrix. In this study, we integrated molecular simulation with high-pressure small-angle neutron scattering (SANS), an experimental technique uniquely capable of characterizing methane behavior in situ within shale nanopores at elevated pressures. Samples were created using Marcellus shale, a gas-generative formation comprising the largest natural gas field in the United States. Our results demonstrate that, contrary to the conventional wisdom that elevated drawdown pressure increases methane recovery, a higher peak pressure led to the trapping of dense, liquid-like methane in sub-2 nm radius nanopores, which comprise more than 90% of the measured nanopore volume, due to irreversible deformation of the kerogen matrix. These findings have critical implications for pressure management strategies to maximize hydrocarbon recovery, as well as broad implications for fluid behavior under confinement.

Russian LNG Aims High, Leveraging Big Reserves and Logistical Advantages

2021 ◽  
Vol 73 (09) ◽  
pp. 22-25
Author(s):  
Pat Davis Szymczak
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Far East ◽  
Oil Field ◽  
Asia Pacific ◽  
Yamal Peninsula ◽  
Resource Base ◽  
Gas Field ◽  
Energy Investment ◽  
Competitive Prices

Russia’s market influence as an exporter of liquefied natural gas (LNG) is growing, possessing the world’s largest reserves of natural gas and the logistical options to deliver it at competitive prices to Asia and Europe along the now-navigable Northern Sea Route (NSR). The country became a player in the LNG market when it shipped its first cargo in 2009 to Japan from what was then Russia’s first offshore gas project, Sakhalin-2 in the Far East, operated by Sakhalin Energy Investment Company Ltd. and owned by Russia’s pipe-line gas monopoly Gazprom (50% plus one share), Shell (27.5% minus one share), and Japan’s Mitsui (12.5%) and Mitsubishi (10%). Sakhalin Energy operates three oil and gas platforms producing its current resource base from the Piltun-Astokhskoye oil field and the Lunskoye gas field off the northeastern coast of Sakhalin. To date, Sakhalin Energy has sold all the LNG produced at its 11.49-mtpa-capacity Prigorodnoye LNG production complex on the southern tip of Sakhalin Island, under long-term contracts to buyers in the Asia Pacific and North America, according to Shell’s website. In 2024–2026, the partners say they will add a third train to expand capacity by 5.4 mtpa, though they have repeatedly delayed this expansion for years due to a lack of investment capital to develop a new resource base and low gas prices in Asia. The same holds true for Gazprom’s plan for an LNG plant near Vladivostok. However, the market has now changed with rising demand for gas to replace coal, giving gas producers an incentive to invest into new E&P gas projects and mid-to-downstream megaprojects like those for producing LNG. https://jpt.spe.org/compared-to-last-year-gas-prices-are-looking-good In 2018 and again this past January, European spot gas prices spiked on Gasunie’s leading TTF (title transfer facility) virtual trading platform and other European trading hubs when Asian gas markets began offering high premiums to divert LNG cargos from Europe, according to the EU Commission’s latest European Gas Market report. The Rise of a Russian IOC—Novatek in Yamal Russia’s largest independent natural gas producer Novatek was Russia’s second entrant into the LNG market when its Yamal LNG project rose above the permafrost atop an estimated 65,000 piles on the Yamal Peninsula, home to Russia’s largest gas deposits and the source of Russian pipeline gas sold into Europe. Yamal LNG shipped its first cargo (170000 m3) in December 2017. It then upped the ante with exports from a second train in August 2018, and added a third train in November 2018, according to Novatek’s website. Situated on the South Tambeyskoye field on the coast of Ob Bay, the plant boasts a capacity of 17.4 mtpa.

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