scholarly journals Depositional environment of E Oligocene sedimentary and prediction of sand distribution in Southeast area, Cuu Long basin

2020 ◽  
Vol 4 (2) ◽  
pp. First
Author(s):  
Tran Van Xuan ◽  
Nguyen Dinh Chuc ◽  
Nguyen Tuan ◽  
Truong Quoc Thanh ◽  
Pham Viet Au
Keyword(s):  
Depositional Environment ◽  
Oil And Gas ◽  
Sedimentary Facies ◽  
Effective Porosity ◽  
Reservoir Modeling ◽  
Large Area ◽  
Seismic Line ◽  
Gas Industry ◽  
Petroleum Systems ◽  
Gas Potential

According to petrophysical and geophysical data, the depositional facies of E Oligocene are determined. Furthermore, the correlation lines between wells and the seismic line also created for confirming Oligocene E distribution in Cuu Long basin. Using appropriate methods such as petrophysical curves, geophysical characteristics, interpretation of gross depositional environment as well as mapping of seismic attributes for sub-sequence Oligocene E upper and E lower in Southeast area, results of prediction the sand distribution in Oligocene E upper and E lower sub-sequence, factors effect to porosity-permeability preservation of E sand reservoirs in Southeast area, Cuu Long basin and oil-gas industry flow-producing possibility in varied sedimentary facies were reported in this paper. The E Oligocene sedimentary distributes in a large area with hydrocarbon accumulations along the Southeast margin Cuu Long basin in relation with the existence of half-grabens along Con Son swell, in which formation rocks consist of varying grain size, mainly sandstone interbeds by siltstone and shale stone. A bitum shale layer of 20÷70 m thickness exits to play the role of a shield to maintain a much higher effective porosity of the reservoir section than usual (up to 18%). In the area, there are two sandstone reservoirs of excellent quality at 2,600÷2,700 mMD and 3,000÷3,400 mMD depths. In order to determine the oil and gas potential of the target, petroleum systems in exploration activities must carefully be evaluated, especially looking for stratigraphic traps, and the reservoir modeling should be modified accurately.

A Revised Gassmann Fluid Replacement Model Based on Neutron-Density Logs in Shaly Sandstone Reservoirs

2021 ◽  
pp. 1-13
Author(s):  
Shantanu Chakraborty ◽  
Samit Mondal ◽  
Rima Chatterjee
Keyword(s):  
Oil And Gas ◽  
Reservoir Characterization ◽  
Rock Physics ◽  
Oil And Gas Industry ◽  
Effective Porosity ◽  
Fluid Replacement ◽  
Neutron Density ◽  
Gas Industry ◽  
Sandstone Reservoirs ◽  
Shaly Sandstone

Summary Fluid-replacement modeling (FRM) is a fundamental step in rock physics scenario modeling. The results help to conduct forward modeling for prediction of seismic signatures. Further, the analysis of the results improves the accuracy of quantitative interpretation and leads to an updated reservoir characterization. While modeling for different possible reservoir pore fluid scenarios, the quality of the results largely depends on the accuracy of the FRM. Gassmann (1951)fluid-replacement modeling (GFRM) is one of the widely adopted methods across the oil and gas industry. However, the Gassmann method assumes the reservoir as clean sandstone with connected pores. This causes Gassmann fluid-replacement results to overestimate the fluid effect in shaly sandstones. This study uses neutron and density logs to correct the overestimated results in shaly sandstone reservoirs. Due to the nature of these recordings, both of these log readings have close dependencies on the presence of shale. When the logs are plotted in a justified scale, the differences between the logs provide an accurate measurement of shaliness within the reservoir. The study has formulated a weight factor using the logs, which has further been used to scale the overestimated Gassmann-modeled fluid effect. The results of the revised method are independent of type of clay presence and associated effective porosity. Moreover, the corrected FRM results from the revised Gassmann method shows good agreement with rock physical interpretation of shaly sandstone reservoirs.

The extent of methane emission associated with the natural gas industry in southeastern Poland.

2021 ◽  
Author(s):  
Paweł Jagoda ◽  
Jarosław Nęcki ◽  
Jakub Bartyzel ◽  
Piotr Korbeń ◽  
Michał Kud ◽  
...  
Keyword(s):  
Natural Gas ◽  
Methane Emission ◽  
Oil And Gas ◽  
Science Studies ◽  
Oil And Gas Industry ◽  
Detection Methods ◽  
Current Phase ◽  
Large Area ◽  
Gas Wells ◽  
Gas Industry

<p>Goal of the CCAC project is to observe urban emission of natural gas over Canada and different countries in Europe. Our team was responsible for the Silesia and Sub-Carpathia regions in southern Poland. In this presentation we will focus on the methane emission measurements from gas pipelines, storages, gas wells as well as gathering and processing facilities, which was realized by our team in years 2018-2020.</p><p>South eastern Poland is rather rural part of the country with rich history of oil and gas industry going back to the XVI-th century. Currently Carpathians and Carpathian Foredeep regions gas industry produces 1.35 BILLIONS of m<sup>3</sup> [1]</p><p>The measurements have been carried out since summer 2016 mainly with Micro-Portable Greenhouse Gas Analyzer ‘Los Gatos Research, MGGA-918’ mounted on board of a car. We also had capability to deploy analyser in difficult terrain with its own power supply. During our measurements our team visited over 300 gas wells. We found that over half of these sites show elevated methane concentrations which can be attributed to either gas well itself or soil fractures around site. Transects paths were designed to follow pipelines. This allowed us to monitor possible leaks from the natural gas infrastructure. However there are numerous possible sources in close proximity of pipelines. We will discuss detection methods and variability study for dozens of transects. As of the 2017 only 9 gathering and processing facilities report release which states the emission of 1.8*10<sup>6</sup> m<sup>3</sup> CH<sub>4</sub> per year. One of the focus points of our project was to estimate how uncertain were methane emission from O&G in Poland which at current phase concludes methane emission of 7.5-40 kt CH4/year</p><p>During the presentation we will outline challenges in carrying out measurements with GPM, OTM 33a methods that were performed alongside large-area screening. We are developing oversized flow chamber method. Mobile structure is built in the shape of a dome. It has the radius of 3 meters which gives the chamber volume of 49 m<sup>3</sup>.</p><p><strong>This work was funded under the Climate and Clean Air Coalition (CCAC) Oil and Gas Methane Science Studies.</strong></p><p>[1]PSG, „Bilans zasobów złóż kopalin w Polsce wg stanu na 31 XII 2019 r,” PIG-PIB, Warsaw, 2020.</p><p> </p>

Three-Dimensional Sedimentary Microfacies Modeling in Chunguang Oilfield - A Case of P2 Block

2013 ◽  
Vol 718-720 ◽  
pp. 377-382
Author(s):  
Chen Qiang Dong ◽  
Xue Li
Keyword(s):  
Spatial Distribution ◽  
Oil And Gas ◽  
Three Dimensional ◽  
Sedimentary Facies ◽  
Modeling Method ◽  
Reservoir Modeling ◽  
Gas Recovery ◽  
Indicator Simulation ◽  
Sedimentary Microfacies ◽  
Reasonable Choice

Reservoir microfacies is an important factor affecting the reservoir heterogeneity, and it is significant to accurately predict reservoir microfacies distribution in order to improve oil and gas recovery. The stochastic reservoir modeling method has a strong geological suitability. The reasonable choice of the stochastic modeling method can effectively improve the accuracy of modeling. During the sedimentary facies modeling, sequence indicator simulation is used to characterize the spatial distribution of different microfacies with different variogram,to reproduce the complex microfacies spatial distribution.

Exploring for the Future—a new oil and gas frontier in northern Australia

2020 ◽  
Vol 60 (2) ◽  
pp. 703
Author(s):  
Paul Henson ◽  
David Robinson ◽  
Lidena Carr ◽  
Dianne S. Edwards ◽  
Susannah K. MacFarlane ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Rock Properties ◽  
Geochemical Data ◽  
Seismic Line ◽  
Petroleum Systems ◽  
Systems Model ◽  
The Future ◽  
Territory Government ◽  
Analytical Tools ◽  
Systems Framework

Exploring for the Future (EFTF) is a four-year, AU$100.5 million initiative from the Australian Government conducted by Geoscience Australia in partnership with state and Northern Territory government agencies, CSIRO and universities to provide new geoscientific datasets for frontier regions. As part of this program, Geoscience Australia acquired two new seismic surveys that collectively extend across the South Nicholson Basin (L120 South Nicholson seismic line) and into the Beetaloo Sub-basin of the McArthur Basin (L212 Barkly seismic line). Interpretation of the seismic has resulted in the discovery of new basins that both contain a significant section of presumed Proterozoic strata. Integration of the seismic results with petroleum systems geochemistry, structural analyses, geochronology, rock properties and a petroleum systems model has expanded the knowledge of the region for energy exploration. These datasets are available through Geoscience Australia’s newly developed Data Discovery Portal: an online platform delivering digital geoscientific information, including seismic locations and cross-section images, and field site and well based sample data. Specifically for the EFTF energy project, a petroleum systems framework with supporting organic geochemical data has been built to access source rock, crude oil and natural gas datasets via interactive maps, graphs and analytical tools that enable the user to gain a better and faster understanding of a basin’s petroleum prospectivity.

scholarly journals Remote sensing of methane leakage from natural gas and petroleum systems revisited

2020 ◽  
Vol 20 (15) ◽  
pp. 9169-9182
Author(s):  
Oliver Schneising ◽  
Michael Buchwitz ◽  
Maximilian Reuter ◽  
Steffen Vanselow ◽  
Heinrich Bovensmann ◽  
...  
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
The United States ◽  
Methane Emissions ◽  
Anadarko Basin ◽  
Gas Industry ◽  
Petroleum Systems ◽  
Time Period ◽  
Gas Fields

Abstract. The switch from the use of coal to natural gas or oil for energy generation potentially reduces greenhouse gas emissions and thus the impact on global warming and climate change because of the higher energy creation per CO2 molecule emitted. However, the climate benefit over coal is offset by methane (CH4) leakage from natural gas and petroleum systems, which reverses the climate impact mitigation if the rate of fugitive emissions exceeds the compensation point at which the global warming resulting from the leakage and the benefit from the reduction of coal combustion coincide. Consequently, an accurate quantification of CH4 emissions from the oil and gas industry is essential to evaluate the suitability of natural gas and petroleum as bridging fuels on the way to a carbon-neutral future. We show that regional CH4 release from large oil and gas fields can be monitored from space by using dense daily recurrent measurements of the TROPOspheric Monitoring Instrument (TROPOMI) onboard the Sentinel-5 Precursor satellite to quantify emissions and leakage rates. The average emissions for the time period 2018/2019 from the five most productive basins in the United States, the Permian, Appalachian, Eagle Ford, Bakken, and Anadarko, are estimated to be 3.18±1.13, 2.36±0.88, 1.37±0.63, 0.89±0.56, and 2.74±0.74 Mt yr−1, respectively. This corresponds to CH4 leakage rates relative to the associated production between 1.2 % and 1.4 % for the first four production regions, which are consistent with bottom-up estimates and likely fall below the break-even leakage rate for immediate climate benefit. For the Anadarko Basin, the fugitive emission rate is larger and amounts to 3.9±1.1 %, which likely exceeds the break-even rate for immediate benefit and roughly corresponds to the break-even rate for a 20-year time horizon. The determined values are smaller than previously derived satellite-based leakage rates for the time period 2009–2011, which was an early phase of hydraulic fracturing, indicating that it is possible to improve the climate footprint of the oil and gas industry by adopting new technologies and that efforts to reduce methane emissions have been successful. For two of the world's largest natural gas fields, Galkynysh and Dauletabad in Turkmenistan, we find collective methane emissions of 3.26±1.17 Mt yr−1, which corresponds to a leakage rate of 4.1±1.5 %, suggesting that the Turkmen energy industry is not employing methane emission avoidance strategies and technologies as successfully as those currently widely used in the United States. The leakage rates in Turkmenistan and in the Anadarko Basin indicate that there is potential to reduce fugitive methane emissions from natural gas and petroleum systems worldwide. In particular, relatively newly developed oil and gas plays appear to have larger leakage rates compared to more mature production areas.

scholarly journals Oil and gas potential of Kuma source rock in Bakhchsisarai area, Crimea

2016 ◽  
pp. 44-51
Author(s):  
G. A. Peshkov ◽  
N. N. Barabanov ◽  
M. A. Bolshakova ◽  
S. I. Bordunov ◽  
L. F. Kopaevich ◽  
...  
Keyword(s):  
Organic Matter ◽  
Liquid Chromatography ◽  
Source Rock ◽  
Depositional Environment ◽  
Oil And Gas ◽  
Gas Liquid Chromatography ◽  
Gas Potential ◽  
Potential Area

Based on lithological and micropaleontological studies of geosection and geochemical investigations (lumino-bituminological, gas-liquid chromatography, pyrolysis, isotopes) of organic matter of rocks Kuma Formation authors justify oil and gaz potential of source rock formed during Bartonian depositional environment and define possible potential area of research, where possible the plays with this formation.

scholarly journals Remote sensing of methane leakage from natural gas and petroleum systems revisited

2020 ◽  
Author(s):  
Oliver Schneising ◽  
Michael Buchwitz ◽  
Maximilian Reuter ◽  
Steffen Vanselow ◽  
Heinrich Bovensmann ◽  
...  
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
The United States ◽  
Methane Emissions ◽  
Leakage Rate ◽  
Gas Industry ◽  
Petroleum Systems ◽  
Time Period ◽  
Gas Fields

Abstract. The switch from the use of coal to natural gas or oil for the energy generation potentially reduces the greenhouse gas emissions and thus the impact on global warming and climate change because of the larger energy content per CO2 molecule emitted. However, the climate benefit over coal is offset by methane (CH4) leakage from natural gas and petroleum systems, which reverses the climate impact mitigation if the rate of fugitive emissions exceeds the compensation point at which the global warming resulting from the leakage and the benefit from the reduction of coal combustion coincide. Consequently, an accurate quantification of the CH4 emissions from the oil and gas industry is essential to evaluate the suitability of natural gas and petroleum as bridging fuels on the way to a carbon-neutral future. We show that regional CH4 release from large oil and gas fields can be monitored from space by using dense daily recurrent measurements of the TROPOspheric Monitoring Instrument (TROPOMI) onboard the Sentinel-5 Precursor satellite to quantify emissions and leakage rates. The average emissions for the time period 2018/2019 from the five most productive basins in the United States, the Permian, Appalachia, Eagle Ford, Bakken, and Anadarko are estimated to be 3.16 ± 1.13 Mt yr−1, 2.36 ± 0.88 Mt yr−1, 1.52 ± 0.68 Mt yr−1, 0.89 ± 0.56 Mt yr−1, and 2.81 ± 0.77 Mt yr−1, respectively. This corresponds to CH4 leakage rates relative to the associated production between 1.2 % and 1.6 % for the first four production regions, which are consistent with bottom-up estimates and likely fall below the break-even leakage rate for immediate climate benefit. For the Anadarko Basin, the fugitive emission rate is larger and amounts to 4.0 ± 1.1 %, which likely exceeds the break-even rate for immediate benefit and roughly corresponds to the break-even rate for a 20-year time horizon. The determined values are smaller than previously derived satellite-based leakage rates for the time period 2009–2011, which was an early phase of hydraulic fracturing, indicating that it is possible to improve the climate footprint of the oil and gas industry by adopting new technologies and that the efforts to reduce the methane emissions have been successful. For two of the world's largest natural gas fields Galkynysh and Dauletabad in Turkmenistan, we find collective methane emissions of 3.23 ± 1.17 Mt yr−1, which corresponds to a leakage rate of 4.1 ± 1.5 % suggesting that the Turkmen energy industry has not the technological standards concerning avoidance of emissions than the United States average. Together with the high leakage rate for the Anadarko Basin, this indicates that there is potential to reduce fugitive methane emissions from natural gas and petroleum systems worldwide. In particular, relatively newly developed oil and gas plays appear to have larger leakage rates in contrast to more mature production areas.

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