scholarly journals Pyrogenic nature reservoir rocks as a factor of geofluidodynamic inhomogeneity

2019 ◽  
Vol 489 (3) ◽  
pp. 277-280
Author(s):  
L. A. Abukova ◽  
I. F. Yusupova

The article considers the Kansko-Achinsky brown coal basin. Huge reserves of solid organic matter (OM) are concentrated in еру Jurassic age sandy-clay sediments. For example, the average thickness of the Borodino field Itatsky layer is 51 m. Attention is drawn to the paleo-centers of heat generation where the coal layers lost (in a whole or partly) their OM. They were destroyed by the underground fires of the past eras. The loss of large masses of the OM in local areas was accompanied by deformations of the coal layers (as well as overlapping ones), appearance of burned and caved ground, failure topographic form (subsidence, funnels, bolsons), and most importantly, the formation of epigenetic cavernosity and pyrogenic reservoir rocks. It is emphasized that the increased fluid conductivity of burned rocks has survived up to the present days. The areas with the burnt rocks are separated into independent fluid dynamic structures with their own parameters (filtration coefficient, water transmissibility, etc.). It has been suggested that pyrogenic reservoir rocks could occur in oil-and-gas basins with coal shale deposits at certain stages of geological development, and at the oil-and-gas generating depths they are able to become reservoirs of catagenic hydrocarbons.

Georesursy ◽  
2021 ◽  
Vol 23 (2) ◽  
pp. 67-72
Author(s):  
Iskra F. Yusupova ◽  
Natalia P. Fadeeva ◽  
Leyla A. Abukova

The paper considers palaeoincisions in the Turnean limestones of the Volga-Ural basin, made by alluvial-deluvial sediments of the Visean age and containing interlayers of coals. Processes occurring in these sediments (catagenic reduction of thickness of coal beds and coal-bearing mudstones, aggressive influence of products of defluidization of coal organic matter on the host rocks, etc.) strengthen the fluid dynamic heterogeneity of intracrustal deposits and contribute to emigration of hydrocarbons (HC). The main oil-and-gas-generating strata in the Carboniferous section include rocks of the Tournaisian stage and the Bobrikovsky horizon of the Viseian stage. Palaeoincisions, along with the area distribution of Viseian coals, can be considered as centers of fluid generation, including liquid and gas HC.


2017 ◽  
Vol 3 (2) ◽  
pp. 177
Author(s):  
Nur Huzeima Mohd Hussain ◽  
Hugh Byrd ◽  
Nur Azfahani Ahmad

Globalisation combined with resources of oil and gas has led to an industrial society in Malaysia.  For the past 30 years, rapid urban growth has shifted from 73% rural to 73% urban population. However, the peak oil crisis and economic issues are threatening the growth of urbanisation and influencing the trends of population mobility. This paper documents the beginnings of a reverse migration (urban-to-rural) in Malaysia.  The method adopted case study that involves questionnaires with the urban migrants to establish the desires, definite intentions and reasons for future migration. Based on this data, it predicts a trend and rate of reverse migration in Malaysia. 


1996 ◽  
Vol 15 (3) ◽  
pp. 249-257 ◽  
Author(s):  
Zhang Wenhuai ◽  
Zhang Zhijian ◽  
Ming Houli ◽  
Wu Gang ◽  
Ye Song

2021 ◽  
Vol 73 (07) ◽  
pp. 64-64
Author(s):  
Nigel Jenvey

Have you noticed the change in the oil and gas industry over the past year with its engagement in carbon management, decarbonization, and net-zero-emissions targets? Policy support and technology advances in alternative energies have delivered massive cost reduction in renewables more quickly, and to a greater degree, than expected. Over the past few years, more of the world’s capital has been spent on electricity than oil and gas sup-ply, and more than half of all new energy-generation capacity is now renewable. Some elements of society, therefore, have suggested that this is the beginning of the end for the fossil-fuel sector and call for investors to turn away from oil and gas and “leave it in the ground.” In more than a century of almost continuous change, however, the oil and gas industry has a long track record of innovative thinking, creative solutions, and different business models. SPE papers and events that covered decarbonization during the past year show that a wide variety of solutions already exist that avoid, reduce, replace, offset, or sequester greenhouse gas (GHG) emissions. It is clear, therefore, that decarbonization technologies will now be as important as 4D seismic, horizontal wells, and hydraulic fracturing. That is why we now bring you this inaugural Technology Focus feature dedicated to decarbonization. The experience and capability of the entire JPT community in decarbonization is critical. Please enjoy the following summary of three selected papers on the role of natural gas in fuel-switching; carbon capture, use, and storage (CCUS); and hydrogen technologies that deliver the dual challenge of providing more energy with less GHG emission. There are many ways to engage in the SPE decarbonization efforts in the remainder of 2021. Regional events have addressed CCUS, hydrogen, geothermal, and methane. There is also the new SPE Gaia sustainability program to enable and empower all members who wish to engage in the alignment of the future of energy with sustainable development. The Gaia program has an on-demand library of materials, including an existing series on methane, and upcoming similar events on other energy transition, natural capital and regeneration, and social responsibility priorities. Get involved through your SPE section or chapter or contact your regional Gaia liaison to find out what Gaia programming you can support or lead at www.spe.org/en/gaia.


2021 ◽  
pp. 57-68
Author(s):  
N. Yu. Moskalenkо

The relevance of the article is associated with the importance of the object of the research. Dozens of unique and giant oil and gas fields, such as Urengoyskoye, Medvezhye, Yamburgskoye, Vyngapurovskoye, Messoyakhskoye, Nakhodkinskoye, Russkoye, have been identified within the Cenomanian complex. The main feature of Cenomanian rocks is their slow rock cementation. This leads to significant difficulties in core sampling and the following studies of it; that is the direct and most informative source of data on the composition and properties of rocks that create a geological section.The identification of the factors, which determine the slow rock cementation of reservoir rocks, allows establishing a certain order in sampling and laboratory core studies. Consequently, reliable data on the reservoir and estimation of hydrocarbon reserves both of discovered and exploited fields and newly discovered fields that are being developed on the territory of the Gydan peninsula and the Bolshekhetskaya depression will be obtained. This study is also important for the exploration and development of hydrocarbon resources of the continental shelf in the waters of the Arctic seas of Russia as one of the most promising areas.As a result of the analysis, it was found that the formation of rocks of the PK1-3 Cenomanian age of the Bolshekhetskaya depression happened under conditions of normal compaction of terrigenous sedimentary rocks that are located in the West Siberian basin. Slow rock cementation of reservoir rocks is associated with relatively low thermobaric conditions of their occurrence, as well as the low content of clay and absence of carbonate cements. Their lithological and petrophysical characteristics are close to the analogous Cenomanian deposits of the northern fields of Western Siberia and can be applied to other unconsolidated rocks studied areas.


2001 ◽  
Author(s):  
Mohamed I. Hassan ◽  
A. Helali ◽  
Kozo Saito

Abstract Fire whirl is one of the most destructive phenomena in mass fires. To study thermal and fluid dynamic structures of a fire whirl in a laboratory, a fire whirl generator consisting of two vertically oriented split-cylinders were placed in an asymmetric position to form a compartment leaving two open slits in each end. A 5-cm diameter liquid pool fire was placed at the center of the compartment floor, the fire generated buoyancy flow moved upwardly, and fresh air entered to the compartment creating swirl motion. The visible flame height of the generated fire whirl was measured by a video camera, 2-D azimuthal velocity profiles at several different heights by particle image velocimetry (PIV), and the average heat flux input to the fuel surface by a Gardon gauge type heat flux meter.


2021 ◽  
Vol 73 (09) ◽  
pp. 50-50
Author(s):  
Ardian Nengkoda

For this feature, I have had the pleasure of reviewing 122 papers submitted to SPE in the field of offshore facilities over the past year. Brent crude oil price finally has reached $75/bbl at the time of writing. So far, this oil price is the highest since before the COVID-19 pandemic, which is a good sign that demand is picking up. Oil and gas offshore projects also seem to be picking up; most offshore greenfield projects are dictated by economics and the price of oil. As predicted by some analysts, global oil consumption will continue to increase as the world’s economy recovers from the pandemic. A new trend has arisen, however, where, in addition to traditional economic screening, oil and gas investors look to environment, social, and governance considerations to value the prospects of a project and minimize financial risk from environmental and social issues. The oil price being around $75/bbl has not necessarily led to more-attractive offshore exploration and production (E&P) projects, even though the typical offshore breakeven price is in the range of $40–55/bbl. We must acknowledge the energy transition, while also acknowledging that oil and natural gas will continue to be essential to meeting the world’s energy needs for many years. At least five European oil and gas E&P companies have announced net-zero 2050 ambitions so far. According to Rystad Energy, continuous major investments in E&P still are needed to meet growing global oil and gas demand. For the past 2 years, the global investment in E&P project spending is limited to $200 billion, including offshore, so a situation might arise with reserve replacement becoming challenging while demand accelerates rapidly. Because of well productivity, operability challenges, and uncertainty, however, opening the choke valve or pipeline tap is not as easy as the public thinks, especially on aging facilities. On another note, the technology landscape is moving to emerging areas such as net-zero; decarbonization; carbon capture, use, and storage; renewables; hydrogen; novel geothermal solutions; and a circular carbon economy. Historically, however, the Offshore Technology Conference began proactively discussing renewables technology—such as wave, tidal, ocean thermal, and solar—in 1980. The remaining question, then, is how to balance the lack of capital expenditure spending during the pandemic and, to some extent, what the role of offshore is in the energy transition. Maximizing offshore oil and gas recovery is not enough anymore. In the short term, engaging the low-carbon energy transition as early as possible and leading efforts in decarbonization will become a strategic move. Leveraging our expertise in offshore infrastructure, supply chains, sea transportation, storage, and oil and gas market development to support low-carbon energy deployment in the energy transition will become vital. We have plenty of technical knowledge and skill to offer for offshore wind projects, for instance. The Hywind wind farm offshore Scotland is one example of a project that is using the same spar technology as typical offshore oil and gas infrastructure. Innovation, optimization, effective use of capital and operational expenditures, more-affordable offshore technology, and excellent project management, no doubt, also will become a new normal offshore. Recommended additional reading at OnePetro: www.onepetro.org. SPE 202911 - Harnessing Benefits of Integrated Asset Modeling for Bottleneck Management of Large Offshore Facilities in the Matured Giant Oil Field by Yukito Nomura, ADNOC, et al. OTC 30970 - Optimizing Deepwater Rig Operations With Advanced Remotely Operated Vehicle Technology by Bernard McCoy Jr., TechnipFMC, et al. OTC 31089 - From Basic Engineering to Ramp-Up: The New Successful Execution Approach for Commissioning in Brazil by Paulino Bruno Santos, Petrobras, et al.


Author(s):  
Scott D. Ironside ◽  
L. Blair Carroll

Enbridge Pipelines Inc. operates the world’s longest and most complex liquids pipeline network. As part of Enbridge’s Integrity Management Program In-Line Inspections have been and will continue to be conducted on more than 15,000 km of pipeline. The Inspection Programs have included using the most technologically advanced geometry tools in the world to detect geometrical discontinuities such as ovality, dents, and buckles. During the past number of years, Enbridge Pipelines Inc. has been involved in developing a method of evaluating the suitability of dents in pipelines for continued service. The majority of the work involved the development of a method of modeling the stresses within a dent using Finite Element Analysis (FEA). The development and validation of this model was completed by Fleet Technology Limited (FTL) through several projects sponsored by Enbridge, which included field trials and comparisons to previously published data. This model combined with proven fracture mechanics theory provides a method of determining a predicted life of a dent based on either the past or future operating conditions of the pipeline. CSA Standard Z662 – Oil and Gas Pipeline Systems provides criteria for the acceptability of dents for continued service. There have been occurrences, however, where dents that meet the CSA acceptability criteria have experienced failure. The dent model is being used to help define shape characteristics in addition to dent depth, the only shape factor considered by CSA, which contribute to dent failure. The dent model has also been utilized to validate the accuracy of current In-Line Inspection techniques. Typically a dent will lose some of its shape as the overburden is lifted from the pipeline and after the indentor is removed. Often there can be a dramatic “re-rounding” that will occur. The work included comparing the re-rounded dent shapes from a Finite Element model simulating the removal of the constraint on the pipe to the measured dent profile from a mold of the dent taken in the field after it has been excavated. This provided a measure of the accuracy of the tool. This paper will provide an overview of Enbridge’s dent management program, a description of the dent selection process for the excavation program, and a detailed review of the ILI validation work.


2010 ◽  
Vol 182 (7) ◽  
pp. 858-878 ◽  
Author(s):  
Jesse Lozano ◽  
Watcharapong Tachajapong ◽  
David R. Weise ◽  
Shankar Mahalingam ◽  
Marko Princevac

2016 ◽  
Vol 4 (2) ◽  
pp. 28 ◽  
Author(s):  
Sunmonu Ayobami ◽  
Adabanija Adedapo ◽  
Adagunodo Aanuoluwa ◽  
Adeniji Ayokunnu

Hydrocarbon resources have become the most essential commodity contributing to any nation’s growth and development in the recent years. For the past decades now, the quest for hydrocarbon resources has been increasing in an arithmetic rate that its supply can no longer meets the demand for its consumption today. In petroleum industry, seismic and well log analyses play a vital role in oil and gas exploration and formation evaluation. This study is aimed to effectively characterize the reservoirs and analyze the by-passed pay in Philus Field, Niger-Delta, Nigeria in order to look into the economic viability and profitability of the volume of oil in the identified reservoir(s). The faults in the study area trend in NW-SE direction and dip towards the south. Seven reservoirs were mapped on Philus field. A discovery trap and a by-passed (new prospect) trap were mapped out on the field. The petrophysical analysis showed that porosity of Philus field was 0.24. The volumetric analysis showed that the Stock Tank Original Oil in Place of discovery trap (Philus field) ranged from 1.6 to 43.1 Mbbl while that of new prospect trap ranged from 18.1 to 211.3 Mbbl. It is recommended that the oil reserve of Philus field needs to be recalculated.


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