scholarly journals A Method to Simulate the Migration and Accumulation of Hydrocarbon with Analogue Modeling

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-10
Author(s):  
Jian Cui ◽  
Dong Jia ◽  
Hongbin Wang ◽  
Hongwei Yin ◽  
Yanjun Wang ◽  
...  
Keyword(s):  
Fault Zone ◽  
Oil And Gas ◽  
Ct Scanning ◽  
Northwest China ◽  
Hydrocarbon Migration ◽  
Oil Migration ◽  
Suitable Material ◽  
Long Time ◽  
Fine Quartz ◽  
Migration Pathways

Subsurface migration and accumulation of oil and gas have interested researchers for a long time, but these processes may occur over very long geological periods and are difficult to observe directly, so experimental simulations are warranted. In this study, an experimental method was developed to model hydrocarbon migration in the subsurface structure. Oil migration was simulated in a sandbox model, and industrial CT scanning was used to observe both the internal geometry of the model and the oil migration pathways. In the sandbox model, a NaI solution was used to simulate water, white oil was used to simulate hydrocarbon, and fine quartz sand, glass bead, silica powder, and brown corundum were chosen to represent brittle crust, based on suitable material parameters. A NaI-saturated layered sandbox model was constructed with an along-strike basal discontinuity, which during compression allowed a simple anticline with doubly verging reverse faults to form. Oil was then released continuously at a low rate from an orifice under one limb of the anticline. Initially, the oil migrated vertically through the fault zone until it reached the top of the fault zone; it then migrated laterally along the core of the anticline, saturating a model reservoir by buoyancy and capillary force. This experimental analog helps to explain hydrocarbon migration and accumulation within the Anjihai and Santai anticlines in northwest China.

Hydrocarbon-bearing characteristics of the SB1 strike-slip fault zone in the north of the Shuntuo Low Uplift, Tarim Basin

2020 ◽  
Vol 27 (1) ◽  
pp. petgeo2019-144
Author(s):  
Ziyi Wang ◽  
Zhiqian Gao ◽  
Tailiang Fan ◽  
Hehang Zhang ◽  
Lixin Qi ◽  
...  
Keyword(s):  
Fault Zone ◽  
Tarim Basin ◽  
Oil And Gas ◽  
Strike Slip ◽  
Strike Slip Fault ◽  
Hydrocarbon Exploration ◽  
Phase Iii ◽  
Permeability Barrier ◽  
The North ◽  
Migration Pathways

The SB1 strike-slip fault zone, which developed in the north of the Shuntuo Low Uplift of the Tarim Basin, plays an essential role in reservoir formation and hydrocarbon accumulation in deep Ordovician carbonate rocks. In this research, through the analysis of high-quality 3D seismic volumes, outcrop, drilling and production data, the hydrocarbon-bearing characteristics of the SB1 fault are systematically studied. The SB1 fault developed sequentially in the Paleozoic and formed as a result of a three-fold evolution: Middle Caledonian (phase III), Late Caledonian–Early Hercynian and Middle–Late Hercynian. Multiple fault activities are beneficial to reservoir development and hydrocarbon filling. In the Middle–Lower Ordovician carbonate strata, linear shear structures without deformation segments, pull-apart structure segments and push-up structure segments alternately developed along the SB1 fault. Pull-apart structure segments are the most favourable areas for oil and gas accumulation. The tight fault core in the centre of the strike-slip fault zone is typically a low-permeability barrier, whilst the damage zones on both sides of the fault core are migration pathways and accumulation traps for hydrocarbons, leading to heterogeneity in the reservoirs controlled by the SB1 fault. This study provides a reference for hydrocarbon exploration and development of similar deep-marine carbonate reservoirs controlled by strike-slip faults in the Tarim Basin and similar ancient hydrocarbon-rich basins.

scholarly journals Chemically Active Elements of Reservoir Quartz Cement Trace Hydrocarbon Migration in the Mahu Sag, Junggar Basin, NW China

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-19
Author(s):  
Linjun Huang ◽  
Yin Liu ◽  
Baoli Bian ◽  
Yongping Ma ◽  
Hailei Liu ◽  
...  
Keyword(s):  
Organic Geochemistry ◽  
Petroleum Reservoirs ◽  
Junggar Basin ◽  
Northwest China ◽  
Fluid Migration ◽  
Hydrocarbon Migration ◽  
Geochemical Study ◽  
Migration Pathways ◽  
Quartz Grains

Element exchange and enrichment during fluid-rock interactions are common, providing potentially novel proxies to trace hydrocarbon migration in addition to the traditional organic geochemistry tracers. However, the processes, mechanisms, and geological and geochemical fingerprints of these interactions are complex, hampering the applications of hydrocarbon migration tracers. To investigate such interactions, we conducted a petrological, mineralogical, and in situ and bulk geochemical study of authigenic quartz and whole-rock samples from the Mahu Sag, northwestern Junggar Basin, northwest China. We found that dissolution, clay and chlorite formation, and overgrowth occurred on quartz grains in hydrocarbon fluid migration pathways, suggestive of strong fluid-rock interactions. In situ quantitative elemental analysis of quartz grains revealed elemental enrichment (e.g., Mn, Fe, Al, Sr, and W) in quartz overgrowth rims compared with their cores, indicating that migration of hydrocarbon-bearing fluids in reservoirs may promote elemental exchange between fluids and minerals. Whole-rock geochemical analysis showed that decreasing contents of some elements may reflect the direction of hydrocarbon-bearing fluid migration and can be monitored with three geochemical proxies, which are the MnO contents and MnO/Zr and Y/Ho ratios. Our data provide new constraints on fluid-rock interactions in petroleum reservoirs and have implications for using inorganic geochemical methods to trace hydrocarbon migration.

Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO2

2021 ◽  
pp. 1-11
Author(s):  
Sara LIFSHITS
Keyword(s):  
Supercritical Fluid ◽  
Oil And Gas ◽  
Gas Permeability ◽  
Sedimentary Rocks ◽  
Source Rocks ◽  
Reservoir Properties ◽  
Hydrocarbon Migration ◽  
Geological Processes ◽  
Before And After ◽  
Oil Source

ABSTRACT Hydrocarbon migration mechanism into a reservoir is one of the most controversial in oil and gas geology. The research aimed to study the effect of supercritical carbon dioxide (СО2) on the permeability of sedimentary rocks (carbonates, argillite, oil shale), which was assessed by the yield of chloroform extracts and gas permeability (carbonate, argillite) before and after the treatment of rocks with supercritical СО2. An increase in the permeability of dense potentially oil-source rocks has been noted, which is explained by the dissolution of carbonates to bicarbonates due to the high chemical activity of supercritical СО2 and water dissolved in it. Similarly, in geological processes, the introduction of deep supercritical fluid into sedimentary rocks can increase the permeability and, possibly, the porosity of rocks, which will facilitate the primary migration of hydrocarbons and improve the reservoir properties of the rocks. The considered mechanism of hydrocarbon migration in the flow of deep supercritical fluid makes it possible to revise the time and duration of the formation of gas–oil deposits decreasingly, as well as to explain features in the formation of various sources of hydrocarbons and observed inflow of oil into operating and exhausted wells.

Reliability Analysis of Redundant Dynamic Positioning Control System With Human Factor Involved

2016 ◽  
Author(s):  
Fang Wang ◽  
Yong Bai ◽  
Feng Xu
Keyword(s):  
Control System ◽  
Markov Process ◽  
Reliability Analysis ◽  
Oil And Gas ◽  
Dynamic Positioning ◽  
Positioning Control ◽  
Safety And Reliability ◽  
Long Time ◽  
Component Failure Rates ◽  
Technical Failures

Deepwater oil and gas explorations bring more safety and reliability problems for the dynamically positioned vessels. With the demands for the safety of vessel crew and onboard device increasing, the single control architecture of dynamic positioning (DP) system can not guarantee the long-time faultless operation for deeper waters, which calls for much more reliable control architectures, such as the Class 2 and Class 3 system, which can tolerate a single failure of system according to International Maritime Organization’s (IMO) DP classification. The reliability analysis of the main control station of DP Class 3 system is proposed from a general technical prospective. The fault transitions of the triple-redundant DP control system are modeled by Markov process. The effects of variation in component failure rates on the system reliability are investigated. Considering the DP operation involved a human-machine system, the DP operator factors are taken into account, and the human operation error failures together with technical failures are incorporated to the Markov process to predict the reliability of the DP control system.

scholarly journals Fluid geochemistry of the Jurassic Ahe Formation and implications for reservoir formation in the Dibei area, Tarim Basin, northwest China

2018 ◽  
Vol 36 (4) ◽  
pp. 801-819 ◽  
Author(s):  
Shuangfeng Zhao ◽  
Wen Chen ◽  
Zhenhong Wang ◽  
Ting Li ◽  
Hongxing Wei ◽  
...  
Keyword(s):  
Natural Gas ◽  
Tarim Basin ◽  
Oil And Gas ◽  
Northwest China ◽  
Source Rocks ◽  
Coal Measure ◽  
Hydrocarbon Generation ◽  
Gas Reservoirs ◽  
Isotopic Analyses ◽  
Jurassic Coal

The condensate gas reservoirs of the Jurassic Ahe Formation in the Dibei area of the Tarim Basin, northwest China are typical tight sandstone gas reservoirs and contain abundant resources. However, the hydrocarbon sources and reservoir accumulation mechanism remain debated. Here the distribution and geochemistry of fluids in the Ahe gas reservoirs are used to investigate the formation of the hydrocarbon reservoirs, including the history of hydrocarbon generation, trap development, and reservoir evolution. Carbon isotopic analyses show that the oil and natural gas of the Ahe Formation originated from different sources. The natural gas was derived from Jurassic coal measure source rocks, whereas the oil has mixed sources of Lower Triassic lacustrine source rocks and minor amounts of coal-derived oil from Jurassic coal measure source rocks. The geochemistry of light hydrocarbon components and n-alkanes shows that the early accumulated oil was later altered by infilling gas due to gas washing. Consequently, n-alkanes in the oil are scarce, whereas naphthenic and aromatic hydrocarbons with the same carbon numbers are relatively abundant. The fluids in the Ahe Formation gas reservoirs have an unusual distribution, where oil is distributed above gas and water is locally produced from the middle of some gas reservoirs. The geochemical characteristics of the fluids show that this anomalous distribution was closely related to the dynamic accumulation of oil and gas. The period of reservoir densification occurred between the two stages of oil and gas accumulation, which led to the early accumulated oil and part of the residual formation water being trapped in the tight reservoir. After later gas filling into the reservoir, the fluids could not undergo gravity differentiation, which accounts for the anomalous distribution of fluids in the Ahe Formation.

scholarly journals Removal of Hydrogen Sulfide (H2S) Using MOFs: A Review of the Latest Developments

2020 ◽  
Vol 2 (1) ◽  
pp. 27
Author(s):  
Amvrosios G. Georgiadis ◽  
Nikolaos D. Charisiou ◽  
Ioannis V. Yentekakis ◽  
Maria A. Goula
Keyword(s):  
Hydrogen Sulfide ◽  
Oil And Gas ◽  
Great Promise ◽  
New Developments ◽  
Specific Heats ◽  
Gas Streams ◽  
Long Time ◽  
Metal Organic ◽  
Bed Stability ◽  
Made In

The removal of hydrogen sulfide (H2S) from gas streams with varying overall pressure and H2S concentrations is a long-standing challenge faced by the oil and gas industries. The present work focuses on H2S capture using metal–organic frameworks (MOFs), in an effort to shed light on their potential as adsorbents in the field of gas storage and separation. MOFs hold great promise as they make possible the design of structures from organic and inorganic units, but also, they have provided an answer to a long-time challenging issue, i.e., how to design extended structures of materials. Moreover, the functionalization of the MOF’s surface can result in increased H2S uptake. For example, the insertion of 1% of a fluorinated linker in MIL-101(Cr)-4F(1%) allows for enhanced H2S capture. Although noticeable efforts have been made in studying the adsorption capacity of H2S using MOFs, there is a clear need for gaining a deeper understanding in terms of their thermal conductivities and specific heats in order to design more stable adsorption beds, experiencing high exothermicity. Simply put, the exothermic nature of adsorption means that sharp rises in temperature can negatively affect the bed stability in the absence of sufficient heat transfer. The work presented herein provides a detailed discussion by thoroughly combining the existing literature on new developments in MOFs for H2S removal, and tries to provide insight into new areas for further research.

scholarly journals Challenges and their remedies while cementing production casing in high-temperature wells

2019 ◽  
pp. 39-46
Author(s):  
Vasiliy P. Ovchinnikov ◽  
Pavel V. Ovchinnikov ◽  
Alexander V. Melekhov ◽  
Oksana V. Rozhkova
Keyword(s):  
Oil And Gas ◽  
High Strength ◽  
Oil Well ◽  
Hydrocarbon Production ◽  
New Methods ◽  
Oil And Gas Fields ◽  
Deep Wells ◽  
Long Time ◽  
Gas Fields ◽  
Reliable Isolation

The development of the global oil industry is closely related to the exploration of new oil and gas fields through the drilling new deep and ultra-deep wells, as well as the application of modern methods of hydrocarbon production. Usage of new methods of production, increasing the depth of the wells, bottomhole temperatures and pressures sets strict requirements and restrictions for the applied plugging materials. Oil well cements must have a long time of thickening to successfully complete the cementing process, grouting stone must have high strength characteristics, heat-resistant properties at high temperatures and provide reliable isolation of the annulus, also have corrosion resistance, ensure durability of the well lining.

scholarly journals New representations on oil and gas origin in connection with the opening of the phenomenon of reserves replenishment in exploited oil fields

Georesursy ◽  
2019 ◽  
Vol 21 (4) ◽  
pp. 34-39
Author(s):  
Azariy A. Barenbaum
Keyword(s):  
Oil And Gas ◽  
Oil Fields ◽  
Main Role ◽  
Economic Activities ◽  
Gas Formation ◽  
Long Time ◽  
New Ideas ◽  
Origin Of Oil ◽  
Water Cycles

New ideas about the origin of oil and gas are discussed. They are caused by the discovery of the phenomenon of replenishment of oil and gas reserves in exploited fields. This phenomenon was discovered by the Russian geologists a quarter of a century ago, and a little later it was theoretically justified on the basis of the biosphere concept of oil and gas formation. As a result, the well-known «organic hypothesis» and «mineral hypothesis», which have long time competed in oil and gas geology are being replaced by new representations today, according to which oil and gas are the inexhaustible useful fossils of our planet. And their deposits are traps of movable carbon that circulates via the Earth’s surface in three main cycles with periods of ~108-109, ~106 -107 and ≈ 40 years. The 40-year carbon biosphere cycle, which was not previously taken into account at all, plays a main role in replenishment of deposits. Its accounting makes it possible to balance the carbon and water cycles in the biosphere, taking into account the economic activities of people and modern formation of oil and gas in the bowels, and also open up the possibility of exploiting deposits as constantly replenished sources of hydrocarbons.

The Characteristic of Oil and Gas Accumulation and Main Factors of Reservoir Enrichment in SZ36-1 Region

2015 ◽  
Vol 737 ◽  
pp. 859-862
Author(s):  
Hui Zhi Hao ◽  
Li Juan Tan
Keyword(s):  
Oil And Gas ◽  
Normal Pressure ◽  
Hydrocarbon Reservoirs ◽  
Hydrocarbon Accumulation ◽  
Reservoir Rocks ◽  
Sand Body ◽  
Cap Rock ◽  
Shahejie Formation ◽  
Reservoir Type ◽  
Migration Pathways

The hydrocarbon reservoirs which have been found in SZ36-1 region are located in Liaoxi low uplift and dominated by structural traps. The principle source rock is the first and the third member of the Neogen Shahejie Formation and the main reservoir type is delta sand body which mainly located in the second member of Shahejie Formation. Oil reservoirs are mostly in normal pressure and are possess characteristic of late hydrocarbon accumulation. Hydrocarbon accumulation is mainly controlled by fault,reservoir-cap rock combination, and petroleum migration pathways. Lateral distribution of hydrocarbon reservoirs is mostly controlled by reservoir rocks, while the vertical distribution is controlled by fault.

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