Hydrocarbon migration and accumulation along a long-term growth fault: Example from the BZ25-1 oilfield of Bohai basin, eastern China

Cheng, Zhongqi; Xie, Xinong; Jiang, Tao; Liu, Xiaofeng

doi:10.1016/j.gexplo.2005.11.032

Cited by 6 publications

(5 citation statements)

References 5 publications

(3 reference statements)

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“…The connection between the reservoirs (main deep reservoir and intermediate reservoirs) and these extrados faults shows the path fluids may follow. Indeed, the long‐term growth fault acts as the main hydrocarbon migration pathway [ Zhang et al , 2006]. The fault system serves as a preferential conduit for fluid flow toward the seafloor, analogous to observations by Papatheodorou et al [1993] and Bøe et al [1998].…”

Section: Fluid Conduits and Subsurface Fluid Circulationmentioning

confidence: 97%

Dynamics of fault-fluid-hydrate system around a shale-cored anticline in deepwater Nigeria

et al. 2011

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[1] Gas hydrates were recovered by coring at the eastern border of a shale-cored anticline in the eastern Niger Delta. To characterize the link between faults and fluid release and to identify the role of fluid flow in the gas hydrate dynamics, three piezometers were deployed for periods ranging from 387 to 435 days. Two of them were deployed along a major fault linked to a shallow hydrocarbon reservoir while the third monitored the fluid pressure in a pockmark aligned above the same major fault. In addition, 10 ocean-bottom seismometers (OBS) were deployed for around 60 days. The piezometers simultaneously registered a prolonged fluid flow event lasting 90 days. During this time, OBS measurements record several episodic fluid release events. By combining and analyzing existing and newly acquired data, we show that the fluid-fault system operates according to the following three stages: (1) upward pore fluid migration through existing conduits and free gas circulation within several shallow sandy layers intersecting the major fault, (2) gas accumulation and pore pressure increases within sandy-silty layers, and (3) hydrofracturing and fluid pressure dissipation through sporadic degassing events, causing pore fluid circulation through shallow sandy layers and drawing overlying seawater into the sediment. This paper clearly demonstrates how an integrated approach based on seafloor observations, in situ measurements, and monitoring is essential for understanding fault-fluid-hydrate systems. Citation: Sultan, N., et al. (2011), Dynamics of fault-fluid-hydrate system around a shale-cored anticline in deepwater Nigeria,

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Section: Fluid Conduits and Subsurface Fluid Circulationmentioning

confidence: 97%

Dynamics of fault-fluid-hydrate system around a shale-cored anticline in deepwater Nigeria

et al. 2011

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“…Alternatively, it can be obtained by directly testing core samples in the laboratory using methods like gas testing, mercury intrusion porosimetry, and image analysis. If core samples are not available, both the compacted burial depth (which can be replaced with the present burial depth if the overlying strata have not undergone uplift and denudation) and shale content (obtained by Equations ( 2) and (3) [32] using natural gamma logging data) can be substituted in Equation (1) to calculate the porosity of reservoir rocks.…”

Section: Methods For Evaluating Lateral Sealing Of Faultsmentioning

confidence: 99%

“…This will allow for the calculation of the shale content of fault rocks. Secondly, substitute the calculation results into Equation (1) to derive the relationship between the porosity of surrounding rocks with identical shale content as the fault rocks and their compaction depth (Figure 4). Finally, the geologic period corresponding to the compaction depth is obtained via stratigraphic paleo-burial depth recovery [34], and the aforementioned relationship is adjusted from the period when surrounding rocks stopped depositing (T m ) to the period when faults ceased activity (T 0 ) (Figure 4).…”

Section: Methods For Evaluating Lateral Sealing Of Faultsmentioning

confidence: 99%

“…Numerous studies have shown that faults play a dual role in hydrocarbon accumulation in clastic strata, serving as both migration pathways for hydrocarbon transport [1,2] and lateral sealing objects for hydrocarbon accumulation [3,4]. When operating as lateral sealing objects, the effectiveness of fault traps and their degree of hydrocarbon filling are controlled by the lateral closure of the fault [5,6].…”

Section: Introductionmentioning

confidence: 99%

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Evaluation of Lateral Sealing of Faults Based on Porosity: A Case Study of the F1 Fault of the Nanpu No. 5 Structure in the Nanpu Sag

Zhang,

Yu,

Zhang

et al. 2024

Energies

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The lateral sealing of a fault plays a pivotal role in the efficacy of a fault trap and its degree of hydrocarbon filling. Nevertheless, the evaluation of this phenomenon remains a challenging task, with evaluation methods either unable to accurately reflect subsurface reality or obtaining the necessary parameters difficult. In light of these considerations, a porosity-based fault laterality evaluation method was proposed, with the F1 Fault of the Nanpu No. 5 structure in the Nanpu Sag serving as the research object. First, the relationship between porosity and the product of burial depth and shale content was established using measured porosity, burial depth, and shale content data of the surrounding rocks in the study area. Subsequently, the reservoir rock porosity was obtained by employing logging data or core samples or by calculating the reservoir rock shale content from natural gamma logging data. Concurrently, the shale content of fault rock was calculated using three-dimensional (3D) seismic data, mud logging data, and natural gamma logging data, thereby enabling its porosity to be determined. Finally, the porosity difference between the two was employed to assess the lateral closure of faults. The results indicate that the porosity difference is less than 0 at lines L1~L3 of the F1 Fault, which suggests that the fault is not laterally closed at this site. Conversely, the F1 Fault is laterally sealed at this location, as indicated by the porosity difference being greater than 0 at lines L4~L10. The findings of this evaluation were found to be in close alignment with the actual distribution of oil and water, indicating that the proposed method can accurately evaluate the lateral closure of faults with developed fault rocks and provide valuable guidance for the exploration of faulted oil and gas reservoirs.

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“…The migration of hydrocarbons controls hydrocarbon accumulation, and it has been widely accepted that faults are the secondary migration pathway for hydrocarbons. This can become the main controlling factor of oil and gas accumulation in faulted basins, in particular [15][16][17][18][19][20]. However, the controlling factors of oil and gas distribution in structurally complex reservoirs such as the Wang Guantun area in the Bohai Bay Basin with well-developed growth faults are still unclear and require further studies.…”

Section: Introductionmentioning

confidence: 99%

Mechanism Study of Hydrocarbon Differential Distribution Controlled by the Activity of Growing Faults in Faulted Basins: Case Study of Paleogene in the Wang Guantun Area, Bohai Bay Basin, China

Wang

Zhou

et al. 2022

Lithosphere

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Mechanisms that lead to different quantities of hydrocarbon accumulation in complex fault blocks are a major subject that impacts further development plans of oil and gas fields. To better understand such mechanisms, fault activity has been interpreted along with existing electron micrographs from the fault zone, petrophysical data, and the occurrence of the seismic pump. This enabled us to investigate the controlling mechanisms of the growth faults and other associated faults with the main growth fault in the Wang Guantun area that could have impacted hydrocarbon distribution. The results showed that the activity of Kongdong growth fault is periodic and intermittent, which produced strong seismic pumping action. Furthermore, a series of secondary faults were generated in adjacent strata due to the fault activity, which could have led to the formation of a secondary seismic pump source. A combination of these two incidents is believed to influence the differential distribution of hydrocarbons in the area, in fault-associated reservoirs. Ultimately, we correlated the activity of the growth fault to the strength of the pumping force causing the distribution of hydrocarbons in the active parts of the faults (pump source position) on the horizontal plane and vertically located reservoirs to be more dominant.

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Hydrocarbon migration and accumulation along a long-term growth fault: Example from the BZ25-1 oilfield of Bohai basin, eastern China

Cited by 6 publications

References 5 publications

Dynamics of fault-fluid-hydrate system around a shale-cored anticline in deepwater Nigeria

Dynamics of fault-fluid-hydrate system around a shale-cored anticline in deepwater Nigeria

Evaluation of Lateral Sealing of Faults Based on Porosity: A Case Study of the F1 Fault of the Nanpu No. 5 Structure in the Nanpu Sag

Mechanism Study of Hydrocarbon Differential Distribution Controlled by the Activity of Growing Faults in Faulted Basins: Case Study of Paleogene in the Wang Guantun Area, Bohai Bay Basin, China

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