Seismic Sections Research Articles

Fault-karst systems in the deep Ordovician carbonate reservoirs in the Yingshan Formation of Tahe Oilfield Tarim Basin, China

Fault-karst systems in deep and ultra-deep carbonate reservoirs have a huge potential for hydrocarbon exploration. However the characteristics of reservoir space and the main controlling factors of fault-karst reservoirs are unclear due to strong heterogeneity. Therefore, the exploration and development of deep and ultra-deep carbonate reservoirs are restricted. To fill the gap, core, thin section and well log (conventional logs and image logs) data are used to analyze the lithology and main reservoir space in the deep Ordovician reservoirs in the Tahe Oilfield, Tarim Basin, China. The lithologies are dominated by intraclastic limestone, dolomitic limestone and silt to fine-sized crystalline dolostone. The reservoir space mainly includes dissolution vug, fracture, fracture-vug and cave. Among them, caves and their surrounding fractures are the main storage spaces for hydrocarbons in the Ordovician reservoir. Four fault-karst systems are divided including “V” shape, “U” shape, “layer” shape and compound type according to the morphology of the seismic section. In addition, the reservoir space of different fault-karst systems is clarified using image logs. Combined with drilling data, it is found that the reservoir scale of “U” shape fault-karst system is larger, while that of “layer” shape fault-karst system is smaller. In addition, the direction of maximum horizontal in-situ stress is NE-SW determined by induced fractures picked up by image logs. The NE orientation faults and fractures are increased and the effect of karst fluid on reservoirs is enhanced. However, the NW direction faults and fractures are restricted. Therefore, the fault-karst system is mainly observed along the NE main fault. The fluid alteration has two influences on the reservoir quality. On the one hand, the fluid alteration can dissolve the carbonate rocks and expand the reservoir scale; on the other hand, the fluid will carry mud and sand, which will reduce the reservoir space scale. The distance from the fault will affect the types of reservoir space of the fault-karst system. Away from the fault, the reservoir space will change from caves and fractures to facture-vug, and finally into small-scale dissolution vugs. Therefore, it should not only pay attention to seismic beads features but also to the size of available reservoir space on logging during drilling. This study can provide insight into the different types of fault-karst system models, and help clarify the main controlling factors of the fault-karst system scale.

Three-Dimensional Integrated Geo-Static Modeling for Prospect Identification and Reserve Estimation in the Middle Miocene Multi-Reservoirs: A Case Study from Amal Field, Southern Gulf of Suez Province

Middle Miocene reservoirs in the southern part of the Gulf of Suez province are characterized by geometrical uncertainties due to their structural settings, lateral facies change, different lithologies, and diverse reservoir quality. Therefore, in this study, detailed 3D geo-static models were constructed by integrating multiple datasets, including 2D seismic sections and digital well-logs. The 3D models were constructed for the Belayim Formation (Hammam Faraun Member), Kareem Formation (Markha Member), and Rudies Formation (Upper Rudies Member) with detailed structuration, zonation, and layering for Amal Field in the southern Gulf of Suez province to assess the hydrocarbon potential, calculate accurate reserves, recommend development and exploration plans, and propose locations for future drilling. The resultant structural model exhibited a compartmentalized area of major and minor normal faults trending NW–SE, forming structurally high potential hydrocarbon trapping locations in the study area. The petrophysical models indicated the good potentiality of Hammam Faraun as a reservoir with porosity values of 15–23%, increasing towards the central part of the area, volume of shale (Vsh) of 21–31%, water saturation (Sw) of 34–49%, and sand thickness increasing toward the northeastern part of the area. The Markha Member was also interpreted as a good reservoir, with porosity values of 15–22%, increasing towards the southeastern part of the area, Vsh of 13–29%, Sw of 16–38%, and sandy facies accumulating in the central horst block. Upper Rudies exhibits good reservoir properties with porosity values of 16–23%, Vsh of 29–37%, Sw of 35–40%, and good sandy facies in the central horst block of the area. The study results showed hydrocarbon potential in the central horst block of the study area for the Middle Miocene multi-reservoirs.

The Upper Cretaceous petroleum system of the East Beni Suef Basin, Egypt: an integrated geological and 2D basin modelling approach

We integrated geological and 2D basin modelling to investigate the tectonostratigraphic evolution of the East Beni Suef Basin (EBSB) of north central Egypt and its implications for the Upper Cretaceous petroleum system. Two intersecting seismic sections and three exploration wells were used for this study. The geological model defines the structural and geometrical framework of the basin, which formed the basis for subsequent 2D basin modelling. The developed basin models were calibrated and fine-tuned using vitrinite reflectance and corrected temperature data. Modelling results indicate that the Abu Roash ‘F’ source-rock maturity ranges from the early oil window at the basin margins to the main oil window in the centre. The main phase of hydrocarbon generation occurred during the Eocene after trap formation in the Late Cretaceous. Generated hydrocarbons have migrated both laterally and vertically, most likely from the central part of the basin towards the basin margins, particularly eastwards to the structural traps. The model predicts low accumulation rates for the EBSB, which are caused by the ineffective sealing capacity of the overburden rocks and normal faults. In addition to the proven kitchen for the charging of the Abu Roash ‘E’ reservoirs, an additional kitchen area to the NW of the basin is suggested for the Abu Roash ‘G’ reservoirs.

Identification and Characterization of Gas Hydrate using Marine Seismic and Well Data: South Makassar Strait case study

Gas hydrate has the potential as an alternative unconventional resource to current oil and gas. Identification of gas hydrate is made possible by applying the seismic method with the main indicator of the bottom simulating reflector (BSR). BSR is characterized on the seismic section by the presence of high amplitudes, reverse polarity reflections, and cutting through the stratigraphy. In this study, the presence and thickness of the gas hydrate zone have been identified using five 2D seismic tracks, namely CM02-57, SM93-06 SM93-08, SM93-09 and SM93-11, and the SULTAN-1 well. The gas hydrate zone was identified at a depth of about 2300 m. The existence of the gas hydrate zone is followed by the presence of a gas chimney indicator as a free gas migration path. The gas hydrate zones are estimated to be 15 m, 28 m, 33 m, 23 m, and 30 m thick from the respective seismic tracks CM02-57, SM93-06 SM93-08, SM93-09 and SM93-11.

Hybrid thrust sequences – A new structural perspective

Thrust sequences show a range of geometric and kinematic characteristics in cross-sections and in map view. Two types of thrust sequences are commonly observed in thrust systems – forward-breaking and break-back thrust sequences. For nearly half a century, it has been hypothesized that forward-breaking and break-back thrust sequences represent end-members of a continuous spectrum of brittle and ductile structures. Many natural and experimental observations of transitional thrust sequences display both forward-breaking and break-back (hybrid) thrust sequences within the same thrust system. An explanation of hybrid thrust sequence development has neither been provided conceptually nor experimentally. We present geometric and kinematic results of natural observations and numerical experiments that show a transition from forward-breaking to break-back thrust sequences caused by the effects of stratigraphic variations, sedimentary environment, surface processes, critical-wedge effects, progressive deformation with an increase in compressive stress, presence of detachments and their frictional properties, and strain rate. We also discuss numerous geometric, kinematic, chronological and mechanical criteria to identify the characteristic signatures of hybrid thrust sequences. This study provides a template to distinguish different thrust sequences and to characterize the deformation conditions under which hybrid thrust sequences develop in contractional settings. Mechanical and field criteria, displacement patterns imaged on seismic reflection sections across onshore and offshore thrust systems, and the way that thrusts interact in terms of geometry, kinematics and strain, are used to illustrate thrust development.

Delineation of Subsurface Structural Geology in Buzrgan Oil Field Using 2D Seismic Interpretation

This study focuses on the structural picture interpretation of Buzurgan oil field in the Maysan province of southern Iraq. Using 2D seismic data, Synthetic traces are created by selecting reflectors on the seismic section using the Petrel software and the well (BU-1) data currently available. The reflectors represented Paleocene to middle Miocene, which are L-Fars-Kirkuk-Jaddala-Aaliji. A thrust fault that solely impacts the L-Fars formation is dividing the research region into two blocks that are each affected by the examined reflectors. The fault system extends from northwest to southeast. The structural interpretation of depth maps reveals that some anticline folds were localized roughly surrounding well locations were marked on all maps.

A novel seismic full waveform inversion approach for assessing the internal structure of a medieval sea dike

AbstractCoastal protection in the form of dike constructions has a long history at the German North Frisian coast dating back to the High Middle Ages. As the vast majority of the dikes built prior to the devastating storm surges of the Middle Ages have been irretrievably destroyed, mostly sparse remains and only a few well preserved of these medieval dikes are found along the German North Frisian coast and within the Wadden Sea. Not all details of their construction and dimensions are yet understood. In the present case study, we investigate the historical Schardeich on the island of Pellworm in the German North Sea in a noninvasive way using shear waves (SH‐waves). For the data interpretation, we applied a combination of seismic full waveform inversion and classical seismic reflection imaging to determine the interior structure of the dike and its underlying layers at the highest possible resolution. The results obtained on land are compared with dike remains found in the tidal flats. These remains show up in marine seismic sections as characteristic reflections, which probably represent a compaction layer caused by the load of the former dike. For ground truthing, we compare the seismic results with internal dike structures found in nearby excavations. The comparison highlights that FWI is a reliable tool for near‐surface archaeological prospecting. We find that SH‐wave FWI provides decimetre‐scale velocity and density models that allow, together with the seismic reflection section, to determine distinct construction phases of the dike. The investigated dike further shows a depression at base level of about 0.75 m, which is of the same order as observed for the dike base reflections in the tidal flats. Transferring these findings to the dike remains mapped in the tidal flats, we derive a height of the former dike from 2.2 to 4.4 m.

An expanded idea of imaging in geophysics through multimodal data analysis

In situations where visual stimuli are uncertain or degraded, auditory perception is crucial and can complement visual perception. Research on multimodal perception has confirmed in many areas of study that the existence of one stimulus can impact the perception of another type of stimulus. Based on these concepts, which are well-established in cognitive sciences, we introduce the idea of expanded (or augmented) imaging in geophysics, which refers to an integrated and coherent data representation based on dual-sensory (audiovisual) perception of the same data set. First, we explain the basic principles of multimodal analysis of seismic data using the theory of augmented imaging. Then, we provide examples and applications on real data at varying spatial scales, from individual seismic traces to entire seismic sections.

Innovative land seismic investigations for CO2 geologic storage in Denmark

The increasing global interest in geologic carbon storage as a feasible way of reducing CO2 atmospheric levels requires extensive onshore high-resolution seismic investigations to characterize suitable storage sites, for example, close to major CO2 emitters. To partly address this challenge and to acquire quality data at shallower and greater depths in a cost- and time-effective approach, a tailored acquisition scheme is adopted and tested at a candidate site in Stenlille, Denmark. The survey aims to understand whether an anticline reservoir structure known to exist at a 1000 m depth can serve for long-term CO2 storage and presents the structural integrity for this purpose. The data are recorded using a combination of nodal arrays, spaced at 10 m in a fixed geometry, and a set of more closely (2 m) spaced digital recorders, mounted on a landstreamer, which was moved at each shot location. Two 12 t mini vibrators are used as seismic sources. The nodal and landstreamer data sets are compared and combined into a unique data set for reflection imaging purposes along five profiles with a total length of approximately 12 km. The seismic sections obtained using this tailored combination of different recorders provide images of the entire shallow and deeper structures with an unprecedented resolution at the different depth levels necessary to assess the full potential of the suggested CO2 storage reservoir. The results significantly increase the existing knowledge of the extent and structural closure of the reservoir as well as a possible fault, all of which are critical for future risk analysis and planning of the storage.

Regional stratigraphically discordant dolomite mapping based on a dolomitization mechanism on the Arabian carbonate shelf

Dolomite mapping, as a first step of carbonate diagenetic modeling, is critical to understanding dolomitization mechanisms and predicting reservoir quality. Stratigraphically discordant dolomite bodies within the Upper Jurassic intervals have long been studied on the Arabian shelf. Our dolomitization mechanisms find that faults/fractures serve as migration conduits and determine dolomite distribution by controlling fluid flow. We establish an innovative approach based on the diagenetic mechanisms and comprehensive characterization of fracture systems at multiple scales to delineate dolomite in the study area. The complex fracture networks in the subsurface are categorized into macroscale, mesoscale, and microscale fractures. Macroscale fractures, i.e., faults, are much greater than the seismic wavelength and are easily observed in seismic sections due to their obvious seismic discontinuities. Mesoscale fractures are slightly greater than or equal to the seismic wavelength and are recognized using seismic attributes. Microscale fractures are significantly smaller than the seismic wavelength and are observed mainly on core samples and thin sections. The dolomite mapping workflow includes three steps: (1) calibrate the seismic response of multiscale fractures with borehole image logs and core interpretations, (2) implement multiscale fracture characterization using multiple seismic attributes, and (3) interpret dolomite bodies based on fracture characterization and log identification. The mapping results show that massive dolomite bodies are heterogeneously developed and distributed mainly in the northeastern part of the study area, with a southward decrease in dolomite content. The application demonstrates that multiscale fracture systems play critical roles in massive dolomitization, and multiscale fracture prediction provides an innovative solution to delineate complex dolomitization systems and the combination of reservoir and seal in diagenetic traps.

Bayesian linearized rock-physics amplitude-variation-with-offset inversion for petrophysical and pore-geometry parameters in carbonate reservoirs

Rock-physics amplitude-variation-with-offset (AVO) inversion aims at directly predicting reservoir properties from prestack seismic data. However, carbonate reservoir rocks often develop complex pore structures, which limits the application of conventional inversion methods with fixed pore-geometry parameters. We derive a PP-wave reflectivity equation in terms of porosity, water saturation, and pore-aspect ratio and we develop a rock-physics AVO inversion method to jointly estimate the petrophysical and pore-geometry parameters in carbonates. The reflectivity equation is obtained by linearizing the rock-physics model based on the differential effective medium model and Gassmann’s equation using Taylor series approximation, and we combine the linearization with the Aki-Richards equation. Thanks to the linearized model, the analytical solution to the inverse problem is derived using Bayesian linear theory. Our solution combines simulated annealing to estimate the prior information of the pore geometry and the iterative Bayesian inversion to update the posterior model. The method is tested on a benchmark data set and compared with conventional methods with a fixed aspect ratio. The results show that our method improves the petrophysical results. The method is also compared with two-step and nonlinear inversion methods to demonstrate its advantages. The method is applied to a field seismic section from a carbonate reservoir with a complex pore structure to demonstrate its advantages in terms of prediction accuracy.

Gas Hydrates, Subsurface Structures and Tectonic Features of the Tuaheni Landslide Complex in the Northern Hikurangi Margin, New Zealand, Revealed by Seismic Attribute Analysis

The Tuaheni Landslide Complex, located on the upper slope of the northern Hikurangi Margin in New Zealand, is a unique place to research on slow slip creep-like deformation and seabed failure, as well as their possible relationship with the presence of gas hydrates, cold seeps, and fluid migration. Based on the visual interpretation of seismic data, it is sometimes very difficult to identify various subsurface structures and tectonic features. We study certain seismic attributes, namely the reflection strength, instantaneous frequency, instantaneous phase, and the Hilbert transform, in the Tuaheni Landslide Complex and observe that these attributes play a very important role in identifying and interpreting various subsurface geological features and bed boundaries that are not clearly visible in the seismic sections. In general, these seismic attributes are studied to identify hydrocarbons such as oil and gas. However, in this present study these seismic attributes nicely illustrate the fluid migration pathways, the decollement of the sediment slide, the base of the debris flow, the base of the deformed sediment and gas migration, etc., along two perpendicular seismic profiles crossing the Site U1517 of IODP Expedition 372. The instantaneous phase and Hilbert transform attribute depict the bed boundaries and discontinuities, whereas the reflection strength and instantaneous frequency attributes characterize the various strata in terms of whether they are associated with fluid at their bases. The possible role of tectonic activity and seafloor slope failure due to gas hydrate dissociation and vice versa is clearly visible through fluid-filled weak zones in the seismic attribute volumes. Gas hydrates are dissociating and BSRs are abruptly pinching out towards the seafloor due to the movement of hot fluid and free gas, enhancing seafloor sliding and local tectonic activities together.

Highlighting relationships between sand thicknesses, reservoir-seal pairs and paleobathymetry from a sequence stratigraphic perspective: An example from Tortonian Serravallian deposits, onshore Niger Delta Basin

The utilization of sequence stratigraphic concepts in identifying sands and their spatial continuity in distinct gross depositional settings is key, especially in frontier settings where data paucity is a common challenge. In the Baka field, onshore Niger Delta, detailed reservoir correlation guided by sequence stratigraphic framework analysis showed the distribution of sand and shale units constituting reservoir-seal pairs (RSP) correlatable across the field. Within the 3rd-order packages, it is observed that the lowstand systems tract (LST) and highstand systems tract (HST) contain more RSPs and thicker 4th- and 5th-order sands than the transgressive systems tract (TST). In terms of bathymetry, it is noted that irrespective of systems tracts, the RSP Index (RI) decreases from the proximal shallow/inner shelf settings to the more distal outer shelf areas. Amongst all three systems tracts, intervals interpreted as lowstand prograding complexes contain the best developed sands and highest RSP. Sand development within the LSTs has been controlled by a pronounced growth fault regime accompanied by high subsidence and sedimentation rates. This is linked to the basinward migration of the sands during prolonged sea-level fall, creating significant accommodation space for sand deposition. On the other hand, the TSTs known to mark periods of progressive sea-level rise and landward migration of sandy facies, show thinner sands enclosed in much thicker, laterally extensive, and better-preserved deeper marine shales. Interpreted seismic sections indicate intense growth faulting and channelization that influenced the syn- and post-depositional development of the sand packages across the field. The initial timing of deformation of sub-regional faults in this area coincides with periods of abrupt falls in sea level. This approach could be useful for predicting sand-prone areas in frontier fields as well as possible reservoir-seal parameters required for some aspects of petroleum system analysis and quick-look volume estimation.

Identification of structural & tectonic features and prospects of oil and gas potential in the northwestern part of Shimali Absheron uplift

In this thesis, based on geological and geophysical data from zone of uplift in Northwestern part of Shimali Absheron (Northern Absheron), it was considered clarifying the geological structure involved in the Pliocene section, in particular, the Podkirmaky suite (PK). It was established that, several non-anticline (stratigraphic and tectonically screened) traps that are formed in the traced zones of pinching out of the Podkirmaky formation (PK). As a result of the studies, the reservoir properties of the deposits corresponding to Podkirmaky suite (PK) and the Nadkirmaky sandy suite (NKP) (which are characterized by high NetToGross) were studied. A re interpretation of seismic sections (in time and depth) of past and recent years was carried out, together with well data, and a structural map of Podkirmaky suite (PK) was build. Keywords: uplift zone; seismic exploration; geological structure; productive series (PS); pinch-out zone; non-anticline trap; oil and gas content; seismic section in time and in depth.

Crustal structure beneath the Jiamusi Block and the Nadanhada Terrane from seismic and magnetotelluric studies: Implications for the subduction of the Pacific Plate

The Nadanhada terrane is considered to accrete to the eastern end of the Jiamusi Block during the Pacific Plate subduction. Constraints on the deep structure of the Nadanhada terrane and Jiamusi Block are essential to study the evolution, transformation and current activity of the eastern Asian continental margin. To reconstruct the accretion processes, two magnetotelluric sounding sections and a seismic reflection section were conducted in the eastern part of Jiamusi Block, the middle, and the southern end of the Nadanhada terrane respectively. Geophysical data revealed resistant stable structures and west-dipping discontinuous reflections with a thickness of around 15 km in the upper crust of Jiamusi Block. In contrast, the lower crust of the Jiamusi block exhibited high conductivity and short sub-horizontal reflections that suggest upwelling of mantle material under Pacific Plate subduction. Moreover, the low resistivity zone observed connecting the shallow crust with the upper mantle in the Tongjiang-Yuejinshan fault was interpreted as the boundary line between the Jiamusi block and Nadanhada terrane. The Nadanhada terrane can be subdivided into the Yuejinshan and Raohe complexes based on their distinct geophysical features. The Yuejinshan Complex is characterized by irregular bodies with high resistivity and short arc reflections with a thickness of about 10 km. In contrast, the Raohe Complex displays high-resistivity blocks and west-dipping thrust nappe strong reflections with a thickness of about 5 km. Additionally, the high-conductivity layer located between the Raohe Complex and the underlying basement is believed to be the detachment zone. Since the Cretaceous, the continuous subduction of the Pacific Plate has caused magmatism that has led to the high conductivity crust. The observation of low-resistivity channels and arcuate reflections within the crust supports the notion of upwelling of mantle-derived materials brought about by the subduction of the Pacific Plate in the Cenozoic era.

The Upper Jurassic sediments, Marib-Shabwa Basin, Yemen: Lithofacies aspects and sequence stratigraphic analysis

The present study is devoted to understanding the evolution of the Upper Jurassic Sab'atayn Formation in the Marib-Shabwa Basin, Yemen, through a sequence stratigraphic analysis based on integrating datasets of sedimentology, seismic sections, and well logs. The Sab'atayn Formation (Tithonian age) is represented by a series of clastic and evaporites that were deposited under fluvio-deltaic to prodeltaic settings. It is divided into four members including Yah (at the base), upwards to Seen, Alif, and Safir at the top. Two third-order depositional sequences were determined for the Tithonian succession which were separated by three sequence boundaries. These sequences were classified into their systems tracts signifying several sedimentation patterns of progradational, aggradational, and retrogradational parasequence sets. The first depositional sequence corresponds to the early-middle Tithonian Yah and Seen units that can be classified into lowstand, transgressive, and highstand systems tracts. The second sequence comprises the late Tithonian Alif unit that can be subdivided into transgressive and highstand systems tracts. The sandy deposits of the Alif Member (highstand deposits) represent the most productive hydrocarbon reservoir in the basin. The Upper Jurassic sediments in the study area were resulted from a combination of eustatic and tectonic effects.

TECTONIC SCHEME FOR THE AMERASIA BASIN OF THE ARCTIC OCEAN

The tectonic scheme of the Amerasia Basin, as a result of a comprehensive analysis of geological and geophysical data, was created for the first time at 1:2 500 000 scale. The structural framework of the scheme was developed based on the results of basement mapping using reflection seismic sections and its detailing according to potential fields. The results of three-dimensional gravity modeling, presented by Moho depth and consolidated crust thickness calculations were used as basic indicators of the genesis of the crust. Tectonic elements of different ranks and kinematics were identified on seismic sections and traced according to potential fields. The created scheme is the most detailed among the published earlier, it demonstrates the features of the tectonic structure of individual geostructures, their nature and allows us to draw conclusions about the evolution of the Amerasia Basin. The listed issues are discussed in the text of the article.

A Tectonic Scheme for the Amerasia Basin of the Arctic Ocean

A tectonic scheme of the Amerasia Basin was created for the first time on a 1 : 2 500 000 scale on the basis of integrated analysis of geological and geophysical data. The structural framework of the scheme was developed according to the mapping of the basement surface using reflection seismic sections; the surface was detailed on the basis of potential fields. The results of three-dimensional gravity modeling according to calculation of the Moho depths and consolidated earth crust thickness were used as the basic indicators of the origin of the crust. Tectonic elements of different ranks and kinematics were identified on the seismic sections and traced according to the potential fields. The created scheme is the most detailed out of those published previously. It demonstrates the features of the tectonic structure of individual geostructures and their nature and allows us to draw conclusions about the evolution of the Amerasia Basin.

Imaging of post‐collisional deformations on the NE Tisza continental unit using ambient seismic noise: A case study from the Țicău area, Romania

AbstractThe Ţicău area (NW Romania) is part of the collisional zone between the Tisza and Dacia mega‐units. Imaging of Ţicău area's subsurface geological structure will contribute to the understanding of the processes, which controlled its tectonic evolution. Analysis of outcrops provides accurate information for the building of kinematic sections used to explain the small‐scale deformations of sedimentary formations, such as those developed south of the Ţicău mountains. Imaging of large‐scale deformations requires analysis of data recorded and/or measured over a wider area. We use Seismic Interferometry by cross‐correlation on ambient noise recorded along with a line located north of the Ţicău mountains. The passive seismic section obtained after virtual body‐wave reflections processing displays folded and faulted Paleogene formations, which are in good agreement with the observations on outcrops found to the south of the Ţicău mountains. The active‐source data recorded along with the same line are too noisy for interpretation.

Опасные газонасыщенные объекты на акваториях Мирового океана: море Бофорта, шельф Северного склона Аляски

The article is devoted to the study of gas saturation of the upper part of the sedimentary cover in the western sector of the Beaufort Sea adjacent to Alaska. For the first time, the interpretation of the upper part of the seismic sections of CDP (common depth point) seismic survey was performed for 52 seismic lines of the United States Geological Survey (USGS) with a total length of 4050 km. 184 anomalous objects were found in near-bottom sediments, potentially associated with shallow gas accumulations (gas pockets). The average distance between these objects along the seismic lines was 22 km, which is 80% more than in the Chukchi Sea. This is apparently due to less tectonic activity in the Beaufort Sea. The statistically established similarity of anomalous objects in these seas in terms of depths and lengths is due to similar geological conditions for the formation of sedimentary deposits. In addition, 60 seismic lines with a total length of 4390 km show a wide distribution of potential gas hydrate deposits on the continental slope of the Beaufort Sea, which is consistent with the earlier conclusions of the US and Norwegian scientists (K. Andreassen, P. E. Hart, A. Grantz and others).