Journal articles: 'Hydrocarbon-bearing'

1

Zemanek, Joe. "Low-Resistivity Hydrocarbon-Bearing Sand Reservoirs." SPE Formation Evaluation 4, no. 04 (December 1, 1989): 515–21. http://dx.doi.org/10.2118/15713-pa.

Full text

APA, Harvard, Vancouver, ISO, and other styles

2

Harrison, R. K. "Hydrocarbon-bearing nodules from Heysham, Lancashire." Geological Journal 7, no. 1 (April 30, 2007): 101–10. http://dx.doi.org/10.1002/gj.3350070106.

Full text

APA, Harvard, Vancouver, ISO, and other styles

3

Wen, Bo, and Kung K. Wang. "Solution-phase synthesis of bowl- and basket-shaped fullerene fragments via benzannulated enyne–allenes." Pure and Applied Chemistry 84, no. 4 (January 26, 2012): 893–905. http://dx.doi.org/10.1351/pac-con-11-09-03.

Full text

Abstract:

Benzannulated enyne-allenes bearing an aryl substituent at both the alkynyl and allenyl termini are excellent precursors of 5-aryl-11H-benzo[b]fluorenyl derivatives having the carbon frameworks of fullerene fragments. The mildness of the reaction conditions and the availability of several synthetic methods for benzannulated enyne-allenes allow the design of new synthetic pathways leading to bowl- and basket-shaped fullerene fragments. Specifically, a bowl-shaped C28H18 hydrocarbon bearing a 27-carbon framework of C60 and a basket-shaped C56H40 hydrocarbon bearing a 54-carbon framework of C60 were synthesized. The interior 30-carbon core of the C56H40 hydrocarbon can be regarded as a partially hydrogenated [5,5]circulene, a C30H12 semibuckminsterfullerene. In addition, a basket-shaped C56H38 hydrocarbon was also constructed to serve as a precursor toward an end-cap template for (6,6) carbon nanotubes.

APA, Harvard, Vancouver, ISO, and other styles

4

Worthington, Paul F. "Quality-assured evaluation of freshwater-bearing hydrocarbon reservoirs." Journal of Petroleum Science and Engineering 78, no. 2 (August 2011): 542–51. http://dx.doi.org/10.1016/j.petrol.2011.06.008.

Full text

APA, Harvard, Vancouver, ISO, and other styles

5

He, Faqi, Ying Rao, Weihong Wang, and Yanghua Wang. "Prediction of hydrocarbon reservoirs within coal-bearing formations." Journal of Geophysics and Engineering 17, no. 3 (February 25, 2020): 484–92. http://dx.doi.org/10.1093/jge/gxaa007.

Full text

Abstract:

Abstract This paper presents a case study on the prediction of hydrocarbon reservoirs within coal-bearing formations of the Upper Palaeozoic. The target reservoirs are low-permeability low-pressure tight-sandstone reservoirs in the Daniudi Gas Field, Ordos Basin, China. The prime difficulty in reservoir prediction is caused by the interbedding coal seams within the formations, which generate low-frequency strong-amplitude reflections in seismic profiles. To tackle this difficulty, first, we undertook a careful analysis regarding the stratigraphy and lithology of these coal-bearing formations within the study area. Then, we conducted a geostatistical inversion using 3D seismic data and obtained reservoir parameters including seismic impedance, gamma ray, porosity and density. Finally, we carried out a reservoir prediction in the coal-bearing formations, based on the reservoir parameters obtained from geostatistical inversion and combined with petrophysical analysis results. The prediction result is accurately matched with the actual gas-test data for the targeted four segments of the coal-bearing formations.

APA, Harvard, Vancouver, ISO, and other styles

6

Jiang, Zaixing, Hongjie Duan, Chao Liang, Jing Wu, Wenzhao Zhang, and Jianguo Zhang. "Classification of hydrocarbon-bearing fine-grained sedimentary rocks." Journal of Earth Science 28, no. 6 (December 2017): 693–976. http://dx.doi.org/10.1007/s12583-016-0920-0.

Full text

APA, Harvard, Vancouver, ISO, and other styles

7

Gryadunova, E. N., R. N. Polyakov, and N. V. Tokmakov. "Photometric Method of Diagnosis of Bearing Units Operating with Hydrocarbon Mixtures." Solid State Phenomena 284 (October 2018): 1342–48. http://dx.doi.org/10.4028/www.scientific.net/ssp.284.1342.

Full text

Abstract:

The article is devoted to the diagnosis of bearing units working with hydrocarbon mixtures. The diagnostic is based on the photometric method. This method allows you to determine the internal damage to the bearing unit at the stage of the appearance of the microcrack. The photometric method is based on changing the color of the indicator fabric. As the indicator substance, a bromine solution was used which had a dark brown color. If there is a leak, the hydrocarbon reacts with bromine molecules and a bright spot appears on the tape. Indicator fabric is applied to the bearing unit during assembling.The material of the article contains a model of the physicochemical process, which is the basis of the photometric method. Various stages of leakage of hydrocarbon mixtures through microcracks were studied. The results of the experimental studies are consistent with the theoretical propositions. The proposed diagnostic method can be used as a method for non-destructive testing of bearing units.

APA, Harvard, Vancouver, ISO, and other styles

8

Cao, Tong, and Shao Bin Guo. "Application of Absorption and Attenuation Analysis Based on Pre-Stack Seismic Data: Su-77 Block Gas Field Example." Advanced Materials Research 772 (September 2013): 771–75. http://dx.doi.org/10.4028/www.scientific.net/amr.772.771.

Full text

Abstract:

Most hydrocarbon absorption attenuation studies are based on poststack seismic data processing but, because of multiple stacks at full angle, poststack data will lose some lithology and hydrocarbon-bearing capacity information. To overcome this disadvantage, a prestack angle-domain absorption attenuation analysis technique can be performed for seismic data stacked at various angles to obtain angle-domain-dependent absorption profiles. The absorption anomaly reflects the gas-bearing reservoir and also decreases as the angle increases. Actual data from the Sulige gas field, Ordos Basin, have been processed, and the hydrocarbon predictions match very well with actual drilling results, validating the method's effectiveness.

APA, Harvard, Vancouver, ISO, and other styles

9

Xiao, Jun, Bei Zhu, and Ji Hua Liao. "Hydrocarbon Detection Techniques on Subtle Reservoir Exploration in Qiongdongnan Basin." Advanced Materials Research 356-360 (October 2011): 3028–32. http://dx.doi.org/10.4028/www.scientific.net/amr.356-360.3028.

Full text

Abstract:

Subtle reservoir is an important area of hydrocarbon exploration in Qiongdongnan basin. The reservoir hydrocarbon-bearing potential is one of the cores of this research, and the geophysical technology is the main research tool. In this paper, AVO, AVD, DR and seismic attenuation gradient techniques are carried out to evaluate the hydrocarbon-bearing ability. Taking the JY area of eastern Qiongdongnan basin as a case study, the results show that the characteristics of gas-bearing reservoir in JY area are the 3rd AVO anomaly, high AVD and DR, and low attenuation gradient. Furthermore, multi-information fusion technique is used to qualify the gas resource scale and provide decision-making advice for the future exploration. It shows that the seismic anomaly sand body of the first member of Sanya Formation in JY area has large gas resource potential and good exploration prospect.

APA, Harvard, Vancouver, ISO, and other styles

10

Akulov, Nikolay I., and Varvara V. Akulova. "Pyrolysis of Technogenic-Redeposited Coal-Bearing Rocks of Spoil Heaps." Geosciences 10, no. 4 (March 28, 2020): 122. http://dx.doi.org/10.3390/geosciences10040122.

Full text

Abstract:

The paper presents the results of a study of epigenetic changes in technogenic-redeposited coal-bearing rocks of Irkutsk and Kuznetsk coal basin spoil heaps (Russia). Hydrocarbon products formed under high-temperature and low-temperature pyrolysis of coal-bearing rocks were studied by using a chromatography-mass spectrometer GCMS-QP2010NC Plus (made by Shimadzu Company). The average temperature of low-temperature natural pyrolysis does not exceed 120 °C, and its average speed is approximately 2 m/year. In this case, three pyrolysis zones gradually built metamorphic rock mass (from bottom to top) are clearly established: heating (focal) activated and enriched. The average temperature of high-temperature pyrolysis reaches 850 °C, and its average speed is approximately 20 m/year. Unlike low-temperature pyrolysis, high-temperature pyrolysis is accompanied by the presence of two major zones (from bottom to top): pyrogenic (focal) and enriched (coke). The chemical composition of the enriched pyrolysis zone was studied in detail. It has been established that hydrocarbon compounds in samples of the pyrolysis zone are presented by six classes: asphaltic-resinous substances; polycyclic aromatic hydrocarbons, heterocyclic compounds, organic sulphur compounds; pyrolytic hydrocarbon and heavy hydrocarbon residue. Quantitative content of hydrocarbon compounds in the analyzed samples varies from 0.35% to 41.88%.

APA, Harvard, Vancouver, ISO, and other styles

11

Wu, Da-tian, Johanne Iomimalala Ramaniraka, Feng-ming Xu, Jian-bo Shao, Yong-heng Zhou, Yuan-dong Zhao, and Bruno Ralison. "Characteristics and potential analysis of Madagascar hydrocarbon-bearing basins." China Geology 2, no. 1 (2019): 56–66. http://dx.doi.org/10.31035/cg2018076.

Full text

APA, Harvard, Vancouver, ISO, and other styles

12

Mala, Shashank, Eyosias Beneberu, and Nur Yazdani. "Hydrocarbon Fire Performance of Reinforced Elastomeric Bridge Bearing Pads." Journal of Performance of Constructed Facilities 33, no. 4 (August 2019): 04019038. http://dx.doi.org/10.1061/(asce)cf.1943-5509.0001301.

Full text

APA, Harvard, Vancouver, ISO, and other styles

13

Gretskaya, E. V., and M. V. Dakhnova. "Hydrocarbon potential of coal-bearing deposits of South Sakhalin." Doklady Earth Sciences 432, no. 2 (June 2010): 825–28. http://dx.doi.org/10.1134/s1028334x10060255.

Full text

APA, Harvard, Vancouver, ISO, and other styles

14

Narimanov, N., G. Gahramanov, M. Babayev, S. Shpyrko, G. Nasibova, and Kh Mukhtarova. "PROGNOSIS OF BAKU ARCHIPELAGO HYDROCARBON POTENTIAL BY TYPES OF MUD VOLCANOES." Visnyk of Taras Shevchenko National University of Kyiv. Geology, no. 4 (87) (2019): 55–61. http://dx.doi.org/10.17721/1728-2713.87.08.

Full text

Abstract:

Mud volcanoes are indicators of the oil and gas generation processes in the hydrocarbon basins and can show the hydrocarbon potential of local anticline structures where they arise. The quantitative study of the composition of gas ejecta from volcanoes and their age can reveal the generation zones in the sedimentary cover and help assess the hydrocarbon bearing potential of an area. Mud volcanoes are often spatially related to the disjunctive faults intersections, and, on the other hand, there is a clear correlation between the location of the major oil and gas deposits and deep faults. Therefore, ejecta of mud volcanoes present a tool for geochemical probing of potentially hydrocarbon bearing structures. We used a spatial analysis of the composition of gases in mud volcanoes in order to reveal the prospective hydrocarbon targets in Baku Archipelago, located in the western part of the South Caspian Basin. The results confirm the prognosis for the existence of major gas condensate and gas accumulations in its deep water part. The calculations for the ages of mud volcanoes show that they refer to Cretaceous and Miocene-Pliocene periods.

APA, Harvard, Vancouver, ISO, and other styles

15

Huang, Linjun, Yin Liu, Baoli Bian, Yongping Ma, Hailei Liu, Juanjuan Guo, and Jian Cao. "Chemically Active Elements of Reservoir Quartz Cement Trace Hydrocarbon Migration in the Mahu Sag, Junggar Basin, NW China." Geofluids 2021 (April 7, 2021): 1–19. http://dx.doi.org/10.1155/2021/6617945.

Full text

Abstract:

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.

APA, Harvard, Vancouver, ISO, and other styles

16

Kutcherov, V. G., K. S. Ivanov, and A. Yu Serovaiskii. "Deep hydrocarbon cycle." LITHOSPHERE (Russia) 21, no. 3 (July 8, 2021): 289–305. http://dx.doi.org/10.24930/1681-9004-2021-21-3-289-305.

Full text

Abstract:

Research subject. Experimental modelling of the transformation of complex hydrocarbon systems under extreme thermobaric conditions was carried out. The results obtained were compared with geological observations in the Urals, Kamchatka and other regions.Material and methods. The materials for the research were a model hydrocarbon system similar in composition to natural gas condensate and a system consisting of a mixture of saturated hydrocarbons and various iron-containing minerals enriched in 57Fe. Two types of high-pressure equipment were used: a diamond anvils cell and a Toroid-type high-pressure chamber. The experiments were carried out at pressures up to 8.8 GPa in the temperature range 593–1600 K.Results. According to the obtained results, hydrocarbon systems submerged in a subduction slab can maintain their stability down to a depth of 50 km. Upon further immersion, during contact of the hydrocarbon fluid with the surrounding iron-bearing minerals, iron hydrides and carbides are formed. When iron carbides react with water under the thermobaric conditions of the asthenosphere, a water-hydrocarbon fluid is formed. Geological observations, such as methane finds in olivines from ultramafic rocks unaffected by serpentinization, the presence of polycyclic aromatic and heavy saturated hydrocarbons in ophiolite allochthons and ultramafic rocks squeezed out from the paleo-subduction zone of the Urals, are in good agreement with the experimental data.Conclusion. The obtained experimental results and presented geological observations made it possible to propose a concept of deep hydrocarbon cycle. Upon the contact of hydrocarbon systems immersed in a subduction slab with iron-bearing minerals, iron hydrides and carbides are formed. Iron carbides carried in the asthenosphere by convective flows can react with hydrogen contained in the hydroxyl group of some minerals or with water present in the asthenosphere and form a water-hydrocarbon fluid. The mantle fluid can migrate along deep faults into the Earth’s crust and form multilayer oil and gas deposits in rocks of any lithological composition, genesis and age. In addition to iron carbide coming from the subduction slab, the asthenosphere contains other carbon donors. These donors can serve as a source of deep hydrocarbons, also participating in the deep hydrocarbon cycle, being an additional recharge of the total upward flow of a water-hydrocarbon fluid. The described deep hydrocarbon cycle appears to be part of a more general deep carbon cycle.

APA, Harvard, Vancouver, ISO, and other styles

17

Ahmad, Naveed, Sikandar Khan, Eisha Fatima Noor, Zhihui Zou, and Abdullatif Al-Shuhail. "Seismic Data Interpretation and Identification of Hydrocarbon-Bearing Zones of Rajian Area, Pakistan." Minerals 11, no. 8 (August 18, 2021): 891. http://dx.doi.org/10.3390/min11080891.

Full text

Abstract:

The present study interprets the subsurface structure of the Rajian area using seismic sections and the identification of hydrocarbon-bearing zones using petrophysical analysis. The Rajian area lies within the Upper Indus Basin in the southeast (SE) of the Salt Range Potwar Foreland Basin. The marked horizons are identified using formation tops from two vertical wells. Seismic interpretation of the given 2D seismic data reveals that the study area has undergone severe distortion illustrated by thrusts and back thrusts, forming a triangular zone within the subsurface. The final trend of those structures is northwest–southeast (NW–SE), indicating that the area is part of the compressional regime. The zones interpreted by the study of hydrocarbon potential include Sakessar limestone and Khewra sandstone. Due to the unavailability of a petrophysics log within the desired investigation depths, lithology cross-plots were used for the identification of two potential hydrocarbon-bearing zones in one well at depths of 3740–3835 m (zone 1) and 4015–4100 m (zone 2). The results show that zone 2 is almost devoid of hydrocarbons, while zone 1 has an average hydrocarbon saturation of about 11%.

APA, Harvard, Vancouver, ISO, and other styles

18

Rudko, H. I., and V. V. Sobol. "Prospects of oil-and-gas-bearing capacity of Ukraine at great depths for the expansion of hydrocarbon potential of Ukraine." Мінеральні ресурси України, no. 2 (August 19, 2020): 36–42. http://dx.doi.org/10.31996/mru.2020.2.36-42.

Full text

Abstract:

Energy independence is an important component of sustainable development and security of the state. Ukraine has a great hydrocarbon potential of the subsoil, which is why the priority objective is a search and exploration of new deposits of hydrocarbon raw materials. One of the important directions for increase of potential resources and reserves of oil and gas is the development of large deep (over 4500–5000 m) deposits, as hydrocarbon reserves at small and medium depths are quite depleted in many regions. For a long time, hydrocarbon reservoirs in basement rocks were underestimated during geological exploration works. Obtained results indicate that new concepts of the formation of hydrocarbon deposits can dramatically change the system of oil production, methods of prospecting and development of deposits. It is important to assess possible oil-and-gas-bearing capacity of sediments and rocks of the basement by identifying prospective areas of hydrocarbon deposits, including in the rocks of the crystalline basement. In Ukraine, main prospects of discovery of oil and gas deposits at great depths are associated nowadays with the Dnieper-Donets Rift (DDR). Deposits with accumulations of hydrocarbons at depths of more than 5000 m are concentrated in the main oil-and-gas-bearing areas of the Rift that coincide with the central paraxial and marginal zones of the graben. It was in the central segment of the DDR that the main regularities of oil-and-gas-bearing capacity of deep-lying geological formations were first discovered: secondary nature of reservoirs, discovery of the phenomenon of supercollectors and associated huge debits. It is relevant and promising to study the process of recovery/replenishment of gas reserves by the example of deposits that are at the final stage of development.

APA, Harvard, Vancouver, ISO, and other styles

19

S S, Paul, Okwueze ., E. E, and Udo K I. "Petrophysical Analysis of Well Logs for the Estimation of Oil Reserves in Southern Niger Delta." International Journal of Advanced Geosciences 6, no. 1 (June 12, 2018): 145. http://dx.doi.org/10.14419/ijag.v6i1.11815.

Full text

Abstract:

Gamma Ray log, Resistivity log, Density log, Micro-spherical focus log (MSFL), Deep Induction log (ILD) , Medium Induction log(ILM) and Spontaneous Potential (SP) log were collected for 2 wells in onshore Niger Delta. These insitu well logs were analyzed and interpreted. Porosity, permeability, water saturation, reservoir thickness and Shale volume were estimated for each hydrocarbon bearing zone delineated for each well. The parameters obtained were further analyzed and interpreted quantitatively to estimate the hydrocarbon potentials of each well. Twelve reservoir zones of interest (sand bodies) were delineated, correlated across the field and were ranked using average results of petrophysical parameters. In well one, Reservoirs E and F were identified as the thickest with 41ft each while reservoir A is the smallest in thickness (30ft). Petrophysical properties of hydrocarbon bearing zones delineated in well one ranged from 17.81% to 23.20% for porosity, 1292.09mD to 2018.17mD for permeability and 56.40% to 68.40% for hydrocarbon saturation compared to well 2 with 14.67% to 19.52% for porosity, 1211.61mD to1843.11mD for permeability and 51.80% to 66.40% for hydrocarbon saturation. The estimated averages of petrophysical properties for well one are 20.14% porosity, 1643.65mD permeability, 63.20% hydrocarbon saturation compared to well 2 with 15.55% porosity, 1582.58mD permeability and 61.93% hydrocarbon saturation. Results show 148.45MMBB and 145.91MMBB as oil reserve (Recoverable) for the field. From the results obtained, well one is likely to be more productive than well [2] and the field has exploitable oil in place.

APA, Harvard, Vancouver, ISO, and other styles

20

Yang, Di Sheng, Ru Feng Jiang, Xing Ping Luo, Zhong Hong Chen, and Jun Min Ren. "Organic Facies and Distribution Forecast of Hydrocarbon Source Rocks in Carboniferous, Northern Xinjiang." Applied Mechanics and Materials 318 (May 2013): 399–404. http://dx.doi.org/10.4028/www.scientific.net/amm.318.399.

Full text

Abstract:

Carboniferous, the sedimentary basement in northern Xinjiang, formed under the circumstances of sea-land transition, sedimentary evolution and intense tectonic movement with various sedimentary facies, causing the differences in regional distribution of hydrocarbon source rocks. According to the sedimentary facies, organic matter component and organic geochemistry of hydrocarbon source rocks, organic facies in Upper Carboniferous may be divided into 5 types, which are lake delta – shallow lake – semideep lake organic facies with mineral asphalt matrix, small sporophyte, desmocollinite and planktonic algae, lake delta – shallow lake organic facies with mineral asphalt matrix, shell debris and vitrodetrinite, shallow sea and transitional organic facies with vitrodetrinite, shallow sea – shallow sea shelf organic facies with vitrodetrinite, semideep sea organic facies with clastic-bearing and planktonic-algae-bearing small sporophyte. Based on outcrop sections, drilling data and lateral prediction of seismic facies, the principal characteristics for hydrocarbon source rocks of Upper and Lower Carboniferous in Junggar, Santanghu and Tuha Basin have been described in details, as well as the distribution forecast of hydrocarbon source rocks in Upper and Lower Carboniferous from different basins.

APA, Harvard, Vancouver, ISO, and other styles

21

Revil, A., W. F. Woodruff, C. Torres-Verdín, and M. Prasad. "Complex conductivity tensor of anisotropic hydrocarbon-bearing shales and mudrocks." GEOPHYSICS 78, no. 6 (November 1, 2013): D403—D418. http://dx.doi.org/10.1190/geo2013-0100.1.

Full text

Abstract:

A model was recently introduced to describe the complex electrical conductivity and high-frequency dielectric constant of isotropic clayey porous materials. We generalized that approach to the case of anisotropic and tight hydrocarbon-bearing shales and mudrocks by introducing tensorial versions of formation factor and tortuosity. In-phase and quadrature conductivity tensors have common eigenvectors, but the eigenvectors of the dielectric tensor may be different due to influence of the solid phase at high frequencies. In-phase and quadrature contributions to complex electrical conductivity depend on saturation, salinity, porosity, temperature, and cation exchange capacity (alternatively, specific surface area) of the porous material. Kerogen is likely to have a negligible contribution to the cation exchange capacity of the material because all exchangeable sites in the functional groups of organic matter may have been polymerized during diagenesis. An anisotropic experiment is performed to validate some of the properties described by the proposed model, especially to verify that the electrical anisotropy factor is the same for in-phase and quadrature conductivities. We used two samples from the Bakken formation. Experimental data confirm the validity of the model. Also, the range of values for cation exchange capacity determined when implementing the new model with experimental data agree with the known range of cation exchange capacity for the Bakken shale. Measurements indicate that the bulk-space tortuosity in the direction normal to bedding plane can be higher than 100.

APA, Harvard, Vancouver, ISO, and other styles

22

Serovaiskii, A. Yu, A. Yu Kolesnikov, and V. G. Kutcherov. "Formation of iron hydride and iron carbide from hydrocarbon systems at ultra high thermobaric conditions." Геохимия 64, no. 9 (September 20, 2019): 995–1002. http://dx.doi.org/10.31857/s0016-7525649995-1002.

Full text

Abstract:

The chemical interaction of hydrocarbon systems and iron-bearing minerals was investigated under extreme thermobaric conditions, corresponding to the Earth upper mantle. As a result of the reaction, the formation of iron carbide and iron hydride was detected. The experiments were carried out in diamond anvils cells with laser heating. Natural petroleum from the Korchaginskoe deposit and a synthetic mixture of paraffin hydrocarbons were used as hydrocarbon systems, and pyroxene-like glass and ferropericlase (57Fe enriched) as iron bearing minerals. The experiments were carried out in the pressure range of 26–95 kbar and temperature range of 1000–1500°C (±100°C). As a result of the experiments, the formation of iron hydride was detected at pressure of 26–69 kbar (corresponds to a depth of 100–200 km), and a mixture of iron carbide and iron hydride at pressure of 75–95 kbar (corresponds to a depth of 210–290 km). The formation of hydrides and iron carbides as a results of the interaction of hydrocarbon systems with iron-bearing minerals may indicate the possible existence of these compounds in the upper mantle.

APA, Harvard, Vancouver, ISO, and other styles

23

Liu, Cheng Long, Hui Guo, Xiang Hao Wang, and Jin Wang. "Organic Petrology Study of the Early Cretaceous Source Rocks in Weichang, Chifeng Basin." Applied Mechanics and Materials 508 (January 2014): 137–40. http://dx.doi.org/10.4028/www.scientific.net/amm.508.137.

Full text

Abstract:

Organic petrology method is applied to analysis hydrocarbon potential of early Cretaceous source rocks in Hebei Weichang, Chifeng basin. Conclusions are drawn as follows: Organic Maceral is mainly pieces of vitrinite, liptinite consists algae and small spores; organic matter abundance is better; organic type isI-II1, in an immature stage which currently does not have potential for bearing hydrocarbon.

APA, Harvard, Vancouver, ISO, and other styles

24

Ren, Hongjia, Xianchang Wang, Hongbo Ren, and Qiulin Guo. "Spatial Distribution Prediction of Oil and Gas Based on Bayesian Network with Case Study." Mathematical Problems in Engineering 2020 (August 27, 2020): 1–9. http://dx.doi.org/10.1155/2020/4986563.

Full text

Abstract:

Effectively predicting the spatial distribution of oil and gas contributes to delineating promising target areas for further exploration. Determining the location of hydrocarbon is a complex and uncertain decision problem. This paper proposes a method for predicting the spatial distribution of oil and gas resource based on Bayesian network. In this method, qualitative dependency relationship between the hydrocarbon occurrence and key geologic factors is obtained using Bayesian network structure learning by integrating the available geoscience information and the current exploration results and then using Bayesian network topology structure to predict the probability of hydrocarbon occurrence in the undiscovered area; finally, the probability map of hydrocarbon-bearing is formed by interpolation method. The proposed method and workflow are further illustrated using an example from the Carboniferous Huanglong Formation (C2hl) in the eastern part of the Sichuan Basin in China. The prediction results show that the coincidence rate between the results of 248 known exploration wells and the predicted results reaches 89.5%, and it has been found that the gas fields are basically located in the high value area of the hydrocarbon-bearing probability map. The application results show that the Bayesian network method can effectively predict the spatial distribution of oil and gas resources, thereby reducing exploration risks, optimizing exploration targets, and improving exploration benefits.

APA, Harvard, Vancouver, ISO, and other styles

25

Lu, Jia, Chen Zhang, Jianhui Zeng, and Haowei Yuan. "Research on the Oil-Bearing Difference of Bedding Fractures: A Case Study of Lucaogou Formation in Jimsar Sag." Geofluids 2021 (May 31, 2021): 1–21. http://dx.doi.org/10.1155/2021/5567491.

Full text

Abstract:

Lucaogou formation in Jimsar sag is host to large quantities of bedding fractures which are known to play a critical role in the enrichment, accumulation, and efficient development of tight oil. In this paper, we examine and finely characterize the development of the bedding fractures found in the upper and lower sweet spots of Lucaogou formation of tight oil reservoir through field outcrop and core observation, cast thin section analysis, and imaging log recognition and investigate the factors affecting their differentiated oil-bearing by means of inclusion temperature measurement, TOC testing, physical property testing, high-pressure mercury injection, and physical simulation experiment. By comparison with the linear density, bedding fractures are more developed in the lower sweet spot. These fractures occur in parallel to the formation boundary and have small aperture. Most of bedding fractures are unfilled fractures. Among the few types of fractures found there, bedding fractures have the best oil-bearing property, but the oil-bearing can differ from one bedding fracture to another. The factors affecting the differentiated oil-bearing of bedding fractures include the temporal coupling of the formation of these fractures with the hydrocarbon generation of the source rocks and the spatial coupling of the bedding fractures with the source rocks. In terms of temporal coupling, mass hydrocarbon generation in Jimsar sag began in Late Jurassic. Inclusion temperature measurement indicates that the bedding fractures there formed in or after Early Cretaceous. Hence, by matching the mass hydrocarbon generation period of the source rocks with the formation period of the bedding fractures, we discovered that the bedding fractures formed within the mass hydrocarbon generation period, which favored the oil-bearing of these fractures. The spatial coupling is manifested in TOC, porosity, permeability, and pore throat, with TOC being the main controlling factor. For TOC, the higher the formation TOC, the better the oil-bearing property of the bedding fractures. For porosity, subject to the TOC level, if the TOC is adequate, the larger the porosity, the larger the chloroform asphalt “A,” accordingly the higher the oil content of the formation, and the better the oil-bearing property of the bedding fractures developed therein. In this sense, in terms of spatial coupling, TOC constitutes the main controlling factor of the oil-bearing property of bedding fractures.

APA, Harvard, Vancouver, ISO, and other styles

26

Riccobono, Alessio, Rachel R. Parker, Adrian C. Whitwood, John M. Slattery, Duncan W. Bruce, Ivana Pibiri, and Andrea Pace. "1,2,4-Triazolium ions as flexible scaffolds for the construction of polyphilic ionic liquid crystals." Chemical Communications 54, no. 71 (2018): 9965–68. http://dx.doi.org/10.1039/c8cc04704a.

Full text

APA, Harvard, Vancouver, ISO, and other styles

27

Tomaschautzky, Janek, Beate Neumann, Hans-Georg Stammler, and Norbert W. Mitzel. "Poly-Lewis-acids based on bowl-shaped tribenzotriquinacene." Dalton Transactions 46, no. 4 (2017): 1112–23. http://dx.doi.org/10.1039/c6dt04350j.

Full text

APA, Harvard, Vancouver, ISO, and other styles

28

Kotaki, T., N. Nishimura, M. Ozawa, A. Fujimori, H. Muraoka, S. Ogawa, T. Korenaga, E. Suzuki, Y. Oishi, and Y. Shibasaki. "Synthesis of highly refractive and highly fluorescent rigid cyanuryl polyimines with polycyclic aromatic hydrocarbon pendants." Polymer Chemistry 7, no. 6 (2016): 1297–308. http://dx.doi.org/10.1039/c5py01920f.

Full text

Abstract:

A series of rigid cyanuryl polyimines, polyguanamines (PGs) bearing polycyclic aromatic hydrocarbon pendants were successfully synthesized from 2-substituted 4,6-dichloro-1,3,5-triazine and aromatic diamine monomers.

APA, Harvard, Vancouver, ISO, and other styles

29

Du Bois, Ernest P. "Review of principal hydrocarbon-bearing basins around the South China Sea." Bulletin of the Geological Society of Malaysia 18 (November 30, 1985): 167–209. http://dx.doi.org/10.7186/bgsm18198508.

Full text

APA, Harvard, Vancouver, ISO, and other styles

30

Phan, Trung Dien. "Some Cenozoic hydrocarbon bearing basins on the continental shelf of Vietnam." Bulletin of the Geological Society of Malaysia 37 (July 30, 1995): 33–54. http://dx.doi.org/10.7186/bgsm37199503.

Full text

APA, Harvard, Vancouver, ISO, and other styles

31

Zhang, Xiaofei, Xiancai Jiang, Xi Zhang, and Hua Dai. "Solution properties of thermothickening copolymers bearing hydrocarbon end-capped oxyethylene units." Journal of Polymer Science Part B: Polymer Physics 48, no. 16 (July 8, 2010): 1799–808. http://dx.doi.org/10.1002/polb.22047.

Full text

APA, Harvard, Vancouver, ISO, and other styles

32

Syvitski, J. P. M., and G. E. Farrow. "Fjord sedimentation as an analogue for small hydrocarbon-bearing fan deltas." Geological Society, London, Special Publications 41, no. 1 (1989): 21–43. http://dx.doi.org/10.1144/gsl.sp.1989.041.01.03.

Full text

APA, Harvard, Vancouver, ISO, and other styles

33

Menshov, Oleksandr, Roman Kuderavets, Sergiy Vyzhva, Valentyn Maksymchuk, Igor Chobotok, and Tatyana Pastushenko. "Magnetic studies at Starunia paleontological and hydrocarbon bearing site (Carpathians, Ukraine)." Studia Geophysica et Geodaetica 60, no. 4 (July 27, 2016): 731–46. http://dx.doi.org/10.1007/s11200-016-0621-2.

Full text

APA, Harvard, Vancouver, ISO, and other styles

34

Al-Attar, Hazim, Hala Alshadafan, Mariam Al Kaabi, Aysha Al Hassani, and Shatha Al Mheiri. "Integrated optimum design of hydraulic fracturing for tight hydrocarbon-bearing reservoirs." Journal of Petroleum Exploration and Production Technology 10, no. 8 (September 10, 2020): 3347–61. http://dx.doi.org/10.1007/s13202-020-00990-6.

Full text

Abstract:

Abstract Although hydraulic fracturing is not a new technology, it has not yet been implemented in the United Arab Emirates. Abu Dhabi National Oil Company (ADNOC), the regional producer in United Arab Emirates, has set out to initiate the utilization of this treatment during year 2019. In this work, a systematic design procedure for hydraulic fracturing in tight petroleum-bearing reservoirs is proposed. The design caters for surface and subsurface flow parameters, and it is hoped to provide basic guidelines for ADNOC in this respect. The proposed design process incorporates both unified fracture design (UFD) methodology and the fracture geometry (PKN) model. Excel spreadsheets were developed and utilized to run sensitivity analysis for optimal performance and predict long-term production profiles before and after fracturing. The excel spreadsheets made are flexible in use, in the sense that they resolve issues with infinite/finite fractures, high/low surface injection rate as well as investigate for non-Darcy flow effects. Reliable published data were used to perform the necessary calculations. The results of the performance calculations have shown that it is possible to access commercial quantities of hydrocarbons from a tight reservoir. In addition, improved productivity by 15-folds and increased gas recovery of 1.02 MMMscf over the first 8 years of production can be achieved by proper hydraulic fracturing design and implementation in tight gas reservoirs. The results of calculations of non-Darcy effect revealed a threshold velocity of approximately 0.2 fps above which these effects could become significant in predicting the overall flow efficiency inside the fracture. To the authors’ knowledge, the literature has not fully addressed the hydraulic fracturing design analytically, and the methodology proposed in this work provides a complete design package which incorporates the UFD concept, the PKN model, the non-Darcy model, and long-term prediction of post-fracturing production performance, and applying the proposed approach in a case study.

APA, Harvard, Vancouver, ISO, and other styles

35

MUKHERJEE, BAPPA, and P. N. S. ROY. "CHARACTERIZATION OF THE HYDROCARBON POTENTIAL AND NON-POTENTIAL ZONES USING WAVELET-BASED FRACTAL ANALYSIS." Fractals 26, no. 01 (February 2018): 1850001. http://dx.doi.org/10.1142/s0218348x18500019.

Full text

Abstract:

The identification of prospective and dry zone is of major importance from well log data. Truthfulness in the identification of potential zone is a very crucial issue in hydrocarbon exploration. In this line, the problem has received considerable attention and many conventional techniques have been proposed. The purpose of this study is to recognize the hydrocarbon and non-hydrocarbon bearing portion within a reservoir by using the non-conventional technique. The wavelet based fractal analysis (WBFA) has been applied on the wire-line log data in order to obtain the pre-defined hydrocarbon (HC) and non-hydrocarbon (NHC) zones by their self-affine signal nature is demonstrated in this paper. The feasibility of the proposed technique is tested with the help of most commonly used logs, like self-potential, gamma ray, resistivity and porosity log responses. These logs are obtained from the industry to make out several HC and NHC zones of all wells in the study region belonging to the upper Assam basin. The results obtained in this study for a particular log response, where in the case of HC bearing zones, it is found that they are mainly situated in a variety of sandstones lithology which leads to the higher Hurst exponent. Further, the NHC zones found to be analogous to lithology with higher shale content having lower Hurst exponent. The above proposed technique can overcome the chance of miss interpretation in conventional reservoir characterization.

APA, Harvard, Vancouver, ISO, and other styles

36

Sun, Yu, Shi Zhong Ma, Bai Quan Yan, and Chen Chen. "Controlling Factors for Reservoirs Distribution of the Putaohua Oil Layer in the Saozhao Sag." Advanced Materials Research 616-618 (December 2012): 816–20. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.816.

Full text

Abstract:

Types of found reservoirs and its distribution characteristics of Putaohua oil layer in the Sanzhao Sag were analyzed. The controlling factors of hydrocarbon distribution were investigated. Sanzhao Sag is Sag-wide oil-bearing, but its distribution of oil and water is extremely complicated. The reservoir types are mainly fault block reservoirs, low amplitude structure reservoirs, fault-lithologic reservoirs and lithologic reservoirs. The distribution of reservoirs is mainly controlled by three geological factors: first, long-term inherited nose-like structure is predominant direction of petroleum migration; it induced oil and gas migration at a critical period of hydrocarbon accumulation and formed oil-gas accumulation area. Second, fault across main-line of hydrocarbon migration and high angle skew plug off hydrocarbon, and its side adjacent to Sag is a large number of hydrocarbon accumulation areas. Third, multi-fault region can easily form a fault (-lithological) reservoir accumulation area in the slope of sag.

APA, Harvard, Vancouver, ISO, and other styles

37

Omoja, UC, and T. N. Obiekezie. "Evaluation of Petrophysical Parameters of Reservoir Sand Wells in Uzot-Field, Onshore Niger Delta Basin, Nigeria." Journal of Applied Sciences and Environmental Management 25, no. 2 (April 14, 2021): 157–71. http://dx.doi.org/10.4314/jasem.v25i2.5.

Full text

Abstract:

Evaluation of the petrophysical parameters in Uzot-field was carried out using Well log data. The target for this study was the D3100 reservoir sand of wells Uz 004, Uz 005, U008 and Uz 011 with depth range of 5540ft to 5800ft across the four wells. Resistivity logs were used to identify hydrocarbon or water-bearing zones and hence indicate permeable zones while the various sand bodies were then identified using the gamma ray logs. The results showed the delineated reservoir units having porosity ranging from 21.40% to 33.80% indicating a suitable reservoir quality; permeability values from 1314md to 18089md attributed to the well sorted nature of the sands and hydrocarbon saturation range from 12.00% to 85.79% implying high hydrocarbon production. These results suggest a reservoir system whose performance is considered satisfactory for hydrocarbon production. Keywords: Petrophysical parameters, porosity, permeability, hydrocarbon saturation, Niger Delta Basin

APA, Harvard, Vancouver, ISO, and other styles

38

Alentiev, Dmitry A., Elena S. Egorova, Maxim V. Bermeshev, Ludmila E. Starannikova, Maxim A. Topchiy, Andrey F. Asachenko, Pavel S. Gribanov, Mikhail S. Nechaev, Yuri P. Yampolskii, and Eugene Sh Finkelshtein. "Janus tricyclononene polymers bearing tri(n-alkoxy)silyl side groups for membrane gas separation." Journal of Materials Chemistry A 6, no. 40 (2018): 19393–408. http://dx.doi.org/10.1039/c8ta06034g.

Full text

Abstract:

Being not prone to aging and possessing high C₄/C₁ selectivity, new tricyclononene polymers bearing (AlkO)₃Si side groups are prospective materials for hydrocarbon mixture separation.

APA, Harvard, Vancouver, ISO, and other styles

39

Ross, Christopher P. "Incomplete AVO near salt structures." GEOPHYSICS 57, no. 4 (April 1992): 543–53. http://dx.doi.org/10.1190/1.1443268.

Full text

Abstract:

Amplitude versus offset (AVO) measurements for deep hydrocarbon‐bearing sands can be compromised when made in close proximity to a shallow salt piercement structure. Anomalous responses are observed, particularly on low acoustic impedance bright spots. CMP data from key seismic profiles traversing the bright spots do not show the expected Class 3 offset responses. On these CMPs, significant decrease of far trace energy is observed. CMP data from other seismic profiles off‐structure do exhibit the Class 3 offset responses, implying that structural complications may be interfering with the offset response. A synthetic AVO gather was generated using well log data, which supports the off‐structure Class 3 responses, further reinforcing the concept of structurally‐biased AVO responses. Acoustic, pseudo‐spectral modeling of the structure substantiates the misleading AVO response. Pseudo‐spectral modeling results suggest that signal degradation observed on the far offsets is caused by wavefield refraction—a shadow zone, where the known hydrocarbon‐bearing sands are not completely illuminated. Such shadow zones obscure the correct AVO response, which may have bearing on exploration and development.

APA, Harvard, Vancouver, ISO, and other styles

40

Guilhaumou, Nicole, Nathalie Szydlowskii, and Bernard Pradier. "Characterization of hydrocarbon fluid inclusions by infra-red and fluorescence microspectrometry." Mineralogical Magazine 54, no. 375 (June 1990): 311–24. http://dx.doi.org/10.1180/minmag.1990.054.375.17.

Full text

Abstract:

AbstractLiquid-hydrocarbon-bearing fluid inclusions have often been described associated with petroleum occurrences and diagenetic sediments. Infra-red microspectrometry allows characterization of fluid inclusions greater than 20 µm by establishing the presence of aliphatic and aromatic hydrocarbons as well as associated H2O, CO2 and CH4. Semi-quantitative analyses have been made by focussing on gaseous and liquid phases separately. Some CH2/CH3 and CO2/CH4 ratios have been determined by this method.Fluorescence microspectrometry permits precise measurements of the fluorescence emission spectrum of chromophore-bearing organic phases (essentially aromatic hydrocarbons) in fluid inclusions greater than 10 µm. Such a spectrum is a function of both the gross composition of the trapped oil and its thermal history.Both of these methods lead to the in situ characterization of hydrocarbon fluid inclusions. They are useful in providing a quantifiable distinction between different oil generations trapped during mineral growth in diagenetic and epigenetic minerals.

APA, Harvard, Vancouver, ISO, and other styles

41

Prykhodko, Oleksandr, Ihor Hrytsyk, Ihor Kurovets, and Svitlana Melnychuk. "Vertical thermobaric zoning of hydrocarbon deposits of the Eastern oil- and gas-bearing region of Ukraine." Geology and Geochemistry of Combustible Minerals 3, no. 180 (December 18, 2019): 60–75. http://dx.doi.org/10.15407/ggcm2019.03.060.

Full text

Abstract:

For the predictive appraisal of the perspective exploratory territories as well as prediction of separate producing horizons of prospecting and exploration areas for oil and gas it is necessary to establish the regularities of distribution of already explored deposits of hydrocarbons with structural-tectonic construction, lithological-stratigraphic features, hydrogeological and geothermobaric conditions of oil- and gas-bearing region taken into account. Interconnection between geothermobaric parameters and the phase state of hydrocarbons in the vertical section should be an important factor for the solution of the posed task. Within the limits of the Eastern oil- and gas-bearing area of Ukraine, the spatial zoning is established in the location of gas, oil and gas-condensate deposits. As a whole, the distribution of temperatures and pressures at different depths, average geothermal gradients, gradients of the lithological-stratigraphical horizons of the same name (sustained both as to the area and thickness) are closely connected with the deep geological structure of the studied region (area) and confirm the existing notions of the role of tectonic, lithological-stratigraphic and hydrogeological factors in the formation of the thermal regime of sedimentary basins. Vertical zoning of the distribution of hydrocarbon deposits of oil- and gas-bearing horizons was developed according to geothermobaric parameters of the north-western part of the Dnieper-Donets Depression and 8 areas from 15 ones of the Eastern oil- and gas-bearing region, namely: Monastyryshche-Sofiivka and Talalaivka-Rybalske oil- and gas-bearing areas, Glynsk-Solokha gas- and oil-bearing area, Ryabukhyne-Northern Golubivka and Mashivka-Shebelynka gas-bearing areas, Rudenky-Proletarske oil- and gas-bearing region, Krasna Rika gas-bearing area and also oil- and gas-bearing area of the Northern edge. Revealed regularities of the distribution of formation temperatures, pressures, geothermal and thermobaric coefficients with peculiarities of the tectonic structure of the Dnieper-Donets graben taken into account will make it possible to solve theoretical problems connected with hydrocarbon migration, the formation and preservation of deposits in more well-founded way that will make it possible to conduct prospecting for new fields at great depths within the studied territory more effectively.

APA, Harvard, Vancouver, ISO, and other styles

42

Gao, Jianhu, Bingyang Liu, Shengjun Li, and Hongqiu Wang. "Sparse spectral attributes to detect hydrocarbons: A case study from deep dolomite reservoirs." Interpretation 7, no. 3 (August 1, 2019): T701—T711. http://dx.doi.org/10.1190/int-2018-0170.1.

Full text

Abstract:

Hydrocarbon detection is always one of the most critical sections in geophysical exploration, which plays an important role in subsequent hydrocarbon production. However, due to the low signal-to-noise ratio and weak reflection amplitude of deep seismic data, some conventional methods do not always provide favorable hydrocarbon prediction results. The interesting dolomite reservoirs in Central Sichuan are buried over an average depth of 4500 m, and the dolomite rocks have a low porosity below approximately 4%, which is measured by well-logging data. Furthermore, the dominant system of pores and fractures as well as strong heterogeneity along the lateral and vertical directions lead to some difficulties in describing the reservoir distribution. Spectral decomposition (SD) has become successful in illuminating subsurface features and can also be used to identify potential hydrocarbon reservoirs by detecting low-frequency shadows. However, the current applications for hydrocarbon detection always suffer from low resolution for thin reservoirs, probably due to the influence of the window function and without a prior constraint. To address this issue, we developed sparse inverse SD (SISD) based on the wavelet transform, which involves a sparse constraint of time-frequency spectra. We focus on investigating the applications of sparse spectral attributes derived from SISD to deep marine dolomite hydrocarbon detection from a 3D real seismic data set with an area of approximately [Formula: see text]. We predict and evaluate gas-bearing zones in two target reservoir segments by analyzing and comparing the spectral amplitude responses of relatively high- and low-frequency components. The predicted results indicate that most favorable gas-bearing areas are located near the northeast fault zone in the upper reservoir segment and at the relatively high structural positions in the lower reservoir segment, which are in good agreement with the gas-testing results of three wells in the study area.

APA, Harvard, Vancouver, ISO, and other styles

43

Körmös, Sándor, Georgina Lukoczki, and Félix Schubert. "Indication of hydrocarbon migration in the Western Mecsek Mountains evidenced by fluid inclusion chemostratigraphy." Földtani Közlöny 150, no. 4 (December 29, 2020): 611. http://dx.doi.org/10.23928/foldt.kozl.2020.150.4.611.

Full text

Abstract:

Primary and secondary hydrocarbon-bearing fluid inclusion (HCFI) assemblages occur in the Middle Triassic Lapis Limestone in the Szuadó Valley of the Western Mecsek Mts. The primary HCFIs were trapped in saddle dolomite crystals, and the secondary HCFIs were enclosed in calcite neospar and fracture-filling calcite. Solid bitumen is also present along fractures. The volatile compounds liberated from fluid inclusions are characterized by non-hydrocarbon and hydrocarbon species. The fluorescent properties of HCFIs, the occurrence of the solid bitumen, as well as the composition of inclusion oils indicate the migration of light oils through the Lapis Limestone. Petrographic observations suggest a prolonged oil charge event, which resulted in HCFIs beeing trapped under evolving diagenetic conditions.

APA, Harvard, Vancouver, ISO, and other styles

44

Hossain, Md Imam Sohel, A. S. M. Woobaidullah, and Md Jamilur Rahman. "Reservoir characterization and identification of new prospect in Srikail gas field using wireline and seismic data." Journal of Petroleum Exploration and Production Technology 11, no. 6 (June 2021): 2481–95. http://dx.doi.org/10.1007/s13202-021-01217-y.

Full text

Abstract:

AbstractAlthough reservoir characterization has been carried out by many researchers on the sedimentary package of the Bengal basin hydrocarbon province, integration of petrophysical and seismic sequence-based reservoir evaluation is rarely taken into account. This paper focuses on the identification of gas zones, reserve estimation and identification of new prospects in Srikail gas field within the eastern fold belt of Bengal basin integrating four wireline logs and 2D seismic data. Our study finds seven hydrocarbon-bearing zones (A, B, C, D, E, F and G) within the measured depth between 2429.5 and 3501 m. Petrophysical properties of seven hydrocarbon-bearing zones indicate that they are good quality reservoir sands. The gas horizons were mapped on seismic sections which reveal that the NW–SE anticlinal structure is largely affected by channels in the crest and western flank. The channels are infilled by fine-grained sediments which act as cap rock on northern and western parts of the structure. Thus, the anticlinal structure and fine-grained sediments make a potential trap for hydrocarbon accumulation and laterally and vertically well-distributed sequence remnants are the main reservoir rocks in this area. Volumetric reserve estimation of these sands provided a total gas initially in place as 552 billion cubic feet. Moreover, all the four wells are drilled in the southern block of the structure, and since there is a structural continuity from south to the north, it is highly recommended to drill a well up to 3000 m depth in the northern block to test its hydrocarbon potentiality. Overall, the outcomes of this study contribute new insights for reservoir characterization and identification of new prospects in an efficient way.

APA, Harvard, Vancouver, ISO, and other styles

45

Jiang, Shu, Zhengyu Xu, Youliang Feng, Jinchuan Zhang, Dongsheng Cai, Lei Chen, Yue Wu, Dongsheng Zhou, Shujing Bao, and Shengxiang Long. "Geologic characteristics of hydrocarbon-bearing marine, transitional and lacustrine shales in China." Journal of Asian Earth Sciences 115 (January 2016): 404–18. http://dx.doi.org/10.1016/j.jseaes.2015.10.016.

Full text

APA, Harvard, Vancouver, ISO, and other styles

46

Dehua, Liang, and Liu Zonghui. "THE GENESIS OF THE SOUTH CHINA SEA AND ITS HYDROCARBON-BEARING BASINS." Journal of Petroleum Geology 13, no. 1 (January 1990): 59–70. http://dx.doi.org/10.1111/j.1747-5457.1990.tb00251.x.

Full text

APA, Harvard, Vancouver, ISO, and other styles

47

Stovba, Sergiy, Oxana Khriachtchevskaia, and Igor Popadyuk. "Hydrocarbon-bearing areas in the eastern part of the Ukrainian Black Sea." Leading Edge 28, no. 9 (September 2009): 1042–45. http://dx.doi.org/10.1190/1.3236373.

Full text

APA, Harvard, Vancouver, ISO, and other styles

48

Sridharan, K., E. H. Wilson, D. F. Lawrence, and J. R. Jacobs. "Application of hydrocarbon plasmas for modifying near-surface characteristics of bearing steel." Applied Surface Science 222, no. 1-4 (January 2004): 208–14. http://dx.doi.org/10.1016/j.apsusc.2003.08.102.

Full text

APA, Harvard, Vancouver, ISO, and other styles

49

Gardam, Michael, and John R. Silvius. "Intermixing of dipalmitoylphosphatidylcholine with phospho- and sphingolipids bearing highly asymmetric hydrocarbon chains." Biochimica et Biophysica Acta (BBA) - Biomembranes 980, no. 3 (April 1989): 319–25. http://dx.doi.org/10.1016/0005-2736(89)90319-2.

Full text

APA, Harvard, Vancouver, ISO, and other styles

50

BLAMEY, N. J. F., A. G. RYDER, M. FEELY, P. DOCKERY, and P. OWENS. "The application of structured-light illumination microscopy to hydrocarbon-bearing fluid inclusions." Geofluids 8, no. 2 (May 2008): 102–12. http://dx.doi.org/10.1111/j.1468-8123.2008.00209.x.

Full text

APA, Harvard, Vancouver, ISO, and other styles

Journal articles on the topic 'Hydrocarbon-bearing'

Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles