Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism

Laboratory of, New Zealand

Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism

Laboratory of, New Zealand
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Hao X.,China University of Geosciences | Hao X.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Junfeng Z.,Petrochina | Dazhen T.,China University of Geosciences | And 5 more authors.
Petroleum Exploration and Development | Year: 2012

Based on the study of low-pressure distribution characteristics, the main factors that control the formation of low-pressure reservoirs in the Sulige gas field are analyzed from several aspects, such as structural evolution, sedimentary characteristics and formation fluid features. It is suggested that the gas pool pressure is low and affected greatly by buried depth. Its roof and floor developed several layers of uncompacted mudstone, indicative of good property and pressure sealing conditions. The formation water also indicates favorable preservation conditions. The reservoir pressure of the Sulige gas field experienced 4 major evolutionary stages: the normal pressure stage of the Late Triassic-early Jurassic, the pressure rising stage of the Middle Jurassic-Late Jurassic, the sustainable pressure increasing stage of the Early Cretaceous, and the pressure decreasing stage of the late Early Cretaceous. The pore rebound and temperature decrease caused by intense tectonic uplift after the late period of Early Cretaceous, caused the reservoir pressure of the Sulige gas field to reduce by 0.673 MPa and 23.08% of the original strata pressure, respectively. The low pressure of the Sulige gas field is related to sedimentary assemblage, tectonic evolution and hydrocarbon accumulation. © 2012 Research Institute of Petroleum Exploration & Development, PetroChina.


Ju B.,China University of Geosciences | Ju B.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Fan T.,China University of Geosciences
Petroleum Science and Technology | Year: 2012

The experiments validate that the wettability of reservoir rocks changes from weak water wetness to strong water wetness during secondary oil recovery. The relative permeabilities of the oil and water show that the increase in water wetness results in an obvious decrease in the water permeability. A numerical simulator considering wettability alteration was developed to predict oil production. The simulation indicates the wettability alteration during water flooding has strong effects on the water cut and oil recovery. It is found that the increase in water wetness during water flooding leads to a higher oil recovery and less accumulated production water at a water cut. © 2012 Taylor & Francis Group, LLC.


Ju B.,China University of Geosciences | Ju B.,Key Laboratory of Geological Evaluation and Development Engineering of Unconventional Natural Gas Energy | Ju B.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism
Journal of Petroleum Science and Engineering | Year: 2014

Formation deformation of oil reservoirs is a widespread phenomenon for unconsolidated or abnormal high-pressure formations due to the depletion of reservoir pressure in the process of oil recovery. It may not only result in formation damage, but also have an adverse influence on production performance. In this paper, the deformation behavior of formation and formation damage are analyzed by elastic, elastic-plastic and plastic theory of solid porous media, and a set of expressions is derived to describe the change in porosity and permeability caused by linear or nonlinear deformation. Based on the comprehensive study on deformation of reservoir rock and multiphase flow in porous media, a new three dimensional and three phase-flow mathematical model that is used to predict the changes of porosity and permeability is presented, and the model is solved by the finite-difference method and self-adaptive iterative technique. A field-scale numerical simulator written in FORTRAN code is developed to predict the change trend of porosity and permeability in elastic and elastic-plastic deformation range.The runs of an oil field example with five-spot patterns are calculated on the simulator, and the formation damage and its influence on the pressure profiles in the vicinity around production well are studied under the condition of linear and nonlinear deformation of a reservoir. This work implies that the deformation of oil formation may be elastic, elastic-plastic or plastic in actual oil formation during the oil exploitation. The declines of porosity and permeability induced by the deformation are completely recoverable only for elastic deformation. Furthermore, elastic-plastic and plastic deformation may occur in the vicinity of production wells in unconsolidated formations. It is found that the increase of deformation coefficients presented in this work results in a sharp pressure-drop funnels on the vertical cross profile, which can be interpreted by the permeability decline induced by rock deformation. © 2014 Elsevier B.V.


Zhang F.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Zhang F.,China University of Geosciences | She Y.,Yangtze University | Banat I.M.,University of Ulster | And 5 more authors.
Energy and Fuels | Year: 2014

Based on 454 pyrosequencing of 16S rRNA gene amplicons, microbial communities in samples collected from seven wells, six of which had positive paraffin deposition reduction and one with negative paraffin deposition reduction upon a microbial treatment designed for the prevention of paraffin precipitation, were analyzed. Microbial communities' structures were significantly different for the samples from the negative well and the positive wells. Microbes affiliated with Diaphorobacter belonging to β- Proteobacteria were predominant in the negative well, While γ- Proteobacteria-affiliated microbes of Pseudomonas and Enterobacter and Firmicute-affiliated Bacillus were shared and dominant in the positive wells. Microbes shared in the positive wells could be considered as potential candidates for investigations into microbial paraffin control. In addition, microbial activity of hydrocarbon-degradation and microbial products such as biosurfactants were proposed to be the main potential mechanisms for the microbial treatment for the prevention of paraffin precipitation. © 2014 American Chemical Society.


Tao S.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Tao S.,China University of Geosciences | Tang D.-Z.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Tang D.-Z.,China University of Geosciences | And 7 more authors.
Oil Shale | Year: 2010

This paper aims at exploring new evaluation indicators of oil shale in order to evaluate and classify the industrial grade of oil shale and to provide the evaluation parameters for exploration and development of Bogda Mountain oil shale in China. We use organic petrology and organic geochemistry methods to make a systematic study on the relationship between petrological type, organic component content, hydrocarbon-generating potential, total organic carbon (TOC) and oil yield of the oil shale, basing on the results, the corresponding evaluation indexes are proposed. The results show that lithologic types and industrial grade of oil shales can be categorized as follows: videlicet, the content of organic component lower than 5%, between 5% and 15%, between 15% and 25%, and over 25% correspond to non-oil shale, low-quality, medium-quality, and high-quality oil shale. The total content of organic components, hydrocarbon-generating potential, TOC and oil yield correlate significantly with each other, so they can be easily used as indexes to evaluate the industrial grade of oil shale. For example, the coefficient R between organic carbon content of oil shale and oil content is 0.978, the oil yield 3.5% corresponds to the TOC 7.5%, the oil yield 5% corresponds to the TOC 9.5%, and 10% to the TOC 17.0%. © 2010 Estonian Academy Publishers.


Zhang F.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Zhang F.,China University of Geosciences | She Y.,Yangtze University | Zheng Y.,CAS Research Center for Eco Environmental Sciences | And 4 more authors.
Applied Microbiology and Biotechnology | Year: 2010

Currently, molecular biologic techniques achieve a great development in studies of soil samples. The objective of this research is to improve methods for microbial prospecting of oil and gas by applying cultureindependent techniques to soil sampled from above a known oil and gas field. Firstly, the community structure of soil bacteria above the Ban 876 Gas and Oil Field was analyzed based on 16S rRNA gene clone libraries. The soil bacteria communities were consistently different along the depth; however, Chloroflexi and Gemmatimonadetes were predominant and methanotrophs were minor in both bacteria libraries (DGS1 and DGS2). Secondly, the numbers of methane-oxidizing bacteria, quantified using a culture-dependent procedure and culture-independent group-specific real-time PCR (RT-PCR), respectively, were inconsistent with a quantify variance of one or two orders of magnitude. Special emphasis was given to the counting advantages of RT-PCR based on the methanotrophic pmoA gene. Finally, the diversity and distribution of methanotrophic communities in the soil samples were analyzed by constructing clone libraries of functional gene. All 508-bp inserts in clones phylogenetically belonged to the methanotrophic pmoA gene with similarities from 83% to 100%. However, most of the similarities were below 96%. Five clone libraries of methanotrophs clearly showed that the anomalous methanotrophs (Methylosinus and Methylocystis) occupy the studied area. © 2010 Springer-Verlag.


Yang C.,China University of Geosciences | Yang C.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Zhang J.,China University of Geosciences | Zhang J.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | And 2 more authors.
Earth Science Frontiers | Year: 2013

For further research on microscopic pore characteristics and geological accumulation significance of Ordos continental shale reservoir, samples from drilling cores of Benxi, Shanxi and member 7 and 9 of Yanchang Formation were collected to perform a series of experiments, including the Focused Ion Beam-Scanning Electron Microscopy (FIB-SEM), Mercury Injection, Helium Sorption-Desorption (HSD) and related chemical and physical experiments. The FIB-SEM confirmed that there are six kinds of microscopic pore types in Ordos continental shale, including inter-particle, intra-particle, inter-crystal, dissolution, organic pores and micro-cracks, of which the inter-particle pore (micro-scale) and intra-particle pore (nanoscale) of the clay minerals are most prevalent, coinciding with pore characterization by HSD; the dissolution pore and inter-crystal pore only exist in certain minerals with pore size in nanoscale; organic pore are also not well developed, with pore size less than 20 nm, characterized by its inclined occurrence in adhesive-combination organic matter and its pitted or gneissic shape; micro-cracks are a few, which are mostly brittle mineral splits or large through-type cracks. Furthermore, the results show that the inter-particle pores of clay mineral aggregation and intra-particle pores between layers make the greatest contribution to the occurrence and transportation of shale oil and gas, which is also the mainly controlling factor of the anisotropic of the shale reservoir. Inter-crystal pore and dissolution pore are ranked the second; organic pores are relatively undeveloped, so its contribution to permeability is small, but it still plays an important role in the occurrence of shale oil and gas. Meanwhile, the impact of micro-cracks cannot be ignored, which are the main channel connecting macropores with mesopores.


Zhang X.T.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Zhang X.T.,China University of Geosciences | Zhao H.J.,Yangtze University | Yu Q.,No. 1 Drilling Company | Hu J.J.,Yangtze University
Petroleum Science and Technology | Year: 2013

The source rocks of 20 oils in Eocene reservoir from Lengdong oil field have been evaluated using geochemical biomarkers. Most of the oil samples have been undergone light to moderate biodegradation and four of these oil samples suffered heavy biodegradation. The oils were originated from low maturity source rocks within early to middle oil window according to the thermal-maturation- dependent biomarker ratios. Source-related biomarkers indicated that the oils originated from carbonate source rock possessed both high plants and algae organic matter input, while high plants' input was dominant in almost all the oils. The source rocks concerning the oils were deposited under anoxic to suboxic (low EH), salinity to hypersaline, and lacustrine environment with deep water. © 2013 Copyright Taylor and Francis Group, LLC.


Tao S.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Tao S.,China University of Geosciences | Tang D.-Z.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Tang D.-Z.,China University of Geosciences | And 6 more authors.
Oil Shale | Year: 2011

On the basis of pyrolysis gas chromatography (PGC) technique, the retorting process of oil shale found at the northern foot of Bogda Mountain was simulated by a step-by-step procedure. The dynamic changes in recovery of all kinds of oil (gas) products, and their total recovery rate at different temperature ranges during pyrolysis were studied. Meanwhile, the reasons for these changes were analyzed, and the properties of oil shale were discussed. This paper provides some parameters to evaluate these properties precisely. The results show that the retorting process and the corresponding pyrolysis occur in three stages: 1) a few hydrocarbon products are generated below 410 °C, their amount increasing slowly with temperature; 2) the amount of hydrocarbon products increases rapidly in the range of 450-510 °C, accounting for 70% of the total, and the yield has maximum at about 490 °C; 3) gaseous hydrocarbons are the main products above 510 °C, whereas their yield is small. Oil shale found at northern foot of Bogda Mountain is characterized by the advantage to yield light oil. In future processing and refining, the temperature should be maintained between 450 °C and 510 °C to recover oil (gas) products, especially light oil, effectively. Original hydrocarbon-generating potential is the principal factor in controlling the behavior of oil shale during the process. The greater the original hydrocarbon-generating potential, the larger the amount of heavy oil products generated at the high-temperature stage. © 2011 Estonian Academy Publishers.


Mingjian W.,China University of Geosciences | Mingjian W.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | Dengfa H.,China University of Geosciences | Dengfa H.,Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism | And 3 more authors.
Petroleum Exploration and Development | Year: 2011

This paper analyzes the Upper Palaeozoic gas accumulations and conditions of the study area by using the definition and method of petroleum system, and summarizes the natural gas accumulation pattern. The Upper Palaeozoic natural gas in the Yimeng Uplift is mainly from source rocks of Taiyuan and Shanxi Formations in the southern part and Wushenqi area. Braided channel sandbodies of alluvial fan, river channel sandbodies and distributary channel sandbodies of delta plain in the Shanxi and Xiashihezi Formations are the most favorable reservoirs. The thick mudstone layers of the Shangshihezi and Shiqianfeng Formations which cover the whole region constitute the regional seal rock, and there are also many local seal rocks. Oil source, reservoir and seal rocks form a good relationship in time and space and they form two types of assemblage which are the self-generating and self-preserving assemblage in the southern part of the Yimeng Uplift and the lower-generating and upper-preserving assemblage in the southern and northern parts. Natural gas migrated to the north through the migration pathways composed by advantageous sandbody, unconformity, faults and cracks. Structural traps and the distal accumulation pattern dominate in the northern part, while the southern part is characterized by lithologic traps and the proximal accumulation pattern. © 2011 Research Institute of Petroleum Exploration & Development, PetroChina.

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