Oil Zone Research Articles

Source Rock Evaluation and 1-D Basin Modelling Approach for the Sargelu Formation, Atrush-2 Well, Kurdistan Region-Iraq

The present study focuses on source rock evaluation of the Sargelu Formation by using core chips of rocks collected from well Atrush-2, Duhok, Kurdistan Region-Iraq. The Rock-Eval pyrolysis and vitrinite reflectance were executed. Subsequently, the selected parameters were used for source rock evaluation and 1-D Basin Modelling calibration. The upper part of the formation mainly comprises argillaceous limestone with low content of organic matter (0.64% - 1% TOC). By contrast, the lower part is dominated with shale interval and contains high amounts of TOC values (>4% for 1272 - 1278 m) reveling good to very good quality source rock. Accordingly, good to very good hydrocarbon generation potential is suggested for this formation. Organic matter of the Sargelu Formation contains type II and mixed-type II-III kerogen. The values of Tmax and vitrinite reflectance (Ro%) demonstrate that the formation is thermally mature and in the oil zone. In order to construct a thermal history of the formation and determine the timing of hydrocarbon maturation and generation, the 1-D basin modelling PetroMod 2019.1 was used in this study. Based on the 1-D Basin modelling simulation and its outputs, about 3500 m of overburden have been eroded at the study area. The present-day heat flow was found to be 30 mW/m2. The organic matter of Sargelu Formation entered the early oil zone in 64 Ma and reached the main oil zone ca. 5 Ma. The formation is still in the main oil zone at present-day. In well Atrush-2, the highest rate of oil generation for the Sargelu Formation was in the 8.5 Ma, the onset of oil expulsion from Sargelu Formation was in 50 Ma and the expulsion mass has been reached 0.5 Mtons at present-day.

Разработка вероятностных моделей зонального прогноза нефтегазоносности центральной части Пермского свода по структурно-мощностным критериям

The task to which this article is devoted has not received due attention in recent years, since the preparation of structures for deep drilling is carried out using seismic exploration. At the same time, there is a huge array of data on structured drilling, unfortunately, it has not been fully used. Thus, the goal of the study is to use data on structured drilling to solve not only structural problems for marking surfaces, but also more complex ones related to zonal oil and gas potential of territories. The forecast of oil and gas content for marking and oil and gas horizons was carried out in three zones of oil and gas geological zoning. Using the data on these territories, studies were carried out to build probabilistic models for the zonal forecast of oil and gas content. To substantiate the joint use of data on marking surfaces and data on the tops of oil-bearing horizons, materials were studied for 447 deep wells. Probabilistic models of zonal forecast of oil and gas content of the central part of the Permian uplift were developed according to structural and capacity criteria. The complex use of data on the absolute marks of deep and structured wells made it possible to rank the territory of the central part of the Permian uplift by the degree of zonal oil and gas content. Severokamskoye (0.73), Krasnokamskoye (0.67), Baklanovskoye (0.67), Polaznenskoye (0.67), Rassvetnoye (0.64) and Mezhevskoye (0.63) fields were characterized by the maximum values of P COM. For the Kozubaevskoye field, the P COM was 0.57. The Gorskoye, Lobanovskoye, Talitskoye, Zorinskoye and Shemetinskoye fields were characterized by minimum values of P COM, varying in the range of 0.51–0.53. This scheme can be used when designing prospecting and exploration works in this area.

Assessing the charactersistic of hydrocarbon is showed by intergrating petrophysic data field X

Based on the analysis and interpretation of drilling and petrophysics documents, the paper evaluates the hydrocarbon potential of the Oligocene sandstone set at field X. The paper presents some methods of gas classification based on gas chromatographic indicators and the hydrocarbon content in the drilling fluid. Besides, the paper also developed a process to analyze the fluid composition in the formation based on the Wh-Bh-Ch indexes on the gas peaks in the mud logging. The interpreted results from 8 gas peaks in the X-S16P well through the Oligocene sedimentary set identified potential oil and gas zones of field X, as well as the distribution of reservoir fluid. By comparing the results of well logging from GR, density, resistivity curves and the analysis of DST, it corrects the O&G behaviors at field X. The DST’s results of X-S16P well at X field in a depth interval of 2,827- 2,887m throughout the interlaced sandstone set indicate an oil flow rate of 8,826 barrels/day, which is coincident with the results of O&G behavior in mud logging; therefore, it’s concluded that the integration of mud logging with other petrophysical documents allows increasing the reliability of O&G potential evaluation. Furthermore, analyzing and evaluating different indicators to determine the gas composition throughout the drilling process is considered a quick way to predict and classify the products.

Bauxite Reservoirs at the Contact Zone between Paleozoic and Mesozoic Deposits of the West Siberian Plate

Bauxite rocks of the pre-Jurassic complex of the Urmano-Archinskaya oil and gas zone of the West Siberian Plate, which mainly formed due to redeposition of the products of crust weathering into karst traps, are considered. Igneous rocks of the intermediate composition and shales exposed in erosion–tectonic uplift of the basement to the northeast of the studied area could be the parent rocks. The aluminous composition and reservoir properties of bauxite rocks are due to filtration of hydrothermal solutions at the intermediate or deep burial diagenesis.

To the issue of oil and gas potential in the decompression zones of the Dnieper-Donets depression

Formulation of the problem. Currently, interest in the foundation as a gas and oil field facility has increased significantly. The low efficiency of oil and gas exploration in the basement rocks is usually explained by the absence of a generally accepted hypothesis about the genesis of oil and gas and as a result of migration and accumulation of hydrocarbons. One of the main factors of accumulation is the presence of decompression zones of the foundation, as potential hydrocarbon traps. The article is devoted to the problem of identifying oil and gas bearing zones of foundation decompression. Analysis of recent research and publications. A number of scientific articles on the composition, age, structure and oil and gas potential of the foundation are analyzed. The first step in identifying decompression zones is to conduct gravimetric and magnetic surveys and apply various techniques to interpret the resulting mathematical model of the wave field pattern in order to localize the sources of its anomalies. Identification of previously unresolved parts of a common problem. In order to save money when conducting prospecting and exploration for oil and gas, the foundation proposes an improvement in the methodology for separating gas-bearing “vaulted” parts of decompression zones. Formation of the purpose of the article. The aim of the work is to establish a seismic pattern of anomalies in the geophysical fields of the base decompression zones. The object of research is the zone of decompression of the foundation on the northern side of the Dnieper-Donets depression. The subject of the study is a seismic drawing of the anomaly of the geophysical field of the gas-bearing zone of decompression of the foundation of the Rozsoshinsk structure. Report of the main material. The article analyzes a few materials to identify areas of base decompaction in various oil and gas regions. It was found that for localization of decompression zones, the Berezkin “singular points” method and the correlation method of separation of geophysical anomalies are most effective. The essence of these methods is a kind of filtering of field anomalies, where against the background of the "structural" factor, one can distinguish the "non-structural factor", i.e. decompression zone. This zone in wave fields (∆g and ∆Т) is fixed by a seismic pattern, where minima are usually fixed over hydrocarbon accumulations in relation to contouring maxima. Based on the results of the application of these methods, the structure-testing ground of the gas-bearing decompression zone is established. As an illustrative example of the successful localization of ∆g and ∆Т, data are presented on modeling the foundation softening zone in one of the oil and gas regions of the northern side of the Dnieper-Donets depression.

О ВОЗМОЖНОСТИ УВЕЛИЧЕНИЯ РЕСУРСОВ УВ СЫРЬЯ В ЦЕНТРАЛЬНОЙ ЧАСТИ РЕСПУБЛИКИ САХА (ЯКУТИЯ)

The article presents the results of geological exploration carried out in 2016–2018 in the Sinskaya area, located on the adjacent territory of the Vilyui syneclise and Aldan anteclise. Based on the complex of geochemical and seismic surveys in the northern part of the area, the identification of predicted oil and gas accumulation zones is substantiated. Predicted zones are distinguished at the site of reduced thicknesses and pinch-out of Permian and Triassic deposits. Taking into account the nature of concentration variations of HC components sorbed by subsoil sediments, it is assumed that hydrocarbon fluids have predominantly gas-condensate state. The appearance of the oil phase is predicted for the southern perspective zone. On the ground of predictive definitions and the results of performed operations, recommendations were given on the placement of parametric drilling and allocation of licensed blocks for subsequent exploration. Prognosis evaluations of HC resources are done.

МАТЕМАТИЧНА МОДЕЛЬ ІНТЕГРАЦІЇ ГЕТЕРОГЕННИХ ДАНИХ ПРИ ОЦІНЮВАННІ НАФТОГАЗОПЕРСПЕКТИВНИХ ТЕРИТОРІЙ

Основною метою досліджень є підвищення точності і надійності прогнозу нафтогазоперспективних зон і нафтогазоносних об'єктів. Космогеологічні дослідження проводяться для оперативної оцінки нафтогазоносності пошукових площ на етапі, що передує їх введення в розвідувальне буріння. Сучасні технології застосування матеріалів дистанційного зондування Землі в геолого-пошукових дослідженнях ґрунтуються на інтеграції з іншими геопросторовими даними - картографічними, геологічними, геофізичними, геохімічними та іншими. Це дозволяє усунути суб'єктивізм, що має місце при візуальній інтерпретації супутникових зображень. Інтегрування дистанційних та геолого-геофізичних просторових даних дає можливість автоматизувати процес оцінки досліджуваної площі і встановити її схожість з еталонними ділянками (родовищами). Класифікація гіперкуба дистанційних та геолого-геофізичних даних дозволяє визначити ступінь подібності досліджуваних ділянок з еталонами і проранжувати їх за перспективністю. Пропонується модель інтеграції дистанційних та геолого-геофізичних даних на основі байєсівського імовірнісного виведення. При картуванні нафтогазоперспективних ділянок оцінюються апріорні і умовні ймовірності приналежності растрових елементів гіперкуба даних позитивному або негативному еталону з подальшим обчисленням апостеріорної ймовірності приналежності кожного елемента позитивному еталону. Запропонована модель апробована на прикладі Хухрінского нафтогазоконденсатного родовища, розташованого в Охтирському районі Сумської області України. Родовище характеризується складною геологічною будовою і для його вивчення використовувалися всі наявні гетерогенні геопросторові дані. В результаті виконаної інтеграції дистанційних та геолого- геофізичних даних отримано просторовий розподіл апостеріорної ймовірності, яку можна трактувати як комплексну оцінку нафтогазоперспективності площі, що досліджувалася. Результати апробації добре узгоджуються з попередніми геологічними прогнозами.

ДИНАМІКА РОЗВИТКУ ЛІТОФЛЮЇДНИХ НАФТОГАЗОВИХ СИСТЕМ У КРЕЙДОВИХ ВІДКЛАДАХ ЗАХІДНОЇ ЦЕНТРИКЛІНАЛІ ПРИЧОРНОМОРСЬКОГО МЕГАПРОГИНУ

On the basis of modeling the dynamics of the catagenesis of the Cretaceous deposits, the lateral heterogeneity of the history of their catagenesis within the western part of the Black Sea megadepression, caused by the tectonic regime of the blocks separated by the Golitsyn, Sulino-Tarkhankutsky, Gubkino-Donuzlavsky sublatitudinal faults, was established. The spatio-temporal features of the development of reservoirs and migration paths of hydrocarbon fluids have been established, the predicted zones of oil and gas accumulation have been localized. There are four types of lithogenetic reservoirs, which differed in the time of formation, structural features, fluid regime and the nature of oil and gas saturation.In the first cycle of catagenesis, the generation center was localized mainly in the sediments of the Lower Albian (t 80–100 оС), in the second – the Middle Albian (t 100–120 оС), in the third – the Upper Albian (t 130–150 оС).Given a certain difference in the situations of sedimentation of these stratigraphic units, the composition and content of scattered organic matter in the sediments were different. This, as well as the different generation temperatures, obviously caused the specific composition of hydrocarbon fluids formed during individual cycles of catagenesis. Along the migration pathways and during structural changes, these fluids were mixed, multicomponent systems were formed, and the composition of hydrocarbons changed.The possibility of the existence of subvertical "vein" areas of oil and gas accumulation with a width of up to 10 km and a height of 1,5–2,0 km is argued. Such reservoirs, on the one hand, may contain deposits and, on the other hand, supply hydrocarbons to overlying traps. Given the nature of oil and gas accumulation, the potential resources and, consequently, the prospects for oil and gas in the region can be much higher.

Detection of intervals / layers in sections of the wells with anomalous areas of drilling mud filtrate contamination according to the well logging (with negative test results of horizons)

The zone of infiltration of the drilling fluid filtrate into the reservoir rock creates significant difficulties for the study by logging methods and during further testing of the formation. Due to the penetration of filtrate, significant contamination of the near-wellbore zone occurs. The porosity and filtration characteristics of reservoir rocks are changing. There is a possibility of blockage by filtrate in the invaded zone of oil or gas flow from the formation to the well. As a result of the studies carried out using well logging data, it was found that the presence and distribution of a mud cake on the borehole wall opposite the reservoir is an important factor influencing the process of filtration of the drilling fluid into the layers. On the examples of the Yablunivske oil and gas and Kolomatske gas fields of the Dnieper-Donets basin, it is shown that the absence of a mud cake on the borehole walls leads to the formation of maximum, anomalous zones of filtrate invasion. The determining of the diameter of the invaded zone was carried out according to the data of electrical logging methods. In addition, the diameter of the invaded zone was calculated as a solution direct task equation for the case of direct filtration without blocking by the mud cake. Comparison of the results of determining the diameter of the invaded zone by two methods made it possible to draw certain conclusions. An important conclusion is that even partial absence of mud cake on the reservoir wall in the well leads to horizontal and vertical filtration of the drilling fluid from the well into the formation. As a result, the invaded zone may be so deep, that the gas flow rate is absent even at high values of porosity, permeability and gas saturation

Катагенетическая характеристика органического вещества пород Гыданской параметрической скважины

The study of dispersed organic matter of the Mesozoic sediments of the Gydan parametric well 130 (north of Western Siberia) made it possible to reveal its genesis, maceral composition, and secondary changes. Obtained information allowed reconstructing and the catagenetic zoning of the section, determining the position of the lower boundary of oil occurrence, the main zones of oil and gas generation

Sedimentary micro-phase and reservoir display characteristics in shale Oil

Sedimentary microphilic and its exhibition feature is of great significance for identifying the distribution of remaining oil. This paper studies the development of geological characteristics of Zhidan Oil Zone, mineralogue and scanning electron microscopy experiments, and obtains the sedimentary micro-phase and reservoir display characteristics. The results show that combined with logging data, the core phase analysis, logging phase analysis, single well phase analysis, etc. Taking the leading edge of the Delta, the microphase type such as the river, the diversion bay and the underwater natural embankment is developed under water, due to the lifting of the lake, form a number of invested, plus, replenishment, in which water The downstream river is facilitating the advantages of the reservoir. The sedimentary phase and the angle effect of the zone are dominated by 4 + 5, chang 6 oil and gas, showing the characteristics of the rock sex reservoir. The type of reservoir is a rock sex reservoir. The main development of sandstone is impaired and the sandstone lens is a rock sex reservoir. The reservoir is an important influencing factor in the reservoir. The area has no uniform oil and water interface, lacking edge, bottom water.

CO2-EOR+ in Australia: achieving low-emissions oil and unlocking residual oil resources

The petroleum industry, through the production and consumption of oil and gas, contributes to global greenhouse gas emissions. However, the industry’s leadership and experience in underground injection and storage of CO2, especially through CO2 enhanced oil recovery (CO2-EOR), which has been proposed as a possible solution to reducing atmospheric CO2 levels, has not been well acknowledged. Unlike traditional CO2-EOR, which tends to be a net carbon emitter due to the use of predominantly natural CO2, rather than anthropogenic, CO2-EOR+ focuses on storing a larger volume of CO2. Thus CO2-EOR+ not only provides a potential solution to dispose of anthropogenic emissions but at the same time reduces reliance on imported oil through increased domestic production. Increased industry interest and energy policy strategies directed at reducing and/or removing emissions from industry processes reflect the growing social and economic impetus to improve operation practices and the petroleum industry’s reputation. Residual oil zones (ROZs) below identified oil–water contacts provide an excellent target for the application of CO2-EOR+. They offer a producible residual oil resource accessible through CO2-EOR, as well as a large pore volume for CO2 storage, with efforts focused on converting ROZs into resources and reserves. Existing fields in the Surat and Cooper-Eromanga Basins are already well placed to utilise anthropogenic CO2 sources to achieve conventional CO2-EOR metrics. The ROZs in these basins will hopefully allow potential EOR projects to increase the CO2 volumes stored, per incremental barrel of oil, well past traditional levels (0.2–0.3 tCO2/bbl), and in doing so, potentially achieve net negative-emission oil.

Геохимическая роль метеорных вод как фактор формирования пустотного пространства коллекторов нефти и газа

The features of the chemical composition of formation waters of the Upper Permian, Lower and Middle Triassic aquifers within individual structures of the Malozemelsk-Kolguev monocline of the Timan-Pechora oil and gas bearing basin are examined. It is shown that the aquifers that, despite their remoteness from the recharge areas, had experienced repeated processes of dipping and uplifting of the territory, preserved the infiltration waters, but significantly transformed ones. To identify their genetic profile and determine the relationship with the processes of catagenetic changes, hydrochemical coefficients and indices of water saturation of calcium carbonate and calcium sulfate are calculated. It is established that the examined infiltration waters are characterized by high aggressiveness, dissolution ability, leaching and removal of main minerals. It is pointed out that the consequence of these processes is the formation of secondary void space and the creation of high capacitive and filtration properties of rocks. The universality of geochemical interaction between water and rocks in thermodynamically open geological systems is emphasized and it is confirmed by individual geological examples that the heterogeneity of the hydrochemical field can act as a cause of screening zones of oil and gas accumulation, as well as provide appropriate conditions for localization of hydrocarbon fluids.

Роль водонапорных систем древних осадочных бассейнов в процессах нефтегазонакопления

The article presents the authors’ ideas about the role of post-expulsion water-drive systems in localization of hydrocarbon deposits. It substantiates the key factors of hydrodynamic stagnation, which is a characteristic feature of the large depths of ancient sedimentary basins; it reveals that, within their bounds, in conditions of regional reservoir pressure deficiency the formation of synclinal hydrocarbon deposits is possible, and under ultra-high reservoir pressure – that of zones of oil and gas accumulation of autoclave type, within which the hydrogenation of mixed humus–sapropel organic matter is viable.

Западная часть Терско-Каспийского прогиба как зона разгрузки глубинных флюидных систем

The article describes the mechanisms of formation of the Terek and Sunzha anticlinoria as the main zones of oil and gas accumulation. An assumption is made about the formation of high-amplitude anticlinal folds in the Upper Cretaceous deposits as a result of vertical migration of high-pressure fluids along deep faults with a breakthrough of their upper horizons of the sedimentary cover into the late orogenic phases of folding. The main prerequisites for the deep genesis of oil and gas are listed – a pronounced unevenness in the distribution of hydrocarbon accumulations, abnormal pressure, hydrochemical anomalies.

An improved hydrocarbon generating model of source rocks and its application: a case study of shale oil in-situ transformation of the Yanchang Formation in the Ordos Basin

Hydrogen index, HI, and original hydrogen index, HIo, are important indicators for measuring the hydrocarbon generation potential of the source rock. Through addressing the shortcomings of existent HIo models, improved models are proposed to improve the coincidence between calculated and measured results. According to the statistics of rock pyrolysis and TOC data of 1,249 cores taken in seven basins, key parameters of HIo models for types I, IIa, IIb, and III kerogen are obtained, complements quantitative evaluation methods for effective source rocks and provides a theoretical basis for evaluating in situ transformation of shale oil and hydrocarbon generating potential of deep source rocks. These models have been applied to evaluate the in situ transformed shale oil in the Yanchang Formation of the Ordos Basin, and the result reveals: (1) the transformed shale oil amounts to 375.9 × 108 t, and natural gas to 4.17 × 1012 m3; the average resource abundance of shale oil is 114.6 × 104 t/km2; the new organic porosity originated averages 6.9%; and the sweet spot zones of shale oil are mainly distributed on the north of Zhengning and Well Mu78; (2) in situ transformation would increase in situ resources, gas-to-oil ratio, porosity and permeability, and improve the productivity of shale oil in the Chang 7 member.

Multi-physics approach to modelling near-miscible CO2-WAG process

CO2 Water-Alternating-Gas injection (CO2-WAG) under near-miscible conditions entails interactions between multi-physical processes at different length scales, which is not fully understood mechanistically. This research contributes to our fundamental understanding of the fluid behaviour driven by major physical mechanisms including compositional effects (denoted as MCE), interfacial tension effects (denoted as MIFT), capillary forces and gas trapping. The total system size was of order 1 large-scale “grid block” (~50m), which allowed us to capture the multi-scale behaviour from the cm to the 50m scale. Using fine-scale 2D areal simulations, this study identifies the separate and combined contributions of mechanisms to the recovery of bypassed oil induced by viscous fingering. Mechanisms MCE and MIFT work in tandem to improve the oil recovery through stripping oil components and enhancing viscous crossflow. However, the magnitude of such benefits is highly dependent on the ancillary effects of gas trapping and the capillary forces (system wettability). In a water-wet system, gas trapping modestly constricts actions of MIFT whereas capillary forces significantly degrade the sweep efficiency and lead to multiple isolated oil zones. We also found that the negative impacts of capillary pressure on the oil recovery can be much reduced if CO2 is injected prior to any water injection. On the other hand, oil-wet capillary forces hardly decrease the ultimate oil recovery in our cases. For the first time, flow trajectories, phase occupancies, oil compositions and interfacial tension as a function of permeability are explicitly depicted for each WAG cycle, which effectively unpicks the complexity of near-miscible CO2-WAG process.

Rifting and Lifting Neogene Age in Biak-Yapen Basin Based on Structural Trajectory Analogy in Biak and Supiori Island

The aim of this study is to calculate the rifting and lifting phase of Neogene age in the Biak - Yapen Basin region, related to the prediction of an oil and gas trap zone based on the analogy of the surface measurement trajectory. The methodology used is the measurement of geological structures on the surface and in the data analysis using Delvaux, 1997 and Zoback, 2007 concept. Based on the structure measurement in outcrop, there are 78 stations along Biak Island and Supiori Island, which will be used and projected as an analogy to the offshore basin. Statistically in the archipelago shows that there are three times rifting phase domination candidates categorized as maximum intensity and a lifting phase candidates are also categorized as maximum intensity. There are three times rifting phase with movement direction, σ-3 is relatively horizontal, consisting of NE-SW direction with an intensity of 15.60% rifting aged Middle to Late Miocene, ENE-WSW direction with intensity 13.30% rifting aged Late Miocene to Pliocene and finally from the W-E direction with an intensity of 17.80% rifting aged Pleistocene. The three rifting phases are followed by sedimentation of carbonate rock from the Middle Miocene to the Pleistocene aged which consists of Napisendi Fm, Korem Fm, Wardo Fm, and Mokmer Fm. The lifting phase once occurred with the compressional direction, σ-1 is relatively horizontal, directed at W-E with an intensity of 21.20% lifting aged Pleistocene to Resen. This phase has elevated formations from the age of the Late Oligocene to the Pleistocene in the archipelago.

Comparison of In Vitro Testing Antifungal Activity between Rosemary Essentials Oil and Fluconazol on Candida species Isolate from HIV/AIDS Patients with Candidiasis Oral

Background: The most common opportunistic infection obtained in patients with Human Immunodeficiency Virus (HIV)/Acquired Immune Deficiency Syndrome (AIDS) is Oral Candidiasis (OC). Currently widely reported about increased fluconazole resistance, as a therapy that is often used in patients with HIV/AIDS with OC. For this reason, effective antifungal agents are needed as alternative therapies. Several studies have reported some antifungal activity from rosemary essential oils. Purpose: The aim of this study is to evaluate the antifungal activity between rosemary essential oils and fluconazole against the isolates used by Candida sp. taken from HIV / AIDS patients with OC. Methods: This research was an experimental laboratory study with a post-test only design of 40 Candida sp. isolates from HIV / AIDS patients with OC in the Outpatient Unit and Inpatient Installation of the Infectious Disease Intermediate Care Unit (UPIPI) Dr. Soetomo General Academic Teaching Hospital, Surabaya. Examination of antifungal activity using conventional test methods with disk diffusion. Result: Disk diffusion test result revealed average inhibition zone of rosemary essential oil in Candida albicans 1,75±3,64 mm and Candida non-albicans 1,5±3,08 mm, while the average inhibition zone of fluconazole in Candida albicans 17,9±8,62 mm and Candida non-albicans 4,85±7,9 mm. There was significant difference (p <0.001) between the inhibition zone formed in Candida albicans by fluconazole and rosemary essential oil, but no significant difference of inhibition zone formed in Candida non-albicans. Conclusion: Antifungal activity fluconazole has greater than Rosemary essential oils in Candida albicans.

Reservoir Formation Model and Main Controlling Factors of the Carboniferous Volcanic Reservoir in the Hong-Che Fault Zone, Junggar Basin

The Hong-Che Fault Zone is one of the important oil and gas enrichment zones in the Junggar Basin, especially in the Carboniferous. In recent five years, it has been proven that the Carboniferous volcanic rock has 140 million tons of oil reserves, and has built the Carboniferous volcanic reservoir with a capacity of million tons. Practice has proven that the volcanic rocks in this area have great potential for oil and gas exploration and development. To date, Carboniferous volcanic reservoirs have been discovered in well areas such as Che 32, Che 47, Che 91, Chefeng 3, Che 210, and Che 471. The study of drilling, logging, and seismic data shows that the Carboniferous volcanic reservoirs in the Hong-Che Fault Zone are mainly distributed in the hanging wall of the fault zone, and oil and gas have mainly accumulated in the high part of the structure. The reservoirs are controlled by faults and lithofacies in the plane and are vertically distributed within 400 m from the top of the Carboniferous. The Carboniferous of the Hong-Che Fault Zone has experienced weathering leaching and has developed a weathering crust. The vertical zonation characteristics of the weathering crust at the top of the Carboniferous in the area of the Che 210 well are obvious. The soil layer, leached zone, disintegration zone, and parent rock developed from top to bottom. Among these reservoirs, the reservoirs with the best physical properties are mainly developed in the leached zone. Based on a comprehensive analysis of the Carboniferous oil and gas reservoirs in areas of the Chefeng 3 and Che 210 wells, it is believed that the formation of volcanic reservoirs in the Hong-Che Fault Zone was mainly controlled by structures and was also controlled by lithofacies, unconformity surfaces, and physical properties.