Characteristics of Fracture and Fractured Reservoir of Hailaer Basin Budart Group

2013 ◽  
Vol 316-317 ◽  
pp. 826-829
Author(s):  
Cui Ju Feng ◽  
Wei Lin Yan
Keyword(s):  
Oil And Gas ◽  
Low Permeability ◽  
Fractured Reservoir ◽  
Fracture Density ◽  
High Angle ◽  
Pore System ◽  
Reservoir Evaluation ◽  
Angle Fracture ◽  
Conventional Logs ◽  
Huge Challenge

The output of fracture pool is over half of the entire outout of oil and gas,and fracture pool is one of the important fields of oil inhancing yield in 21st Century. Fractured reservoir evaluation is always a huge challenge for the oil exploration and development. Budart Group of Sudert district in Hailaer Basin is a reservoir that has very low porosity、very low permeability、double pore system and it is rich of fracture. The paper summarized Hailaer Basin Budart Group reservoir’s characteristics, especially fractures’s characteristics in conventional logs,fracture’s parameters,such as fracture density,dip,width and filling and illustrate the response of low angle fracture and high angle fracture in logs.

Fractures and Flow Patterns Detection in Carbonate Reservoirs Using Intelligent Sensor Selection in a Deep Learning and Uncertainty Framework

2021 ◽  
Author(s):  
Klemens Katterbauer ◽  
Alberto Marsala ◽  
Abdallah Al Shehri ◽  
Ali Yousif
Keyword(s):  
Deep Learning ◽  
Industrial Revolution ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Sensor Selection ◽  
Sensor Data ◽  
Data Uncertainty ◽  
Fractured Reservoir ◽  
Sweep Efficiency ◽  
Reservoir Evaluation

Abstract 4th Industrial Revolution (4IR) technologies have assumed critical importance in the oil and gas industry, enabling data analysis and automation at unprecedented levels. Formation evaluation and reservoir monitoring are crucial areas for optimizing reservoir production, maximizing sweep efficiency and characterizing the reservoirs. Automation, robotics and artificial intelligence (AI) have led to tremendous transformations in these areas, in particular in subsurface sensing. We present a novel 4IR inspired framework for the real-time sensor selection for subsurface pressure and temperature monitoring, as well as reservoir evaluation. The framework encompasses a deep learning technique for sensor data uncertainty estimation, which is then integrated into an integer programming framework for the optimal selection of sensors to monitor the reservoir formation. The results are rather promising, showing that a relatively small numbers of sensors can be utilized to properly monitor the fractured reservoir structure.

Fracture Qualitative Identification Using Conventional Logging Data

2013 ◽  
Vol 316-317 ◽  
pp. 822-825
Author(s):  
Cui Ju Feng ◽  
Wei Lin Yan
Keyword(s):  
Oil Exploration ◽  
Fractured Reservoir ◽  
Reservoir Evaluation ◽  
Response Characteristics ◽  
Actual Production ◽  
Huge Challenge ◽  
Probability Index

Fractured reservoir evaluation is always a huge challenge for the oil exploration and development.The paper summarizes the response characteristics of fracture in conventional logging curves and gives 4 parameters which can identify fractures.Furthermore the paper proposes a comprehensive probability index of fracture which can integrate the 4 parameters above and indicate fracture develop rate qualitatively.In addition,the paper classified fracture developing level into three levels.Actual process shows that this method can indicate fracture develop rate,search fractured formation and guide actual production.

ASSESSMENT OF OIL WELL PRODUCTIVITY IN LOW-PERMEABILITY RESERVOIRS IN THE FIELDS OF EASTERN SIBERIA

2017 ◽  
pp. 30-36
Author(s):  
R. V. Urvantsev ◽  
S. E. Cheban
Keyword(s):  
Oil Recovery ◽  
Large Scale ◽  
Oil And Gas ◽  
Oil Extraction ◽  
Low Permeability ◽  
Oil Well ◽  
Eastern Siberia ◽  
Development Costs ◽  
Traditional Fields ◽  
Low Permeability Reservoirs

The 21st century witnessed the development of the oil extraction industry in Russia due to the intensifica- tion of its production at the existing traditional fields of Western Siberia, the Volga region and other oil-extracting regions, and due discovering new oil and gas provinces. At that time the path to the development of fields in Eastern Siberia was already paved. The large-scale discoveries of a number of fields made here in the 70s-80s of the 20th century are only being developed now. The process of development itself is rather slow in view of a number of reasons. Create a problem of high cost value of oil extraction in the region. One of the major tasks is obtaining the maximum oil recovery factor while reducing the development costs. The carbonate layer lying within the Katangsky suite is low-permeability, and its inventories are categorised as hard to recover. Now, the object is at a stage of trial development,which foregrounds researches on selecting the effective methods of oil extraction.

scholarly journals Impact of Diagenesis on the Low Permeability Sandstone Reservoir: Case Study of the Lower Jurassic Reservoir in the Niudong Area, Northern Margin of Qaidam Basin

Minerals ◽  
2021 ◽  
Vol 11 (5) ◽  
pp. 453
Author(s):  
Wenhuan Li ◽  
Tailiang Fan ◽  
Zhiqian Gao ◽  
Zhixiong Wu ◽  
Ya’nan Li ◽  
...  
Keyword(s):  
Physical Properties ◽  
Oil And Gas ◽  
Qaidam Basin ◽  
Isotope Analysis ◽  
Lower Jurassic ◽  
Low Permeability ◽  
Hydrocarbon Generation ◽  
Northern Margin ◽  
Pore Evolution ◽  
Sandstone Reservoir

The Lower Jurassic reservoir in the Niudong area of the northern margin of Qaidam Basin is a typical low permeability sandstone reservoir and an important target for oil and gas exploration in the northern margin of the Qaidam Basin. In this paper, casting thin section analysis, scanning electron microscopy, X-ray diffraction, and stable isotope analysis among other methods were used to identify the diagenetic characteristics and evolution as well as the main factors influencing reservoir quality in the study area. The predominant types of sandstone in the study area are mainly feldspathic lithic sandstone and lithic arkose, followed by feldspathic sandstone and lithic sandstone. Reservoir porosity ranges from 0.01% to 19.5% (average of 9.9%), and permeability ranges from 0.01 to 32.4 mD (average of 3.8 mD). The reservoir exhibits robust heterogeneity and its quality is mainly influenced by diagenesis. The Lower Jurassic reservoir in the study area has undergone complex diagenesis and reached the middle diagenesis stage (A–B). The quantitative analysis of pore evolution showed that the porosity loss rate caused by compaction and cementation was 69.0% and 25.7% on average, and the porosity increase via dissolution was 4.8% on average. Compaction was the main cause of the reduction in the physical property of the reservoir in the study area, while cementation and dissolution were the main causes of reservoir heterogeneity. Cementation can reduce reservoir space by filling primary intergranular pores and secondary dissolved pores via cementation such as a calcite and illite/smectite mixed layer, whereas high cement content increased the compaction resistance of particles to preserve certain primary pores. δ13C and δ18O isotopes showed that the carbonate cement in the study area was the product of hydrocarbon generation by organic matter. The study area has conditions that are conductive to strong dissolution and mainly occur in feldspar dissolution, which produces a large number of secondary pores. It is important to improve the physical properties of the reservoir. Structurally, the Niudong area is a large nose uplift structure with developed fractures, which can be used as an effective oil and gas reservoir space and migration channel. In addition, the existence of fractures provides favorable conditions for the uninterrupted entry of acid fluid into the reservoir, promoting the occurrence of dissolution, and ultimately improves the physical properties of reservoirs, which is mainly manifested in improving the reservoir permeability.

The Current Situation and Prospects of Development of Low Permeability Oil Reservoir

2013 ◽  
Vol 734-737 ◽  
pp. 1286-1289 ◽  
Author(s):  
Lin Cong ◽  
Wen Long Li ◽  
Jing Chao Lei ◽  
Ru Bin Li
Keyword(s):  
Research Methods ◽  
Oil And Gas ◽  
Low Permeability ◽  
Oil Reservoir ◽  
Oil Exploration ◽  
Gas Field ◽  
Oil And Gas Field ◽  
Low Permeability Reservoirs ◽  
Technical Measures ◽  
Exploration And Development

Internationally the research of low permeability oil reservoir is a difficult point in the exploration and development of oil and gas field. This thesis, based on the research methods of low permeability reservoirs at home and abroad, summaries several major problems encountered in the process of low permeability oil exploration and development under the current technical conditions as well as the corresponding, but more effective technical measures that need to be constantly improved. And that exploration and development of low permeability of the reservoir will be the main battle field for some time in the future of oil exploration and development.

Estimation of driving pressure ratio and paleostresses from veins in the Pelling-Munsiari shear zone, Sikkim Himalayan Fold Thrust Belt

2021 ◽  
Author(s):  
Deblina Ray ◽  
Kathakali Bhattacharyya
Keyword(s):  
Crustal Deformation ◽  
Pressure Ratio ◽  
Fluid Pressure ◽  
Driving Pressure ◽  
Field Analysis ◽  
Stress Axis ◽  
High Angle ◽  
Mylonitic Foliation ◽  
Angle Fracture ◽  
Dominant Sets

<p>We analyze veins from the deepest exposure of the regionally folded Pelling-Munsiari thrust (PT), the roof thrust of the Lesser Himalayan duplex, in the Sikkim Himalaya. The PT is exposed as a discontinuous, ~970 m thick quartz-mica mylonite zone near Mangan (27°29′ N, 88°31′ E), and records progressive deformation path where shallow crustal deformation features overprint deeper crustal deformation structures. The mean mylonitic foliation is north easterly oriented in the studied location (mean ~31°, 042°).  Based on the angular relationship with respect to the mylonitic foliation, we recognize three different fracture- and associated vein-sets at the outcrop scale. These are low-angle set (<30° with respect to the mylonitic foliation), moderate-angle (30°-60°) and high-angle set (>60°).The high-angle fracture set overprints the mylonitic foliation and is the youngest set. These are also the most dominant fracture set (~58 %), followed by the moderate-angle (~32%) and low-angle (~10%) sets. Interestingly, the low-angle vein set (mean orientation ~ 29°, 054°) is the most  dominant set (~61%), followed by the moderate-angle set (~26%; mean orientation  ~ 19°,  055°),  and the high-angle set (~13% ; mean ~23°, 340°).Field analysis indicates that ~95% of low-angle, ~71% of moderate-angle and ~ 40% of high-angle fracture-sets form veins. Some of the low- and moderate-angle veins are locally folded along with the mylonitic foliation. The co-efficient of variation (C<sub>v</sub>) of spacing of both the fracture and vein sets are less than 1, indicating that these follow anti-clustered distribution. The poles to the veins indicate two distinct patterns. The low- and moderate-angle veins define girdle distribution, implying pore fluid pressure (P<sub>f</sub>) exceeded intermediate principal stress axis (σ<sub>2</sub>), whereas the high-angle set shows a clustered distribution indicating σ<sub>2</sub> exceeded P<sub>f</sub>. A preliminary study reveals presence of blocky texture in the low- and moderate-angle veins with quartz growing at high angles with respect to the vein walls. The average thickness of the low-angle, moderate-angle, and high-angle veins, measured along appropriate scan-lines are ~ 0.92 cm, ~1.03 cm and ~0.64 cm respectively. As the low- and moderate-angle vein-sets are the most dominant sets and both show girdle distribution, we estimated a driving pressure ratio (R' ~0.35-0.6) and stress ratio (ɸ~0.251) for these veins.  The estimated paleostresses from these veins are σ<sub>1</sub> (28°, 058°), σ<sub>2</sub> (2°, 327°), σ<sub>3</sub> (62°, 233°).</p>

NATURAL FRACTURES OF THE SOUTHERN COOPER AND EASTERN WARBURTON BASINS, SOUTH AUSTRALIA

2001 ◽  
Vol 41 (1) ◽  
pp. 201 ◽  
Author(s):  
X. Sun
Keyword(s):  
South Australia ◽  
Open Fractures ◽  
Fracture Density ◽  
Natural Fractures ◽  
High Angle ◽  
Local Structures ◽  
Fracture Systems ◽  
Brittle Sandstone ◽  
Major Fault ◽  
Well Trajectory

A study of the southern Cooper and eastern Warburton Basins has resulted in classifying natural fractures and delineating regional fracture systems and orientations of open and partially open fractures. Firstly, natural fractures have been identified from selected lithological units in 44 wells of the southern Cooper Basin. Open fractures are developed mainly within the brittle Tirrawarra Sandstone. These open fractures are mostly high angle to subvertical, with measured apertures of up to 2 mm. Secondly, natural fractures have been characterised in Warburton Basin cores from 91 wells, 27 of which have dipmeter and/or FMS (Formation Micro- Scanner) logs. Fractures more commonly occur within brittle sandstone, dolomite, grainy limestone and ignimbrite.Two systems of orthogonal, high-angle, regional fracture sets (four fractures) have been identified. They extend across local structures in both basins in South Australia. System I is comprised of a pair of orthogonal fractures, striking NNE–SSW (20–200°) and ESE–WNW (110–290°), while a second pair of orthogonal fracture sets, striking NE–SW (60–240°) and NW–SE (150–330°), characterises System II. Open, steeply dipping SW fractures striking WNW and NW within Systems I and II have been interpreted from core and FMS data in several wells. The results indicate that an optimum well trajectory designed to maximise intersection with open natural fractures should be 200–210° and 240–250°, and possibly also 270–290°. The deviation angle should be 30° from horizontal in the fracture zone due to the high-angle and subvertical fracture dips. A semi-quantitative estimate of fracture density from cores in both basins has been determined: the greatest fracture density is located within major fault zones and structural culminations.

GEOLOGY OF BARROW ISLAND OIL FIELD

1973 ◽  
Vol 13 (1) ◽  
pp. 49 ◽  
Author(s):  
Keith Crank
Keyword(s):  
Oil And Gas ◽  
Water Injection ◽  
Water Source ◽  
Upper Jurassic ◽  
Oil Field ◽  
Late Triassic ◽  
Low Permeability ◽  
High Porosity ◽  
The South ◽  
The North

The Barrow Island oil field, which was discovered by the drilling of Barrow 1 in 1964, was declared commercial in 1966. Since then 520 wells have been drilled in the development of this field which has resulted in 309 Windalia Sand oil producers (from about 2200 feet), eight Muderong Greensand oil wells (2800 feet), five Neocomian/Upper Jurassic gas and oil producers (6200 to 6700 feet), eight Barrow Group water source wells and 157 water injection wells.Production averages 41,200 barrels of oil per day, and 98% of this comes from the shallow Windalia Sand Member of Cretaceous (Aptian to Albian) age. These reserves are contained in a broad north-plunging nose truncated to the south by a major down-to-the-south fault. The anticline is thought to have been formed initially from a basement uplift during Late Triassic to Early Jurassic time. Subsequent periods of deposition, uplift and erosion have continued into the Tertiary and modified the structure to its present form. The known sedimentary section on Barrow Island ranges from Late Jurassic to Miocene.The Neocomian/Jurassic accumulations are small and irregular and are not thought to be commercial in themselves. The Muderong Greensand pool is also a limited, low permeability reservoir. Migration of hydrocarbons is thought to have occurred mainly in the Tertiary as major arching did not take place until very late in the Cretaceous or early in the Palaeocene.The Windalia Sand reservoir is a high porosity, low permeability sand which is found only on Barrow Island. One of the most unusual features of this reservoir is the presence of a perched gas cap. Apparently the entire sand was originally saturated with oil, and gas subsequently moved upstructure from the north, displacing it. This movement was probably obstructed by randomly-located permeability barriers.

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