scholarly journals Importance of Velocity Deviation Technique and Negative Secondary Porosity in Detection of Hydrocarbon Zones in Khasib Formation, East Baghdad Oil Field

2021 ◽  
Vol 54 (2E) ◽  
pp. 86-103
Author(s):  
Bashar Al-Juraisy
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Oil Field ◽  
Clear Correlation ◽  
Low Velocity ◽  
Secondary Porosity ◽  
Sonic Log ◽  
Velocity Deviation ◽  
Primary Porosity ◽  
Porosity Analysis

The velocity deviation technique is one of the important techniques in hydrocarbon investigations, through which it is possible to identify the types and the content of rock pores. The current study aimed to demonstrate the benefit of this technique in discovering the oil sites of the Khasib formation in the East Baghdad oil field, as well as the possibility of separating the oil and gas zones by combining the velocity deviation technique with the anomalous primary porosity information that leads to negative secondary porosity. In this study, log data of three wells distributed in the study area (EB-04, EB-16, and EB-34) were used. From these data, the velocity was estimated by the sonic log, the porosity was estimated by the neutron and the density log, while the velocity deviation was determined by subtracting the velocity calculated from the density log from the sonic log velocity. The result showed that there is significant agreement between the secondary porosity values that turned positive after the oil effect was removed and the confirmed oil zones derived from the core information. Also, there was a clear correlation between velocity deviation values above -500 m/s and the permeability zone of formation, which may reflect the importance of this technique in the identification of the permeability zone. Both techniques (Velocity Deviation and log porosity analysis) can be correlated to predict the locations of gas, large-scale fractures, and unconsolidated beds in sites of high negative secondary porosity and low-velocity deviation (under -500 m/s).

scholarly journals Petrophysical Properties and Digenetic Evolution of Shuaiba Formation in Nasiriyah Oil Field, Southern Iraq

2021 ◽  
pp. 4810-4818
Author(s):  
Marwah H. Khudhair
Keyword(s):  
Gamma Ray ◽  
Water Saturation ◽  
Middle Part ◽  
Effective Porosity ◽  
Oil Field ◽  
Neutron Density ◽  
Petrophysical Properties ◽  
Secondary Porosity ◽  
Primary Porosity ◽  
Gamma Ray Log

     Shuaiba Formation is a carbonate succession deposited within Aptian Sequences. This research deals with the petrophysical and reservoir characterizations characteristics of the interval of interest in five wells of the Nasiriyah oil field. The petrophysical properties were determined by using different types of well logs, such as electric logs (LLS, LLD, MFSL), porosity logs (neutron, density, sonic), as well as gamma ray log. The studied sequence was mostly affected by dolomitization, which changed the lithology of the formation to dolostone and enhanced the secondary porosity that replaced the primary porosity. Depending on gamma ray log response and the shale volume, the formation is classified into three zones. These zones are A, B, and C, each can be split into three rock intervals in respect to the bulk porosity measurements. The resulted porosity intervals are: (I) High to medium effective porosity, (II) High to medium inactive porosity, and (III) Low or non-porosity intervals. In relevance to porosity, resistivity, and water saturation points of view, there are two main reservoir horizon intervals within Shuaiba Formation. Both horizons appear in the middle part of the formation, being located within the wells Ns-1, 2, and 3. These intervals are attributed to high to medium effective porosity, low shale content, and high values of the deep resistivity logs. The second horizon appears clearly in Ns-2 well only.

scholarly journals Petrophysical Properties and Well Log Interpretations of Tertiary Reservoir in Khabaz Oil Field / Northern Iraq

2020 ◽  
Vol 26 (6) ◽  
pp. 18-34
Author(s):  
Yousif Najeeb Abdul-majeed ◽  
Ahmad Abdullah Ramadhan ◽  
Ahmed Jubiar Mahmood
Keyword(s):  
Water Saturation ◽  
Total Porosity ◽  
Effective Porosity ◽  
Oil Field ◽  
Neutron Density ◽  
Petrophysical Properties ◽  
Secondary Porosity ◽  
Northern Iraq ◽  
Sonic Log ◽  
Oil Concentration

The aim of this study is interpretation well logs to determine Petrophysical properties of tertiary reservoir in Khabaz oil field using IP software (V.3.5). The study consisted of seven wells which distributed in Khabaz oilfield. Tertiary reservoir composed from mainly several reservoir units. These units are : Jeribe, Unit (A), Unit (A'), Unit (B), Unit (BE), Unit (E),the Unit (B) considers best reservoir unit because it has good Petrophysical properties (low water saturation and high porous media ) with high existence of hydrocarbon in this unit. Several well logging tools such as Neutron, Density, and Sonic log were used to identify total porosity, secondary porosity, and effective porosity in tertiary reservoir. For Lithological identification for tertiary reservoir units using (NPHI-RHOB) cross plot composed of dolomitic-limestone and mineralogical identification using (M/N) cross plot consist of calcite and dolomite. Shale content was estimated less than (8%) for all wells in Khabaz field. CPI results were applied for all wells in Khabaz field which be clarified movable oil concentration in specific units are: Unit (B), Unit (A') , small interval of Jeribe formation , and upper part of Unit (EB).

UPPER PERMIAN CARBONATE RESERVOIRS OF THE NORTH WEST SHELF AND NORTHERN PERTH BASIN, AUSTRALIA

1999 ◽  
Vol 39 (1) ◽  
pp. 343 ◽  
Author(s):  
J.D. Gorter ◽  
J.M. Davies
Keyword(s):  
Oil And Gas ◽  
Upper Permian ◽  
Gas Reservoirs ◽  
Secondary Porosity ◽  
North West ◽  
Associated Gas ◽  
The North ◽  
Timor Sea ◽  
Primary Porosity ◽  
Carnarvon Basin

The Perth, Carnarvon, Browse, and Bonaparte basins contain Permian shallowmarine carbonates. Interbedded with clastic oil and gas reservoirs in the northern Perth Basin (Wagina Formation), and gas reservoirs in the Bonaparte Basin (Cape Hay and Tern formations), these carbonates also have the potential to contain significant hydrocarbon reservoirs. Limestone porosity may be related to the primary depositional fabric, or secondary processes such as dolomitisation, karstification, and fracturing. However, in the Upper Permian interval of the North West Shelf and northern Perth Basin, where there are no indications of significant preserved primary porosity in the limestones, all known permeable zones are associated with secondary porosity. Fractured Permian carbonates have the greatest reservoir potential in the Timor Sea. Tests of fractured Pearce Formation limestones in Kelp Deep–1 produced significant quantities of gas, and a test of fractured Dombey Formation limestone in Osprey–1 flowed significant quantities of water and associated gas. Minor fracture porosity was associated with gas shows in dolomitic limestones in Fennel–1 in the Carnarvon Basin, and fractures enhance the reservoir in the Woodada Field in the northern Perth Basin. Karst formation at sub-aerial unconformities can lead to the development of secondary porosity and caverns, as in the Carnarvon Basin around Dillson–1. Minor karst is also developed at the top Dombey Formation unconformity surface in the Timor Sea region.

More bang for your buck: optimising CSG extraction to achieve increased project value

2016 ◽  
Vol 56 (1) ◽  
pp. 75 ◽  
Author(s):  
Nick Allison
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Integrated Approach ◽  
Commodity Price ◽  
Oil Field ◽  
Production Model ◽  
Economic Resource ◽  
Fully Integrated ◽  
Unit Energy ◽  
Gas Market

Recent challenges within Australia’s oil and gas market have placed increased pressure on Australia’s CSG industry to reel-in burgeoning project costs. In a tight commodity price environment, developments need to extract greater value from projects. This paper outlines an innovative approach to CSG gathering system design by leveraging the digital oil field approach, utilising technology to rapidly optimise design, reduce design costs and optimise the development processes behind economic resource extraction aimed at ultimately delivering increased project value. In the past few years a step-change has been made in the optimisation of the engineering design model, with expanded concept level design, FEED-less design, and partially automated detailed design being executed on gathering system projects now being adopted. This was a step towards a fully integrated approach of the digital oil field. Through this process, it has become apparent that this methodology can be extended further through the targeted optimisation of the production model used in the establishment of CSG projects. This will enable increased revenue for a project. Field production profiles for both gas and water can be developed from preliminary reservoir assessment data. Using cost data for materials and installation, various scenarios can be assessed to optimise production volumes, surface infrastructure configuration, and total volume extracted on a dollar margin per unit energy basis. The optimisation measures explored in this paper are most critical to reservoir locations with a low drainage area per well, where reservoir drainage is maximised by refinement of the configuration of above-ground infrastructure. This has the potential to translate to a more optimised network, and greater profitability in the development of large-scale CSG fields.

Technology Focus: Acidizing (June 2021)

2021 ◽  
Vol 73 (06) ◽  
pp. 48-48
Author(s):  
Frank Chang
Keyword(s):  
Hydrochloric Acid ◽  
Hydraulic Fracturing ◽  
United Arab Emirates ◽  
Large Scale ◽  
Oil And Gas ◽  
New Technologies ◽  
Critical Role ◽  
Oil Field ◽  
Well Completion ◽  
Desirable Outcome

Hydraulic fracturing technologies propagated from North America outward to other oil- and gas-producing regions in the world. In earlier days, the main technology developments were mostly related to the materials, such as fluids and proppants, and their characterizations. In recent years, more advancements have been made in tools, engineering processes, and analyses. In a cased-hole fracturing treatment, perforating plays a critical role to the success of the job, though it is often overlooked because perforations are visualized as holes with empty tunnel behind the pipe. Any damage is irrelevant because fracturing will simply bypass the damage. In fact, a shaped charge is made of metal liner and case with explosive loaded in between. The metal material is pushed into the formation under extremely high pressure from the detonation of the explosive. Without backflow of reservoir fluid to flush out the debris, the perforation tunnels are very likely plugged. In tight formations, the backflow is not efficient because the permeability is too low and the time scale of the surge is very short. Obtaining information about perforation before pumping the fracture treatment allows the engineers to adjust the job design, adding perforations or other means to deliver a more-desirable outcome for the fracturing treatment. Not all the wells or zones are suitable for hydraulic fracturing. Concerns over the well completion rating, nearby water layers, equipment and water availability, and other environmental and infrastructure constraints can limit the selection of stimulation method. Matrix chemical injection has often been the preferred or sometimes the only option. More-advanced technologies, however, are needed to extend reservoir access beyond the distance of matrix stimulation. Mechanical tunneling tools have been developed in recent years. They can bridge the gap between matrix and fracturing treatment very well. When combined with chemicals, this process can add efficiency in certain carbonate reservoirs. Hydrochloric acid continues to be the most effective and low-cost material for carbonate stimulation. Though exotic chemistries such as chelating agents and organic acids have been promoted for being less corrosive at high temperatures, the cost and dissolving capacity limit their use to large-scale implementation. The ability to inhibit the corrosion tendency of hydrochloric acid can prove to be beneficial in the economics of acidizing. New technologies in corrosion prevention, both in acid stimulation and production processes, should always be beneficial. During the tough year of 2020, and for the foreseeable future, implementation of engineering ingenuity will become more critical to maintain economical energy delivery in our industry. Recommended additional reading at OnePetro: www.onepetro.org. SPE 202369 Novel High-Effective Component for Acidizing Corrosion Inhibitors: Indolizine Derivatives of the Quaternary Quinolinium Salts by Zhen Yang, China University of Petroleum, et al. SPE 203086 First Successful Fishbone Stimulation Completion in Onshore Oil Field in the United Arab Emirates by Fernando Quintero, ADNOC, et al.

scholarly journals Study on Ground Engineering and Management of Carbonate Oil Field A under Rolling Development Mode

2021 ◽  
Vol 4 (1) ◽  
pp. 32
Author(s):  
Hang Chen
Keyword(s):  
Carbonate Rock ◽  
Large Scale ◽  
Surface Engineering ◽  
Oil And Gas ◽  
Oil Field ◽  
High Yield ◽  
Development Mode ◽  
Gas Reservoirs ◽  
Engineering Programs ◽  
Management Recommendations

Carbonate rock has the characteristics of complicated accumulation rules, large-scale development, high yield but unstable production. Therefore, the management and control of surface engineering projects of carbonate rock oil and gas reservoirs faces huge difficulties and challenges. The construction of surface engineering should conform to the principle of integrated underground and ground construction and adapt to the oilfield development model. This paper takes the newly added area A of the carbonated oil field as an example to study the ground engineering under the rolling development mode and aims to provide the constructive ideas for the surface engineering under rolling development mode. The overall regional process design adheres to the design concept of "environmental protection, efficiency, and innovation", strictly follows the design specifications, and combines reservoir engineering and oil production engineering programs, oil and gas physical properties and chemical composition, product programs, ground natural conditions, etc. According to the technical and economic analysis and comparison of area A, this paper has worked out a suitable surface engineering construction, pipeline network layout and oil and gas gathering and transportation plan for area A. Some auxiliary management recommendations are also proposed in this paper, like sand prevention management and HSE management for carbonate reservoirs.

scholarly journals Well log data super-resolution based on locally linear embedding

2021 ◽  
Vol 76 ◽  
pp. 63
Author(s):  
Jian Han ◽  
Pan Gao ◽  
Zhimin Cao ◽  
Jing Li ◽  
Sijie Wang ◽  
...  
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Super Resolution ◽  
Oil Field ◽  
Locally Linear Embedding ◽  
Well Log ◽  
Log Data ◽  
Oil And Gas Resources ◽  
Linear Embedding ◽  
Locally Linear

Unconventional remaining oil and gas resources such as tight oil, shale oil, and coalbed gas are currently the focus of the exploration and development of major oil fields all over the world. Therefore, to make best understand of target reservoirs, enhancing the vertical resolution of well log data is crucial important. However, in the face of the continuous low-level fluctuations of international oil price, large scale use of expensive high resolution well logging hardware tools has always been unaffordable and unacceptable. In another aspect, traditional well log interpolation methods can always not realize high reliable information enhancement for crucial high frequency components. In this paper, in order to improve the well log data super-resolution performance, we propose for the first time to employ Locally Linear Embedding (LLE) technique to reveal the nonlinear mapping relationship between 2-times-scale-difference well log data. Several super resolution experiments with well log data from a given area of Daqing Oil field, China, were conducted. Experimental results illustrated that the proposed LLE-based method can efficiently achieve more reliable super-resolution results than other state-of-the-art methods.

Gas Cap and Oil Rim Collaborative Development Technique Policy of Carbonate Reservoir with Condensate Gas Cap

2013 ◽  
Vol 734-737 ◽  
pp. 1381-1390
Author(s):  
Heng Song ◽  
Zi Fei Fan ◽  
Lun Zhao ◽  
An Gang Zhang
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Carbonate Reservoir ◽  
Oil Field ◽  
Pressure Balance ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Collaborative Development ◽  
Technical Problems ◽  
Oil And Gas Reservoirs

Zhanazhol oilfield is a large-scale complicated carbonated oil and gas field , Гnorth is the main oil and gas reservoirs of the oil field, The gas cap index is 0.38, the gas cap on a high condensate content. Reservoir development for nearly 25 years, exploitation in the past only to oil ring. Due to insufficient water injection in early age, the oil ring pressure dropped substantially, and the formation pressure to maintain the level of only 58%. For oil and gas reservoirs with a condensate gas cap, gas cap and oil ring at the same pressure system, with the decline in the pressure of the oil ring, the gas cap continue to spread to the oil region, while there are a large number of condensate oil anti-condensate from the gas cap, which loss into the formation. In this paper, the authors consider the characteristics of the oil and gas reservoirs and research the technique policy of collaborative development, These are all in order to solve technical problems, which is keep the pressure balance between the gas cap and oil ring during collaborative development. Not only provide technical to support the rational and efficient development of the Г North oil and gas reservoirs, but also provide a stable source for natural gas pipeline from Kazakhstan to China.

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