Simulation of the North Brae Gas Condensate Reservoir Development

1991 ◽  
Author(s):  
D.K. O'Bryne ◽  
S. Sadighi ◽  
G.L. Lane
Keyword(s):  
Gas Condensate ◽  
The North ◽  
Reservoir Development ◽  
Condensate Reservoir

scholarly journals Management of injected nitrogen into a gas condensate reservoir

2016 ◽  
Vol 36 (1) ◽  
pp. 52-61 ◽  
Author(s):  
Hadi Belhaj
Keyword(s):  
Gas Condensate ◽  
Abu Dhabi ◽  
Processing Plant ◽  
Peak Shaving ◽  
Gas Streams ◽  
Gas Processing ◽  
The North ◽  
Condensate Reservoir ◽  
Heat Value ◽  
The Impact

<p>This study investigates the means of deferring the breakthrough of injected N2 and alleviating the impact of such on production rates and specifications as well as minimizing the required changes to the gas processing facilities. This aimed at assisting the ongoing efforts to transfer the Cantarell experience to Abu Dhabi, where large amounts of N2 gas will be generated and injected into a large gas condensate reservoir to partially substitute the recycling of lean gas. This will bring forward the opportunity to exploit lean gas by securing base load supplies before the start of reservoir blowdown, compared to the peak shaving approach currently practiced. Managing N2 breakthrough starts by better understanding the pattern at which N2 injection spreads into the gas accumulation. Based on the findings of initial subsurface and plant simulations carried out in 2008, N2 breakthrough in Abu Dhabi might be possibly deferred by segmenting the reservoir into a rich N2 region and lean N2 region. The approach assumes no thief zones will be faced and no channeling of N2 injected between the two regions is taking place. N2 is injected in the north region of the reservoir. The production of that region will be segregated and fed to a gas processing plant of lower NGL (natural gas liquid) recovery, which essentially takes longer time to start suffering the deterioration of residue gas (gas mixture resulted after separating NGL) quality. The residue gas use can be limited to re-injection where the effect of below specification LHV (Low Heat Value) would not be an issue. The rest of the reservoir feeds another gas processing plant of higher NGL recovery level from which an amount of residue gas equivalent to that of the injected N2 will be rerouted to the sales network. This scenario will significantly delay as well as downsize the requirement of a N2 rejection plant. There is technical and certainly economical advantage of deferring the installation of costly N2 rejection units. Such a requirement can be entirely eliminated if the sales gas specification can be relaxed considering blending with other gas streams of higher LHV, and in collaboration with gas customers, i.e. assessing their capability to tolerate feedstock of lower specifications. It must be noted that such school of thinking may not necessarily be eventually embraced. The chosen scenario will also depend on the final configuration, i.e., wells grouping and gas gathering, of the ongoing project.</p>

The problem of adapting the gas-condensate reservoir model under conditions of a low volume and low reliability of the initial data

2021 ◽  
pp. 177-187
Author(s):  
P. A. Shulgin ◽  
E. V. Raudanen ◽  
R. R. Shakirov
Keyword(s):  
Hydrodynamic Model ◽  
Laboratory Data ◽  
Gas Condensate ◽  
Water Flooding ◽  
Well Testing ◽  
Reservoir Water ◽  
Reservoir Development ◽  
Water Wells ◽  
Condensate Reservoir ◽  
Low Volume

The article is dedicated to the problem of adapting the hydrodynamic model of a gas-condensate reservoir with a low volume and low reliability of the field and laboratory data. The purpose of the work is a qualitative reservoir development forecast. All available formation fluid downhole samples were studied. The authors analyzed water samples taken during the reservoir development process. The monthly production reports data and the gas-condensate well testing installation measurements were used in the article. The authors carried out the hydrodynamic model multivariate calculations in order to mathematically repeat historical waterflooding. An approach to the retrospective analysis of the production and laboratory data is shown in order to remove uncertainties in the reservoir and production engineering. The work performed made it possible to determine the most probable content of C5+ components in the reservoir gas, as well as to assess the risk of the future formation water invasion into the reservoir. As a result of this work, it was recommended to exclude two edge wells in order to reduce the gas well waterflooding. In addition, the authors calculated an improved reservoir development variant. They proposed to transfer a part of gas wells to water wells at the stage of declining production. This operation will reduce the reservoir water-flooding rate.

Increase of condensation for gas-condensate discharges at the finishing stage of development

2020 ◽  
pp. 83-89
Author(s):  
M.S. Khalilov ◽  
Keyword(s):  
Mass Exchange ◽  
Final Stage ◽  
Gas Condensate ◽  
Liquid Hydrocarbons ◽  
Two Phase ◽  
Stage Of Development ◽  
Reservoir Development ◽  
Condensate Reservoir ◽  
Continuous Mass ◽  
Filtration Model

Based on a two-phase multicomponent filtration model, the process of retrograde condensate extraction at the final stage of the development of a gas-condensate reservoir was investigated, with the creation of a volume of ethane rims in the reservoir with subsequent injection of the separated gas. It has been established that ethane dissolves in a retrograde condensate during continuous mass exchange between the phases of the system, creates a shaft of liquid hydrocarbons higher than critical at the front of displacement, at which two-phase filtration begins, which allows for the development of reserves of retrograde hydrocarbon condensate and, ultimately, provides effective reservoir development.

scholarly journals Influence of geological reservoir heterogeneity on exploitation conditions of Garadagh field / underground gas storage (Azerbaijan)

2021 ◽  
Vol 6 (2) ◽  
pp. 105-113
Author(s):  
A. A. Feyzullayev ◽  
A. G. Gojayev
Keyword(s):  
Oil And Gas ◽  
Gas Storage ◽  
Gas Condensate ◽  
Underground Gas Storage ◽  
Gas Reservoirs ◽  
Well Productivity ◽  
Reservoir Heterogeneity ◽  
Reservoir Development ◽  
Condensate Reservoir ◽  
Lithological Composition

Underground oil and gas reservoirs (formations) are characterized by spatial variability of their structure, material composition and petrophysical properties of its constituent rocks: particle size distribution, porosity, permeability, structure and texture of the pore space, carbonate content, electrical resistivity, oil and water saturation and other properties. When assessing development and exploitation conditions for underground gas storages, created in depleted underground oil and gas reservoirs, the inherited nature of the reservoir development should be taken into account. Therefore, identifying the features of variations in well productivity is a crucial task, solution of which can contribute to the creation of more efficient system for underground gas storage exploitation. The paper presents the findings of comparative analysis of spatial variations in well productivity during the exploitation of the Garadagh underground gas storage (Azerbaijan), created in the depleted gas condensate reservoir. An uneven nature of the variations in well productivity was established, which was connected with the reservoir heterogeneity (variations in the reservoir lithological composition and poroperm properties). The research was based on the analysis of spatial variations of a number of reservoir parameters: the reservoir net thickness, lithological composition and poroperm properties. The analysis of variations in the net thickness and poroperm properties of the VII horizon of the Garadagh gas condensate field was carried out based on the data of geophysical logging of about 40 wells and studying more than 90 core samples. The data on of more than 90 wells formed the basis for the spacial productivity variation analysis. The analysis of productivity variation in the space of well technological characteristics (based on data from 18 wells) in the Garadagh underground gas storage (UGS) was carried out through the example of the volume of cyclic gas injection and withdrawal in 2020–2021 season. The studies allowed revealing non-uniform spacial variations in the volumes of injected and withdrawn gas at the Garadagh UGS, created in the corresponding depleted gas condensate reservoir. The features of the UGS exploitation conditions are in good agreement with the features of the reservoir development conditions (variations in the well productivity). The inherited nature of the reservoir development and the underground gas storage exploitation is substantiated by the reservoir heterogeneity caused by the spatial variability of the reservoir lithological composition and poroperm properties. Assessing and taking into account the reservoir heterogeneity when designing underground gas storage exploitation conditions should be an important prerequisite for increasing UGS exploitation efficiency.

Effect of High Reynolds and Capillary Numbers on Over-Pressured Rich Gas Condensate Reservoir Development

2014 ◽  
Author(s):  
Bachir Mabrouki ◽  
Liz Sturman ◽  
Chantorn Butphet ◽  
Anthony William Peacock
Keyword(s):  
Gas Condensate ◽  
Reservoir Development ◽  
Condensate Reservoir ◽  
High Reynolds
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