A Phenomenological Model for Scaling at Reservoir Level the Impact over Oil Production due to Formation Damage by Fines Migration and Clays Swelling

2016 ◽  
Author(s):  
R. D. Zabala ◽  
M. A. Ruiz
Keyword(s):  
Phenomenological Model ◽  
Oil Production ◽  
Formation Damage ◽  
Reservoir Level ◽  
Fines Migration ◽  
The Impact

From Lab to Field - Assessing the Impact of Laboratory Scale Conditions on Formation Damage Assessment in Gas Wells

2020 ◽  
Author(s):  
Ike Mokogwu ◽  
Paul Hammonds ◽  
Sam Clare Wilson ◽  
Caitlin Healy ◽  
Ewan Sheach
Keyword(s):  
Damage Assessment ◽  
Laboratory Scale ◽  
Formation Damage ◽  
Gas Wells ◽  
The Impact

Waterflooding in Carbonate Reservoirs: Does the Salinity Matter?

2014 ◽  
Vol 17 (03) ◽  
pp. 304-313 ◽  
Author(s):  
A.M.. M. Shehata ◽  
M.B.. B. Alotaibi ◽  
H.A.. A. Nasr-El-Din
Keyword(s):  
Oil Recovery ◽  
Sudden Change ◽  
Oil Production ◽  
Deionized Water ◽  
Production Performance ◽  
Shallow Aquifer ◽  
Secondary Recovery ◽  
Tertiary Recovery ◽  
The Impact ◽  
Indiana Limestone

Summary Waterflooding has been used for decades as a secondary oil-recovery mode to support oil-reservoir pressure and to drive oil into producing wells. Recently, the tuning of the salinity of the injected water in sandstone reservoirs was used to enhance oil recovery at different injection modes. Several possible low-salinity-waterflooding mechanisms in sandstone formations were studied. Also, modified seawater was tested in chalk reservoirs as a tertiary recovery mode and consequently reduced the residual oil saturation (ROS). In carbonate formations, the effect of the ionic strength of the injected brine on oil recovery has remained questionable. In this paper, coreflood studies were conducted on Indiana limestone rock samples at 195°F. The main objective of this study was to investigate the impact of the salinity of the injected brine on the oil recovery during secondary and tertiary recovery modes. Various brines were tested including deionized water, shallow-aquifer water, seawater, and as diluted seawater. Also, ions (Na+, Ca2+, Mg2+, and SO42−) were particularly excluded from seawater to determine their individual impact on fluid/rock interactions and hence on oil recovery. Oil recovery, pressure drop across the core, and core-effluent samples were analyzed for each coreflood experiment. The oil recovery using seawater, as in the secondary recovery mode, was, on the average, 50% of original oil in place (OOIP). A sudden change in the salinity of the injected brine from seawater in the secondary recovery mode to deionized water in the tertiary mode or vice versa had a significant effect on the oil-production performance. A solution of 20% diluted seawater did not reduce the ROS in the tertiary recovery mode after the injection of seawater as a secondary recovery mode for the Indiana limestone reservoir. On the other hand, 50% diluted seawater showed a slight change in the oil production after the injection of seawater and deionized water slugs. The Ca2+, Mg2+, and SO42− ions play a key role in oil mobilization in limestone rocks. Changing the ion composition of the injected brine between the different slugs of secondary and tertiary recovery modes showed a measurable increase in the oil production.

Monte Carlo Risk Assessment of Formation Damage Caused by Asphaltene Deposition

2021 ◽  
pp. 1-8
Author(s):  
Arley S. Carvalhal ◽  
Gloria M. N. Costa ◽  
Silvio A. B. Vieira de Melo
Keyword(s):  
Monte Carlo ◽  
Probability Distribution ◽  
Oil Production ◽  
Rock Properties ◽  
Formation Damage ◽  
Permeability Reduction ◽  
Prevention Policy ◽  
Oil Composition ◽  
Hypothetical Scenario ◽  
Asphaltene Deposition

Summary Uncertainties regarding the factors that influence asphaltene deposition in porous media (e.g., those resulting from oil composition, rock properties, and rock/fluid interaction) strongly affect the prediction of important variables, such as oil production. Besides, some aspects of these predictions are stochastic processes, such as the aggregation phenomenon of asphaltene precipitates. For this reason, a well-defined output from an asphaltene-deposition model might not be feasible. Instead of this, obtaining the probability distribution of important outputs (e.g., permeability reduction and oil production) should be the objective of rigorous modeling of this phenomenon. This probability distribution would support the design of a risk-based policy for the prevention and mitigation of asphaltene deposition. In this paper we aim to present a new approach to assessing the risk of formation damage caused by asphaltene deposition using Monte Carlo simulations. Using this approach, the probability-distribution function of the permeability reduction was obtained. To connect this information to a parameter more related to economic concepts, the probability distribution of the damage ratio (DR) was also calculated, which is the fraction of production loss caused by formation damage. A hypothetical scenario involving a decision in the asphaltene-prevention policy is presented as an application of the method. A novel approach to model the prevention of asphaltene aggregation using inhibitors has been proposed and successfully applied in this scenario.

Formation Damage Issues Impacting the Productivity of Low Permeability, Low Initial Water Saturation Gas Producing Formations

2005 ◽  
Vol 127 (3) ◽  
pp. 240-247 ◽  
Author(s):  
D. Brant Bennion ◽  
F. Brent Thomas
Keyword(s):  
Capillary Pressure ◽  
Water Saturation ◽  
The United States ◽  
Gas Production ◽  
Pressure Effects ◽  
Formation Damage ◽  
Low Permeability ◽  
Gas Reservoirs ◽  
Initial Water ◽  
The Impact

Very low in situ permeability gas reservoirs (Kgas<0.1mD) are very common and represent a major portion of the current exploitation market for unconventional gas production. Many of these reservoirs exist regionally in Canada and the United States and also on a worldwide basis. A considerable fraction of these formations appear to exist in a state of noncapillary equilibrium (abnormally low initial water saturation given the pore geometry and capillary pressure characteristics of the rock). These reservoirs have many unique challenges associated with the drilling and completion practices required in order to obtain economic production rates. Formation damage mechanisms affecting these very low permeability gas reservoirs, with a particular emphasis on relative permeability and capillary pressure effects (phase trapping) will be discussed in this article. Examples of reservoirs prone to these types of problems will be reviewed, and techniques which can be used to minimize the impact of formation damage on the productivity of tight gas reservoirs of this type will be presented.

Quantifying the Impact of Water and Gas on Oil Production

2018 ◽  
Author(s):  
Amba Ndoma Egba ◽  
Joseph A. Ajienka ◽  
Omowumi O. Iledare
Keyword(s):  
Oil Production ◽  
The Impact

Oil price uncertainty and equity returns

2016 ◽  
Vol 8 (1) ◽  
pp. 64-79 ◽  
Author(s):  
Aktham Maghyereh ◽  
Basel Awartani
Keyword(s):  
Stock Returns ◽  
Oil Production ◽  
Equity Returns ◽  
Oil Price ◽  
Policy Implications ◽  
Price Uncertainty ◽  
Mena Region ◽  
Stock Market Returns ◽  
Content Type ◽  
The Impact

Purpose This paper aims to examine the impact of oil price uncertainty on the stock market returns of ten oil importing and exporting countries in the Middle East and North Africa (MENA) region. The sample contains both oil importing and oil exporting countries that depend heavily on oil production and exports. Design/methodology/approach This paper intuitively applies the generalized autoregressive conditional heteroskedasticity (GARCH)-in-mean vector autoregression (VAR) model using weekly data over the period January 2001-February 2014. Findings The findings indicate that oil uncertainty matters in the determination of real stock returns. There is a negative and significant relationship between oil price uncertainty and real stock returns in all countries in the sample. The influence of oil price risk is more serious in those economies that depend heavily on oil revenues to grow. Practical implications The findings have important implications. For instance, managers should be aware of the linkages between oil price uncertainty and equity returns when they use oil to hedge and diversify equities, particularly in economies where oil is important for economic growth. The policymakers in oil importing countries should encourage companies to improve efficiency in the usage of energy and to resort to alternative sources to avoid fluctuations in earnings and equity prices. In the countries that heavily depend on oil efforts should focus on diversifying the domestic economy away from oil to protect against oil price fluctuations. Originality/value To the best of our knowledge, this is the first attempt to study the influence of oil price uncertainty in the MENA region. The sample contains both oil importing and oil exporting countries that depend heavily on oil production and exports. The empirical findings of the paper have valuable policy implications for investors, market participants and policymakers.

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