Modelling Asphaltene-Induced Formation Damage in Closed Systems

Lawal, Kazeem A.; Vesovic, Velisa

doi:10.2118/138497-ms

Cited by 10 publications

(4 citation statements)

References 45 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Although not indicated in Table , the oils used in runs 2, 6, and 3 have viscosities of 1.1, 0.71, and 0.59 cP, respectively, suggesting that damage rate is less pronounced in viscous crudes. This may partly explain the typical observation of lower rate and magnitude of impairment in viscous crudes, despite their much higher asphaltene content. , A similar finding on the influence of viscosity in the damage process was reported by Lawal and Vesovic …”

Section: Model Validation and Discussionmentioning

confidence: 99%

“…61,68 A similar finding on the influence of viscosity in the damage process was reported by Lawal and Vesovic. 71 It is noteworthy that the data sets of Fadili et al, 59 notwithstanding the similarity of the porous medium, result in fitting parameters that differ significantly (see Table 2). This is a direct consequence of the fact that when our model is used for history-matching, the empirical parameters reflect the historical behavior of the system and not its initial state.…”

Section: Articlementioning

confidence: 99%

See 1 more Smart Citation

Modeling Permeability Impairment in Porous Media due to Asphaltene Deposition under Dynamic Conditions

2011

Self Cite

View full text Add to dashboard Cite

An investigation into the impairment of permeability in porous media as a result of the deposition of asphaltene particulates in a flowing stream is presented. By incorporating kinetics of asphaltene deposition under dynamic conditions into the deep-bed filtration (DBF) theory, we have developed a new asphaltene deposition and impairment model, which has only three tuning parameters. The parameters, characterizing the key aspects of the deposition process and porous-media hydraulics, are the stabilized filtration coefficient λ 0 , the filtration time constant τ, and the exponent n, relating porosity and permeability. The resulting models are tested against a large number of experimental data sets, representing common porous media and particulate streams. The validation exercise indicates that our dynamic-filtration model is capable of rationalizing about 82% of the reference data sets within 7%.

show abstract

Section: Model Validation and Discussionmentioning

confidence: 99%

Section: Articlementioning

confidence: 99%

Modeling Permeability Impairment in Porous Media due to Asphaltene Deposition under Dynamic Conditions

2011

Self Cite

View full text Add to dashboard Cite

show abstract

“…Similarly, we have tacitly ignored possible CO2-induced asphaltene problems in oil reservoirs as well as salt precipitation in saline aquifers and their negative impacts on injectivity and reservoir dynamics [49][50][51][52][69][70] . its physical properties such as viscosity would not be markedly altered by intervention processes such as heating and dilution.…”

Section: Resultsmentioning

confidence: 99%

An Improved Estimation of the Storage Capacity of Potential Geologic Carbon-Sequestration Sites

Lawal¹

2011

All Days

Self Cite

View full text Add to dashboard Cite

The ideas of open and closed-boundary systems are explored to investigate the technical limits of storage capacity of subsurface porous media, as required for the CO2-mitigation technology of carbon capture and storage (CCS). In particular, the effects of reservoir characteristics as well as the nature and mix of fluids that originally saturate the porous media are elucidated. An improved analytic method, premised on the concept of in-situ fluid displacement and replacement, of estimating the storage capacity of open systems is proposed and evaluated.For closed systems, our analyses show that the general order of attractiveness (technical storage capacity) of potential sites is aquifer < water-depleted oil < undepleted oil < gas-depleted oil < depleted gas < undepleted gas formations. However, owing to the complexity of microscopic and macroscopic events, similar simple conclusion can not be drawn on the relative attractiveness of various open-boundary sinks.As a case study, we examine the applicability of CCS in Nigeria. From first-order estimates of the pore volumes and other reservoir-fluid properties in Nigeria, we quantify the limits and time-scale of "available" geologic sinks to accommodate current and future loads of anthropogenic CO2 emissions from the Nigerian fossil-fired power sources.Due to the relatively poor storage capacity of the potential sites compared to the anticipated CO2 load from power plants, which is just one of the CO2 sources, sequestration into underground formations may not, on its own, be a sustainable technical solution for Nigeria. Additionally, for the open systems, which define the upper limits of storage capacity, the potential challenges of managing displaced formation brine (and other less valuable fluids) may be overwhelming. As a complement, we offer some potential outlets for CO2 generated from these captive and other sources. Finally, long-term carbon-mitigation strategies hinged on mixed solutions are enumerated.

show abstract

“…The sand plugging mechanism of gravel packed well is proposed using flooding tests with multi-point tube, which evaluates the influence of sand migration to gravel layer permeability (Hu et al 2004;Zeng et al 2005;Wang et al 2008). Many theoretical models to evaluate the permeability impairment for particulates deposition are proposed (Gravelle et al 2011;Lawal et al 2005Lawal et al , 2010Lawal et al , 2011Civan et al 2002Civan et al , 2003Civan et al , 2005. The filtration and formation-damage coefficients are important empirical parameters for theoretically evaluate the permeability damage.…”

Section: Introductionmentioning

confidence: 99%

Productivity Prediction of Horizontal Well by Integration of Formation Damage Model during Gravel-pack Completions

Yang

et al. 2013

All Days

View full text Add to dashboard Cite

Sanding is vitally a serious problem during heavy-oil production from unconsolidated reservoirs. In order to effective sand control and high well production, various sand exclusion technologies are used for horizontal well completion, especially, the open-hole gravel pack (OHGP) has been widely used. So it is critical to quantitatively evaluate permeability impairment because of sand particulates migration and plugging in gravel-packed layer, and it is also important to predict horizontal well productivity. In this paper, we have developed one numerical model of permeability impairment based on the previous experimental observation. This numerical model considers the liquid-solid fluid flow process, and sand particles depositing and plugging in gravel-packed layer. The numerical simulation results of permeability impairment at different sand volume fraction, fluid viscosity and sand radius are given, and the simulated results are in good agreement with the previous experimental results.Integrating the permeability impairment model a new model to predict productivity of gravel-packed horizontal well has been proposed. The proposed model couples reservoir inflow and seepage in gravel layer, and it can quantitatively evaluate the damage of gravel layer and predict well productivity performance. The numerical simulation of real-world scenarios investigates that it is more accurate than previous models, and it is very easy to use.

show abstract

Modelling Asphaltene-Induced Formation Damage in Closed Systems

Cited by 10 publications

References 45 publications

Modeling Permeability Impairment in Porous Media due to Asphaltene Deposition under Dynamic Conditions

Modeling Permeability Impairment in Porous Media due to Asphaltene Deposition under Dynamic Conditions

An Improved Estimation of the Storage Capacity of Potential Geologic Carbon-Sequestration Sites

Productivity Prediction of Horizontal Well by Integration of Formation Damage Model during Gravel-pack Completions

Contact Info

Product

Resources

About