Effect of $$\hbox {CO}_{2}$$ CO 2 Injection on Brine Flow and Salt Precipitation After Gas Field Production

Tambach, Tim J.; Loeve, D.; Hofstee, C.; Plug, Willem-Jan; Maas, J.H. van der

doi:10.1007/s11242-014-0283-x

Cited by 14 publications

(8 citation statements)

References 21 publications

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“…For example, a number of previous studies neglected the wellbore flow process or interpreted the wellbore flow by adopting Darcy's law after assigning adequate rock properties [46][47][48]. This approach is called equivalent porous media (EPM) model.…”

Section: Introductionmentioning

confidence: 99%

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

et al. 2018

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For investigating the wellbore flow process in CO 2 injection scenarios, coupled wellbore-reservoir (WR) and conventional equivalent porous media (EPM) models were compared with each other. In WR model, during the injection, conditions for the wellbore including pressure and temperature were dynamically changed from the initial pressure (7.45-8.33 MPa) and temperature (52.0-55.9∘ C) of the storage formation. After 3.35 days, the wellbore flow reached the steady state with adiabatic condition; temperature linearly increased from the well-head (35 ∘ C) to the well-bottom (52 ∘ C). In contrast, the EPM model neglecting the wellbore process revealed that CO 2 temperature was consistently 35∘ C at the screen interval. Differences in temperature from WR and EPM models resulted in density contrast of CO 2 that entered the storage formation (∼200 and ∼600 kg/m 3 , resp.). Subsequently, the WR model causing greater density difference between CO 2 and brine revealed more vertical CO 2 migration and counterflow of brine and also developed the localized salt-precipitation. Finally, a series of sensitivity analyses for the WR model was conducted to assess how the injection conditions influenced interplay between flow system and the localized salt-precipitation in the storage formation.

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Section: Introductionmentioning

confidence: 99%

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

et al. 2018

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“…In geothermal fields, where high levels of silica and other dissolved salts are present, scaling problems are encountered in pipes and geothermal fluid handling equipment . CO 2 injection, often employed as an antiscaling process and long‐term brine flow in oil reservoirs are seriously affected by salt precipitation . Scaling is also encountered in reverse osmosis membranes used in water treatment, where control crystal growth of calcium phosphate and other salts is of prime interest .…”

Section: Introductionmentioning

confidence: 99%

Precipitation of sparingly soluble salts in packed sandbeds in the presence of miscible and immiscible organic substances

Pavlakou

Sygouni

Lioliou

et al. 2016

Crystal Research and Technology

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Sparingly soluble salts precipitation, e.g. calcium carbonate or calcium sulfate, results in pore clogging in rock formations and in the concomitant reduction of the local permeability of oil wells during the oil extraction processes. On the other hand, in situ controlled salt precipitation is desirable in various applications e.g. waterproofing of concrete constructions suffering from leakages, etc. In the present study, calcium carbonate (CaCO 3 ) precipitation in sandbeds was investigated, in the presence of organic solvents simulating the conditions prevalent in oil-well zones. CaCO 3 precipitation was investigated from supersaturated solutions prepared by in-situ mixing of NaHCO 3 and CaCl 2 .2H 2 O solutions before the inlet of sandbeds. The solution resulting from the mixing of the two solutions was supersaturated with respect to all calcium carbonate polymorphs. Three types of experiments were performed depending on the supersaturated solutions: a) aqueous solutions b) aqueous supersaturated solutions in contact with sandbeds presaturated with n-dodecane c) aqueous solutions containing monoethylene glycol (MEG). Results showed that oil-water interfaces enhanced the heterogeneity of the supersaturated solutions and accelerated crystal growth of calcium carbonate at the inlet of the sandbed, resulting in early pore clogging and limitation of local permeability. Maximum sandbed consolidation was obtained with the solutions containing MEG.

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“…The deposition of salts in porous media is an important engineering problem encountered in a number of environmental and industrial applications. Salt deposition in porous formations causes a decrease in the oil production in extraction industries, while similar problems occur in geothermal systems, at water desalination membranes, during capturing of CO 2 in underground wells, etc. − In other installments, the precipitation of salts in porous materials may be desirable and very exploitable for the stabilization of loose rock formations, sandy soils, or other materials. ,,− Scaling phenomena are attributed to the precipitation of salts such as calcium or ferrous carbonate, and calcium or barium sulfates. ,− …”

Section: Introductionmentioning

confidence: 99%

Flow, Transport, and Controlled Sedimentation of Salt Solutions in Porous Formations with Enhanced Structural Properties

Skouras

Sygouni

Constantinides

et al. 2016

Crystal Growth & Design

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Scaling phenomena caused by salt precipitation in pumps and wells are a frequent problem during oil production, CO2 storage, and other underground processes. Several studies have focused on the salt precipitation in porous media, and interesting results concerning salt precipitation have been obtained in the past. Salt precipitation in porous media is a complex phenomenon since it is highly dependent on supersaturation, which is usually not homogeneous along the porous channels. In the present study the coupled solution of the spatiotemporally varied flow and mass transport during mixing and selective precipitation of specific salts in unconsolidated and loosely consolidated porous media were investigated, with a strong dependence on the prevailing conditions. Specific salt solutions mixing, transfer, and deposition rates were studied, targeting the selective enhancement of salts deposition performance to facilitate consolidation of porous formations. Computational fluid dynamics methods have been applied for the transient flow and salt transport with homogeneous or heterogeneous nucleation of crystals on the walls of pores with specific mixing geometry. During modeling of flow in pore networks, the three-dimensional character of the process was taken into account, and the evolution of mass transport and deposition was monitored. The precipitation of salts in supersaturated and unsaturated porous medium and the crystals distribution along the porous medium have been evaluated. Comparison of the simulation results with similar experiments has been performed.

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Effect of $$\hbox {CO}_{2}$$ CO 2 Injection on Brine Flow and Salt Precipitation After Gas Field Production

Cited by 14 publications

References 21 publications

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

Precipitation of sparingly soluble salts in packed sandbeds in the presence of miscible and immiscible organic substances

Flow, Transport, and Controlled Sedimentation of Salt Solutions in Porous Formations with Enhanced Structural Properties

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Effect of $$\hbox {CO}_{2}$$ CO 2 Injection on Brine Flow and Salt Precipitation After Gas Field Production

Cited by 14 publications

References 21 publications

Dynamic Behavior of CO2 in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO2 Sequestration

Dynamic Behavior of CO2 in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO2 Sequestration

Precipitation of sparingly soluble salts in packed sandbeds in the presence of miscible and immiscible organic substances

Flow, Transport, and Controlled Sedimentation of Salt Solutions in Porous Formations with Enhanced Structural Properties

Contact Info

Product

Resources

About

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration

Dynamic Behavior of CO₂ in a Wellbore and Storage Formation: Wellbore-Coupled and Salt-Precipitation Processes during Geologic CO₂ Sequestration