Four-Phase Equilibrium Calculations of Carbon Dioxide/Hydrocarbon/Water Systems With a Reduced Method

Mohebbinia, Saeedeh; Sepehrnoori, Kamy; Johns, Russell T.

doi:10.2118/154218-pa

Cited by 30 publications

(25 citation statements)

References 20 publications

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“…Figure 1 gives the CO 2 solubility in brine as a function of partial pressure with and without calcite. A modified Peng Robinson EOS was used to calculate the hydrocarbon and aqueous phase behavior and CO 2 dissolution following the procedure of Søreide and Whitson (1992) and Mohebbinia et al (2013). The parameters for the modified PR EOS are shown in Tables 1 and 2.…”

Section: Methodsmentioning

confidence: 99%

Compositional Modeling of Reaction-Induced Injectivity Alteration During CO2 Flooding in Carbonate Reservoirs

Qiao

Johns

et al. 2014

SPE Annual Technical Conference and Exhibition

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Geochemical reactions between fluids and carbonate rocks can change porosity and permeability during CO 2 flooding, which may significantly impact well injectivity, well integrity, and oil recovery. Reactions can cause significant scaling in and around injection and production wells leading to high operating costs. Dissolution-induced well integrity issues and seabed subsidence have also been reported as a substantial problem at the Ekofisk field. Furthermore, mineral reactions can create fractures and vugs that can cause injection conformance issues, as has been observed in experiments and pressure transients in field tests. Although these issues are well known, there are differing opinions in the literature regarding the overall impact of geochemical reactions on permeability and injectivity for CO 2 flooding. In this research, we use fully coupled reactive transport and compositional modeling to understand the interplay between multiphase flow, phase behavior, and geochemical reactions under reservoir and injection conditions relevant in the field. Simulations were carried out using a new compositional simulator (PennSim) based on an implicit pressure explicit composition (IMPEC) multiphase finite-volume formulation that is directly coupled with a reactive transport solver. The compositional and geochemical models were validated separately with CMG-GEM and CrunchFlow. Phase and chemical equilibrium constraints are solved simultaneously to account for the interaction between phase splits and chemical speciation. The Søreide and Whitson (1992) modified Peng-Robinson equation-of-state (EOS) is used to model component concentrations present in the aqueous and hydrocarbon phases. The mineral reactions are modeled kinetically and depend on the rock-brine contact area and the brine geochemistry, including pH and water composition. Injectivity changes caused by rock dissolution and formation scaling are investigated for a five-spot pattern using several common field injection boundary conditions. The results show that the type of injection scheme and water used (fresh water, formation water, and seawater) has a significant impact on porosity and permeability changes for the same total volume of CO 2 and water injected. For continuous CO 2 injection, very little porosity changes are observed owing to evaporation of water near the injection well. For wateralternating-gas (WAG) injection, however, the injectivity increases from near zero to 50%, depending on the CO 2 slug size, number of cycles, and the total amount of injected water. Simultaneous water-alternating-gas injection (SWAG) shows significantly greater injectivity increases than WAG, primarily because of greater exposure time of the carbonate surface to CO 2-saturated brine coupled with continued displacement of calcite-saturated brine. For simultaneous water-alternating-gas injection (SWAG), carbonate dissolution primarily occurs very near the injection well, where dissolution occurs out to greater distances. Carbonated water flooding (a special case of SWAG)...

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Section: Methodsmentioning

confidence: 99%

Compositional Modeling of Reaction-Induced Injectivity Alteration During CO2 Flooding in Carbonate Reservoirs

Qiao

Johns

et al. 2014

SPE Annual Technical Conference and Exhibition

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“…In this subsection, the significance of Equation (4) is elucidated by comparing predictions made using it with those made with a BIP value of 0.5, which is a representative value from the literature (Heidman et al, 1985;Peng and Robinson, 1976b;Tsonopoulos and Heidman, 1986;Nasrifar and Moshfeghian, 2002;Eubank et al, 1994;Mohebbinia et al, 2013;Søreide and Whitson, 1992). Equation (4) gives a much lower value of 0.242 for water with heavy nalkanes (see Table 1).…”

Section: Comparison Of the New Bips With Other Recommended Valuesmentioning

confidence: 99%

Characterization of water-containing reservoir oil using an EOS for steam injection processes

Venkatramani

Okuno

2015

Journal of Natural Gas Science and Engineering

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“…On the other hand, the Le Chatelier principle for geochemical reactions proposes that when a system at equilibrium experiences a change (e.g., in concentration, partial pressure, and temperature), the equilibrium shifts to counteract the imposed change and establish a new equilibrium (Le Chatelier 1884; Monk 2008). 1a through 1d compare the predicted ion production of some aqueous ions (Na þ , Ca þ2 , and HCO À 3 ) and pH values for the cases considered.…”

Section: Multiphase Reactive-transport Modeling By Use Of Utcomp-iphrmentioning

confidence: 99%

Mechanistic Modeling of Low-Salinity Waterflooding Through Coupling a Geochemical Package With a Compositional Reservoir Simulator

Korrani

Jerauld

Sepehrnoori

2016

SPE Reservoir Evaluation &Amp; Engineering

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Low-salinity waterflooding is an emerging enhanced-oil-recovery (EOR) technique in which the salinity of the injected water is substantially reduced to improve oil recovery over conventional higher-salinity waterflooding. Although there are many low-salinity experimental results reported in the literature, publications on modeling this process are rare. Although there remains some debate regarding the mechanisms of low salinity waterflooding process (LoSal EOR V R ) * , the geochemical reactions that control the wetting of crude oil on the rock are likely to be central to a detailed description of the process. Because no comprehensive geochemical-based modeling has been applied in this area, it was decided to couple a state-of-the-art geochemical package, IPhreeqc (Charlton and Parkhurst 2011), developed by the US Geological Survey, with UTCOMP (Chang 1990), the compositional reservoir simulator developed by The University of Texas at Austin.A step-by-step algorithm is presented for integrating IPhreeqc with UTCOMP. Through this coupling, we are able to simulate homogeneous and heterogeneous (mineral dissolution/precipitation), irreversible, and ion-exchange reactions under nonisothermal, nonisobaric, and both local-equilibrium (away from the wellbore) and kinetic (near wellbore) conditions. Consistent with the literature, there are significant effects of water-soluble hydrocarbon components-e.g., carbon dioxide (CO 2 ), methane (CH 4 ), and acidic/basic components of the crude-on buffering the aqueous pH value and more generally, on the crude oil, brine, and rock reactions. Thermodynamic constraints are used to explicitly include the effect of these water-soluble hydrocarbon components. Hence, this combines the geochemical power of IPhreeqc with the important aspects of hydrocarbon flow and compositional effects to produce a robust, flexible, and accurate integrated tool capable of including the reactions needed to mechanistically model low-salinity waterflooding.Different geochemical-based approaches to modeling wettability change in sandstones (e.g., interpolation on the basis of total ionic strength and multicomponent ion exchange through surface complexation of the organometallic components) were implemented in UTCOMP-IPhreeqc, and the integrated tool is then used to match and interpret a low-salinity experiment published by Kozaki (2012) and the field trial performed by BP at the Endicott field.

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Four-Phase Equilibrium Calculations of Carbon Dioxide/Hydrocarbon/Water Systems With a Reduced Method

Cited by 30 publications

References 20 publications

Compositional Modeling of Reaction-Induced Injectivity Alteration During CO2 Flooding in Carbonate Reservoirs

Compositional Modeling of Reaction-Induced Injectivity Alteration During CO2 Flooding in Carbonate Reservoirs

Characterization of water-containing reservoir oil using an EOS for steam injection processes

Mechanistic Modeling of Low-Salinity Waterflooding Through Coupling a Geochemical Package With a Compositional Reservoir Simulator

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