Compositional Simulation of Carbonated Waterfloods in Naturally Fractured Reservoirs

Shenawi, Shamsuddin; Wu, C.H.

doi:10.2118/27741-ms

Cited by 6 publications

(2 citation statements)

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“…Our results show that the DME partitions into the residual reservoir oil that remains in the low permeability matrix and that the ensuing swelling of the oil phase is fast and strong enough to significantly increase the ultimate oil recovery. However, there are also other mutually soluble solvent-based EOR techniques that show potential for improving oil recovery in fractured/heterogeneous reservoirs, − with the most well-known of these being CO 2 -saturated brine injection (i.e., carbonated water injection). In both carbonated water injection and DME–brine flooding, water acts as the carrier fluid, and the identified oil recovery mechanisms are oil swelling and viscosity reduction for dead crude oil. ,, The extent of oil recovery in both techniques is directly related to the solvent content in the carrier fluid (brine) , as well as to the partition coefficient of the solvent between the oleic and aqueous phases.…”

Section: Discussionmentioning

confidence: 99%

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Dimethyl Ether Enhanced Oil Recovery in Fractured Reservoirs and Aspects of Phase Behavior

et al. 2019

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The efficiency of the dimethyl ether (DME) enhanced oil recovery (EOR) technique in a fractured chalk reservoir core plug was investigated. The coreflood experiment showed that DME EOR could lead to 44.2% additional oil recovery, amounting to 80.6% of the ultimate oil recovery. A comprehensive set of laboratory experiments, including density measurements of miscible fluids, DME-induced oil swelling factor, and partition coefficient of DME between the aqueous and oleic phase, were performed. The experimental results show that the partition coefficient of DME for the mixture of DME− brine−oil can reach up to 18.3. The oil swelling factor for such a system can reach up to 2.7 under realistic reservoir conditions. Comparing this data set to the available data for other mutually soluble solvent-based EOR techniques shows that the oil swelling caused by DME is far stronger than for other common solvents. Due to the strong partitioning of DME between the phases, the DME from the DME−brine solution rapidly partitions into the bypassed oil in the low permeability matrix, which leads to strong oil swelling and production.

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Section: Discussionmentioning

confidence: 99%

“…Research has shown that mutually soluble solvent-based EOR techniques are viable options for recovery improvement in fractured reservoirs. − These EOR techniques are developed upon the properties of an organic compound which is soluble in both the aqueous and oleic phase. The most well-known of such compounds are CO 2 and alcohols.…”

Section: Introductionmentioning

confidence: 99%

Dimethyl Ether Enhanced Oil Recovery in Fractured Reservoirs and Aspects of Phase Behavior

et al. 2019

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Solvent-enhanced Spontaneous Imbibition in Fractured Reservoirs

et al. 2013

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Oil recovery in fractured reservoirs by water flooding critically depends on the wetting properties of the matrix blocks between the fractures. The recovery from oil-wet reservoirs is small. In incompletely oil-wet systems, the presence of initial water may change the wettability characteristics so that imbibition and some oil recovery can occur. The hypothesis in this work is that water-soluble solvent (diethyl ether) improve the ultimate recovery and the imbibition rate in partially and completely water-wet cores. The main recovery mechanisms are the wettability change of the partially water-wet cores and oil swelling and the oil viscosity reduction in both partially and completely water-wet cores. This paper reports an experimental study concerning the recovery enhancement by water-soluble solvent (diethyl ether). We used an Amott imbibition cell studying oil saturated samples of various wettabilities, permeabilities using oils of different viscosities and two different diethyl ether (solvent) concentrations in the aqueous phase. In the first stage of the experiment, the completely water-wet core was exposed to brine without solvent. In a second stage, the core was put in a new Amott cell that was filled with solvent/ brine mixture. The extra recovery by solvent/brine mixture strongly depends on the residual oil saturation after brine imbibition and it is relatively insensitive to the permeability of the core or the oil viscosity. Therefore, larger residual oil saturation resulted in a higher extra recovery. For the partially water-wet samples, we also started with exposing the core to pure brine without solvent. Contrary to the completely water-wet samples, there was a significant increase in recovery rate when the sample is transferred to another Amott cell where it is exposed to a mixture of solvent and brine. In view of large values of the inverse Bond number in both partially and completely water-wet cores, the transfer between matrix and fracture capillary driven.

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Analytical Rate-Transient Analysis and Production Performance of Waterflooded Fields with Delayed Injection Support

O'Reilly

Haghighi

Sayyafzadeh

et al. 2021

SPE Reservoir Evaluation &Amp; Engineering

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Summary An approach to the analysis of production data from waterflooded oil fields is proposed in this paper. The method builds on the established techniques of rate-transient analysis (RTA) and extends the analysis period to include the transient- and steady-state effects caused by a water-injection well. This includes the initial rate transient during primary production, the depletion period of boundary-dominated flow (BDF), a transient period after injection starts and diffuses across the reservoir, and the steady-state production that follows. RTA will be applied to immiscible displacement using a graph that can be used to ascertain reservoir properties and evaluate performance aspects of the waterflood. The developed solutions can also be used for accurate and rapid forecasting of all production transience and boundary-dominated behavior at all stages of field life. Rigorous solutions are derived for the transient unit mobility displacement of a reservoir fluid, and for both constant-rate-injection and constant-pressure-injection after a period of reservoir depletion. A simple treatment of two-phase flow is given to extend this to the water/oil-displacement problem. The solutions are analytical and are validated using reservoir simulation and applied to field cases. Individual wells or total fields can be studied with this technique; several examples of both will be given. Practical cases are given for use of the new theory. The equations can be applied to production-data interpretation, production forecasting, injection-water allocation, and for the diagnosis of waterflood-performanceproblems.

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Compositional Simulation of Carbonated Waterfloods in Naturally Fractured Reservoirs

Cited by 6 publications

References 0 publications

Dimethyl Ether Enhanced Oil Recovery in Fractured Reservoirs and Aspects of Phase Behavior

Dimethyl Ether Enhanced Oil Recovery in Fractured Reservoirs and Aspects of Phase Behavior

Solvent-enhanced Spontaneous Imbibition in Fractured Reservoirs

Analytical Rate-Transient Analysis and Production Performance of Waterflooded Fields with Delayed Injection Support

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