Gas/Oil Capillary Pressure: Measurements at Reservoir Conditions and Effect on 
Gas-Gravity Drainage

Longeron, D.G.; Kalaydjian, F.; Bardon, C.

doi:10.2523/28612-ms

Cited by 4 publications

(4 citation statements)

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“…The presence of a second liquid phase induces an "over capillarity" that depends on the IFT value and increases with gas saturation. This effect is practically zero for gas saturations below 20% PV and it is at a maximum in the vicinity of residual oil saturation [30]. The increase of "over capillarity" as IFT decreases may be explained by spreading coefficient, C, which is defined as IFT (gas/water) -IIW (water/oil) -IFT (gas/oil) for a strongly water-wet system.…”

Section: Effect Of Flow Ratementioning

confidence: 99%

Near Critical Gas Condensate Relative Permeability of Carbonates

Calisgan¹,

Akın²

2008

TOPEJ

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Typical gas condensate fields contain a gas/liquid system during depletion. Such systems are difficult to model experimentally because they exhibit near-miscible behavior at high pressure and temperature. One way to simplify laboratory experimentation is to use a binary retrograde condensate fluid and to adjust temperature to control miscibility. A series of relative permeability test were conducted on a moderate-permeability carbonate core using methanol/n-hexane at near miscible conditions in the presence of immobile water. Potassium carbonate was added to the water to prevent miscibility with methanol. The experiments used a pseudo-steady-state technique under conditions similar to the near well region of a carbonate gas-condensate reservoir. The flow of gas and condensate at different force ratios was investigated. Relative permeabilities were obtained by matching historical production and pressure data using a coreflood simulator. It was observed that relative permeability depended on fluid composition and flow rate as well as initial condensate and water saturations. As the wetting phase (condensate) flow rate increased or interfacial tension decreased, relative permeability versus wetting phase saturation curves shifted towards lower wetting phase saturations. It was found that a simple three-parameter mathematical model that depends on a new dimensionless number called condensate number successfully modeled the gas-condensate relative permeability data. The developed model resulted in a good agreement with published gas-condensate relative permeability data as well as end point relative permeabilities and saturations. The relative permeability behavior as a function of IFT highly resembles the one observed in sandstones.

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Section: Effect Of Flow Ratementioning

confidence: 99%

Near Critical Gas Condensate Relative Permeability of Carbonates

Calisgan¹,

Akın²

2008

TOPEJ

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“…In the second work , they converted the 1D solution, obtained previously, to 2D to account for the tilted cases. Longeron et al (1994) described drainage performance from the point of view of capillary pressure measurement. A fully theoretical-mathematical study was conducted by Luan (1994) regarding some important factors that affect gravity drainage in naturally fractured reservoirs.…”

Section: Introductionmentioning

confidence: 99%

A New Approach to the Modeling of a Simple Re-infiltration Gravity Drainage Process in Naturally Fractured Reservoirs

Askarinezhad

Kharrat

Shadizadeh

2012

Petroleum Science and Technology

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One of the most important concerns regarding prediction of production performance in naturally fractured reservoirs is the issue of re-infiltration phenomena.In this study, the modeling of a simple re-infiltration process with no effect of capillary continuity between blocks is presented by extending the gravity drainage mechanism for a single block.First, a qualitative analysis of the gravity drainage process through porous media was conducted and the role of gravity and capillary forces was investigated.Then a model for one-dimensional gravity drainage in a single block was developed in dimensionless form, a modified version of which can be found in the literature. Then, using the method of separation of variables, the corresponding partial differential equation was solved for a single block with certain boundary and initial conditions.The upper boundary is a no-feed boundary and at the lower boundary the gas saturation is always zero. At the initial condition, the gas saturation is equal to zero throughout the block.In order to model the simple re-infiltration process, the above-mentioned problem for concept was used and, based on the fact that the blocks of a stack governed by simple re-infiltration process act as single block, using a MATLAB program (The MathWorks, Inc., Natick, MA), the rate of drainage and cumulative production as function of time were obtained. The results are in very good agreement with the nature of the process in an actual case. This method can be extended to solve the problem of a stack of N blocks.

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“…30% OOIP) incremental recoveries over horizontal floods. Longeron et al (1994) studied the influence of capillary pressure on oil recovery by compositional simulation. The gas-oil capillary pressures were always found to be higher in the presence of connate water, as compared to the capillary pressures displayed in the absence of connate water saturation.…”

Section: Gravity Drainage Fundaments and Traditional Modelsmentioning

confidence: 99%