Factors That Affect Gas-Condensate Relative Permeability

Kalla, Subhash; Leonardi, Sergio Adrian; Berry, Daniel W.; Poore, Larry D.; Sahoo, Hemant; Kudva, R. A.; Braun, Edward M.

doi:10.2523/iptc-17264-ms

Cited by 5 publications

(1 citation statement)

References 5 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The fourth region is the closest to the wellbore, the velocity of gas flow is really high, and the liquid phase saturation is decreased through gas velocity stripping (Fevang and Whitson, 1996). To accurately understand the effect of the present of condensate bank on fluid flow, Kalla et al (2015) showed the experimental measurements of the relative permeability of different rock-fluid properties. In their results, the maximum relative permeability of condensate phase is below 0.4, which indicates a relative low conductivity of the liquid phase in condensate reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Yang

Wei²,

Chen

et al. 2016

SPE Low Perm Symposium

View full text Add to dashboard Cite

With the production of a gas condensate tight reservoir, condensate in fracture can significantly decrease the productivity of gas condensate wells. Previous work shows that the negative effect of condensate bank on gas production is more seriously in tighter reservoir. The implement of hydraulic fracture and multi-stages fracturing can mitigate the negative effects on the formation of condensate bank, but the effects cannot be completely removed. A huff-n-puff methane injection has been proven to be an effective method to reduce the effect of condensate by maintaining the reservoir pressure above the dew-point pressure and revaporizing the formed condensate. However, the previous work neglects the effect of hydraulic fractures on the treatment of condensate by gas injection.Non-aqueous components are lumped into fourteen pseudo components. Dual permeability, logarithmically spaced, locally refined grids are implemented to model natural and hydraulic fractures in a simulation model. The laboratory measured relative permeability taking account of condensate bank is used to accurately represent two-phase flow in a shale reservoir. Furthermore, two different settings of cyclic schedule are implemented to test their advantages and disadvantages.The results show that the huff-n-puff dry gas injection can effectively improve gas and condensate recovery. A fracture conductivity has significant influences on well production during the injection, while during the primary recovery its impact is not that obvious. In addition, the huff-n-puff schedules also plays a crucial role in both gas and condensate recovery. Our study highlights gas injection mitigates the effect of condensate bank on gas production in a shale reservoir, and provides an extensive insight on optimal design of Huff-n-Puff gas injection.

show abstract

Section: Introductionmentioning

confidence: 99%

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Yang

Wei²,

Chen

et al. 2016

SPE Low Perm Symposium

View full text Add to dashboard Cite

show abstract

Experimental and theoretical study of gas/oil relative permeability

et al. 2019

View full text Add to dashboard Cite

Using Pressure Transient Analysis to Validate the Initial Hydrocarbon Composition and Improve Hydrocarbon Production Forecasting, Shown at an Example Rich Gas Condensate Field

Perdomo

Clemens²

2016

Day 3 Wed, November 09, 2016

View full text Add to dashboard Cite

In addition to the challenges of production forecasting of gas fields, gas condensate production forecasting needs to address effects related to condensate drop out in the reservoir. To forecast hydrocarbon production from gas condensate fields, Drill Stem Tests (DST) and fluid sampling are required. For the example reservoir, an Equation Of State (EOS) model was generated using laboratory data. DSTs were performed and analysed for reservoir permeability, liquid drop out and velocity stripping near-wellbore. In addition to pressure transient analysis, numerical simulations were performed using the EOS. The simulations indicated that the initial fluid composition determined from fluid sampling leads to a good match of the drawdown and build-up pressures, however, the pressure derivative could not be matched satisfactory for a reasonable set of relative permeabilities, velocity stripping effects and reservoir permeabilities. Using the initial fluid composition as additional matching parameter lead to an acceptable match of the pressure derivative as well. This indicates that despite careful fluid sampling, the composition of the sampled fluid was not representative for the initial reservoir fluid. In addition, simulating the well test revealed that the local equilibrium assumption in the numerical simulation might not always hold in the reservoir. Gas and condensate production forecasts using the initial fluid composition of the sampling and the modified initial fluid composition after history matching were performed. The results indicate that for the example reservoir, the sampling derived initial fluid composition would overestimate the cumulative gas production by 4 %, underestimate condensate production by 9 %, overestimate condensate recovery factor by 17 %, overestimate plateau gas production duration by a factor of 9 and underestimate condensate production rate by 35 %. These differences might lead to different economics and development strategies (e.g. depletion versus gas recycling).

show abstract

Factors That Affect Gas-Condensate Relative Permeability

Cited by 5 publications

References 5 publications

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Experimental and theoretical study of gas/oil relative permeability

Using Pressure Transient Analysis to Validate the Initial Hydrocarbon Composition and Improve Hydrocarbon Production Forecasting, Shown at an Example Rich Gas Condensate Field

Contact Info

Product

Resources

About