Gas-Condensate Relative Permeability Curves Determined from Separator Test Data: Britannia Field Case Study

2011 ◽  
Author(s):  
Baris Goktas ◽  
Thomas S. Thrasher
Keyword(s):  
Relative Permeability ◽  
Test Data ◽  
Gas Condensate ◽  
Field Case ◽  
Relative Permeability Curves

Iterative modeling is as a tool for selecting a geological basis for hydrodynamic modeling and development design

2021 ◽  
pp. 111-126
Author(s):  
A. A. Agarkova ◽  
S. E. Shebankin ◽  
M. A. Tukaev ◽  
M. S. Karmazin
Keyword(s):  
Initial Data ◽  
Hydrodynamic Modeling ◽  
Usual Method ◽  
Gas Condensate ◽  
Digital Model ◽  
Geological Model ◽  
Field Case ◽  
Field Development ◽  
Wide Range

The usual method for constructing a digital model of a field is based on hydrodynamic modeling using the basic implementation of a geological model, usually requires additional adjustments to the initial data, and as a result, leads to a wide range of uncertainties in assessing the predicted technological indicators of field development. The PK1 reservoir of a gas condensate field case study discuss-es the method of iterative modeling, which makes it possible to comprehensively approach the assessment of possible uncertainties.

Evaluation of Transport Properties Effect on the Performance of Gas-Condensate Reservoirs Using Compositional Simulation

2017 ◽  
Vol 139 (3) ◽  
Author(s):  
Bander N. Al Ghamdi ◽  
Luis F. Ayala H.
Keyword(s):  
Transport Properties ◽  
Relative Permeability ◽  
Gas Condensate ◽  
Compositional Simulation ◽  
Saturation Point ◽  
Flow Phenomenon ◽  
Gas Condensate Reservoirs ◽  
Compositional Simulator ◽  
Tight Formations ◽  
Relative Permeability Curves

Gas-condensate productivity is highly dependent on the thermodynamic behavior of the fluids-in-place. The condensation attendant with the depletion of gas-condensate reservoirs leads to a deficiency in the flow of fluids moving toward the production channels. The impairment is a result of condensate accumulation near the production channels in an immobility state until reaching a critical saturation point. Considering the flow phenomenon of gas-condensate reservoirs, tight formations can be inevitably complex hosting environments in which to achieve economical production. This work is aimed to assess the productivity gas-condensate reservoirs in a naturally fractured setting against the effect of capillary pressure and relative permeability constraints. The severity of condensate coating and magnitude of impairment was evaluated in a system with a permeability of 0.001 mD using an in-house compositional simulator. Several composition combinations were considered to portray mixtures ascending in complexity from light to heavy. The examination showed that thicker walls of condensate and greater impairment are attained with mixture containing higher nonvolatile concentrations. In addition, the influence of different capillary curves was insignificant to the overall behavior of fluids-in-place and movement within the pores medium. A greater impact on the transport of fluids was owed to relative permeability curves, which showed dependency on the extent of condensate content. Activating diffusion was found to diminish flow constraints due to the capturing of additional extractions that were not accounted for under Darcy's law alone.

scholarly journals ESTIMATION OF NEW RELATIVE PERMEABILITY CURVES DUE TO COMPACTION CASE STUDY AT BACHAQUERO FIELD – VENEZUELA

2011 ◽  
Vol 14 (2) ◽  
pp. 38-53
Author(s):  
Dung Quoc Ta ◽  
Peter Behrenbruch
Keyword(s):  
Relative Permeability ◽  
Water Production ◽  
Volume Changes ◽  
Mobile Water ◽  
Pore Structures ◽  
Immobile Water ◽  
Relative Permeability Curves

This paper is written to analyse the variation of water production due to compaction in a field in Venezuela. The producing water, after being analysed, was suspected not from aquifer. So where does the water come from? The results shows that pore structures of reservoir changed, and producing water is due to volume changes of immobile water and mobile water as the result of compaction. It means that relative permeability curves have changed when rock deforms.

A Semianalytical Approach for Analysis of Wells Exhibiting Multiphase Transient Linear Flow: Application to Field Data

SPE Journal ◽  
2020 ◽  
Vol 25 (06) ◽  
pp. 3265-3279
Author(s):  
Hamidreza Hamdi ◽  
Hamid Behmanesh ◽  
Christopher R. Clarkson
Keyword(s):  
Numerical Model ◽  
Relative Permeability ◽  
History Matching ◽  
Volatile Oil ◽  
Low Permeability ◽  
Two Phase ◽  
Linear Flow ◽  
Field Case ◽  
Three Phase ◽  
Relative Permeability Curves

Summary Rate-transient analysis (RTA) is a useful reservoir/hydraulic fracture characterization method that can be applied to multifractured horizontal wells (MFHWs) producing from low-permeability (tight) and shale reservoirs. In this paper, we applied a recently developed three-phase RTA technique to the analysis of production data from an MFHW completed in a low-permeability volatile oil reservoir in the Western Canadian Sedimentary Basin. This RTA technique is used to analyze the transient linear flow regime for wells operated under constant flowing bottomhole pressure (BHP) conditions. With this method, the slope of the square-root-of-time plot applied to any of the producing phases can be used to directly calculate the linear flow parameter xfk without defining pseudovariables. The method requires a set of input pressure/volume/temperature (PVT) data and an estimate of two-phase relative permeability curves. For the field case studied herein, the PVT model is constructed by tuning an equation of state (EOS) from a set of PVT experiments, while the relative permeability curves are estimated from numerical model history-matchingresults. The subject well, an MFHW completed in 15 stages, produces oil, water, and gas at a nearly constant (measured downhole) flowing BHP. This well is completed in a low-permeability,near-critical volatile oil system. For this field case, application of the recently proposed RTA method leads to an estimate of xfk that is in close agreement (within 7%) with the results of a numerical model history match performed in parallel. The RTA method also provides pressure–saturation (P–S) relationships for all three phases that are within 2% of those derived from the numerical model. The derived P–S relationships are central to the use of other RTA methods that require calculation of multiphase pseudovariables. The three-phase RTA technique developed herein is a simple-yet-rigorous and accurate alternative to numerical model history matching for estimating xfk when fluid properties and relative permeability data are available.

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