Gas Condensate Reservoir Performance

To effectively evaluate a gas condensate reservoir performance, the reservoir engineer must have a reasonable amount of knowledge about the reservoir to adequately analyze the reservoir performance and predict future production under various modes of operation. Due to the multiphase flow that exists in the reservoir, characterization of gas condensate reservoirs is often a difficult task with the variation of its overall composition in both space and time during production which complicates well deliverability analysis and the sizing of surface facilities. This study is primarily concern with the evaluation of a gas condensate reservoir performance of Akpet GT 9 Reservoir in the Niger Delta region of Nigeria with material balance analysis tool “MBal” without having to run numerical simulations. The result obtained with MBal on the analysis of Akpet GT 9 reservoir gave 23.934 Bscf of gas initially in place which compares favorably with the volume obtained from volumetric techniques. Results also shows that the most likely aquifer model is the Hurst–Van Everdingen - Dake radial aquifer and the reservoir is supported by a combined drive of water influx and fluid expansion. Okotie, S. | Department of Petroleum Engineering, Federal University of Petroleum Resources (FUPRE), Effurun, Delta State, Nigeria.

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APPLICATION OF THE BLACK OIL PVT REPRESENTATION TO SIMULATION OF GAS CONDENSATE RESERVOIR PERFORMANCE

The APPEA Journal ◽

10.1071/aj86032 ◽

1987 ◽

Vol 27 (1) ◽

pp. 370

Author(s):

W.H. Goldthorpe ◽

J.K. Drohm

Keyword(s):

Oil And Gas ◽

Volatile Oil ◽

Gas Condensate ◽

Phase Behaviour ◽

Dew Point ◽

Pressure Drops ◽

Gas Condensate Reservoirs ◽

Reservoir Performance ◽

Black Oil ◽

Condensate Reservoir

Special attention must be paid to the generation of PVT parameters when applying conventional black oil reservoir simulators to the modelling of volatile oil and gas-condensate reservoirs. In such reservoirs phase behaviour is an important phenomenon and common approaches to approximating this, via the black oil PVT representation, introduce errors that may result in prediction of incorrect recoveries of surface gas and condensate. Further, determination of production tubing pressure drops for use in such simulators is also prone to errors. These affect the estimation of well potentials and reservoir abandonment pressures.Calculation of black oil PVT parameters by the method of Coats (1985) is shown to be preferred over conventional approaches, although the PVT parameters themselves lose direct physical meaning. It is essential that a properly tuned equation of state be available for use in conjunction with experimental data.Production forecasting based on simulation output requires further processing in order to translate the black oil surface phase fluxes into products such as sales gas, LPG and condensate. For gas-condensate reservoirs, such post-processing of results from the simulation of depletion or cycling above the dew point is valid. In principle it is invalid for cycling below the dew point but in practice it can still provide useful information.

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Unconventional Shale Gas-Condensate Reservoir Performance: Impact of Rock, Fluid, and Rock-Fluid Properties and their Variations

10.2118/178661-ms ◽

2015 ◽

Cited By ~ 2

Author(s):

A. Orangi ◽

N. R. Nagarajan

Keyword(s):

Shale Gas ◽

Gas Condensate ◽

Performance Impact ◽

Reservoir Performance ◽

Fluid Properties ◽

Condensate Reservoir

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