Advancing Reservoir Simulation Capabilities for Tight Gas Reservoirs

Abacioglu, Yafes; Sebastian, Herbert M.; Oluwa, Jubril Babajide

doi:10.2118/122793-ms

Cited by 20 publications

(6 citation statements)

References 12 publications

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“…A description of prior efforts to apply integrated reservoir modeling to tight gas sands can be found in the literature [3][4][5][6][7] . A common objective mentioned in these papers is the need to define optimum well spacing in thick, tight fluvial systems, and the need to build representative 3D static models with sand body distributions that duplicate reservoir continuity.…”

Section: Integrated Reservoir Modeling Objective: the Search For Optimentioning

confidence: 99%

Integrated Dynamic Reservoir Modeling for Multilayered Tight Gas Sand Development

Roach

Chapin

et al. 2010

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This paper summarizes the approach used for applying integrated reservoir modeling to the tight gas sands of the Pinedale Anticline in western Wyoming. The simulation of tight gas sands such as those at Pinedale has always been challenging because of the high degree of heterogeneity that needs to be retained to replicate reservoir performance, coupled with computing constraints. Added to this, simulating the Pinedale reservoir has its own unique challenges due to its characteristically thick gross sand interval composed of multiple, heterogeneous sand bodies produced commingled in a well.An intensive data-gathering program to investigate optimum well spacing accompanied the simulation effort. A significant part of this program was the installation of pressure monitor wells 1 to detect communication with surrounding producers at the hydraulic fracture stage level. This was coupled with multiple time-lapse production logs. The two data sets together allowed better definition of stage performance at producing wells.Static models were built with fine resolution to duplicate reservoir heterogeneity. However, upscaling was necessary due to computing constraints. The upscaling procedure of Li and Beckner 2 was utilized to maintain substantial geologic heterogeneity. The upscaled model was calibrated to mimic fine scale well performance prior to history matching.Several sector upscale models were history matched using a statistical approach without compromising key aspects such as reservoir connectivity and proper mass withdrawal from each geologic sub layer. Hydraulic fractures in each stage were characterized through history matching. Given the geostatistical nature, an exact match on every frac stage and every pressure gauge located away from the producer should not be expected. Rather, a more statistical definition of a history match should be adapted to a level that still gives confidence in forecasting the value of future infill wells. The history-matched parameters were then statistically distributed to forecast more realistic future development wells.The availability of data including pressures at observation wells and production logs was critical in narrowing the range of uncertainty in the history-matched scenarios and reduced the degree of non-uniqueness in the model thus resulting in increased confidence in model forecasts. This paper describes the methods used to overcome many of the problems encountered in modeling heterogeneous tight gas sands, such as at the Pinedale Anticline.

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Section: Integrated Reservoir Modeling Objective: the Search For Optimentioning

confidence: 99%

Integrated Dynamic Reservoir Modeling for Multilayered Tight Gas Sand Development

Roach

Chapin

et al. 2010

All Days

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“…If one were to artificially adjust gas properties so that fluid mobility term is independent of pressure, then no spatial mobility gradients are introduced for the pressure approach as a result of pressure gradients. In this case, the difference in results between approach and pressure approach is substantially decreased (Abacioglu et al, 2009). …”

mentioning

confidence: 93%

“…Previous research had identified differences of results between a reservoir simulator using the pressure formulation (Eq. 1) and a simulator using pseudopressure formula (Abacioglu et al, 2009).…”

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confidence: 99%

Accurate Tight Gas Flow Simulation: Where the Real Gas Pseudo-pressure Must Be Used

Shiralkar

2014

SPE Western North American and Rocky Mountain Joint Meeting

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Because of the growing importance of unconventional gas (shale gas, coalbed methane, etc.), gas flow simulation has been receiving greater interest in the industry. Although the real gas pseudo-pressure approach has been available for some time, many commercial simulation tools still use gas pressure as the basis for gas flow calculations. There is a widely held perception that, while the approach can result in faster simulation runs, the two approaches are essentially equivalent or interchangeable. Herein, we show that well productivity is often significantly over-estimated when the standard pressure based approach is used for tight gas reservoirs. The effect is more pronounced at lower pressures.We demonstrate that the difference in results arises from the numerical dispersion in the simulator associated with the pressure formulation. We discuss the implementation within a simulator that models both sub-surface flow as well as flow in a surface network. This allows comparison of simulation runs using the two different formulations.Finally, we present several examples simulating gas flow in tight reservoirs with wells that are horizontally and vertically fractured, as well as a multi-well example. The approach is shown to yield accurate results in contrast to the pressure approach. This has important implications for simulations on a field wide scale and when other phases are present along with gas.This paper shows that the real gas pseudo-pressure approach should be used to simulate tight gas reservoirs, through which the well productivity can be accurately estimated. The implementation approach is also applicable to other commercial simulators in the industry.

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“…The permeability of this unconventional gas reservoir is less than 0.1mD (Abacioglu, 2009;Pankaj, 2010). Nowadays, different completion measures have been applied to tight gas reservoir, and may lead to different well performance.…”

Section: Introductionmentioning

confidence: 99%

The Study of CO2 Flooding and Sequestration in Tight Gas Reservoir: Different Completion Measures

Dou

Wang

et al. 2015

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Sequestrating CO 2 in gas reservoirs can substantially enhance gas recovery and effectively mitigate globe warming problem. As a kind of unconventional reservoirs, tight gas reservoir has been one of main sources of natural gas supply. The objective of this paper is to discuss CO 2 sequestration effect for wells with different completion measures in tight gas reservoir.Based on Sulige gas field, a typical block is selected to investigate CO 2 flooding in tight gas reservoir. A compositional numerical model of five-spot pattern is established with a horizontal well in the middle, while 4 vertical wells on the edge. With the model, several CO 2 flooding scenarios of horizontal well with different completion measures are studied to investigate the influence of completion measures. Development strategies such as production rate and total gas injection volume are investigated. The improved gas recovery obtained by CO 2 flooding for each scenario is quantified by comparing with natural depletion mode.Different completion measures can be found in tight gas reservoir. The difference in completion can result in different well performance. The results of this study show that the recovery factor of horizontal well with SRV is larger than those of the other two. Some characteristics of tight gas reservoir, such as reservoir permeability stress-sensitivity, non-Darcy flow should be taken into consideration when determine development strategies. Besides the economy benefit obtained by enhanced gas recovery, CO 2 flooding can also realize greenhouse gas geological sequestration and thus acquire environmental benefit.Technical contributions in this paper including (a) investigating the CO 2 flooding and sequestration effect for different completion measures in tight gas reservoir; (b) discussing the influence of permeability stress-sensitivity, non-Darcy flow on development strategies determination.

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Advancing Reservoir Simulation Capabilities for Tight Gas Reservoirs

Cited by 20 publications

References 12 publications

Integrated Dynamic Reservoir Modeling for Multilayered Tight Gas Sand Development

Integrated Dynamic Reservoir Modeling for Multilayered Tight Gas Sand Development

Accurate Tight Gas Flow Simulation: Where the Real Gas Pseudo-pressure Must Be Used

The Study of CO2 Flooding and Sequestration in Tight Gas Reservoir: Different Completion Measures

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