Combined Effect of Non-Darcy Flow and Formation Damage on Gas Well Performance of Dual-Porosity and Dual-Permeability Reservoirs

Tavares, Carlos Alberto Pereira; Kazemi, Hossein; Özkan, Erdal

doi:10.2118/90623-ms

Cited by 5 publications

(3 citation statements)

References 14 publications

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“…Matrix blocks are connected in this model and participate in the overall fluid flow. In comparison to the dual-porosity model, which is suitable only for intensely fractured reservoirs, the dualporosity/permeability model can be applied for many reservoirs with different fracture degrees [31][32][33][34][35][36].…”

Section: Introductionmentioning

confidence: 99%

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Numerical Well Test Analysis of Condensate Dropout Effects in Dual-Permeability Model of Naturally Fractured Gas Condensate Reservoirs: Case Studies in the South of Iran

Safari-Beidokhti¹,

Hashemi

Abdollahi³

et al. 2021

Mathematical Problems in Engineering

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Naturally fractured reservoirs (NFR) represent an important percentage of worldwide hydrocarbon reserves and production. The performance of naturally fractured gas condensate reservoirs would be more complicated regarding both rock and fluid effects. In contrast to the dual-porosity model, dual-porosity/dual-permeability (dual-permeability) model is considered as a modified model, in which flow to the wellbore occurs through both matrix and fracture systems. Fluid flow in gas condensate reservoirs usually demonstrates intricate flow behavior when the flowing bottom-hole pressure falls below the dew point. Accordingly, different regions with different characteristics are formed within the reservoir. These regions can be recognized by pressure transient analysis. Consequently, distinguishing between reservoir effects and fluid effects is challenging in these specific reservoirs and needs numerical simulation. The main objective of this paper is to examine the effect of condensate banking on the pressure behavior of lean and rich gas condensate NFRs through a simulation approach. Subsequently, evaluation of early-time characteristics of the pressure transient data is provided through a single well compositional simulation model. Then, drawdown, buildup, and multirate tests are conducted to establish the condition in which the flowing bottom-hole pressure drops below the dew point causing retrograde condensation. The simulation results are confirmed through well test analysis in both Iranian naturally fractured rich and lean gas condensate fields. Interpretations of simulation analysis revealed that the richer gas is more prone to condensation. When the pressure drops below the dew point, the pressure derivative curves in the rich gas system encounter a more shift to the right, and the trough becomes more pronounced as compared to the lean one.

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Section: Introductionmentioning

confidence: 99%

“…e only difference is that, in all cases, the matrix can also produce into the well [21]. Many researches have been conducted on naturally fractured reservoirs applying the dual-porosity and dual-permeability model [36,[38][39][40][41][42][43][44][45][46][47][48][49][50][51].…”

Section: Introductionmentioning

confidence: 99%

Numerical Well Test Analysis of Condensate Dropout Effects in Dual-Permeability Model of Naturally Fractured Gas Condensate Reservoirs: Case Studies in the South of Iran

Safari-Beidokhti¹,

Hashemi

Abdollahi³

et al. 2021

Mathematical Problems in Engineering

View full text Add to dashboard Cite

show abstract

“…Comparably same with DPM, dual-porosity-dual-permeability model (DPDP) is also studied which considers the flow in the matrix additionally (Pereira et al 2004;Yan et al 2013). The matrix properties dominate the flow from matrix to fracture.…”

Section: Introductionmentioning

confidence: 99%

Multi-Stage Fractured Horizontal Well Numerical Simulation and Its Application in Tight Shale Reservoirs

et al. 2015

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Unconventional tight shale reservoirs have been developed during recent years due to increasing shortage of conventional resources and a large number of multi-stage fractured horizontal wells (MsFHW) have been drilled to enhance reservoir production performance. Gas flow in tight shale reservoirs is a multi-mechanism process, including: desorption, diffusion, and non-Darcy flow. The productivity of the shale gas reservoir with MsFHW is influenced by both reservoir condition and hydraulic fracture properties. In this paper, a dual-porosity-dual-permeability model was presented to estimate the effect of parameters on shale gas production. Three flow mechanisms have been considered in this model: gas diffusion in nano scale pores, Darcy flow in macro scale pores, and non-Darcy flow in near wellbore hydraulic fractures. Langmuir isotherm was used to simulate the gas desorption process. Hydraulic fractures were performed by Local Grid Refinement (LGR) method.To conduct sensitivity anlaysis on production performance of tight shale reservoirs with MsFHW, parameters influencing shale gas production were classified into two categories: reservoir properties (including matrix permeability, matrix porosity, natural fracture porosity, rock compressibility, gas desorption) and hydraulic fracture properties (including hydraulic fracture spacing, fracture half-length, fracture conductivity, and fracture height). Typical ranges of these parameters have been reviewed. Sensitivity checks for each parameter were performed to analyze the effect of factors on the cumulative gas production. It can be found that matrix porosity is the most influencing reservoir parameter which has greatest effect on cumulative production among reservoir parameters. And hydraulic fracture spacing, fracture half-length, fracture conductivity, and fracture height are all significant parameters. Result of this study can be used to improve the efficiency of history matching process. Also, it can contribute to the design and optimization of hydraulic fracture treatment design in unconventional tight reservoirs.

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Correction of non-Darcy Coefficient and How to Estimate It for Development Wells

Raijo

2011

SPE Asia Pacific Oil and Gas Conference and Exhibition

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Abadi gas field located offshore Arafura Sea, eastern Indonesia (Figure-1) was discovered by INPEX in 2000 and the appraisal activities have been carried out subsequently since then. Total 7 wells have been drilled and 8 DSTs have been conducted so far. The objectives of this work are to obtain more accurate non-Darcy coefficient (D) from the exploration and appraisal well's Drill Stem Test (DST) by accounting for the completion effects, and to estimate D for the development wells. The result shows the importance of accounting for the completion effect in order to get more accurate non-Darcy coefficient (D). The installation of the downhole gauge below packer & flow sub eliminates the need for this kind of correction. It was confirmed that the completion effect can significantly underestimate the IPR (Inflow Performance Relationship) of the high-permeability gas wells. In addition, the turbulence coefficient ß was found from the field data to be the function of not only the reservoir properties but also the gun specification. To use a deep penetration gun and to avoid partial penetration were found to be the key for reducing the pressure drop caused by non-Darcy flow, if the cased & perforation is adopted as a completion technique of the development wells for the reservoir of interest.

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Combined Effect of Non-Darcy Flow and Formation Damage on Gas Well Performance of Dual-Porosity and Dual-Permeability Reservoirs

Cited by 5 publications

References 14 publications

Numerical Well Test Analysis of Condensate Dropout Effects in Dual-Permeability Model of Naturally Fractured Gas Condensate Reservoirs: Case Studies in the South of Iran

Numerical Well Test Analysis of Condensate Dropout Effects in Dual-Permeability Model of Naturally Fractured Gas Condensate Reservoirs: Case Studies in the South of Iran

Multi-Stage Fractured Horizontal Well Numerical Simulation and Its Application in Tight Shale Reservoirs

Correction of non-Darcy Coefficient and How to Estimate It for Development Wells

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