Water blocking damage in hydraulically fractured tight sand gas reservoirs: An example from Perth Basin, Western Australia

Bahrami, Hassan; Rezaee, Reza; Clennell, Ben

doi:10.1016/j.petrol.2012.04.002

Cited by 156 publications

(67 citation statements)

References 4 publications

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“…The trends in production after hydraulic fracturing is strongly influenced by decrease of fracture conductivity and reservoir formation permeability by damage caused during fracturing and post-fracturing production impairment is influenced by various potential damage mechanisms involved in stimulation of unconventional-gas-wells (Shaoul et al 2011, Guo et al 2011, Bahrami et al 2012, and Li et al 2012. Jackson and Rai (2012) describe the sources of skin effects involved in hydraulically-fractured shale gas wells completion efficiency caused by various completion resistances.…”

Section: Fundamental Damage Mechanisms and Skin Factorsmentioning

confidence: 99%

“…In fact, the linear cumulative filtrate invasion trends observed in their experimental tests using non-clay-damaging fracturing fluids indicate that filter cake formation does not occur at such low invasion rates and the spurt-loss effect is negligible. However, Bahrami et al (2012) mention that filtrate invasion problems occur in naturally fractured shale reservoirs, but the weak-mud-cake formation on the wellbore and low porosity and strong capillary suction conditions allow for a prolonged liquid invasion over a long distance from the wellbore into the reservoir formation, and therefore, filter cake lifting is not really an issue of importance during the cleanup period. Filter-cake and pore blockage effects are discussed in detail elsewhere (Civan and Engler, 1994, Civan, 1998a,b, 2007a.…”

Section: Hydraulic-fluid Leakoff and Invasionmentioning

confidence: 99%

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Analyses of Processes, Mechanisms, and Preventive Measures of Shale-Gas Reservoir Fluid, Completion, and Formation Damage

Civan

2014

SPE International Symposium and Exhibition on Formation Damage Control

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A comprehensive review and modeling of the natural and induced fluid, completion, and formation damage processes and their governing mechanisms involving the various aspects of gas-bearing shale reservoir formations is presented. The damage potential of shale formations containing large quantities of clay and nonclay inorganic, and organic materials, and natural fractures filled with cement and other debris is delineated. The thermal, chemical, and stress interactions between the drilling and fracturing fluids and shale formations are described. The relevant processes and their fundamental mechanisms, including under/over balanced drilling, fracturing-fluid disposition and detainment, wettability and nonequilibrium fluid transport and spontaneous imbibitions, swelling and fluidization, and gas and water blockage occurring in extremely-low permeability shale porous media are reviewed. The critical review presented here provides valuable insights into the nature of the shale-gas reservoir formation damage, indicating the significant roles of the different orders of magnitude rate processes and the thermal, chemical, and stress shocks causing formation damage during drilling, completion, and production. The significant differences observed between the rates of adverse processes can be facilitated to effectively control, minimize, and/or prevent the common shale-gas reservoir production problems. The scientifically-guided protocol provided concerning the fluid, completion, and formation damage processes can help in effective mitigation of the flow assurance problems associated with hydraulically-fractured wells completed in gas-bearing shale reservoirs to maximize the well productivity.

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Section: Fundamental Damage Mechanisms and Skin Factorsmentioning

confidence: 99%

Section: Hydraulic-fluid Leakoff and Invasionmentioning

confidence: 99%

Analyses of Processes, Mechanisms, and Preventive Measures of Shale-Gas Reservoir Fluid, Completion, and Formation Damage

Civan

2014

SPE International Symposium and Exhibition on Formation Damage Control

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“…Some examples of hydraulic fracturing applications have been reported all around the world [8][9][10][11][12]. Although the fracturing technique is now considered an essential part of the reservoir management backbone in tight/shale gas field developments, the complexities associated with the hydraulic fracturing dictate some degree of uncertainty in successful economic applications [6,[13][14][15][16]. Some prominent characteristics of these reservoirs, such as very low permeability and high initial gas flow rate followed by a sharp decline, cause the economic evaluation of the process to be usually accompanied with significant difficulties.…”

Section: Introductionmentioning

confidence: 99%

Modeling the Risk of Commercial Failure for Hydraulic Fracturing Projects Due to Reservoir Heterogeneity

et al. 2018

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Abstract:Hydraulic fracturing technologies play a major role in the global energy supply and affect oil pricing. The current oil price fluctuations within 40 to 55 USD per barrel have caused diminished economical margins for hydraulic fracturing projects. Hence, successful decision making the for execution of hydraulic fracturing projects requires a higher level of integration of technical, commercial, and uncertainty analyses. However, the complexity of hydraulic fracturing modeling, and the sensitivity and the effects of uncertainty of reservoir heterogeneity on well performance renders the integration of such studies rather impractical. The impact of reservoir heterogeneity on hydraulic fracturing performance has been quantified by the introduction of Heterogeneity Impact Factor (HIF) and formulas have been developed to forecast well performance using HIF. These advances provide a platform for introducing a practical approach for introducing the Risk of Commercial Failure (RCF) due to reservoir heterogeneity in hydraulic fracturing projects. This paper defines such a parameter and the methodology to calculate it in a time-efficient manner. The proposed approach has been exercised on a real project in which a RCF of 20% is computed. The analysis also covers the sensitivity on Capital Expenditure (CAPEX), Operational Expenditure (OPEX), gas price, HIF and discount rate.

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“…Tight sandstone reservoirs were regarded as their target areas. This type of reservoir comprises fractures with tectonic origins as their main seepage path and reservoir space (Bahrami et al, 2012;Abija & Nwankwoala, 2018). The formation, development, and evolution of structural fractures are the critical issues and difficulties in oil and gas exploration and development, especially in the study of the characteristics and division of the formation stages of reservoir fractures.…”

Section: Introductionmentioning

confidence: 99%

Fractal characteristics of reservoir structural fracture: a case study of Xujiahe Formation in central Yuanba area, Sichuan Basin

Fan¹,

Qin²,

Hu³

et al. 2018

Earth sci. res. j.

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The reservoir structural fractures have excellent fractal characteristics, as well as self-similarities. Based on the fractal theory, the surface fractal characteristics of faults and the fractal characteristic of fractures in the core of the Xujiahe Formation in the Fault-Fold Belt of the central Yuanba area were studied, and a quantitative relationship was set up between them. Based on the fractal characteristics of faults, predictions were made of the favorable fracture zone, which provides a new idea for the research of fracture, as well as offers theoretical references for exploring the fracture development zone during oil-gas exploration. The results show the following: the seismic value of reflection fault fractal dimension of the Xujiahe Formation is 1.5284; the correlation coefficient R 2 is bigger than 0.9901; the capacity dimension linear regression correlation coefficient of the fracture in core of the Xujiahe Formation is bigger than 0.98; the fractal dimension D can well reflect the fault and fracture development degree, as well as the complexity of the fracture system; it can quantitatively calculate the density of the fracture of the reservoir in the area; the areas of capacity dimension bigger than 1.45 are the fracture development zones in the Fault-Fold Belt of the central Yuanba area; the oil and gas enrichment degree is high; the areas with the fractal dimension value between 0.95 and 1.45 are the fracture relatively-developed zones; the fractal dimension with values smaller than 0.95 are the lack of fracture areas.ABSTRACT

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Water blocking damage in hydraulically fractured tight sand gas reservoirs: An example from Perth Basin, Western Australia

Cited by 156 publications

References 4 publications

Analyses of Processes, Mechanisms, and Preventive Measures of Shale-Gas Reservoir Fluid, Completion, and Formation Damage

Analyses of Processes, Mechanisms, and Preventive Measures of Shale-Gas Reservoir Fluid, Completion, and Formation Damage

Modeling the Risk of Commercial Failure for Hydraulic Fracturing Projects Due to Reservoir Heterogeneity

Fractal characteristics of reservoir structural fracture: a case study of Xujiahe Formation in central Yuanba area, Sichuan Basin

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