Optimization of hydraulic fracture geometry in gas condensate reservoirs

Mahdiyar, Hojjat; Jamiolahmady, Mahmoud

doi:10.1016/j.fuel.2013.11.015

Cited by 23 publications

(14 citation statements)

References 21 publications

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“…2,27 Hydraulic fracturing operations are implemented in the condition of extremely low permeability or significantly high capillary pressure. 23,28 The induced fractures create conductive paths between the reservoir and the wellbore and then enhance the process of condensate removal. 28 Gas recycling methods are used to pressurize the near-wellbore region to convert the condensate liquid into the gaseous state.…”

Section: Introductionmentioning

confidence: 99%

“…23,28 The induced fractures create conductive paths between the reservoir and the wellbore and then enhance the process of condensate removal. 28 Gas recycling methods are used to pressurize the near-wellbore region to convert the condensate liquid into the gaseous state. 29,30 However, gas recycling offers only a temporary improvement in the gas production, and the treatment needs to be repeated every 3–6 months.…”

Section: Introductionmentioning

confidence: 99%

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New Chemical Treatment for Permanent Removal of Condensate Banking from Different Gas Reservoirs

et al. 2019

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Condensate banking represents a challenging problem in producing the hydrocarbon from tight gas reservoirs. The accumulation of liquid condensates around the production well can significantly impair the gas flow rate. Gas injection and hydraulic fracturing are the common techniques used to avoid the condensate development by maintaining the reservoir pressure above the dew point curve. However, these treatments are associated with high operational costs and large initial investment. This study presents a new chemical treatment for removing the condensate banking using thermochemical solutions. The presented treatment can cause a permanent impact on the treated formations. Chemicals are injected to react downhole and generate in situ pressure and heat in certain conditions. The generated pressure can raise the gas pressure above the dew point, and the generated heat can change the phase of the liquid condensate to gas. Kinetic analysis indicates that thermochemical fluids can increase the temperature and heat by 85 °C and 369 kJ/mol, respectively. In addition, the impact of clay content on the efficiency of thermochemical treatment was studied using coreflooding experiments. A condensate removal of more than 60% was achieved using the huff and puff injection mode. A good correlation between the rock permeability and the condensate removal efficiency was observed. Higher condensate removal was obtained for the rock samples with high permeability values. Moreover, the presence of clay minerals in the treated rock showed a minor impact on the condensate removal, indicating that the injected chemicals are able to stabilize the clay minerals and avoid clay damage. This research shows that thermochemical treatment can remove more than 60% of the condensate damage for different types of tight sandstones. Huff and puff treatment was found to be a very practical approach to diminish the condensate banking from different sandstone rocks. Also, this work confirms that thermochemical treatment can be applied in the clayey formation for removing the condensate blockage without affecting the clay stability or inducing clay damage. Ultimately, this study introduces a new chemical treatment in the gas industry, and the used chemicals are effective, environmentally friendly, and not expensive.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

New Chemical Treatment for Permanent Removal of Condensate Banking from Different Gas Reservoirs

et al. 2019

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“…Besides the logistical challenges associated with gas transportation, there exists an additional challenge of on-site gas handling during the gas recycling treatment [3,4,17]. Alternatively, hydraulic fracturing is used to mitigate the condensate bank by inducing conductive channels between the wellbore and the reservoir matrix [18][19][20]. The created fractures improve the flow paths available and decrease the drawdown pressure [20][21][22].…”

Section: Introductionmentioning

confidence: 99%

Novel Treatment for Mitigating Condensate Bank Using a Newly Synthesized Gemini Surfactant

et al. 2020

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Condensate accumulation in the vicinity of the gas well is known to curtail hydrocarbon production by up to 80%. Numerous approaches are being employed to mitigate condensate damage and improve gas productivity. Chemical treatment, gas recycling, and hydraulic fracturing are the most effective techniques for combatting the condensate bank. However, the gas injection technique showed temporary condensate recovery and limited improvement in gas productivity. Hydraulic fracturing is considered to be an expensive approach for treating condensate banking problems. In this study, a newly synthesized gemini surfactant (GS) was developed to prevent the formation of condensate blockage in the gas condensate reservoirs. Flushing the near-wellbore area with GS will change the rock wettability and thereby reduce the capillary forces holding the condensate due to the strong adsorption capacity of GS on the rock surface. In this study, several measurements were conducted to assess the performance of GS in mitigating the condensate bank including coreflood, relative permeability, phase behavior, and nuclear magnetic resonance (NMR) measurements. The results show that GS can reduce the capillary pressure by as much as 40%, increase the condensate mobility by more than 80%, and thereby mitigate the condensate bank by up to 84%. Phase behavior measurements indicate that adding GS to the oil–brine system could not induce any emulsions at different salinity levels. Moreover, NMR and permeability measurements reveal that the gemini surfactant has no effect on the pore system and no changes were observed in the T2 relaxation profiles with and without the GS injection. Ultimately, this work introduces a novel and effective treatment for mitigating the condensate bank. The new treatment showed an attractive performance in reducing liquid saturation and increasing the condensate relative permeability.

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“…There are many factors affecting hydraulic fracturing, including reservoir characteristics, fracture parameters, and fracturing treatment parameters. To obtain the best stimulation results, hydraulic fracturing optimization [1] is conducted such as fracturing completion optimization [2], fracture spacing optimization [3], fracture geometry optimization [4][5][6][7], proppant distribution optimization [8,9], treatment parameters optimization [10][11][12][13], optimization for different types of reservoirs [14][15][16][17], optimization considering heterogeneous properties of reservoirs [18][19][20] and complex fracture networks optimization [21][22][23].…”

Section: Introductionmentioning

confidence: 99%

Hydraulic Fracturing Treatment Optimization for Low Permeability Reservoirs Based on Unified Fracture Design

Duan

Gao

et al. 2018

Energies

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Hydraulic fracturing optimization is very important for low permeability reservoir stimulation and development. This paper couples the fracturing treatment optimization with fracture geometry optimization in order to maximize the dimensionless productivity index. The optimal fracture dimensions and optimal dimensionless fracture conductivity, given a certain mass or volume of proppant, can be determined by Unified Fracture Design (UFD) method. When solving the optimal propped fracture length and width, the volume and permeability of the propped fracture should be determined first. However, they vary according to the proppant concentration in the fracture and cannot be obtained in advance. This paper proposes an iterative method to obtain the volume and permeability of propped fractures according to a desired proppant concentration. By introducing the desired proppant concentration, this paper proposes a rapid semi-analytical fracture propagation model, which can optimize fracture treatment parameters such as pad fluid volume, injection rate, fluid rheological parameters, and proppant pumping schedule. This is achieved via an interval search method so as to satisfy the optimal fracture conductivity and dimensions. Case study validation is conducted to demonstrate that this method can obtain optimal solutions under various constraints in order to meet different treatment conditions.

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Optimization of hydraulic fracture geometry in gas condensate reservoirs

Cited by 23 publications

References 21 publications

New Chemical Treatment for Permanent Removal of Condensate Banking from Different Gas Reservoirs

New Chemical Treatment for Permanent Removal of Condensate Banking from Different Gas Reservoirs

Novel Treatment for Mitigating Condensate Bank Using a Newly Synthesized Gemini Surfactant

Hydraulic Fracturing Treatment Optimization for Low Permeability Reservoirs Based on Unified Fracture Design

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