On the Application of Well Stimulation Method in Improvement of Oil Recovery

Gharibi, Abdoullatif; Zoveidavianpoor, Mansoor; Ghadikolaei, Farshad Daraei

doi:10.4028/www.scientific.net/amm.735.31

Cited by 4 publications

(4 citation statements)

References 12 publications

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“…One of the commonly used methods of enhanced oil recovery is hydraulic fracturing. Hydraulic fracturing technology and well development after hydraulic fracturing are discussed in detail in [123,124].…”

Section: Hydraulic Fracturing (Hf)mentioning

confidence: 99%

Overview of Methods for Enhanced Oil Recovery from Conventional and Unconventional Reservoirs

Malozyomov,

Martyushev,

Kukartsev

et al. 2023

Energies

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In world practice, the role of reproduction of raw material base of oil production by implementing modern methods of oil recovery enhancement (thermal, gas, chemical, microbiological) on the basis of innovative techniques and technologies is rapidly growing and is becoming more important. It is concluded that at present, the priority of increasing oil reserves in world oil production is the development and industrial introduction of modern integrated methods of enhanced oil recovery, which can provide a synergistic effect in the development of new and developed oil fields. This article presents a review and comparative analysis of theoretical and practical methods of improving oil recovery of conventional and unconventional reservoirs. The paper examines in detail methods of improving oil recovery, taking into account the factors of enhanced oil recovery of oil reservoirs. Considered the main methods and technologies currently used to develop oil fields and recommendations for their effective use, taking into account the variety of external factors of oil production: the geological structure of the reservoir, its volume, and properties of oils. It is shown that there is no universal method of oil reservoir development, and it must be chosen after a thorough feasibility study among several proposed models. When describing the methods of enhanced oil recovery, special attention is also paid to the physical processes that occur as a result of applying the technology. In conclusion, the positive and negative characteristics of the presented methods included in EOR are presented, and recommendations that may influence the choice of practical solutions for engineers and oil producers are given. Conclusions are made that development systems, placement and choice of operating mode of wells essentially depend on the geological structure of the reservoir, its volume and properties of oils. An important role in this is the construction of a geological model of the production facility. The used hydrodynamic models of development are based on physical laws, about which oil producers sometimes don’t even suspect, and the authors of the models are not always able to convey it to the real producers. The authors consider it reasonable to make a logical generalizing conclusion that understanding processes occurring in the reservoir and taking appropriate measures for optimization and intensification of oil production will allow making oil production as effective as possible.

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Section: Hydraulic Fracturing (Hf)mentioning

confidence: 99%

Overview of Methods for Enhanced Oil Recovery from Conventional and Unconventional Reservoirs

Malozyomov,

Martyushev,

Kukartsev

et al. 2023

Energies

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“…Among them, shale gas reservoirs have great potential for exploration and development in a way they can unlock billions of cubic feet of gas. Multistage hydraulic fracturing is the main stimulation technique, , widely applied for economic gas extraction from such ultra-tight reservoirs. Water has remained the main source of hydraulic fracturing fluid (HFF), which has successfully been used to increase tight gas and shale gas recovery among different fracturing methods. − However, shale formations are highly prone to blockage by water due to the contribution of nanopores to the texture of rock.…”

Section: Introductionmentioning

confidence: 99%

Experimental and Modeling Study of Water Imbibition and Flowback in Shale: Prediction of Relative Permeability and Capillary Pressure Curves

et al. 2023

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Understanding the invasion and flowback processes of water, as the main source of hydraulic fracking fluid, is crucial for the proper evaluation and development of complex gas shale formations. Direct measurements of full gas−water relative permeability and capillary pressure curves by steady-state or unsteady-state techniques are not feasible in ultralow permeability shales. Therefore, the objective of this study is to investigate the dynamic rock−fluid properties of a Mancos shale sample by mimicking water imbibition and flowback experiments. To do so, a water injection experiment was done and tried to measure the flowback. After that, history matching on the experimental data of the water injection and flowback process was done to predict gas− water relative permeability data and capillary pressure curves. Low water flowback was observed, which insists on water entrapment in shale rocks. The results show a high threshold pressure and meaningful relative permeability of water, which can reduce the gas production rate dramatically. The saturation profiles show a high percentage of water in the invaded zone (>75%); however, the continuous imbibition of water with time (increase in shut-in time) helps the front of the invasion zone to move further deep into the shale, which enhances gas production. The S-shape gas relative permeability curve most likely represents the actual trend of the curve. An optimum shut-in time was predicted, which enables us to avoid delays in starting production operations.

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“…Therefore, for many oil companies, the development of hydrocarbon stimulation methods is a priority. Stimulation treatments, such as HF [4,5,6], matrix acidizing, acid fracturing [7,8,9], or EOR [6,10,11,12] are common techniques used to increase the extraction productivity. In all aforementioned cases, the stimulation (injection) fluid is a crucial element and must meet special requirements depending on the goal of the application [13,14,15].…”

Section: Introductionmentioning

confidence: 99%

Impact of Nitrogen Foamed Stimulation Fluids Stabilized by Nanoadditives on Reservoir Rocks of Hydrocarbon Deposits

2019

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The first objective of this experiment was to improve the stabilization of N2 based foam with nanoparticles as an alternative to typical fracturing fluid, which consists of a gelling agent (HPG—hydroxypropyl guar). The second objective of the project was to investigate the damage caused by nanoparticle–based nitrogen foamed fracturing fluids (F.F) on a reference sandstone, using permeability and porosity tests, optical microscope with a Profilometer, and a scanning electron microscope (SEM). The properties of F.F with two types of SiO2 nanoparticles (hydrophilic fumed silica Areosil 300 and silica sol U-2 obtained by the sol-gel method), such as rheology and core damage, were investigated. The discussion of this research results is based on the stability tests carried out with the use of rheology and the foam half-life, formation damage ratio, and observation of exposed samples using SEM and the Profilometer. The permeability and porosity damage ratios of the damaged core samples were found to decrease when nitrogen foamed fluids were used. These results were confirmed with the Profilometer and SEM images. The experimental data showed that the foam stability increased when silica (SiO2) nanoparticles were added. SiO2 nanoparticle-surfactant-stabilized foam for fracturing is superior to traditional water-based fracturing fluids and causes lower core permeability damage than a traditional F.F.

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On the Application of Well Stimulation Method in Improvement of Oil Recovery

Cited by 4 publications

References 12 publications

Overview of Methods for Enhanced Oil Recovery from Conventional and Unconventional Reservoirs

Overview of Methods for Enhanced Oil Recovery from Conventional and Unconventional Reservoirs

Experimental and Modeling Study of Water Imbibition and Flowback in Shale: Prediction of Relative Permeability and Capillary Pressure Curves

Impact of Nitrogen Foamed Stimulation Fluids Stabilized by Nanoadditives on Reservoir Rocks of Hydrocarbon Deposits

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