Advances and Challenges of Reservoir Characterization: A Review of the Current State-of-the-Art

Jia, Ailin; He, Dengfa; Cai, Jia

doi:10.5772/26404

Cited by 7 publications

(5 citation statements)

References 42 publications

(36 reference statements)

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“…Subsequent to water flooding, various EOR techniques, such as chemical EOR, thermal EOR, microbial EOR, and gas injection EOR, are employed depending upon the nature of the reservoir. Out of these EOR methods, chemical EOR methods are one of the most promising methods for conventional crude oil reservoirs due to their improved recovery factor. − Chemical methods primarily include the use of polymer (P), surfactant–polymer (SP), and alkali-surfactant–polymer (ASP) flooding and are applied to enhance the oil recovery by reducing the interfacial tension (IFT) between the crude oil–water present within the reservoir. , Chemical EOR methods, although they have developed over the years, need improvement for their application toward complex reservoir conditions , and for improved reservoir characterization …”

Section: Introductionmentioning

confidence: 99%

“…7,8 Chemical EOR methods, although they have developed over the years, need improvement for their application toward complex reservoir conditions 9,10 and for improved reservoir characterization. 11 Nanotechnology helps to improve the performances of various processes by exploiting the properties of various nanoparticles which typically have the dimensions of the order of 100 nm or less. Nanoparticles have a larger surface area per unit volume than the bulk material.…”

Section: Introductionmentioning

confidence: 99%

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Silica Nanofluids in an Oilfield Polymer Polyacrylamide: Interfacial Properties, Wettability Alteration, and Applications for Chemical Enhanced Oil Recovery

Sharma

Iglauer

Sangwai

2016

Ind. Eng. Chem. Res.

187

147

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Oil production from matured crude oil reservoirs is still associated with low recovery factors. Chemical enhanced oil recovery (EOR) is one of the techniques which can significantly improve the recovery factor of the trapped oil. This is mainly achieved by lowering the interfacial tension (IFT) of the crude oil−brine/aqueous chemical and increasing the viscosity of the injected fluid. Nanofluids have demonstrated potential in this respect, and we thus examined how such nanofluids behave when formulated with standard oilfield polymers, with a particular focus on their EOR efficiency. In this work, silica (SiO 2 ) nanofluids with (NSP) or without (NP) surfactant (sodium dodecyl sulfate) added and with varying nanoparticle concentration were formulated with polyacrylamide (PAM) and characterized by DLS and ζ-potential measurements. These nanofluids were then tested in EOR core-flood experiments. Various studies involving the stability and viscosity of nanofluids, interfacial tension of the nanofluidcrude oil system, their effect on wettability alteration, and efficiency for EOR studies as a function of temperature have been reported. The efficiency of the nanofluid systems for IFT reduction and EOR has also been compared with the conventional polymer (P) and surfactant−polymer (SP) flood schemes. The SiO 2 nanofluids significantly increased oil recoveries, particularly at higher temperatures, mainly due to IFT reduction, fluid viscosity increase, and wettability alteration (from intermediate-wet to strongly water-wet). We conclude that SiO 2 nanofluids can potentially be attractive EOR chemicals, particularly for wettability alteration operations and high temperature applications.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Silica Nanofluids in an Oilfield Polymer Polyacrylamide: Interfacial Properties, Wettability Alteration, and Applications for Chemical Enhanced Oil Recovery

Sharma

Iglauer

Sangwai

2016

Ind. Eng. Chem. Res.

187

147

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“…When the oil has been discovered in a field, many studies will be required to evaluate and comprehend the reservoir heterogeneity, define the extent of the reservoir in the three-dimensional, evaluating the fluid volumetric in the reservoir and identify the suitable method to increase the reservoir fluid recovery. Generally, reservoir characteristics such as lithofacies heterogeneities, porosity, and permeability spatial variation control the reservoir performance, and development plans [1]. The 3D reservoir model represents the reservoir properties, thus building a static reservoir involve to accomplish four tasks which care out by specialists in multiple disciplines, these stages are Structural modeling, Stratigraphic modeling, Lithological modeling, and Petrophysical modeling.…”

Section: Introductionmentioning

confidence: 99%

Application of 3D Reservoir Geological Model on Es1 Formation, Block Nv32, Shenvsi Oilfield, China

Rassas¹,

Ren²,

Sun³

et al. 2020

OJOGas

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Three-dimensional geological modeling of reservoirs is an essential tool to predict reservoir performance and improve the understanding of reservoir uniqueness in Es1 formation. The paper focuses on the use of petrel software to build three-dimensional reservoir geological model which characterizes and assesses block Nv32 that located in the west of the Shenvsi oilfield in the south of Cangzhou city, Hebei province of China, and has an oil-bearing area of 1.4 km 2. This study is depending on integration data from well logs of 22 wells which provided from geology, geophysics, and petrophysics to identify and provide precise depict of the subsurface internal structure and the reservoir heterogeneity. Input data was used to build the structural model, sedimentary facies model, petrophysical properties (porosity, permeability, saturation, and N/G model, and finally to determine the reservoir volume. The lithological facies were simulated using the assigned value method. Moreover, Petrophysical properties (Porosity, permeability, oil saturation and net to gross) were constructed for each zone using the Sequential Gaussian Simulation method to guide the distribution of petrophysical properties of Es1 formation, block Nv32. Statistical analysis of the porosity, permeability, oil saturation and N/G model present that the porosity occurrence distribution is mainly concern between 0.2%-36.39% of block Nv32 with an average porosity value of 17.5%, permeability between 0.017 mD to 974.8 mD, having an average permeability of 59.44 mD, oil saturation between 0.00 to 0.95 having an average value of 0.22, and N/G is mainly concentrated between 0.01 to 1.00 within an average value of 0.61. This research has indicated the reliability of the three-dimensional model technique as a suitable tool to provide a suffi

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“…According to Ailin and Dongbo (2012), it is common knowledge amongst industry experts that reservoir flow properties control the amount of producible hydrocarbon from reservoirs and as such these factors (such as porosity, permeability, and saturation) are essential in making economic decisions on any potential or producing reservoir. According to the theme of the SPE International Conference in 2015 (Society of Petroleum Engineers 2015), for uncertainties in reservoir characterization to be reduced and recovery maximized, an integrated method is best used.…”

Section: Introductionmentioning

confidence: 99%

Integration of 3D-seismic and petrophysical analysis with rock physics analysis in the characterization of SOKAB field, Niger delta, Nigeria

Bodunde

Enikanselu

2018

J Petrol Explor Prod Technol

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Compartmentalization of reservoirs and technical failures experienced in data acquisition, processing and interpretation, without doubt, hinder the effective characterization of reservoirs. In this research, to ensure accuracy, three methods were integrated to characterize reservoirs in SOKAB field. Petrophysical analysis, seismic interpretation, and modeling, and rock physics analysis were utilized. Its objectives were: to develop a template to facilitate improvements in future reservoir characterization research works and producibility determination; to utilize rock physics models to quality check the seismic results and to properly define the pore connectivity of the reservoirs, and to locate the best productive zones for future wells in the field. Forty-three faults were mapped and this included five major faults. Two hydrocarbon bearing sand units (A & B) were correlated across five wells. Structural maps were generated for both reservoirs from which majorly fault assisted and dependent closures were observed. The petrophysical analysis indicated that the reservoirs have good pore interconnectivity (Average Ф effective = 23% & 22% and K average = 1754md & 2295md). The seismic interpretation and modeling alongside the petrophysical analysis were then quality checked via qualitative rock physics analysis. From the K dry /Porosity plot, the sands were generally observed to lie within the lower Reuss and upper Voigt bound which indicates a low level of compaction. From the velocity-porosity cross plot, it was revealed that the lower portions of the reservoirs were poorly cemented and this could hinder their producibility.

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Advances and Challenges of Reservoir Characterization: A Review of the Current State-of-the-Art

Cited by 7 publications

References 42 publications

Silica Nanofluids in an Oilfield Polymer Polyacrylamide: Interfacial Properties, Wettability Alteration, and Applications for Chemical Enhanced Oil Recovery

Silica Nanofluids in an Oilfield Polymer Polyacrylamide: Interfacial Properties, Wettability Alteration, and Applications for Chemical Enhanced Oil Recovery

Application of 3D Reservoir Geological Model on Es1 Formation, Block Nv32, Shenvsi Oilfield, China

Integration of 3D-seismic and petrophysical analysis with rock physics analysis in the characterization of SOKAB field, Niger delta, Nigeria

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