Experimental Investigation of a Novel Nanosilica for Blocking Unwanted Water Production

Abstract Nanotechnology is the design and application of engineered nanoparticles with one minimum dimension in the range of 1 to 100 nanometers. To achieve a specific target, innovative methods are highly required to overcome the challenges in the oil and gas industry, such as undesired water production. Herein, we present an advanced nanosilica, a new eco-friendly, cost-effective, and promising approach to control undesirable water production. The objective of this work is to evaluate our nanofluid system that can be used for water management in different water production mechanisms, including: high permeability streak, wormhole, and fractured reservoirs. A systematic evaluation of novel nanosilica/activator for water shut-off application requires an examination of the chemical properties before, during, and after gelation at given reservoir conditions. The placement of this water shut-off system is highly dependent on gelation time and viscosity. Therefore, we emphasized in this study on investigating these gelation kinetics by conducting extensive rheology experiments at varied temperatures and activator concentrations. We have looked into evaluating the optimum breaker for the gel as a contingency plan for improper placement. Measurements of the nanosilica fluid’s initial viscosity exhibited a low viscosity, less than 10 cP at normal temperature and pressure (NTP) conditions; this provides significant benefit for mixing at surface and pumping requirements for pilot testing. The nanosilica gelation time can be tailored by adjusting activator concentration to match field job design at a given temperature, which is more than 200°F. The gelation time revealed an exponential relationship with temperature and reversible proportionality. The nanosilica gel proved to be a thermally stable fluid system along with different activation ratios. For breaker tests, the gellant fluid showed complete breakdown at altered temperatures to mimic downhole conditions. Our lab observations conclude that nanosilica fluid is verified to be acceptable as a water shut-off system for field applications. This novel nanofluid system is a promising technology to control water production from oil wells. The system has low initial viscosity that can be injected in porous media without hindering the injectivity and getting at risk of fracking the sand. In case of inappropriate placement, the fluid can break down entirely using a non-damaging chemical breaker instead of using mechanical approaches that might damage the completion.

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Planning pipeline pigging operations with predictive maintenance

E3S Web of Conferences ◽

10.1051/e3sconf/202126601017 ◽

2021 ◽

Vol 266 ◽

pp. 01017

Author(s):

A. M. Sousa ◽

M. J. Pereira ◽

H. A. Matos

Keyword(s):

Oil And Gas ◽

Field Measurements ◽

Oil And Gas Industry ◽

Visual Assessment ◽

Predictive Maintenance ◽

Systematic Evaluation ◽

Television System ◽

Gas Industry ◽

Body Of Knowledge ◽

Continuous Field

Deposition of waxes, asphaltenes, scales or hydrates is one of the most challenging operational problems in the oil and gas industry, both during production and transportation. Direct inspection procedures, such as employing a closed-circuit television system, allow visual assessment of the blockage, yet discretely in time and, consequently, of low value for the purpose of ensuring production over time. Therefore, an indirect predictive maintenance method for systematic evaluation of the internal pipe section is herein developed, adding a much needed solution to the current body of knowledge. Using continuous field measurements, it is now possible to predict when pigging should be performed to avoid significant blockages. Moreover, evaluating the maintenance plan risk is another major achievement. Finally, the proposed methodology and model were applied to a real case-study yielding good results compared to the current scheduled maintenance approaches.

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Characterization of barite reserves in Nigeria for use as weighting agent in drilling fluid

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-021-01164-8 ◽

2021 ◽

Vol 11 (5) ◽

pp. 2157-2178

Author(s):

David Oluwasegun Afolayan ◽

Adelana Rasak Adetunji ◽

Azikiwe Peter Onwualu ◽

Oghenerume Ogolo ◽

Richard Kwasi Amankwah

Keyword(s):

Specific Gravity ◽

Oil And Gas ◽

Drilling Fluid ◽

Chemical Properties ◽

Oil And Gas Industry ◽

American Petroleum Institute ◽

Gas Industry ◽

Cu Content ◽

Hardness Scale ◽

Drilling Operations

AbstractSuccessful drilling operations are dependent on the properties of the drilling fluid used to drill wells. Barite is used as a weighting agent during the preparation of drilling fluid. Over the years, oil and gas industry in Nigeria has been depending mainly on imported barite for drilling operations, whereas the country has huge deposits of barite. There is the need to assess the properties of the locally sourced barite for their suitability in drilling fluid formulation. This study presents the local processing methods of barite and examines the crude and on-the-site processed barite’s physio-chemical properties. These parameters were compared with American Petroleum Institute and Department of Petroleum Resources standards. XRD results show that on-the-site beneficiated barite has 87.79% BaSO4, 6.66% silica, 0.03% total soluble salt, 1.39% Fe2O3, and 1.603% heavy metals. Chemical analysis indicated that the pH, moisture content, metallic content such as Ca, Pb, Zn, Mg, Cu, and Cd minerals, and extractable carbonates were within the standard specified for usage as a drilling fluid weighting agent. The analysed crude barite samples were basic, within the pH of 8.3 and 8.6. Locally processed barite has lower Fe, Pb, Cd, and Cu content compared to industrially accepted barite. The specific gravity increased from 4.02 ± 0.07 to 4.15 ± 0.13, and the hardness reduced potentially from 5 Mohr to 3.5 Mohr on the hardness scale. The amount of impurities was sufficiently low, and the specific gravity of the samples improved to meet the needs of any drilling operation and compare favourably with industrially accepted barite.

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A Nano Method for a Big Challenge: Nanosilica-Based Sealing System for Water Shutoff

10.2118/204840-ms ◽

2021 ◽

Author(s):

Ayman Almohsin ◽

Jin Hung ◽

Mohammed Alabdrabalnabi ◽

Mohammed Sherief

Keyword(s):

Chemical Treatment ◽

Fractured Reservoirs ◽

Gelation Time ◽

Cost Effective ◽

Economic Life ◽

Narrow Particle Size Distribution ◽

Water Production ◽

Water Shutoff ◽

Sandstone Rock ◽

Wide Range

Abstract Minimizing unwanted water production from oil wells is highly required in the petroleum industry. This would lead to improved economic life of mature wells that involve new and innovative technologies. Nanosilica-based sealing fluid has been developed to address problems associated with unwanted water production. The objective of this work is to evaluate a newly developed novel water shutoff system based on nanosilica over a wide range of parameters. This modified nanosilica has a smooth, spherical shape, and are present in a narrow particle size distribution. Therefore, it can be used for water management in different water production mechanisms including high permeability streak, wormhole, and fractured reservoirs. A systematic evaluation of novel nanosilica/activator for water shutoff purposes requires the examination of the chemical properties before, during, and after gelation at given reservoir conditions. These properties are solution initial viscosity, gelation time, injectivity, and strength of the formed gel against applied external forces in different flooding systems. This paper details a promising method to control undesired water production using eco-friendly, cost-effective nanosilica. Experimental results revealed that nanosilica initially exhibited a low viscosity and hence providing a significant advantage in terms of mixing and pumping requirements. Nanosilica gelation time, which is a critical factor in placement of injected-chemical treatment, can be tailored by adjusting the activator concentration to match field requirements at the desired temperature. In addition, core flood tests were conducted in carbonate core plugs, Berea sandstone rock, and artificially fractured (metal tube) to investigate the performance of the chemical treatment. Flow tests clearly indicated that the water production significantly dropped in all tested types of rocks. The environmental scanning electron microscope (SEM) results showed the presence of SiO-rich compounds suggesting that the tested nanosilica product filled the porous media; therefore, it blocked the whole core plug. A novel cost-effective sealant that uses nanotechnology to block the near wellbore region has been developed. The performance and methods controlling its propagation rate into a porous medium will be presented. Based on the outcomes, it must be emphasized that these trivial particles have a promising application in the oil reservoir for water shutoff purposes.

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Scale discrepancy paradox between observation and modelling in fractured reservoir models in oil and gas industry.

10.5194/egusphere-egu2020-20161 ◽

2020 ◽

Author(s):

Pascal Richard ◽

Loïc Bazalgette

Keyword(s):

Oil And Gas ◽

Dynamic Models ◽

Fractured Reservoirs ◽

Research Work ◽

Oil And Gas Industry ◽

Naturally Fractured Reservoirs ◽

Natural Fracture ◽

Fractured Reservoir ◽

Dynamic Data ◽

Gas Industry

Naturally fractured reservoirs represent one of the most challenging resource in the oil and gas industry. The understanding based on centimeter scale observations is upscaled and modeled at 100-meter scale.In this paper, we will illustrate with case study examples of conceptual fracture model elaborated using static and dynamic data, the disconnect between the scale of observation and the scale of modelling. We will also discuss the potential disconnect between the detail of fundamental, but necessary, research work in universities against the coarse resolution of the models built in the oil industry, and how we can benefit of the differences in scales and approaches.&#160;The appraisal and development of fractured reservoirs offer challenges due to the variations in reservoir quality and natural fracture distribution. Typically, the presence of open, connected fractures is one of the key elements to achieve a successful development. Fracture modelling studies are carried out routinely to support both appraisal and development strategies of these fractured reservoirs.Overall fracture modelling workflow consists first of a fracture characterization phase concentrating on the understanding of the deformation history and the evaluation of the nature, type and distribution of the fractures; secondly of a fracture modelling part where fracture properties for the dynamic simulation are generated and calibrated against dynamic data. The pillar of the studies is the creation of 3D conceptual fracture diagrams/concepts which summarize both the understanding and the uncertainty of the fracture network of interest. These conceptual diagrams rely on detailed observations at the scale of the wellbore using core and borehole image data which are on contrasting scale compare to the 10&#8217;s of meters to 100&#8217;s of meter scale of the grid cells of the dynamic models used for the production history match and forecast. These contrasting scales will be the thread of the presentation.

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Applications of Graphene and Its Derivatives in the Upstream Oil and Gas Industry: A Systematic Review

Nanomaterials ◽

10.3390/nano10061013 ◽

2020 ◽

Vol 10 (6) ◽

pp. 1013 ◽

Cited By ~ 1

Author(s):

Lipei Fu ◽

Kaili Liao ◽

Bo Tang ◽

Lujun Jiang ◽

Weiqiu Huang

Keyword(s):

Oil Recovery ◽

Oil And Gas ◽

Mechanical Performance ◽

Chemical Properties ◽

Oil And Gas Industry ◽

Research Progress ◽

Future Research ◽

Gas Industry ◽

Oil And Gas Exploration ◽

Profile Control

Graphene and its derivatives, with their unique two-dimensional structures and excellent physical and chemical properties, have been an international research hotspot both in the research community and industry. However, in application-oriented research in the oil and gas industry they have only drawn attention in the past several years. Their excellent optical, electrical, thermal and mechanical performance make them great candidates for use in oil and gas exploration, drilling, production, and transportation. Combined with the actual requirements for well working fluids, chemical enhanced oil recovery, heavy oil recovery, profile control and water shutoff, tracers, oily wastewater treatment, pipeline corrosion prevention treatment, and tools and apparatus, etc., this paper introduces the behavior in water and toxicity to organisms of graphene and its derivatives in detail, and comprehensively reviews the research progress of graphene materials in the upstream oil and gas industry. Based on this, suggestions were put forward for the future research. This work is useful to the in-depth mechanism research and application scope broadening research in the upstream oil and gas industry.

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Scale discrepancy paradox between observation and modelling in fractured reservoir models in oil and gas industry.

10.5194/egusphere-egu21-14729 ◽

2021 ◽

Author(s):

Pascal Richard ◽

Loic Bazalgette

Keyword(s):

Oil And Gas ◽

Dynamic Models ◽

Fractured Reservoirs ◽

Research Work ◽

Oil And Gas Industry ◽

Naturally Fractured Reservoirs ◽

Natural Fracture ◽

Fractured Reservoir ◽

Dynamic Data ◽

Gas Industry

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Use of Smart Controls in Intelligent Well Completion to Optimize Oil & Gas Recovery

Journal of Engineering Research and Reports ◽

10.9734/jerr/2019/v5i416930 ◽

2019 ◽

pp. 1-14

Author(s):

Austin Afuekwe ◽

Kelani Bello

Keyword(s):

Crude Oil ◽

Oil Recovery ◽

Oil And Gas ◽

New Technology ◽

Oil And Gas Industry ◽

Water Production ◽

Monitoring And Control ◽

Reactive Control ◽

Well Completion ◽

Reservoir Simulator

For the past few years, the oil and gas industry has faced several economic, geographic and technical challenges largely due to decline in crude oil prices and market volatility. In the quest to address some of these challenges to accelerate production and subsequently maximize ultimate recovery, operators are limited to remote hydraulic and electro-hydraulic monitoring and control of safety valves providing the means of obtaining downhole production data which demands periodic well intervention-based techniques with risk of loss of associated tools. This has highlighted the need for companies to adopt new technology to take advantage of low crude oil price environment, optimizing recovery without interventions and with minimal production interruption. One of the recent improvements in production technologies which can remedy these problems having unique capabilities to do so is the Intelligent Well Completion (IWC) technology. In this paper the utilization of IWC to optimize oil recovery was evaluated. The use of a reservoir simulator, the Schlumberger ECLIPSE-100 simulator, was employed to model an intelligent well. Case study simulations were performed for an active bottom-water drive. Modeling of the Intelligent Well Inflow Control Devices (ICDs) and downhole sensors for the multilaterals was achieved using the Multi-Segment Well model. Optimal IWC technology combination for maximum hydrocarbon recovery and minimal water production was determined using the reactive control strategy (RCS) which indicated a drastic reduction of about 52.1% in water production with a slight drop of 1.5% in field oil efficiency (FOE). The simulation results obtained clearly showed that the utilization of intelligent well-ICDs in Production wells can significantly increase the cumulative oil production and reduce water production.

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