scholarly journals Investigation of Different Scenarios in Simulation of Controlling Water Production in Oil Wells Using Silica Gel Treatments

2021 ◽  
Vol 5 (1) ◽  
pp. 1-12
Author(s):  
Shabibi M
Keyword(s):  
Production Efficiency ◽  
Treatment Method ◽  
Limiting Factors ◽  
Water Production ◽  
High Concentration ◽  
Water Control ◽  
Injection Wells ◽  
Excess Water ◽  
Real Model ◽  
Gel Treatment

Excess water production is one of the limiting factors in oil recycling, which reduces production efficiency and leaves a lot of costs. In this paper, water control methods were investigated in order to find the best way to control excess water production. For this propos first, a real model was made using the history match of one of Iran's oil fields that produced excess water because of canalization and different simulation scenarios for gel treatment have been investigated. In the study of more scenarios, comparing the water production in the early times and later injecting the gel, the percentage of water production for injection in the early times has been further reduced. When the gel is injected for a fixed period of 6 months in the production and injection wells The best results for lowering the rate of production water are obtained when the gel is injected simultaneously into the injection and production well, which reduces the water production rate by 12,000 barrels, and the best oil production efficiency for when simultaneous injection is performed in the production and injection well. The best treatment method is injection of high concentration gel in the early stages of water production and it's better to inject gel in deeper wells.

scholarly journals Water shutoff and conformance improvement: an introduction

2021 ◽  
Vol 18 (2) ◽  
pp. 450-478 ◽  
Author(s):  
Randy Seright ◽  
Bergit Brattekas
Keyword(s):  
Permeability Reduction ◽  
Problem Type ◽  
Water Production ◽  
Problem Types ◽  
Water Shutoff ◽  
Excess Water ◽  
Gel Treatment ◽  
Oilfield Operations ◽  
The Impact ◽  
Production Problems

AbstractThis paper provides an introduction to the topic of water shutoff and conformance improvement. After indicating the volumes of water produced during oilfield operations, a strategy is provided for attacking excess water production problems. Problem types are categorized, typical methods of problem diagnosis are mentioned, and the range of solutions is introduced for each problem type. In the third section of the paper, the concept of disproportionate permeability reduction is introduced—where polymers and gels may reduce permeability to water more than to oil or gas. When and where this property is of value is discussed. The fourth section describes the properties of formed gels as they extrude through fractures and how those properties can be of value when treating conformance problems caused by fractures. Section 5 covers the efficiency with which gels block fractures after gel placement—especially, the impact of fluids injected subsequent to the gel treatment.

scholarly journals A novel approach in extracting predictive information from water-oil ratio for enhanced water production mechanism diagnosis

2010 ◽  
Vol 50 (1) ◽  
pp. 567 ◽  
Author(s):  
Minou Rabiei ◽  
Ritu Gupta ◽  
Yaw Peng Cheong ◽  
Gerardo A. Sanchez Soto
Keyword(s):  
Oil Recovery ◽  
Water Production ◽  
Ensemble Classifiers ◽  
Production Mechanism ◽  
Water Control ◽  
Predictive Information ◽  
Oil Companies ◽  
Excess Water ◽  
Wide Range ◽  
Production Mechanisms

Despite the advances in water shutoff technologies, the lack of an efficient diagnostic technique to identify excess water production mechanisms in oil wells is preventing these technologies being applied to deliver the desired results, which costs oil companies a lot of time and money. This paper presents a novel integrated approach for diagnosing water production mechanisms by extracting hidden predictive information from water-oil ratio (WOR) graphs and integrating it with static reservoir parameters. Two common types of excess water production mechanism (coning and channelling) were simulated where a wide range of cases were generated by varying a number of reservoir parameters. Plots of WOR against oil recovery factor were used to extract the key features of the WOR data. Tree-based ensemble classifiers were then applied to integrate these features with the reservoir parameters and build classification models for predicting the water production mechanism. Our results show high rates of prediction accuracy for the range of WOR variables and reservoir parameters explored, which demonstrate the efficiency of the proposed ensemble classifiers. Proactive water control procedures based on proper diagnosis obtained by the proposed technique would greatly optimise oil productivity and reduce the environmental impacts of the unwanted water.

scholarly journals Geothermal Boreholes in Poland—Overview of the Current State of Knowledge

Energies ◽  
2021 ◽  
Vol 14 (11) ◽  
pp. 3251
Author(s):  
Tomasz Sliwa ◽  
Aneta Sapińska-Śliwa ◽  
Andrzej Gonet ◽  
Tomasz Kowalski ◽  
Anna Sojczyńska
Keyword(s):  
Heat Exchangers ◽  
Oil And Gas ◽  
Produced Water ◽  
Geothermal Water ◽  
Laboratory System ◽  
Water Production ◽  
Injection Wells ◽  
Geological Conditions ◽  
Geothermal Wells ◽  
Borehole Heat Exchangers

Geothermal energy can be useful after extraction from geothermal wells, borehole heat exchangers and/or natural sources. Types of geothermal boreholes are geothermal wells (for geothermal water production and injection) and borehole heat exchangers (for heat exchange with the ground without mass transfer). The purpose of geothermal production wells is to harvest the geothermal water present in the aquifer. They often involve a pumping chamber. Geothermal injection wells are used for injecting back the produced geothermal water into the aquifer, having harvested the energy contained within. The paper presents the parameters of geothermal boreholes in Poland (geothermal wells and borehole heat exchangers). The definitions of geothermal boreholes, geothermal wells and borehole heat exchangers were ordered. The dates of construction, depth, purposes, spatial orientation, materials used in the construction of geothermal boreholes for casing pipes, method of water production and type of closure for the boreholes are presented. Additionally, production boreholes are presented along with their efficiency and the temperature of produced water measured at the head. Borehole heat exchangers of different designs are presented in the paper. Only 19 boreholes were created at the Laboratory of Geoenergetics at the Faculty of Drilling, Oil and Gas, AGH University of Science and Technology in Krakow; however, it is a globally unique collection of borehole heat exchangers, each of which has a different design for identical geological conditions: heat exchanger pipe configuration, seal/filling and shank spacing are variable. Using these boreholes, the operating parameters for different designs are tested. The laboratory system is also used to provide heat and cold for two university buildings. Two coefficients, which separately characterize geothermal boreholes (wells and borehole heat exchangers) are described in the paper.

Drip Irrigation Schedule of Greenhouse Green Pepper Based on Genetic Algorithm

2014 ◽  
Vol 1010-1012 ◽  
pp. 670-680
Author(s):  
Jian Sun ◽  
Tie Liang Wang ◽  
Bo Li ◽  
Xiao Ting Song
Keyword(s):  
Genetic Algorithm ◽  
Drip Irrigation ◽  
Production Efficiency ◽  
Irrigation Schedule ◽  
Sensitivity Index ◽  
Linear Regression Method ◽  
Water Production ◽  
Green Pepper ◽  
Water Sensitivity ◽  
Autumn And Winter

By drip irrigation experiment of Barrel-planted peppers in a greenhouse during autumn and winter adopting Jensen Model, the water sensitivity index and water production function of green pepper at different stages is obtained through multiple linear regression method based on test datum, and the obtained model is verified by using the measured data. Further, compiling optimization program by C#.net language, drip irrigation schedule of green pepper is optimized by the genetic algorithm with the goal of maximizing the relative production. Results show that drip irrigation water of green pepper dring its whole growth period in a greenhouse in both autumn and winter is 285 mm with the highest water production efficiency. The accuracy of the results was verified by experimental data, too.

Study on the Concentration Process of Glutamic Supernatant Fluid by Vacuum Membrane Distillation and the Reuse of Product Water

2012 ◽  
Vol 217-219 ◽  
pp. 907-913
Author(s):  
Shi Chun Yang ◽  
Xiao Long Lv
Keyword(s):  
Glutamic Acid ◽  
Acid Concentration ◽  
Production Efficiency ◽  
Orthogonal Experiment ◽  
Membrane Distillation ◽  
Peak Time ◽  
Water Production ◽  
Supernatant Fluid ◽  
Product Water ◽  
The Difference

The optimal decoloring conditions for glutamate supernatant in orthogonal experiment are: 15g/l bentonite concentration, 2h decoloring time, and 40°C decoloring temperature. VMD technology can concentrate glutamate supernatant filtrate from 2.01% to 5.35%, and bring down flux from 6.71 L/m2h to 1.94L/m2h, at a concentration rate of 1.72 times. The glutamic acid concentration in supernatant fluid is enriched from 2.03% to 5.16%, and flux attenuated from 5.47 L/m2h to 1.91 L/m2h. As glutamic acid concentration in supernatant increases, membrane flux gradually decreases. Analysis of water production in glutamate supernatant membrane distillation and the meteorological chromatograms of glutamic acid filtrate prove that the difference between water-yielding peak time of supernatant fluid and that of the filtrate is less than 0.1 min. The volatile substances during water production are from glutamic acid filtrate and are of the same matter. Therefore, the product water in supernatant fluid membrane distillation can be reused to improve water production efficiency.

Field Implementation of In-Depth Conformance Gel Treatment Prior to Starting an ASP Flooding Pilot

2021 ◽  
Author(s):  
Mohammed T. Al-Murayri ◽  
Abrahim Hassan ◽  
Naser Alajmi ◽  
Jimmy Nesbit ◽  
Bastien Thery ◽  
...  
Keyword(s):  
Polymer Solution ◽  
Injection Pressure ◽  
High Viscosity ◽  
Production Well ◽  
Sweep Efficiency ◽  
Injection Wells ◽  
Appreciable Change ◽  
Well Pattern ◽  
Gel Treatment ◽  
Viscosity Polymer

Abstract Mature carbonate reservoirs under waterflood in Kuwait suffer from relatively low oil recovery due to poor volumetric sweep efficiency, both areal, vertically, and microscopically. An Alkaline-Surfactant-Polymer (ASP) pilot using a regular five-spot well pattern is in progress targeting the Sabriyah Mauddud (SAMA) reservoir in pursuit of reserves growth and production sustainability. SAMA suffers from reservoir heterogeneities mainly associated with permeability contrast which may be improved with a conformance treatment to de-risk pre-mature breakthrough of water and chemical EOR agents in preparation for subsequent ASP injection and to improve reservoir contact by the injected fluids. Each of the four injection wells in the SAMA ASP pilot was treated with a chemical conformance improvement formulation. A high viscosity polymer solution (HVPS) of 200 cP was injected prior to a gelant formulation consisting of P300 polymer and X1050 crosslinker. After a shut-in period, wells were then returned to water injection. Injection of high viscosity polymer solution (HVPS) at the four injection wells showed no increase in injection pressure and occurred higher than expected injection rates. Early breakthrough of polymer was observed at SA-0561 production well from three of the four injection wells. No appreciable change in oil cut was observed. HVPS did not improve volumetric sweep efficiency based on the injection and production data. Gel treatment to improve the volumetric conformance of the four injection wells resulted in all the injection wells showing increased of injection pressure from approximately 3000 psi to 3600 psi while injecting at a constant rate of approximately 2,000 bb/day/well. Injection profiles from each of the injection well ILTs showed increased injection into lower-capacity zones and decreased injection into high-capacity zones. Inter-well tracer testing showed delayed tracer breakthrough at the center SA-0561 production well from each of the four injection wells after gel placement. SA-0561 produced average daily produced temperature increased from approximately 40°C to over 50°C. SA-0561 oil cuts increased up to almost 12% from negligible oil sheen prior to gel treatments. Gel treatment improved volumetric sweep efficiency in the SAMA SAP pilot area.

A Novel Double-Group Crosslinked Hydrogel with High Thixotropy for Water Control in Horizontal Wells

SPE Journal ◽  
2020 ◽  
pp. 1-15
Author(s):  
Gang Li ◽  
Lifeng Chen ◽  
Meilong Fu ◽  
Lei Wang ◽  
Yadong Chen ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Gelation Time ◽  
Horizontal Wells ◽  
Uniform Grid ◽  
Drilling Fluids ◽  
Water Production ◽  
Water Control ◽  
Recovery Coefficient ◽  
Metastable Structure ◽  
Control Water

Summary Horizontal wells that are completed with slotted liners often suffer from a severe water-production problem, which is detrimental to oil recovery. It is because the annulus between the slotted liners and wellbore cannot be fully filled with common hydrogels with poor thixotropy, which determines the ultimate hydrogel filling shape in the annulus. This paper presents a novel hydrogel with high thixotropy to effectively control water production in horizontal wells. This study is aimed at evaluating the thixotropic performance, gelation time, plugging performance, and degradation performance. The thixotropic performance of the new hydrogel was also investigated by measuring its rheological properties and examining its microstructures. It was found that the new hydrogel thickened rapidly after shearing. Its thixotropic recovery coefficient was 1.747, which was much higher than those of traditional hydrogels. The gelation time can be controlled in the range of 2 to 8 hours by properly adjusting the concentrations of the framework material, crosslinker, and initiator. The hydrogel could be customized for mature oil reservoirs, at which it was stable for more than 90 days. A series of laboratory physical modeling tests showed that the breakthrough pressure gradient and the plugging ratio of the hydrogel in sandpacks were higher than 9.5 MPa/m and 99%, respectively. At the same time, it was found that the hydrogel has good degradation properties; the viscosity of the hydrogel breaking solution was 4.22 mPa·s. Freeze-etching scanning-electron-microscopy examinations indicated that the hydrogel had a uniform grid structure, which can be broken easily by shear and restored quickly. This led to the remarkable thixotropic performance. The formation of a metastable structure caused by the electrostatic interaction and coordination effect was considered to be the primary reason for the high thixotropy. The successful development of the new thixotropic hydrogel not only helps to control water production from the horizontal wells, but also furthers the thixotropic theory of hydrogel. This study also provides technical guidelines for further increasing the thixotropies of drilling fluids, fracturing fluids, and other enhanced-oil-recovery polymers that are commonly used in the petroleum industry.

Water Production Performance and its Control of the Ya-Da Condensate Gas Reservoir

2012 ◽  
Vol 616-618 ◽  
pp. 870-876
Author(s):  
Zong Yu Li ◽  
Ai Zhang ◽  
Shi Sheng Xu ◽  
Yun Feng He
Keyword(s):  
Gas Condensate ◽  
Control Measures ◽  
Production Performance ◽  
Water Production ◽  
Water Control ◽  
Control Effect ◽  
Gas Reservoir ◽  
Production Type ◽  
Water Breakthrough ◽  
Set Up

This paper takes Yakela-dalaoba edge water and the Luntai basal water condensate gas reservoir for example, analyzes the condensate gas reservoir of edge-water or basal-water production characteristics, water production law in development process, and summarizes the three kinds of type water production of condensate gas reservoir, and put forward water control countermeasures specific to different water production type. Set up four edge-water or basal-water breakthrough models of gas condensate wells and the corresponding control measures, and being applied to the water control of Ya-Da gas condensate wells water gradually and the control effect is remarkable. Through the research of water production law and control countermeasures in Ya-Da condensate gas reservoir, provide significant development guidance for the other condensate gas reservoir which contains water.

On Analog Simulation of Liquid-Metal Flows in Space Rankine-Cycle Power-Systems

2005 ◽  
Author(s):  
Nengli Zhang ◽  
David F. Chao ◽  
John M. Sankovic ◽  
John B. McQuillen ◽  
John F. Lekan
Keyword(s):  
Liquid Metal ◽  
Production Efficiency ◽  
Liquid Metals ◽  
Metal Flow ◽  
Rankine Cycle ◽  
High Concentration ◽  
Two Phase ◽  
Analog Simulation ◽  
Cycle System ◽  
Phase Liquid

In the development of liquid metal Rankine cycle system, experiments using liquid metals generally cannot be conducted on the International Space Station (ISS) or the space shuttles due to a number of issues including safety. Some other fluids must be used to simulate potassium flows in a Rankine cycle. In this paper an analysis for the simulation using surrogate fluids is made. The results of the analysis indicate that single-phase liquid metal flows, either liquid or vapor, can be simulated using surrogate fluids both in ground and space experiments. For two-phase liquid-metal flow, a credible simulation with a surrogate fluid is currently not possible. For the problem of vapor-production efficiency in a boiler, a simulation using a surrogate fluid whose properties are similar to potassium is workable. A high concentration of copper nanoparticles in water (Cu-water nanofluid) is considered a potential possibility for a fluid to simulate liquid-metal turbulent flow and the boiling process. In the final stage of developing the liquid-metal Rankine-cycle system, experimental tests in a subscale liquid-metal system are still indispensable.

scholarly journals Interpretation of geochemical researches of oil and formation water of one particular oil field (Republic of Kazakhstan)

2020 ◽  
Vol 15 (3) ◽  
Author(s):  
E.Sh. Seytkhaziev ◽  
◽  
N.D. Sarsenbekov ◽  
Keyword(s):  
Ionic Composition ◽  
Oil Field ◽  
Formation Water ◽  
High Concentration ◽  
Injection Wells ◽  
The North ◽  
North Eastern ◽  
Water Cut ◽  
Eastern Edge ◽  
North Eastern Part

46 oil samples were collected at the wellheads of different wells of a particular oil field and “oil fingerprinting” was performed by gas chromatographic analysis on LTM-MD-GC in order to understand the fluid connectivity of the reservoir within the field. This field located in the eastern edge of the Caspian Basin. According to the results of cluster analyzes, it was found that the studied samples of the north-eastern part of the oil field differ from those of the south-western part. Since the oil field has a massive reservoir height, all wells operate with minimum water-cut values, except for the production well. In this regard, the ionic composition of the water and the titration method were used to analyze the ionic composition of water, separated from the oil of producing well, two neighboring injection wells and block cluster pumping station of this field, to determine the ionic composition and identify differences and similarities of waters at the molecular level. According to the results of the analyzes, we came to the conclusion that all the studied formation water samples have common origin. The relatively high NaCl value in producing well water may be due to the high concentration of chloride in the oil.

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