scholarly journals Excess Water Production Diagnosis in Oil Fields Using Ensemble Classifiers

2009 ◽  
Author(s):  
Minou Rabiei ◽  
Ritu Gupta ◽  
Yaw Peng Cheong ◽  
Gerardo Alonso Sanchez Soto
Keyword(s):  
Oil Fields ◽  
Water Production ◽  
Ensemble Classifiers ◽  
Excess Water

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.

Elimination of Tight Emulsions

2021 ◽  
Author(s):  
Haakon Ellingsen ◽  
Hikmat Jaouhar ◽  
Andreas Hannisdal
Keyword(s):  
Crude Oil ◽  
Separation Efficiency ◽  
Operating Temperature ◽  
Oil Fields ◽  
Water Removal ◽  
Water Production ◽  
Test Results ◽  
Electrical Field ◽  
High Electrical Field ◽  
Performance Specifications

Abstract Maturing oil fields can pose a severe challenge for separation of oil and water. Increasing water production and tie in of new fields into existing infrastructure may result in separators struggling to meet performance specifications. Operational challenges are particularly experienced when the facilities are processing cold feedstock and tight emulsions. Typical solutions for overcoming separation challenges would be increasing operating temperature, injecting an increased quantity of demulsifier chemicals, or installing new larger separators. These alternatives may not be economically attractive or feasible for other reasons. The ability to successfully operate existing plants with tight and water-rich emulsions without incurring significant added operating expenditure is perceived as a major advantage. This paper will share the results from testing on a separator operating with Flotta Gold crude oil. The oil is known to produce particularly tight emulsions at low temperatures. The ePack technology has been tested to study its capability of separating water and crude oil from tight emulsions by means of electrical forces. The force generated by the high electrical field can break even tight emulsions, and the test results shown have proven the ability to go from very low separation efficiency without the ePack, to more than 90% water removal with the ePack turned on. Testing with residence times of up to 19 minutes without the ePack was not able to surpass the performance of a three minutes residence time with the ePack energized.

scholarly journals MONITORING AND CONTROL OF NEW TECHNOLOGIES FOR ENHANCED OIL RECOVERY AT THE PRODUCTION FIELDS IN WESTERN KAZAKHSTAN

2021 ◽  
pp. 1-9
Author(s):  
Gulnaz Zh. Moldabayeva ◽  
Raikhan T. Suleimenova ◽  
Sairanbek M. Akhmetov ◽  
Zhanar B. Shayakhmetova ◽  
Gabit E. Suyungariyev
Keyword(s):  
Factor Analysis ◽  
Oil Recovery ◽  
Statistical Models ◽  
New Technologies ◽  
Oil Field ◽  
Oil Fields ◽  
Water Production ◽  
Western Kazakhstan ◽  
Wide Range ◽  
Technical Measures

This paper discusses topical problems of further effective development of depleted oil fields (DOF) to increase their final oil recovery on the example of the oil field in Western Kazakhstan. Further exploitation of fields using waterflooding becomes unprofitable. At the same time, on average at these facilities, at least 50% of the reserves will remain unrecovered. Most of the oil fields in the Republic of Kazakhstan are at the late and final stages of development, which is characterised by an increase in the share of hard-to-recover oil reserves, a decrease in annual oil withdrawals, and a high water cut of the produced oil. Therefore, the problems of improving the technology aimed at reducing the volume of associated water production and increasing oil recovery from partially flooded deposits is very urgent. With an increase in the well density, the degree of field drilling and aging of the well stock, the work with the current declining well stock remains a very topical issue. Improving the efficiency of diagnostics and the systematic selection of wells for repair and isolation works is an important element for rationalising field development in the current conditions of profit variance in the oil and gas industry. The methods of bottomhole zone treatment also implement a deflecting effect on filtration flows. Therefore, this method includes a wide range of geological and technical measures: down-spacing; water production restraining; conformance control of injectivity profiles; forced production; all types of mechanical, thermochemical and thermal technologies. Consider a number of geological and technical measures that perform the tasks of occupational safety rules. Geological and statistical models are proposed for diagnosing wells for a premature increase of water production using factor analysis calculations for base production and Hall plots. Results. The degree of temperature influence of the primary components of the compounds on the rheology, filtration characteristics, and stability of inverted emulsions was determined. The classification of oil loss factors was carried out based on the results of downhole analysis and oil production losses were determined. Geological and statistical models for well diagnostics for premature increase in water production were built using factor analysis calculations for base production and Hall plots.

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.

Field Performances, Effective Times, and Economic Assessments of Polymer Gel Treatments in Controlling Excessive Water Production From Mature Oil Fields

2020 ◽  
Vol 143 (8) ◽  
Author(s):  
Munqith Aldhaheri ◽  
Mingzhen Wei ◽  
Ali Alhuraishawy ◽  
Baojun Bai
Keyword(s):  
Fractured Reservoirs ◽  
Descriptive Analysis ◽  
Naturally Fractured Reservoirs ◽  
Oil Fields ◽  
Water Production ◽  
Polymer Gel ◽  
Rock Formations ◽  
Water Cut ◽  
Matrix Rock ◽  
Excessive Water

Abstract Polymer bulk gels have been widely applied to mitigate excessive water production from mature oil fields by correcting the reservoir permeability heterogeneity. This paper reviews water responses, effective times, and economic assessments of injection-well gel treatments based on 61 field projects. Eight parameters were evaluated per the reservoir type using the descriptive analysis, stacked histograms, and scatterplots. Results show that water production generally continues to increase after the treatment for undeveloped conformance problems. Contrarily, it typically decreases after the reactive gel treatments target developed conformance issues. For the developed problems, gel treatments do not always mitigate the water production where the water cut may stabilize or increase by 17% in 22% of instances. In addition, they often do reduce water production but not dramatically to really low levels where the water cut stays above 70% and reduces by only 10% in most cases. Gel treatments are economically appraised based only on the oil production response, and both water responses (injection and production) are not considered in the evaluation. They have a typical payout time of 9.2 months, cost of incremental oil barrel of 2 $/barrel, and effective time of 1.9 years. In addition, they have better water responses and economics in carbonates than in sandstones and in unconsolidated and naturally fractured reservoirs than in matrix-rock formations. The current review strongly warns reservoir engineers that gel treatments are not superior in alleviating the water production and candidates should be nominated based on this fact to achieve favorable economics and avoid treatment failures.

scholarly journals STUDY OF GRANULAR GELS PROPERTIES TO CONTROLTHE DEVELOPMENT OF OIL FIELDS

2016 ◽  
pp. 98-101
Author(s):  
S. V. Ovchinnikova ◽  
G. H. Ali
Keyword(s):  
Particle Size ◽  
Experimental Studies ◽  
Oil Fields ◽  
Water Production ◽  
Rock Samples ◽  
Permeable Rock ◽  
Different Types ◽  
Before And After ◽  
Brine Concentration

Study of granular gels properties to control the development of oil fields. Ovchinnikova S. V., Ali G. H. The ultimate goal of this work was to develop a method to be used in mature oil fields aimed at plugging the highpermeability water flooded layers with further displacement of oil from the low-permeable interlayers and decreasing the water production. The experimental studies were carried out to assess the influence of different types of PPG gels (30 mesh and 40 mesh) on the injectivity of low permeable rock samples. In this study the permeability of the rock samples was measured before and after the gels injection. The injection of gels was run at different pressures and various concentrations of the brine. Additionally, the influence of the brine concentration on the gels swelling and strength was studied. The gel particle size is in the ranged from 30 to 80 mesh.

scholarly journals Prototype System Water Level Reservoir untuk Pengendalian Kelebihan Air dengan Mikrokontroller Arduino Uno R3

2021 ◽  
Vol 5 (2) ◽  
pp. 352-361
Author(s):  
Budi Yannur ◽  
◽  
Didit Suprihanto ◽  
Happy Nugroho ◽  
Aji Ery Burhandenny ◽  
...  
Keyword(s):  
Water Level ◽  
Solenoid Valve ◽  
Prototype System ◽  
Clean Water ◽  
Water Production ◽  
Average Output ◽  
Excess Water ◽  
Measurement Results ◽  
Arduino Uno ◽  
System Water

PDAM Loa Kulu Branch still uses sticks or poles as an indicator of the water level in the reservoir. Reservoir is a place to store clean water production from PDAM, the weakness of using sticks or poles is when the operator does not monitor continuously causing air loss when production becomes large. The goal of the study was to design a water-level prototype to control excess water in the reservoir. The method used is a prototype with the stage of gathering information through interviewing PDAM staff, creating and repairing prototypes and testing prototypes. The test used hardware consisting of Arduino uno r3, ultrasonic sensor hc-sr04, flowmeter sensor yf-s201, 16 x 2 lcd, relay module, buzzer, solenoid valve 12 V_dc, pump 12 V_dc and display measurement results in the visual studio application 2019. Our findings are that the length of reservoir charging with an average input discharge of 3.6 liters / minute is 2.93 minutes. As for the length of emptying the reservoir with an average output discharge of 1.06 liters / minute is 12.10 minutes. The conclusion of this study is that the system can monitor the water level inside the reservoir automatically and know the time needed for the feeling and emptying process of the reservoir.

Sign in / Sign up

Export Citation Format

Share Document