Process Design of Cyclic Water Flooding by Real-Time Monitoring

2018 ◽  
Vol 140 (11) ◽  
Author(s):  
Kobra Pourabdollah
Keyword(s):  
Real Time ◽  
Production Rate ◽  
Process Design ◽  
Water Injection ◽  
Oil Production ◽  
Oil Field ◽  
Water Flooding ◽  
Injection System ◽  
Real Time Monitoring ◽  
Naturally Fractured

The gradual decline in the oil production rate of water flooded reservoirs leads to decrease in the profit of water flooding system. Although cyclic water injection (CWI) was introduced to reduce the descending trend of oil production in water flooded reservoirs, it must be optimized based upon the process parameters. The objective of this study is to develop all process design criteria based upon the real-time monitoring of CWI process in a naturally fractured reservoir having five producing wells and five injector wells completed in an Arab carbonated formation containing light crude oil (API = 42 deg). For this aim, a small pilot oil field was selected with water injection facilities and naturally producing oil wells and all data were collected from the field tests. During a five years' field test, the primary observations at the onset of shutdown periods of the water injection system revealed a repeatable significant enhancement in oil production rate by a factor of plus 5% leading us to assess the application of CWI. This paper represents the significant parameters of pressure and productivity affected during CWI in naturally fractured carbonate reservoirs based upon a dual porosity generalized compositional model. The results hopefully introduce other oil producer companies to the potential of using CWI to increase oil production in conventional water injection systems. The results also outline situations where such applications would be desirable.

Nanotechnology Helps Decrease Pressure, Increase Injection in Offshore China Oil Field

2021 ◽  
Vol 73 (09) ◽  
pp. 58-59
Author(s):  
Chris Carpenter
Keyword(s):  
Water Injection ◽  
Injection Pressure ◽  
Gas Production ◽  
Oil Field ◽  
Water Flooding ◽  
Injection System ◽  
Bohai Bay ◽  
Reservoir Properties ◽  
Positive Effects ◽  
Offshore Technology

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper OTC 30407, “Case Study of Nanopolysilicon Materials’ Depressurization and Injection-Increasing Technology in Offshore Bohai Bay Oil Field KL21-1,” by Qing Feng, Nan Xiao Li, and Jun Zi Huang, China Oilfield Services, et al., prepared for the 2020 Offshore Technology Conference Asia, originally scheduled to be held in Kuala Lumpur, 2–6 November. The paper has not been peer reviewed. Copyright 2020 Offshore Technology Conference. Reproduced by permission. Nanotechnology offers creative approaches to solve problems of oil and gas production that also provide potential for pressure-decreasing application in oil fields. However, at the time of writing, successful pressure-decreasing nanotechnology has rarely been reported. The complete paper reports nanopolysilicon as a new depressurization and injection-increasing agent. The stability of nanopolysilicon was studied in the presence of various ions, including sodium (Na+), calcium (Ca2+), and magnesium (Mg2+). The study found that the addition of nanomaterials can improve porosity and permeability of porous media. Introduction More than 600 water-injection wells exist in Bohai Bay, China. Offshore Field KL21-1, developed by water-flooding, is confronted with the following challenges: - Rapid increase and reduction of water-injection pressure - Weak water-injection capacity of reservoir - Decline of oil production - Poor reservoir properties - Serious hydration and expansion effects of clay minerals To overcome injection difficulties in offshore fields, conventional acidizing measures usually are taken. But, after multiple cycles of acidification, the amount of soluble substances in the rock gradually decreases and injection performance is shortened. Through injection-performance experiments, it can be determined that the biological nanopolysilicon colloid has positive effects on pressure reduction and injection increase. Fluid-seepage-resistance decreases, the injection rate increases by 40%, and injection pressure decreases by 10%. Features of Biological Nanopolysilicon Systems The biological nanopolysilicon-injection system was composed of a bioemulsifier (CDL32), a biological dispersant (DS2), and a nanopolysilicon hydrophobic system (NP12). The bacterial strain of CDL32 was used to obtain the culture colloid of biological emulsifier at 37°C for 5 days. DS2 was made from biological emulsifier CDL32 and some industrial raw materials described in Table 1 of the complete paper. Nanopolysilicon hydrophobic system NP12 was composed of silicon dioxide particles. The hydrophobic nanopolysilicons selected in this project featured particle sizes of less than 100 nm. In the original samples, a floc of nanopolysilicon was fluffy and uniform. But, when wet, nanopolysilicon will self-aggregate and its particle size increases greatly. At the same time, nanopolysilicon features significant agglomeration in water. Because of its high interface energy, nanopolysilicon is easily agglomerated, as shown in Fig. 1.

Optimising Oil Field Net Present Value with Produced Water Salinities and Tracers

2021 ◽  
Author(s):  
Babalola Daramola
Keyword(s):  
Reservoir Simulation ◽  
Produced Water ◽  
Water Injection ◽  
Oil Production ◽  
Oil Field ◽  
Water Flooding ◽  
Water Salinity ◽  
History Match ◽  
Infill Drilling ◽  
Salinity Data

Abstract This paper presents case studies of how produced water salinity data was used to transform the performance of two oil producing fields in Nigeria. Produced water salinity data was used to improve Field B’s reservoir simulation history match, generate infill drilling targets, and reinstate Field C’s oil production. A reservoir simulation study was unable to history match the water cut in 3 production wells in Field B. Water salinity data enabled the asset team to estimate the arrival time of injected sea water at each production well in oil field B. This improved the reservoir simulation history match, increased model confidence, and validated the simulation model for the placement of infill drilling targets. The asset team also gained additional insight on the existing water flood performance, transformed the water flooding strategy, and added 9.6 MMSTB oil reserves. The asset team at Field C was unable to recover oil production from a well after it died suddenly. The team evaluated water salinity data, which suggested scale build up in the well, and completed a bottom-hole camera survey to prove the diagnosis. This justified a scale clean-out workover, and added 5000 barrels per day of oil production. A case study of how injection tracer data was used to characterise a water injection short circuit in Field D is also presented. Methods of using produced water salinity and injection tracer data to manage base production and add significant value to petroleum fields are presented. Produced water salinity and injection tracer data also simplify water injection connectivity evaluations, and can be used to justify test pipeline and test separator installation for data acquisition.

A Method to Determine the Optimal Water Injection Intensity Based on Oil Production Rate and Water Cut

2012 ◽  
Vol 594-597 ◽  
pp. 2442-2445 ◽  
Author(s):  
Ji Cheng Zhang ◽  
Ying Jia ◽  
Xiao Na Cui
Keyword(s):  
Production Rate ◽  
Water Injection ◽  
Oil Production ◽  
Water Flooding ◽  
Water Intensity ◽  
Water Cut ◽  
Relationship Of ◽  
The Relationship ◽  
Oilfield Development ◽  
Zone Water

Water injection is one of the important ways to maintain reservoir pressure and improving the oilfield development effect. And separate zone water injection is the main technology in water flooding oilfield. The optimal water intensity which has been allocated plays an important role in all kinds of reservoir. This paper proposed a method to optimize the water injection intensity based on oil production rate and water cut. Conceptual model was constructed on the basis of real reservoir. By numerical simulation, a chart board was derived which describes the relationship of water injection intensity versus oil production rate and water cut. Using this chart, we can determine the optimal water injection intensity on different oil production rate and water cut.

Study and Comparison of Vibration-Based Intrusive and Non-Intrusive Sand Monitoring System

2013 ◽  
Vol 701 ◽  
pp. 440-444
Author(s):  
Gang Liu ◽  
Peng Tao Liu ◽  
Bao Sheng He
Keyword(s):  
Real Time ◽  
Monitoring System ◽  
Oil Production ◽  
Oil Wells ◽  
Oil Field ◽  
Sand Production ◽  
The Status

Sand production is a serious problem during the exploitation of oil wells, and people put forward the concept of limited sand to alleviate this problem. Oil production with limited sanding is an efficient mod of production. In order to complete limited sand exploitation, improve the productivity of oil wells, a real-time sand monitoring system is needed to monitor the status of wells production. Besides acoustic sand monitoring and erosion-based sand monitoring, a vibration-based sand monitoring system with two installing styles is proposed recently. The paper points out the relationships between sand monitoring signals collected under intrusive and non-intrusive installing styles and sanding parameters, which lays a good foundation for further study and actual sand monitoring in oil field.

Real-Time Water Injection Monitoring with Distributed Fiber Optics Using Physics-Informed Machine Learning

2021 ◽  
Author(s):  
Teymur Sadigov ◽  
Cagri Cerrahoglu ◽  
James Ramsay ◽  
Laurence Burchell ◽  
Sean Cavalero ◽  
...  
Keyword(s):  
Machine Learning ◽  
High Resolution ◽  
Real Time ◽  
Fiber Optics ◽  
Water Injection ◽  
The Real ◽  
Start Up ◽  
Naturally Fractured ◽  
Monitoring Application ◽  
Time Injection

Abstract This paper introduces a novel technique that allows real-time injection monitoring with distributed fiber optics using physics-informed machine learning methods and presents results from Clair Ridge asset where a cloud-based, real-time application is deployed. Clair Ridge is a structural high comprising of naturally fractured Devonian to Carboniferous continental sandstones, with a significantly naturally fractured ridge area. The fractured nature of the reservoir lends itself to permanent deployment of Distributed Fiber Optic Sensing (DFOS) to enable real-time injection monitoring to maximise recovery from the field. In addition to their default limitations, such as providing a snapshot measurement and disturbing the natural well flow with up and down flowing passes, wireline-conveyed production logs (PL) are also unable to provide a high-resolution profile of the water injection along the reservoir due to the completion type. DFOS offers unique surveillance capability when permanently installed along the reservoir interface and continuously providing injection profiles with full visibility along the reservoir section without the need for an intervention. The real-time injection monitoring application uses both distributed acoustic and temperature sensing (DAS & DTS) and is based on physics-informed machine learning models. It is now running and available to all asset users on the cloud. So far, the application has generated high-resolution injection profiles over a dozen multi-rate injection periods automatically and the results are cross-checked against the profiles from the warmback analyses that were also generated automatically as part of the same application. The real-time monitoring insights have been effectively applied to provide significant business value using the capability for start-up optimization to manage and improve injection conformance, monitor fractured formations and caprock monitoring.

Smart Reservoir Management with Real-Time Monitoring in an Offshore Carbonate Digital Oil Field under Miscible Gas Injection

2020 ◽  
Author(s):  
Khalid Javid ◽  
Guido Bascialla ◽  
Alvaro Sainz ◽  
Mohamed Hossni Ali ◽  
Srinivas Ettireddi ◽  
...  
Keyword(s):  
Real Time ◽  
Gas Injection ◽  
Reservoir Management ◽  
Oil Field ◽  
Real Time Monitoring ◽  
Miscible Gas Injection

Use of Diverter Compositions for Enhancing the Effectiveness of Oil Recovery from Productive Deposits

2018 ◽  
Vol 785 ◽  
pp. 159-170
Author(s):  
Vadim Aleksandrov ◽  
Kirill Galinskij ◽  
Andrey Ponomarev ◽  
Vadim Golozubenko ◽  
Yuriy Sivkov
Keyword(s):  
Oil Recovery ◽  
Complex Structure ◽  
Water Injection ◽  
Geological Structure ◽  
Oil Field ◽  
Field Analysis ◽  
Water Flooding ◽  
Simple Method ◽  
Oil Companies ◽  
Porosity And Permeability

One of the most important aspects in the activities of oil companies in the Western Siberia is to improve the effectiveness of water-flooding as the main method of impact on the formation. This is due to the fact that at the present time reservoirs of a complex structure with difficult to recover reserves prevail among newly introduced development objects, the extraction of which is extremely difficult using a simple method of water injection volumes regulation. First of all, this refers to reservoirs of Jurassic deposits, which are characterized by the most complex geological structure and porosity and permeability properties. A promising direction in improving the water-flooding system at such objects is the use of physical and chemical technologies to enhance the oil recovery of formations, and primarily, referring to the diverter technology. The research objective is to evaluate the effectiveness of using “hard” type diverter compositions to enhance oil recovery of formations. With the help of detailed oil-field analysis and field-geophysical studies, the nature of the development of oil reserves for Jurassic development sites has been assessed.

scholarly journals Optimization of reinjection treatment technology for oilfield wastewater in Longdong area

2020 ◽  
Vol 194 ◽  
pp. 04046
Author(s):  
Xiulan Zhu ◽  
Yanlong Ran ◽  
Wenjie Guo ◽  
Ke Gai ◽  
Yanju Li ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Solid Phase ◽  
Sewage Treatment ◽  
Water Injection ◽  
Oil Production ◽  
High Water ◽  
Oil Field ◽  
Treatment Technology ◽  
Water Separation ◽  
High Water Cut

With the long-term water injection development of Longdong oilfields, most of the oilfield blocks have been fully in the mid-high water cut period, and the amount of oil production wastewater is increasing year by year. In order to prevent the waste of resources and energy of oil production sewage, the oil production sewage after reaching the standard is treated for reinjection, which will ensure the sustainable development of the oil field. Oil production wastewater contains crude oil, solid-phase suspended solids and other pollutants, with high salinity, and problems such as difficulty in oil-water separation, sludge, scaling and corrosion. The sewage treatment system uses a multifunctional water treatment device to effectively remove oil and filter through the “special microorganism + air flotation + filtration” process, and build a sludge sewage tank for sludge discharge and backwashing. The reformed oil recovery wastewater reinjection treatment technology turns “sewage” into “clear flow”, reduces operating costs, improves wastewater treatment efficiency, and meets the water quality requirements of oilfield reinjection water.

The Key Technology Research of the Water Injection System Energy Saving for Super Low Permeability Reservoir in Changqing Oil Field

2012 ◽  
Vol 524-527 ◽  
pp. 1217-1222 ◽  
Author(s):  
Zhi Qiang Huang ◽  
Zhen Chen ◽  
Gang Zheng ◽  
Jian Qiang Xue ◽  
Xue Yuan Li
Keyword(s):  
Energy Consumption ◽  
Energy Saving ◽  
Large Scale ◽  
Water Injection ◽  
High Energy ◽  
Economic Benefits ◽  
Oil Field ◽  
Injection System ◽  
Low Permeability ◽  
Load Rate

With the characteristics of low permeability, pressure and abundance, it's extremely hard to exploit the super low permeability reservoirs in ChangQing oil field. For this reason, the water injection recovery technique has been widely used. Analysis showed that a serious problem of high energy consumption exist in the water injection system, the power consumption of which accounts for about 44%. And the energy cost of pump units reach up to 43%, it's the highest energy consumption link in the system. In this paper the load rate classification method (LRCM) is firstly adopted to statistical analyze water injection stations, which are divided into the owing and over load rate stations. As a result, the owing load rate stations accounts for 83.8%, with a serious phenomenon of the Big Horse Pull A Small Carriage, causing the large-scale backflow in the station, and the efficiency is low, the energy consumption is on the high side. Aimed at water injection stations with different load rate, the methods of reasonable shutting down the pumps, pump replacement, optimizing the transmission ratio and piston size, as well as the speed control technology have been used to make the outlet flow and actual demand reasonable matching. The test result shows that the energy saving technology is well targeted, simple, practical and low cost. The pump units’ efficiency improves obviously, the consumption reduces by 10%, which greatly improve the oilfield economic benefits.

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