scholarly journals Representative Sector Modeling and Waterflooding Performance in Rumaila Oilfield

2021 ◽  
pp. 192-203
Author(s):  
Mustafa Kamil Shamkhi ◽  
Mohammed Salih Aljawad
Keyword(s):  
History Matching ◽  
Dynamic Models ◽  
Water Injection ◽  
High Water ◽  
Full Field ◽  
Field Development ◽  
The North ◽  
Pvt Data ◽  
High Water Cut ◽  
Water Cut

Rumaila supergiant oilfield, located in Southern Iraq has a huge footprint and is considered as the second largest oilfield in the world. It contains many productive reservoirs, some known but without produced zones, and significant exploration potential. A fault divides the field into two domes to the north and south. Mishrif reservoir is the main producing reservoir in the North Rumaila oilfield. It has been producing for more than 40 years and is under depletion. However, it was subjected to water injection processes in 2015, which assisted in recovery and pressure support. Thus, requirements of managing flooding strategies and water-cut limitations are necessary in the next stages of the field life.      In this paper, sector modeling was applied to a specific portion of the field, rather than full-field modeling, to accelerate history matching strategy and correlate static to dynamic models’ efficiently, with a minimum level of tolerance. The sector was modeled by surrounding with additional grid blocks and two pseudo wells to achieve a good matching with actual available data.      PVT data were used for fluid modeling of a well contained in the sector, and two rock functions were inserted to the model to achieve acceptable history matching. Twelve wells were considered in this research, two of them were injectors and the remaining are producers. For future performance, some of these wells were subjected to new completion and workover processes for field development and pressure maintenance. The importance of the development plan is to represent a way for field development without new wells to be drilled. This was conducted by adding perforations to some wells, plugging the high water-cut production zones, changing production and injection rates, and converting the producers to injectors.

scholarly journals Thief zone identification and classification in unconsolidated sandstone reservoirs: A field case study

2021 ◽  
Author(s):  
Anzhu Xu ◽  
Fachao Shan ◽  
Xiao Yang ◽  
Jiaqi Li ◽  
Chenggang Wang ◽  
...  
Keyword(s):  
Comprehensive Evaluation ◽  
Water Injection ◽  
Fuzzy Comprehensive Evaluation ◽  
High Water ◽  
Field Development ◽  
High Water Cut ◽  
Water Cut ◽  
Bypassed Oil

AbstractChanneling between injectors and producers leads to bypassed oil left in the reservoir, which is one of most common reasons that wells in mature oil fields experience high water cut after long-term waterflooding. Identification and evaluation of the higher permeable channels (thief zones) are the key to effectively plug these thief zones and improve the conformance of water flood. This study applies three different methods to identify and evaluate the thief zones of a water injection project in North Buzazi Oilfield, a thick-bedded unconsolidated sandstone heavy oil reservoir in Manghestau, Kazakhstan. The thief zones, which evolve as a result of formation erosion and sand production, are identified and classified with respect to four different levels of significance using fuzzy comprehensive evaluation, production/injection profile method and pressure index (PI) methods. Good consistency is observed among the identification results using these methods. Finally, we present two ways to quantitatively evaluate the characteristics of the thief zones using water–oil-ratio as the input, which can be readily applied for future field development design.

scholarly journals Optimizing Water Injection Performance by Using Sector Modeling of the Mishrif Formation in West Qurna-1 Oil Field, Southern Iraq

2021 ◽  
Vol 54 (2D) ◽  
pp. 59-74
Author(s):  
Sajjad Jameel Naser
Keyword(s):  
Development Strategy ◽  
History Matching ◽  
Water Movement ◽  
Fluid Model ◽  
Water Injection ◽  
High Water ◽  
Oil Field ◽  
Full Field ◽  
Water Cut ◽  
Injection Rates

The regular job of a reservoir engineer is to put a development plan to increase hydrocarbon production as possible and within economic and technical considerations. The development strategy for the giant reservoir is a complex and challenging task through the decision-making analysis process. Due to the limited surface water treatment facility, the reservoir management team focuses on minimizing water cut as low as possible by check the flow of formation and injected water movement through the Mishrif reservoir. In this research, a representative sector was used to make the review of water injection configuration, which is considered an efficient tool to make study in a particular area of the entire field when compared with the full-field model on the basis of time-consuming and computational analysis. The sector model was neighboring by extra grid blocks and three pseudo wells as injector wells to realize the pressure on the sector boundary, which attained an acceptable history matching. The fluid model and physics model were introduced by using Pressure Volume Temperature data of well involved in the study area and two relative permeability curves. Fourteen wells were utilized in this work, four wells are injectors, and the rest are producer. The development scenarios were implemented by setting various targets of oil production and different water injection rates required for pressure maintenance operations. Optimization of water cut has been applied by adjustment of production and injection rates and shut off the high water cut intervals. The results obtained from this study showed that the inverted 9-spot has a good recovery which is illustrated in the case_2C, the production rate was (49,000 STB/D) with minimum water cut (27.5%) as compared with a five-spot pattern.

scholarly journals New Waterflooding Characteristic Curves Based on Cumulative Water Injection

2020 ◽  
Vol 2020 ◽  
pp. 1-12
Author(s):  
Zhiwang Yuan ◽  
Zhiping Li ◽  
Li Yang ◽  
Yingchun Zhang
Keyword(s):  
Characteristic Curve ◽  
Water Injection ◽  
Material Balance ◽  
Oil Production ◽  
High Water ◽  
Difficult Problem ◽  
Prediction Errors ◽  
High Water Cut Stage ◽  
High Water Cut ◽  
Water Cut

When a conventional waterflooding characteristic curve (WFCC) is used to predict cumulative oil production at a certain stage, the curve depends on the predicted water cut at the predicted cutoff point, but forecasting the water cut is very difficult. For the reservoirs whose pressure is maintained by water injection, based on the water-oil phase seepage theory and the principle of material balance, the equations relating the cumulative oil production and cumulative water injection at the moderately high water cut stage and the ultrahigh water cut stage are derived and termed the Yuan-A and Yuan-B curves, respectively. And then, we theoretically analyze the causes of the prediction errors of cumulative oil production by the Yuan-A curve and give suggestions. In addition, at the ultrahigh water cut stage, the Yuan-B water cut prediction formula is established, which can predict the water cut according to the cumulative water injection and solve the difficult problem of water cut prediction. The application results show Yuan-A and Yuan-B curves are applied to forecast oil production based on cumulative water injection data obtained by the balance of injection and production, avoiding reliance on the water cut forecast and solving the problems of predicting the cumulative oil production of producers or reservoirs that have not yet shown the decline rule. Furthermore, the formulas are simple and convenient, providing certain guiding significance for the prediction of cumulative oil production and water cut for the same reservoir types.

A Novel Multi-Layer Intelligent Test and Adjustment Technology for Water Injection Well

2012 ◽  
Vol 424-425 ◽  
pp. 732-736 ◽  
Author(s):  
De Li Jia ◽  
Feng Shan Wang ◽  
Shu Jin Zhang
Keyword(s):  
Water Injection ◽  
Dynamic Test ◽  
High Water ◽  
Adjustment Process ◽  
Flow Adjustment ◽  
High Water Cut ◽  
Water Cut ◽  
Injection Effect ◽  
Injection Technology ◽  
Clock Calibration

The layered recovery technology has been applied to the heterogeneous multi-layer standstone oilfields for many years. However, as these standstone oilfields have been entering into the ultra-high water cut period, the conventional layered water injection technology has too long test and adjustment period and heavy workload and cannot determine the reservoir condition. To solve this problem, this paper proposes and develops an intelligent multi-layer water injection technology suitable for the ultra-high water cut period based on the synchronous dynamic test and adjustment idea. The whole flow adjustment process has no any intervention and the synchronous dynamic flow adjustment of each layer finishes by the digital clock calibration thereby avoiding interlayer interference. This technology also can obtain data by the redisplay of computer. The experimental results show that this technology not only improves water injection effect and reduces the field workload, but also provides the basis of data analysis for implementation and adjustment of meticulous oil development plan

scholarly journals Experimental study on waterflooding development of low-amplitude reservoir with big bottom water

2021 ◽  
Author(s):  
Yanlai Li ◽  
Jie Tan ◽  
Songru Mou ◽  
Chunyan Liu ◽  
Dongdong Yang
Keyword(s):  
Bottom Water ◽  
Water Injection ◽  
Water Reservoir ◽  
High Water ◽  
Recovery Factor ◽  
Low Viscosity ◽  
Well Spacing ◽  
High Water Cut Stage ◽  
High Water Cut ◽  
Water Cut

AbstractFor offshore reservoirs with a big bottom water range, the water cut rises quickly and soon enters the ultra-high water cut stage. After entering the ultra-high water cut stage, due to the influence of offshore production facilities, there are few potential tapping measures, so it is urgent to explore the feasibility study of artificial water injection development. The quasi-three-dimensional and two-dimensional displacement experiments are designed using the experimental similarity criteria according to the actual reservoir parameters. Several experimental schemes are designed, fluid physical properties, interlayer distribution, and development mode according to the actual reservoir physical properties. Through the visualization of experimental equipment, the bottom water reservoir is visually stimulated. The displacement and sweep law of natural water drive and artificial water injection in bottom water reservoir with or without an interlayer, different viscosity, and different well spacing is analyzed. The following conclusions are obtained: (1) For reservoirs with a viscosity of 150 cp. The recovery factor after water injection is slightly higher than before water injection. However, the recovery factor is lower than that without injection production. The reason is that the increment of injection conversion is limited to reduce one production well after injection conversion. (2) For reservoirs with a viscosity of 30 cp. The recovery factor after injection is 39.8%, which is slightly higher than 38.9% without injection. (3) For reservoirs with a viscosity of 150 cp. In the case of the interlayer. The recovery factor after injection is 30.7%, which is significantly higher than 24.8% without injection. (4) After the well spacing of the low-viscosity reservoir is reduced, the recovery factor reaches 46.1%, which is higher than 38.9% of the non-infill scheme. After the infill well in a low-viscosity reservoir is transferred to injection, the recovery factor is 45.6%, which has little change compared with non-injection, and most of the cumulative production fluid is water. The feasibility and effect of water flooding in a strong bottom water reservoir are demonstrated. This study provides the basis for the proposal of production well injection conversion and the adjustment of production parameters in the highest water cut stage of a big bottom water reservoir.

scholarly journals Techniques for improving the water-flooding of oil fields during the high water-cut stage

2019 ◽  
Vol 74 ◽  
pp. 69 ◽  
Author(s):  
Kuiqian Ma ◽  
Ao Li ◽  
Shuhao Guo ◽  
Jieqiong Pang ◽  
Yongchao Xue ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Water Injection ◽  
Reduction Rate ◽  
High Water ◽  
Water Flooding ◽  
Variable Intensity ◽  
Remaining Oil ◽  
High Water Cut Stage ◽  
High Water Cut ◽  
Water Cut

The multi-layer co-exploitation method is often used in offshore oilfields because of the large spacing between the injection and production wells. As oilfields gradually enter the high water-cut stage, the contradiction between the horizontal and vertical directions becomes more prominent, and the distribution of the remaining oil is more complex. Oilfields are facing unprecedented challenges in further enhancing oil recovery. Using oilfield A, which is in the high water-cut stage, as the research object, we compiled a detailed description of the remaining oil during the high water-cut stage using the information collected during the comprehensive adjustment and infilling of the oilfield. In addition various techniques for tapping the potential reservoir, stabilizing the oil, and controlling the water were investigated. A set of key techniques for the continuous improvement of the efficiency of water injection after comprehensive adjustment of high water-cut fields was generated. Based on the determined configuration of the offshore deltaic reservoir, a set of detailed descriptive methods and tapping technology for extracting the remaining oil in the offshore high water-cut oilfield after comprehensive adjustment was established. By considering the equilibrium displacement and using a new quantitative characterization method that includes displacement, a new technique for determining the quantity of water that needs to be injected into a stratified injection well during the high water-cut stage was established. Based on the principle of flow field intensity reconfiguration, a linear, variable-intensity, alternating injection and withdrawal technique was proposed. With the application of this series of techniques, the increase in the water content was controlled to within 1%, the natural reduction rate was controlled to within 9%, and the production increased by 1.060 × 107 m3.

On the Feasibility of Applying Electric Field to Increase Oil Recovery in Old Oil Field

2014 ◽  
Vol 900 ◽  
pp. 677-680
Author(s):  
Chun Hong Nie
Keyword(s):  
Electric Field ◽  
Oil Recovery ◽  
Water Injection ◽  
High Water ◽  
Oil Field ◽  
Thin Layers ◽  
Stable Yield ◽  
High Water Cut Stage ◽  
High Water Cut ◽  
Water Cut

This paper has discussed the characteristics, roles, feasibility and obvious effects of the technology by applying electric field to enhance oil recovery when the oil field is in high water cut stage and super high water cut stage. In view that most oil wells in old oil field have entered into the super high water cut production, the remaining oil in the main reservoir is in fragmented distribution with poor results of water injection and new reserves of oil mostly have a low penetration rate and are thin layers of poor physical properties, the use of the direct current field in period of high water cut is the best policy to achieve high and stable yield and is fairly promising.

scholarly journals A method for determining rational fluid production scale in conglomerate reservoir in the stage of high water cut

2021 ◽  
Vol 329 ◽  
pp. 01048
Author(s):  
Wentao Liu ◽  
Xiaodong Wang ◽  
Chaoliang Zhang ◽  
Rui Xue ◽  
Guifang Zhu ◽  
...  
Keyword(s):  
Formation Energy ◽  
Water Injection ◽  
Reference Value ◽  
High Water ◽  
Theoretical Research ◽  
Reservoir Water ◽  
Production Scale ◽  
Production Ratio ◽  
High Water Cut ◽  
Water Cut

In view of the problem that water cut rises quickly in conglomerate reservoirs with high water cut, based on the variation law of reservoir water injection and liquid production characteristics, a method for determining the maximum liquid production scale in conglomerate reservoirs with high water cut is established by using reservoir engineering and field statistics.Considering the maximum liquid production capacity at the well end, the maximum injection capacity at the well end and the injecting-production ratio limit to keep the formation energy, a method to determine the maximum liquid production scale in conglomerate reservoir is established to keep the formation energy sufficient.This method ensures that the injection and production ends of the reservoir are coordinated and matched, and the formation energy is sufficient, so that the reservoir development keeps a benign cycle.The research method and conclusion have important reference value and significance for theoretical research and practical application of ultra-high water cut oilfield development.

Research and Application of Synchronous Dynamic Test and Adjustment Technology for Novel Water Injection Well

2010 ◽  
Vol 44-47 ◽  
pp. 1476-1481 ◽  
Author(s):  
De Li Jia ◽  
Chang Jiang Zhao ◽  
Shu Jin Zhang ◽  
Ming Xin Zhao ◽  
De Kui Xu
Keyword(s):  
Water Injection ◽  
Electric Energy ◽  
Dynamic Test ◽  
High Water ◽  
High Water Cut Stage ◽  
High Water Cut ◽  
Water Cut ◽  
Injection Effect ◽  
Injection Technology ◽  
Information Test

To solve the problem that the conventional layered water injection technology has too long test and adjustment period and strong interference among layers at the ultra-high water cut stage, a novel digital synchronous dynamic test and adjustment technology is proposed and developed in this paper. Many advanced technologies, including digital multi-information test and adjustment, bidirectional transmission of remote wireless signals and non-contact electric energy transformation, are adopted to combine multi-information test and flow control to be a whole thrown into the well. This technology can automatically monitor each water injection layer and adjust water flow in user-defined period without any intervention; it can synchronously and dynamically adjust flow of each layer; and it also can monitor and adjust flow data by the redisplay of computer. The experimental results show that this technology not only reduces the field workload and improves water injection effect, but also provides the basis of data analysis for implementation and adjustment of meticulous oil development plan.

Sign in / Sign up

Export Citation Format

Share Document