Characterization and Prediction of Gas Breakthrough With Cyclic Steam and Gas Stimulation Technique in an Offshore Heavy Oil Reservoir

2016 ◽  
Vol 139 (3) ◽  
Author(s):  
Haijun Wu ◽  
Qingjun Du ◽  
Jian Hou ◽  
Jingsong Li ◽  
Ruxiang Gong ◽  
...  
Keyword(s):  
Regression Model ◽  
Simulation Study ◽  
Reservoir Simulation ◽  
Heavy Oil ◽  
Horizontal Well ◽  
Oil Reservoir ◽  
Calibration Curves ◽  
Heavy Oil Reservoir ◽  
Stimulation Technique

In this paper, a reservoir simulation study was conducted for the characterization and prediction of gas breakthrough during the development of cyclic steam and gas stimulation (CSGS) for a horizontal well. A new concept named the gas breakthrough coefficient (GBC) was proposed to characterize the gas breakthrough degree quantitatively, and a regression model and two calibration curves were established to predict the gas breakthrough degree. The method of foam plugging to inhibit gas breakthrough was also discussed. It was found that the gas breakthrough degree could be well characterized by the GBC and distinguished as four types: weak, moderate, strong, and severe. The regression model and calibration curves could also be used to predict the gas breakthrough degree under different reservoir and development conditions. Foam plugging was found to be effective to inhibit gas breakthrough when the gas breakthrough degree was moderate or strong.

Impact of Rheology Models on Horizontal Well Polymer Flooding in a Heavy Oil Reservoir on Alaska North Slope: A Simulation Study

2021 ◽  
Author(s):  
Jianqiao Leng ◽  
Mingzhen Wei ◽  
Baojun Bai ◽  
Randall S. Seright ◽  
Yin Zhang ◽  
...  
Keyword(s):  
Bulk Viscosity ◽  
Simulation Study ◽  
Heavy Oil ◽  
Horizontal Well ◽  
Horizontal Wells ◽  
Polymer Flooding ◽  
North Slope ◽  
Oil Reservoir ◽  
Polymer Rheology ◽  
Heavy Oil Reservoir

Abstract Polymer rheology can have either a positive or a negative effect on polymer flooding performance under varied circumstances. Many researchers have studied the effect of polymer rheology in a vertical well, but no field scale studies have been conducted to investigate whether polymer rheology is beneficial to polymer flooding in heavy oil reservoirs developed by horizontal wells. In this paper, we conducted a numerical simulation study to examine the effect of HPAM polymer rheology on a polymer flooding pilot, which is the first-ever project conducted on a heavy oil reservoir from Alaska North Slope (ANS) developed by horizontal wells. Three rheology types were considered in the study including the apparent viscosity measured during coreflooding of using a HPAM polymer, the bulk viscosity measured with a viscometer, and a Newtonian flow model. The results suggest that using the bulk viscosity in simulation underestimates the conformance control and the water-oil-ratio reduction capability of the HPAM polymer solution. When the apparent viscosity is used, the incremental oil and sweep were largely increased, and the optimal recovery period of polymer flooding was extended greatly, especially for the heterogeneous formations. Therefore, the rheology type of polymer plays a significant role in the incremental oil recovery and injection profile of the horizontal well system given the pilot testconditions. This study has provided practical guidance to field operators for the ongoing polymer flooding pilot on ANS and will also provide valuable information for other polymer projects conducted in similar conditions.

Study on Heating Zone and Producing Zone of Cyclic Steam Stimulation with Horizontal Well in Heavy Oil Reservoir

2012 ◽  
Vol 594-597 ◽  
pp. 2438-2441 ◽  
Author(s):  
Shi Jun Huang ◽  
Ping Hu ◽  
Qiu Li
Keyword(s):  
Heavy Oil ◽  
Horizontal Well ◽  
Thermal Recovery ◽  
Oil Reservoir ◽  
Heating Zone ◽  
Oil Viscosity ◽  
Cyclic Steam Stimulation ◽  
Heavy Oil Reservoir ◽  
Critical Viscosity ◽  
Steam Stimulation

In this paper, employing reservoir simulation and mathematical analysis methods, considering typical heavy oil reservoir and fluid thermal properties, the heating and producing shape of thermal recovery with horizontal well for different heavy oil reservoirs including ordinary, extra and super heavy oil are investigated based on the modification of thermal recovery parameters of different viscosity. By introducing heating radius and producing radius and considering the coupling effect of temperature, pressure and oil saturation fields, a quantitative expression between heating radius/producing radius and oil viscosity, formation thickness is presented, so is the impact of oil viscosity on the heating radius. Results shows that for Cyclic Steam Stimulation, the producing radius of horizontal well is bigger than its heating radius for light oil, both of which, however, shrink with higher viscosity. Beyond a critical viscosity, where the heating radius equals to the producing radius, the heating radius of horizontal well would be bigger than its producing radius. More over, the critical viscosity shows tight relationship to the formation thickness.

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