The Research and Application of Segregated Completion Technology in Horizontal Wells in the Heavy Oil Reservoirs

2014 ◽  
Vol 694 ◽  
pp. 350-353
Author(s):  
Zhen Yu Sun ◽  
Ji Cheng Zhao
Keyword(s):  
Heavy Oil ◽  
Horizontal Wells ◽  
Steam Injection ◽  
Thermal Recovery ◽  
Oil Reservoirs ◽  
Oil Well ◽  
Horizontal Section ◽  
Liaohe Oilfield ◽  
Heavy Oil Reservoirs ◽  
Injection Technology

Liaohe oilfield is the biggest production base of the heavy oil in China. There are more than 800 horizontal wells with thermal recovery in the heavy oil reservoirs. Most of them adopt screen to complete the wells without packer outside of the casing, which results in packing off annulus space between screen and layer and only commingled steam or step steam can be injected inside the screen. Because of the areal and vertical anisotropy of the reservoirs, the horizontal sections are exploited unequally. According to the statistics, the horizontal wells with nonuniform exploitation accounts for 80 percent of all the horizontal wells with thermal recovery, and only 1/3 to 1/2 of the horizontal sections are comparatively well produced. The oil well productivity is seriously affected. So based on step steam injection inside the screen, we have developed the segregated completion and segregated steam injection technology applied to the horizontal wells with thermal recovery in heavy oil reservoirs. By means of the research on the segregated completion technology and development of high temperature ECP and casing thermal centralizer, which formed the corresponding technology applied in the horizontal wells with thermal recovery. Till now this technology has been applied in 8 wells, and average cyclic steam/oil ratio increased 0.1 plus, and the uniform development level of the horizontal section has been improved and the oilfield’s development effect has been advanced obviously.

scholarly journals Experimental study on the mechanism and development effect of multi-gas assisted steam huff and puff process in the offshore heavy oil reservoirs

2021 ◽  
Author(s):  
Jie Fan ◽  
Zuqing He ◽  
Wei Pang ◽  
Daoming Fu ◽  
Hanxiu Peng ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Steam Injection ◽  
Thermal Recovery ◽  
Oil Reservoirs ◽  
Viscosity Reduction ◽  
Oil Viscosity ◽  
Enhanced Production ◽  
Heavy Oil Reservoirs ◽  
Water Gas ◽  
Development Mechanism

AbstractMulti-gas assisted steam huff and puff process is a relatively new thermal recovery technology for offshore heavy oil reservoirs. Some blocks of Bohai oilfield have implemented multi-gas assisted steam huff and puff process. However, the development mechanism still requires further study. In this paper, high-temperature high-pressure (HTHP) PVT experiments and different huff and puff experiments of sand pack were carried out to reveal the enhanced production mechanism and evaluate the development effect of multi-gas assisted steam huff and puff process. The results indicated that viscosity reduction and thermal expansion still were the main development mechanism of multi-gas assisted steam huff and puff process. Specifically, CO2 easily dissolved in the heavy oil that made it mainly play the role of reducing oil viscosity, N2 was characteristics of small solubility and good expansibility, and it could improve formation pressure, increase steam sweep volume and even reduce the heat loss. Meanwhile, injecting multi-gas and steam could break the balance of heavy oil component that made the content of resin reduce and the content of saturates, aromatics and asphaltene increase so as to further reduce the viscosity of heavy oil. Compared with steam huff and puff process, multi-gas assisted steam huff and puff process increased the recovery by 2–5%. The optimal water–gas ratio and steam injection temperature were 4:6 and 300℃, respectively. The results suggested that multi-gas assisted steam huff and puff process would have wide application prospect for offshore heavy oil reservoirs.

Variation Characteristics of Reservoir Physical Properties after Thermal Recovery in Heavy Oil Reservoirs

2012 ◽  
Vol 550-553 ◽  
pp. 2848-2852
Author(s):  
Xiao Hu Dong ◽  
Hui Qing Liu ◽  
Zhan Xi Pang ◽  
Yong Gang Yi
Keyword(s):  
Physical Properties ◽  
Heavy Oil ◽  
Steam Injection ◽  
Thermal Recovery ◽  
Oil Reservoirs ◽  
Sand Production ◽  
Heavy Oil Reservoirs ◽  
Variation Characteristics ◽  
Porosity And Permeability ◽  
Production Period

With the development of heavy oil reservoirs, it faced a series of problems. Using the theory of thermal-hydrological-mechanical (THM) coupling, a predictive model of reservoir physical properties (RPP) after thermal recovery is established. Based on this model, the changing process of reservoir physical properties is simulated by the method of numerical simulation. The obtained results show that the sand production has a significant influence on RPP. By contrast with rock deformation, it has a smaller influence on RPP. The influence caused by the former is about 5~8 times than latter. During the period of steam injection, resulting from the movement of sand grain and expansion of reservoir, both porosity and permeability of reservoir are on the rise. Due to the sand production and reservoir compression, a reducing tendency is happened in the production period. The changes of RPP in reservoir are huge along the main streamline direction, and it might change because of the presence of high-permeability path.

scholarly journals Downhole electric heating of heavy-oil wells

2020 ◽  
Vol 10 (2) ◽  
pp. 61-72
Author(s):  
John Karanikas ◽  
Guillermo Pastor ◽  
Scott Penny
Keyword(s):  
Heavy Oil ◽  
Horizontal Wells ◽  
Electric Heating ◽  
Optimization Method ◽  
Economic Benefits ◽  
Production Optimization ◽  
Operating Conditions ◽  
Oil Reservoirs ◽  
Oil Well ◽  
Heavy Oil Reservoirs

Downhole electric heating has historically been unreliable or limited to short, often vertical, well sections. Technology improvements over the past several years now allow for reliable, long length, relatively high-powered, downhole electric heating suitable for extended-reach horizontal wells. The application of this downhole electric heating technology in a horizontal cold-producing heavy oil well in Alberta, Canada is presented in this paper. The field case demonstrates the benefits and efficacy of applying downhole electric heating, especially if it is applied early in the production life of the well. Early production data showed 4X-6X higher oil rates from the heated well than from a cold-producing benchmark well in the same reservoir. In fact, after a few weeks of operation, it was no longer possible to operate the benchmark well in pure cold-production mode as it watered out, whereas the heated well has been producing for twenty (20) months without any increase in water rate. The energy ratio, defined as the heating value of the incremental produced oil to the injected heat, is over 20.0, resulting in a carbon-dioxide footprint of less than 40 kgCO2/bbl, which is lower than the greenhouse gas intensity of the average crude oil consumed in the US. A numerical simulation model that includes reactions that account for the foamy nature of the produced oil and the downhole injection of heat, has been developed and calibrated against field data.  The model can be used to prescribe the range of optimal reservoir and fluid properties to select the most promising targets (fields, wells) for downhole electric heating as a production optimization method. The same model can also be used during the execution of the project to explore optimal operating conditions and operating procedures. Downhole electric heating in long horizontal wells is now a commercially available technology that can be reliably applied as a production optimization recovery scheme in heavy oil reservoirs. Understanding the optimum reservoir conditions where the application of downhole electric heating maximizes economic benefits will assist in identifying areas of opportunity to meaningfully increase reserves and production in heavy oil reservoirs around the world.

scholarly journals Thermal Hydraulic Analysis Using GIS on Application of HTR to Thermal Recovery of Heavy Oil Reservoirs

2012 ◽  
Vol 2012 ◽  
pp. 1-15
Author(s):  
Yangping Zhou ◽  
Fu Li ◽  
Zhiwei Zhou ◽  
Yuanle Ma
Keyword(s):  
Heavy Oil ◽  
Superheated Steam ◽  
Steam Injection ◽  
Thermal Recovery ◽  
Oil Field ◽  
Oil Reservoirs ◽  
Hydraulic Analysis ◽  
Heavy Oil Reservoirs ◽  
Large Water ◽  
Thermal Hydraulic Analysis

At present, large water demand and carbon dioxide (CO2) emissions have emerged as challenges of steam injection for oil thermal recovery. This paper proposed a strategy of superheated steam injection by the high-temperature gas-cooled reactor (HTR) for thermal recovery of heavy oil, which has less demand of water and emission of CO2. The paper outlines the problems of conventional steam injection and addresses the advantages of superheated steam injection by HTR from the aspects of technology, economy, and environment. A Geographic Information System (GIS) embedded with a thermal hydraulic analysis function is designed and developed to analyze the strategy, which can make the analysis work more practical and credible. Thermal hydraulic analysis using this GIS is carried out by applying this strategy to a reference heavy oil field. Two kinds of injection are considered and compared: wet steam injection by conventional boilers and superheated steam injection by HTR. The heat loss, pressure drop, and possible phase transformation are calculated and analyzed when the steam flows through the pipeline and well tube and is finally injected into the oil reservoir. The result shows that the superheated steam injection from HTR is applicable and promising for thermal recovery of heavy oil reservoirs.

The macroscopic and microscopic analysis on the performance of steam foams during thermal recovery in heavy oil reservoirs

Fuel ◽  
2018 ◽  
Vol 233 ◽  
pp. 166-176 ◽  
Author(s):  
Zhanxi Pang ◽  
Xiaocong Lyu ◽  
Fengyi Zhang ◽  
Tingting Wu ◽  
Zhennan Gao ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Microscopic Analysis ◽  
Thermal Recovery ◽  
Oil Reservoirs ◽  
Heavy Oil Reservoirs

Pressure Maintenance and Improving Oil Recovery by Means of Immiscible Water-Alternating-CO2 Processes in Thin Heavy-Oil Reservoirs

2013 ◽  
Vol 16 (01) ◽  
pp. 60-71 ◽  
Author(s):  
Sixu Zheng ◽  
Daoyong Yang
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Oil Production ◽  
Horizontal Wells ◽  
Operating Conditions ◽  
Oil Reservoirs ◽  
Oil Saturation ◽  
Water Alternating Gas ◽  
Heavy Oil Reservoirs ◽  
Water Cut

Summary Techniques have been developed to experimentally and numerically evaluate performance of water-alternating-CO2 processes in thin heavy-oil reservoirs for pressure maintenance and improving oil recovery. Experimentally, a 3D physical model consisting of three horizontal wells and five vertical wells is used to evaluate the performance of water-alternating-CO2 processes. Two well configurations have been designed to examine their effects on heavy-oil recovery. The corresponding initial oil saturation, oil-production rate, water cut, oil recovery, and residual-oil-saturation (ROS) distribution are examined under various operating conditions. Subsequently, numerical simulation is performed to match the experimental measurements and optimize the operating parameters (e.g., slug size and water/CO2 ratio). The incremental oil recoveries of 12.4 and 8.9% through three water-alternating-CO2 cycles are experimentally achieved for the aforementioned two well configurations, respectively. The excellent agreement between the measured and simulated cumulative oil production indicates that the displacement mechanisms governing water-alternating-CO2 processes have been numerically simulated and matched. It has been shown that water-alternating-CO2 processes implemented with horizontal wells can be optimized to significantly improve performance of pressure maintenance and oil recovery in thin heavy-oil reservoirs. Although well configuration imposes a dominant impact on oil recovery, the water-alternating-gas (WAG) ratios of 0.75 and 1.00 are found to be the optimum values for Scenarios 1 and 2, respectively.

Sign in / Sign up

Export Citation Format

Share Document