Evaluation of the Enhance Oil Recovery (EOR) Potential of Water and Gas Injection in Oil Shale Reservoirs

2014 ◽  
Author(s):  
Yasir Shahzad
Keyword(s):  
Oil Recovery ◽  
Oil Shale ◽  
Gas Injection ◽  
Shale Reservoirs ◽  
Enhance Oil Recovery

Study on CO2 Injection for Enhancing the Oil Recovery at Gao89 Block in Shengli Oilfield

2013 ◽  
Vol 734-737 ◽  
pp. 1464-1467
Author(s):  
Song Lin Shi ◽  
Jian Kang ◽  
Meng Li
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Water Injection ◽  
Low Permeability ◽  
Recovery Method ◽  
Shengli Oilfield ◽  
Geological Features ◽  
Efficient Recovery ◽  
Original Production ◽  
Enhance Oil Recovery

Gao 89 Block is a low permeability oil reservoir. These reservoirs have difficulty in water injection, poor well condition, and low original production. Gas injection can solve this problem. It is the most efficient recovery method for low-permeability reservoirs at home and abroad. In accordance with the geological features and development actuality of Gao89 Block, the feasibility and optimization of gas injection are studied, the effect of gas injection on the development index and development results are demonstrated. The results indicate that the gas injection can dramatically enhance oil recovery and increase the oil production.

scholarly journals Numerical Simulation of Immiscible CO2-Assisted Gravity Drainage Process to Enhance Oil Recovery

2020 ◽  
pp. 2004-2016
Author(s):  
Dahlia Abdulhadi Al-Obaidi ◽  
Mohammed Saleh Al-Jawad
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Injection Pressure ◽  
Oil Production ◽  
Simulation Models ◽  
Injection Rate ◽  
Gravity Drainage ◽  
Effective Parameters ◽  
Water Contact ◽  
Enhance Oil Recovery

The Gas Assisted Gravity Drainage (GAGD) process has become one of the most important processes to enhance oil recovery in both secondary and tertiary recovery stages and through immiscible and miscible modes.  Its advantages came from the ability to provide gravity-stable oil displacement for improving oil recovery, when compared with conventional gas injection methods such as Continuous Gas Injection (CGI) and Water – Alternative Gas (WAG). Vertical injectors for CO2   gas were placed at the top of the reservoir to form a gas cap which drives the oil towards the horizontal oil producing wells which are located above the oil-water-contact. The GAGD process was developed and tested in vertical wells to increase oil recovery in reservoirs with bottom water drive and strong water coning tendencies. Many physical and simulation models of GAGD performance were studied at ambient and reservoir conditions to investigate the effects of this method to enhance the recovery of oil and to examine the most effective parameters that control the GAGD process.      A prototype 2D simulation model based on the scaled physical model was built for CO2-assisted gravity drainage in different statement scenarios. The effects of gas injection rate, gas injection pressure and oil production rate on the performance of immiscible CO2-assisted gravity drainage-enhanced oil recovery were investigated. The results revealed that the ultimate oil recovery increases considerably with increasing oil production rates. Increasing gas injection rate improves the performance of the process while high pressure gas injection leads to less effective gravity mediated recovery.

scholarly journals Data Processing Method of Well Testing

2021 ◽  
Vol 134 (3) ◽  
pp. 39-42
Author(s):  
М. М. Bakraev ◽  
◽  
F. Z. Bulyukova ◽  
E. B. Dumler ◽  
T. B. Soltukiev ◽  
...  
Keyword(s):  
High Pressure ◽  
Oil Recovery ◽  
Gas Injection ◽  
Processing Method ◽  
Well Testing ◽  
Comparative Testing ◽  
Data Processing Method ◽  
Production Wells ◽  
Enhance Oil Recovery ◽  
Production Characteristics

The article presents an analysis of technological schemes for the development of the XXIII layer of the Goyt-Kort field, as a result of which the implementation of measures for high pressure gas injection is proposed. The geological and production characteristics of the reservoir, technological features of the developed process and economic needs justified the choice of the Goyt-Кort field as a priority object for high-pressure gas injection to enhance oil recovery. As a result of the proposed measures, an increase in reservoir pressure was noted in the area of the first row of production wells, an improvement in their performance due to gas injection.The characteristic reasons for the frequent well workovers caused by deposits of asphalt-resin-paraffin substances in equipment, in tubing and flow lines have been identified. Measures are provided to eliminate and combat the listed complications. Thus, the field tested and implemented the technology of constant dosing of the inhibitor into the annulus of the well. Comparative testing of the activity of the reagents was carried out. To remove the clay bridging agent of the pore matrix of high-temperature terrigenous objects, the use of reagents based on boronfluorinehydrogen acid is recommended.

Effect of Nanoscale Pore-Size Distribution on Fluid Phase Behavior of Gas-Improved Oil Recovery in Shale Reservoirs

SPE Journal ◽  
2020 ◽  
Vol 25 (03) ◽  
pp. 1406-1415
Author(s):  
Sheng Luo ◽  
Jodie L. Lutkenhaus ◽  
Hadi Nasrabadi
Keyword(s):  
Pore Size Distribution ◽  
Phase Behavior ◽  
Pore Size ◽  
Size Distribution ◽  
Oil Recovery ◽  
Gas Injection ◽  
Fluid Phase ◽  
Improved Oil Recovery ◽  
Nanoscale Pore ◽  
Shale Reservoirs

Summary The improved oil recovery (IOR) of unconventional shale reservoirs has attracted much interest in recent years. Gas injection, such as carbon dioxide (CO2) and natural gas, is one of the most considered techniques for its sweep efficiency and effectiveness in low-permeability reservoirs. However, the uncertainties of fluid phase behavior in shale reservoirs pose a great challenge in evaluating the performance of a gas-injection operation. Shale reservoirs typically have macroscale to nanoscale pore-size distribution in the porous space. In fractures and macropores, the fluid shows bulk behavior, but in nanopores, the phase behavior is significantly altered by the confinement effect. The integrated behavior of reservoir fluids in this complex environment remains uncertain. In this study, we investigate the nanoscale pore-size-distribution effect on the phase behavior of reservoir fluids in gas injection for shale reservoirs. A case of Anadarko Basin shale oil is used. The pore-size distribution is discretized as a multiscale system with pores of specific diameters. The phase equilibria of methane injection into the multiscale system are calculated. The constant-composition expansions are simulated for oil mixed with various fractions of injected gas. It is found that fluid in nanopores becomes supercritical with injected gas, but lowering the pressure to less than the bubblepoint turns it into the subcritical state. The bubblepoint is generally lower than the bulk and the degree of deviation depends on the amount of injected gas. The modeling of confined-fluid swelling shows that fluid swelled from nanopores is predicted to contain more oil than the swelled fluid at bulk state.

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