The Integration of Miscible Gas Injection in Oil Reservoirs with the Development of a Sour Gas Condensate Field

2012 ◽  
Author(s):  
Josephus Martinus Vissers ◽  
Abdullah Kindy ◽  
Ahmed Hassan
Keyword(s):  
Gas Injection ◽  
Gas Condensate ◽  
Oil Reservoirs ◽  
Miscible Gas Injection ◽  
Sour Gas

Production Optimization Coupling Multiple Reservoirs and Facilities With Sour Gas Re-Injection for Miscible EOR in South Oman

2021 ◽  
Author(s):  
Kamlesh Kumar ◽  
Varun Pathak ◽  
Pankaj Agrawal ◽  
Zaal Alias ◽  
Tushar Narwal ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Production System ◽  
Gas Injection ◽  
Ghg Emissions ◽  
Development Project ◽  
Production Optimization ◽  
Oil Reservoirs ◽  
Fully Implicit ◽  
Gas Utilization ◽  
Sour Gas

Abstract Effective gas utilization is critical to any gas injection development project to maximize recoveries for a given purchase of make-up gas, whilst reducing the Green Gas House (GHG) emissions. This paper describes the use of a fully implicit Integrated Production System Model (IPSM) for two inter-connected production system networks, coupling multiple, critically sour oil reservoirs undergoing Miscible Gas Injection (MGI) for Enhanced Oil Recovery (EOR) using produced sour gas from oil and condensate fields in South Oman. The IPSM model links sixteen reservoir models with varying levels of complexities to the facilities network. Complexities in the facilities include multiple nodal constraints that necessitate the use of an Equation of State model (EOS). The IPSM model honors the gas balance implicitly. Gas flood optimization includes prioritizing low GOR production wells (at reservoir and well level) whilst maintaining reservoir pressure above Minimum Miscibility Pressures (MMP). Development schedule optimization also helps in optimizing the compressor size, the key Capex component. Compositional modeling allows continuous tracking of souring levels at different nodes, providing integrity status of overall production system network. The current IPSM model helps in optimization of schedule for the phased development of the oil reservoirs and eventually the most efficient gas utilization. This has enabled low pressure operation in some reservoirs providing oil at very low unit technical cost while waiting for gas availability. Compositional tracking for H2S helps in operating the facilities within design limits whilst planning future developments to cater to this design. Some key parameters can be parameterized for quick sensitivity analysis for an informed decision making for business opportunities. The production potential of the system is also tracked to ensure there is a cushion in the system to deal with any unexpected changes. This feature helps in planning and optimizing the scheduled turn-around activities for these two inter-connected production system networks. The novelty of this work is collaboration across multiple disciplines, especially the surface and subsurface because of complex interactions between facilities constraints and reservoir performance (associated with produced gas reinjection). Compositional tracking and injection gas apportionment across multiple reservoirs is key to the overall value maximization in this complex development.

Evaluation of Miscible Gas Injection in Oil Reservoirs by Monitoring the Asphaltenes Concentration – Moreoil

2005 ◽  
Author(s):  
A.K. Stubos ◽  
T. Aurdal ◽  
H.P. Hjermstadt ◽  
J.A. Stensen ◽  
N. Varotis ◽  
...  
Keyword(s):  
Gas Injection ◽  
Oil Reservoirs ◽  
Miscible Gas Injection

Determination Of Optimum Miscible Gas Injection For Iranian Oil Reservoirs

1997 ◽  
Author(s):  
F.G. Javadpour ◽  
M. Jamlalohmadi ◽  
S.R. Shadizadeh
Keyword(s):  
Gas Injection ◽  
Oil Reservoirs ◽  
Miscible Gas Injection

Simulation Of Sour Gas Injection Into Low Permeability Oil Reservoirs

2003 ◽  
Author(s):  
Sylvain Thibeau ◽  
John W. Barker ◽  
Danielle Morel
Keyword(s):  
Gas Injection ◽  
Oil Reservoirs ◽  
Low Permeability ◽  
Sour Gas

An Attempt to Revitalize Watered-Out Gas Condensate Fractured Reservoir by Gas Injection

2015 ◽  
Author(s):  
Y. Adachi ◽  
T. Hasegawa ◽  
H. Yamamoto ◽  
K. Hosokoshi ◽  
T. Anraku
Keyword(s):  
Gas Injection ◽  
Gas Condensate ◽  
Fractured Reservoir

The Mechanism of Flue Gas Injection for Enhanced Light Oil Recovery

2004 ◽  
Vol 126 (2) ◽  
pp. 119-124 ◽  
Author(s):  
O. S. Shokoya ◽  
S. A. (Raj) Mehta ◽  
R. G. Moore ◽  
B. B. Maini ◽  
M. Pooladi-Darvish ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Flue Gas ◽  
Gas Injection ◽  
Cost Effective ◽  
Air Injection ◽  
Oil Reservoirs ◽  
Flue Gases ◽  
Low Permeability ◽  
Light Oil ◽  
Light Oil Reservoirs

Flue gas injection into light oil reservoirs could be a cost-effective gas displacement method for enhanced oil recovery, especially in low porosity and low permeability reservoirs. The flue gas could be generated in situ as obtained from the spontaneous ignition of oil when air is injected into a high temperature reservoir, or injected directly into the reservoir from some surface source. When operating at high pressures commonly found in deep light oil reservoirs, the flue gas may become miscible or near–miscible with the reservoir oil, thereby displacing it more efficiently than an immiscible gas flood. Some successful high pressure air injection (HPAI) projects have been reported in low permeability and low porosity light oil reservoirs. Spontaneous oil ignition was reported in some of these projects, at least from laboratory experiments; however, the mechanism by which the generated flue gas displaces the oil has not been discussed in clear terms in the literature. An experimental investigation was carried out to study the mechanism by which flue gases displace light oil at a reservoir temperature of 116°C and typical reservoir pressures ranging from 27.63 MPa to 46.06 MPa. The results showed that the flue gases displaced the oil in a forward contacting process resembling a combined vaporizing and condensing multi-contact gas drive mechanism. The flue gases also became near-miscible with the oil at elevated pressures, an indication that high pressure flue gas (or air) injection is a cost-effective process for enhanced recovery of light oils, compared to rich gas or water injection, with the potential of sequestering carbon dioxide, a greenhouse gas.

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