Increased Oil Recovery from a Mature Oil Field by Gas Injection

2015 ◽  
Author(s):  
B. Matre ◽  
J. Rasmussen ◽  
K. Hettervik ◽  
D. Hongbua
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Oil Field ◽  
Increased Oil Recovery

scholarly journals Integrated simulation system of CO2 gas injection application for enhanced oil recovery in the oil field

2020 ◽  
Vol 10 (8) ◽  
pp. 3917-3923
Author(s):  
Dedy Kristanto ◽  
Yulius Deddy Hermawan ◽  
Hariyadi ◽  
Yusmardhany Yusuf
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Gas Injection ◽  
Field Studies ◽  
Pilot Scale ◽  
Integrated System ◽  
Oil Field ◽  
Viscosity Reduction ◽  
Productivity Index ◽  
Final Decision

Abstract CO2 gas injection is one of the recommended enhanced oil recovery (EOR) methods by injecting CO2 through reservoir pores after the residual saturation is reached, since CO2 dissolves easily in oil phase as confirmed by many other researchers in pertaining field studies. An integrated system is urgently required for assessing CO2-EOR study, covering multi-disciplinary aspects as follows: geology, geophysics, reservoir, production, process and economic. Hence, those systems must be reliable in suggesting final decision for feasibility of CO2-EOR operation program, applicable either for pilot scale or for full scale. This paper is proposing an integrated system evaluation, which has the following features: (1) estimate fraction of dissolved CO2, (2) estimate viscosity reduction, (3) estimate future oil productivity index resulted, (4) forecast incremental oil production, (5) estimate surface facilities equipment design, (6) evaluate economical aspects and (7) generate final decision for feasibility of CO2-EOR operation program. Finally, as the main objective of this program, those systems will present a picture of essential reason why we need to promote or reject CO2-EOR plan program, and also some recommendations will be presented in case the CO2-EOR plan does not perform as expected.

Gas Re-Injection in the Laminaria and Corallina Fields, Timor Sea: Established Techniques, New Environmental and Commercial Benefits

2002 ◽  
Author(s):  
David M. Gordon ◽  
Scott A. Ryan ◽  
Steve K. Twartz
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Emission Reduction ◽  
Gas Injection ◽  
Oil Field ◽  
Emissions Reduction ◽  
Timor Sea ◽  
Operational Expenditure ◽  
Offshore Oil ◽  
Dual Objectives

This paper describes a gas re-injection project designed with the dual objectives of emissions reduction and enhanced oil recovery in an Australian offshore oil field. While gas injection for enhancing oil recovery is common oilfield practice, there are fewer projects that look exclusively at greenhouse gas (GHG) control (either by sequestration or emission reduction), although there is increasing environmental awareness in the industry on the benefits of doing so. The predominant contribution to total GHG CO2-e emissions is from flaring. Significant reductions in flaring have been achieved since completion of commissioning of injection. Flare CO2 emissions at the beginning of 2000 (February-March) reduced from approximately 163,000 tonnes per month to an average of approximately 26,000 tonnes per month over the remainder of 2000, and to 9,800 tonnes per month, over the first half of 2001. GHG efficiency, evident in the ratio of GHGs emitted per tonne of hydrocarbon produced, reduced from approximately 0.4 tonnes CO2-e per tonne of total hydrocarbon produced before injection to 0.08 after injection over the remainder of 2000, and to 0.06 over the first half of 2001. Miscible displacement is expected to add around 6 million barrels to ultimate recovery from the Corallina reservoir. The use of stored gas as a fuel is expected to achieve significant reductions in operational expenditure later in field life.

scholarly journals Increased oil recovery from Halfdan chalk by flooding with CO2-enriched water: a laboratory experiment

1969 ◽  
Vol 17 ◽  
pp. 17-20
Author(s):  
Dan Olsen
Keyword(s):  
North America ◽  
Laboratory Experiment ◽  
North Sea ◽  
Oil Recovery ◽  
Oil Field ◽  
Geological Survey ◽  
Low Permeability ◽  
The North ◽  
The North Sea ◽  
Increased Oil Recovery

Injection of CO2 is a method that may increase the recovery of oil from Danish chalk reservoirs in the North Sea. The method is used elsewhere, particularly in North America, but has so far not been used in the North Sea and has nowhere been used for chalk reservoirs, and the performance of the method when used for North Sea chalk is therefore uncertain. A laboratory flooding experiment was conducted at the Geological Survey of Denmark and Greenland on a sample from the Nana-1X well of the Halfdan oil field in the Danish North Sea in order to test the efficiency of CO2-enriched water to produce additional oil from chalk. The sample is a low-permeability chalk from the Ekofisk Formation and represents rocks that are marginal to the Halfdan reservoir in an economical sense.

Influence of oil field production life on optimal CO2 flooding strategies: Insight from the microscopic displacement efficiency

2021 ◽  
Author(s):  
Anna Chernova ◽  
Andrey Afanasyev ◽  
Anna Andreeva
Keyword(s):  
Oil Recovery ◽  
Optimal Strategy ◽  
Net Present Value ◽  
Gas Injection ◽  
Oil Field ◽  
Displacement Efficiency ◽  
Present Value ◽  
Recovery Method ◽  
Gas Flooding ◽  
Injection Rates

<p>We investigate the influence of the microscopic displacement processes on optimal gas flooding strategies. We couple a 1-D compositional reservoir model with an economic model of the flooding to assess profitability of the strategies. In general, we aim at the net present value maximisation, although the oil recovery and CO<sub>2 </sub>storage efficiencies are also estimated. Under certain assumptions, we reduce the number of parameters controlling selection of optimal strategy to just a few dimensionless quantities characterising both physical and economic processes. We show that the production life of oil fields should not be fixed in optimisation studies, especially at low oil prices. A significantly larger net present value can be achieved by varying the reservoir lifetime in addition to the injection rates and volumes and other well controls. Herewith, the optimal strategy can differ from that in the case of a presumed production time. We conclude that waterflooding is the optimal recovery method if the injection rate is low, whereas gas (WAG) flooding applied as a primary method and followed by waterflooding is most optimal for large injection rates. Gas flooding applied as the tertiary recovery method is most optimal for an intermediate range of the rates. In the latter case, gas injection should begin much earlier than water breaks through to producing wells. Finally, we investigate how oil price influences the range of parameters suitable for gas injection.</p><p>The authors acknowledge funding from the Russian Foundation for Basic Research under grant # 20-31-80009.</p>

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