Laboratory Experiments on Enhanced Oil Recovery with Nitrogen Injection

Siregar, Simon; Hidayaturobbi, A. D.; Wijaya, Beatrice Andreanna; Listiani, Sri; Adiningrum, T.; Irwan, Irwan; Pratomo, Agus

doi:10.5614/itbj.eng.sci.2007.39.1.2

Cited by 9 publications

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References 10 publications

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“…Based on past studies, nitrogen injection could recover up to 45-90% of initial reserves. Nitrogen was used back to 50's when it played a crucial role in the petroleum industry, such as in well completion and well work over [22]. Nitrogen has long been successfully used as the injection fluid for EOR and widely used in oil field operations for gas cycling, reservoir pressure maintenance, and gas lift.…”

Section: Nitrogen Injectionmentioning

confidence: 99%

“…Nitrogen is the optimum EOR method for many reservoirs and has been chosen for the following reasons [22]. 1) By applying nitrogen given the fact that a significant increase in oil production has been realized [28].…”

Section: Why Is Nitrogen?mentioning

confidence: 99%

“…6) Nitrogen is friendly to environment, completely inert [28], and remains inert in the presence of water [31]. 7) Nitrogen is non-corrosive to field equipment [22], [30]. 8) Nitrogen can be removed economically from a sales gas stream to increase Btu content ($ 0.9 per MSCF) [32].…”

Section: Why Is Nitrogen?mentioning

confidence: 99%

“…9) Nitrogen gas is less compressible than CO 2 or natural gas, so less is required (N 2 = 0.9998 while it is 0.9949 for CO 2 at 25 C and 14.7 PSIA) [31]. 10) Nitrogen is harmless compared to other gas (not flammable) [22]. 11) Nitrogen vaporizes the lighter components of the crude oil and generates miscibility if the pressure is high enough [33].…”

Section: Why Is Nitrogen?mentioning

confidence: 99%

“…At higher injection rates, oxygen free gas percentage was less, probably due to oxidation process taking place, which used up oxygen in the oil during injection. This oxidation process helped increase the oil recovery [22].…”

Section: Why Is Nitrogen?mentioning

confidence: 99%

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An Overview of Oil Production Stages: Enhanced Oil Recovery Techniques and Nitrogen Injection

Alagorni¹,

Yaacob²,

Nour³

2015

IJESD

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Abstract-During the life oil wells, production process usually passes three stages. Primary recovery uses the natural source of energy. Pumps and gas lifting are involved in the primary recovery. The main purpose of secondary recovery process is to maintain the reservoir pressure by either a natural gas flooding or water flooding.The rise in world oil prices has encouraged the producers to use the new technical developments. Enhanced oil recovery (EOR) is a collection of sophisticated methods, to extract the most oil from a reservoir. EOR can be divided into two major types of techniques: thermal and non-thermal recovery. Each technique has a specific use in a certain type of reservoirs.Among non-thermal techniques is the gas flooding, where gas is generally injected single or intermittently with water. Flue gas and nitrogen have only limited application as agents of a miscible displacement in deep and high pressure reservoirs.Although new development processes such as water alternating gas (WAG) or Simultaneous water alternating gas (SWAG), are implemented, there are still some problems encountered by EOR engineers. This paper is discussing the last updating in this field.Index Terms-Enhanced oil recovery (EOR), miscible flooding, nitrogen injection, water alternating gas (WAG).

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Section: Nitrogen Injectionmentioning

confidence: 99%

Section: Why Is Nitrogen?mentioning

confidence: 99%

Section: Why Is Nitrogen?mentioning

confidence: 99%

Section: Why Is Nitrogen?mentioning

confidence: 99%

Section: Why Is Nitrogen?mentioning

confidence: 99%

See 3 more Smart Citations

An Overview of Oil Production Stages: Enhanced Oil Recovery Techniques and Nitrogen Injection

Alagorni¹,

Yaacob²,

Nour³

2015

IJESD

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Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Wang

et al. 2019

Energy Science & Engineering

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This paper investigates the CO2/N2 injection process in tight oil reservoirs considering the confinement effect. To study the microscopic physical mechanisms, the confinement effect is characterized by properties shift and capillarity and introduced into the flash calculation to obtain the phase equilibrium of mixture fluids (tight oil/CO2/N2) in tight porous media. The results indicate that the injected nitrogen gas could effectively maintain the reservoir pressure, while it also weakens the effects of the CO2 injection recovery mechanisms, notably diffusivity and viscosity reduction. In addition, a dual‐pore tight oil reservoir model is set up to investigate the CO2/N2 injection with ultra‐low permeability and hydraulic fracturing. The basic CO2 injection parameters are optimized by the orthogonal method. Based on CO2 injection process, three injection schemes of CO2/N2 injection, which are mixed‐gas injection, CO2‐alternating‐N2 (CAN) injection, and N2‐alternating‐CO2 (NAC) injection, were investigated and a comparative analysis was made for the pressure distribution, CO2 mole fraction distribution, and cumulative oil production. Based on this analysis, the CAN injection process proved to be the best injection scheme. A parametric analysis further suggested that the nitrogen gas injection rate was the most important factor. Besides, the effect of gravity drainage, reservoir permeability, nature fractures, and permeability heterogeneity on the oil production of CAN injection process were also investigated in detail. The results show that tight oil reservoir with better vertical connectivity, poor fracture growth, and higher heterogeneity is more favorable for the CO2/N2 injection process.

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Enhanced oil recovery application in low permeability formations by the injections of CO2, N2 and CO2/N2 mixture gases

Bougre

Gamadi

2021

J Petrol Explor Prod Technol

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Low oil recovery which is very predominant in shale oil reservoirs has stimulated petroleum engineers to investigate the applications of enhanced oil recovery methods in these formations. One such application is the injection of gases into the formation to stimulate increased oil recovery. In many gas flooding projects performed in the field, the miscibility of the gas injected is usually the most desired displacement mechanism, and carbon dioxide (CO2) gas has been recognized to be the best performing gas for injection due to its ability to be miscible with oil in the reservoir at low pressures compared to other gases such as nitrogen. This minimum miscibility pressure (MMP) is of very crucial importance because it is the primary limiting factor in the feasibility of a miscible gas flooding project. However, there are other limiting factors such as cost and availability and, in these instances, nitrogen (N2) and lean gas are the more preferred candidate as opposed to carbon dioxide gas. Mixing carbon dioxide gas with lean gas or with nitrogen in a required ratio can allow us to design an injection gas that will be suitable enough to satisfy both the availability and cost constraints and at the same time allow us to achieve a reachable and reasonable miscibility pressure. The objective of this paper is to investigate the effect of mixing nitrogen gas and carbon dioxide gas in a 50:50 ratio on oil recovery in tight oil formations. The experiment was performed with controlled constraints such as the same core sample, same crude oil and same core cleaning and saturation process which was repeated for each trial. The oil used was live oil from Eagle ford formation, and the gases used were nitrogen (99.9% purity), carbon dioxide and a mixture of nitrogen and carbon dioxide in a 50:50 ratio. The injection pressure ranged from 1000 to 5000 psi with pressure increments of 1000 psi, and the same flooding time was 6 h. The potential of the N2, CO2 and N2–CO2 mixture for improving oil recovery was assessed along with the breakthrough time. The results showed that CO2 gas had the highest recovery followed by the N2–CO2 mixture and N2 gas had the lowest recovery. The gas breakthrough time results showed that the N2–CO2 mixture had the longest breakthrough time, N2 had the shortest breakthrough time, and CO2 had a significantly longer breakthrough time than pure N2 gas. The RF increased with increasing pressure, but the gas breakthrough time decreased with increasing pressure. However, the incremental RF decreased in all three cases when the injection pressure was above 3000 psi.

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Laboratory Experiments on Enhanced Oil Recovery with Nitrogen Injection

Cited by 9 publications

References 10 publications

An Overview of Oil Production Stages: Enhanced Oil Recovery Techniques and Nitrogen Injection

An Overview of Oil Production Stages: Enhanced Oil Recovery Techniques and Nitrogen Injection

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Enhanced oil recovery application in low permeability formations by the injections of CO2, N2 and CO2/N2 mixture gases

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Laboratory Experiments on Enhanced Oil Recovery with Nitrogen Injection

Cited by 9 publications

References 10 publications

An Overview of Oil Production Stages: Enhanced Oil Recovery Techniques and Nitrogen Injection

An Overview of Oil Production Stages: Enhanced Oil Recovery Techniques and Nitrogen Injection

Investigation of CO2/N2 injection in tight oil reservoirs with confinement effect

Enhanced oil recovery application in low permeability formations by the injections of CO2, N2 and CO2/N2 mixture gases

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Product

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Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect