Experimental investigation of CO2 huff-n-puff process for enhancing oil recovery in tight reservoirs

Pu, Wanfen; Wei, Bing; Jin, Fang; Li, Yibo; Jia, Hu; Liu, Penggang; Tang, Zhi-Juan

doi:10.1016/j.cherd.2016.05.012

Cited by 136 publications

(54 citation statements)

References 18 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Therefore, CO 2 offers better injectivity to the rock matrix than the injected water, and it is more advantageous than other gases such as nitrogen gas. This makes CO 2 the best candidate for improving the tight oil recovery . Several studies report that it can achieve an incremental oil recovery in the range of 5%‐20% in the Bakken and Eagle ford reservoirs using the huff‐n‐puff gas process .…”

Section: Introductionmentioning

confidence: 99%

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

Wang

et al. 2019

Energy Science & Engineering

View full text Add to dashboard Cite

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.

show abstract

Section: Introductionmentioning

confidence: 99%

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

Wang

et al. 2019

Energy Science & Engineering

View full text Add to dashboard Cite

show abstract

“…Carbon dioxide (CO 2 ) flooding is an effective technique for enhancing oil recovery. CO 2 injection offers advantages in the improvement of oil recovery performance (e.g., viscosity reduction, volume swelling, interfacial tension (IFT) reduction, and hydrocarbon extraction), leading to a more flowable crude oil in the reservoir (Cao, Peng, & Ma, 2017;Habibi, Yassin, & Dehghanpour, 2017;Pu, Wei, & Jin, 2016;Song & Yang, 2017). However, there are still some key factors that retarded its development, such as CO 2 source shortage and CO 2 transportation problems (Liu, Sahni, & Hsu, 2014;Temizel, Rodriguez, Saldierna, & Narinesingh, 2016), especially in Chinese oil fields.…”

Section: Introductionmentioning

confidence: 99%

Investigation on Foam Self‐Generation Using In Situ Carbon Dioxide (CO₂) for Enhancing Oil Recovery

Jin

Wei

et al. 2018

J Surfact & Detergents

Self Cite

View full text Add to dashboard Cite

In situ carbon dioxide (CO2) foam flooding has proved to be economically feasible in the oil field, but its self‐generation behavior in the bulk scale/porous media is far from understood. In this study, the optimum in situ CO2‐foaming agent was first screened, and then in situ foam was investigated in the bulk. In situ foam flooding was conducted to evaluate the displacement characteristics and enhanced oil recovery of this system. The results showed that the foaming agent comprising 0.5% sodium dodecyl sulfonate (SDS) + 0.5% lauramido propyl hydroxyl sultaine (LHSB) gave the best foam properties and that the in situ CO2 foam with a slow releasing rate is effective both in bulk scale and in porous media, allowing a considerable enhancement of oil recovery in sand packs with different permeabilities.

show abstract

“…Currently, the discovery of new reservoirs has become difficult and most of the producing reservoirs are in the late stages of production, which means that it is unlikely that a great breakthrough will be made in the first two categories. Taking into consideration the fact that about two-thirds of the oil cannot be recovered by conventional methods such as waterflooding, the importance of enhanced oil recovery techniques (EOR) to improve oil production efficiency has been widely acknowledged [3,4].…”

Section: Introductionmentioning

confidence: 99%

Experimental Study of In‐Situ CO₂Foam Technique and Application in Yangsanmu Oilfield

Jin

Liu

et al. 2016

J Surfact & Detergents

Self Cite

View full text Add to dashboard Cite

The Yangsanmu oilfield of Dagang is a typical heavy oil reservoir. After the maximum primary production (waterflooding), more than half of the original oil is still retained in the formation. Therefore, the implementation of an enhanced oil recovery (EOR) process to further raise the production scheme is inevitable. In this work, a novel in‐situ CO2 foam technique which can be used as a potential EOR technique in this oilfield was studied. A screening of gas producers, foam stabilizers and foaming agents was followed by the study of the properties of the in‐situ CO2 foam systems through static experiments. Core‐flooding experiments and field application were also conducted to evaluate the feasibility of this technique. The results indicated that the in‐situ CO2 foam system can improve both the sweep and displacement efficiencies, due to the capacity of this system in reducing oil viscosity and interfacial tension, respectively. The EOR performance of the in‐situ CO2 foam system is better than the single‐agent and even binary system (surfactant‐polymer) flooding. The filed data demonstrated that the in‐situ CO2 technique can significantly promote oil production and control water cuts. These results are believed to be beneficial in making EOR strategies for similar reservoirs.

show abstract

Experimental investigation of CO2 huff-n-puff process for enhancing oil recovery in tight reservoirs

Cited by 136 publications

References 18 publications

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

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

Investigation on Foam Self‐Generation Using In Situ Carbon Dioxide (CO₂) for Enhancing Oil Recovery

Experimental Study of In‐Situ CO₂Foam Technique and Application in Yangsanmu Oilfield

Contact Info

Product

Resources

About

Experimental investigation of CO2 huff-n-puff process for enhancing oil recovery in tight reservoirs

Cited by 136 publications

References 18 publications

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

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

Investigation on Foam Self‐Generation Using In Situ Carbon Dioxide (CO2) for Enhancing Oil Recovery

Experimental Study of In‐Situ CO2Foam Technique and Application in Yangsanmu Oilfield

Contact Info

Product

Resources

About

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

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

Investigation on Foam Self‐Generation Using In Situ Carbon Dioxide (CO₂) for Enhancing Oil Recovery

Experimental Study of In‐Situ CO₂Foam Technique and Application in Yangsanmu Oilfield