A novel type curve for estimating oil recovery factor of gas flooding

Tang, Yong; ZHANG, Haochuan; He, Youwei; GUO, Xiaodong; Fan, Kun; Wu, Zangyuan; Zhou, Deyun; Tao, Zhengwu; LI, Jinlong

doi:10.1016/s1876-3804(22)60050-8

Cited by 6 publications

(2 citation statements)

References 15 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The movement of the gas–liquid interface between them is a complex three-dimensional motion process, and the stability of the interface is related to whether finger channeling occurs in the gas cap . Affected by the viscosity difference and mobility ratio between injected gas and crude oil, when the mobility of the gas in the displacement front is higher than that of the oil, serious channeling occurs when the displacement front passes through the entire oil layer. − Whenever gas injection and oil recovery technology are involved, gas channeling is the direct reason affecting the low recovery degree . Therefore, it is of great significance to clarify the stable conditions of oil–gas interface movement to avoid gas channeling and to formulate the technical countermeasures of gas-top gravity flooding.…”

Section: Introductionmentioning

confidence: 99%

Establishment of Stability Evaluation Criteria for the Oil–Gas Interface during Gas-Cap Gravity Flooding in Oil Reservoirs with Strong Edge-Water Drive

et al. 2023

View full text Add to dashboard Cite

A three-dimensional (3D) experimental model considering the influence of water energy is established to innovatively analyze oil−gas interface stability, and it is found that a stable gas cap with sufficient driving energy can be formed only under a stable oil and gas interface. So, the bidirectional displacement through the gas cap and edge water can be realized during the late development stage in the strong edge-water drive reservoirs. Results show that the recovery of bidirectional displacement can reach 60%, while the recovery of an unstable interface is basically below 50%. The recovery degree under a stable oil−gas interface is more than 25.63% than that of the unstable interface. Based on the Navier−Stokes equation, a "steady flow velocity u s " formula that considers the influence of multiple factors is defined, and the ratio of the flow velocity at the oil−gas interface to the gas injection rate is controlled between 0.6 and 0.85 to determine the criteria for the stable oil−gas interface. At the same time, the differentiationhindered quasi-number (Gr) is defined to clarify the influence mechanism of various mechanical factors on gravity differentiation and the difficulty of oil and gas replacement. When Gr is equal to 1, the oil−gas interface reaches stable migration conditions. Larger formation dip angle, higher permeability, smaller oil viscosity, and lower gas injection rate are the favorable conditions for forming stable flow. The findings are recommended to be used in reservoirs with relatively homogeneous reservoirs, certain dip angles, and moderate or low oil viscosity.

show abstract

Section: Introductionmentioning

confidence: 99%

Establishment of Stability Evaluation Criteria for the Oil–Gas Interface during Gas-Cap Gravity Flooding in Oil Reservoirs with Strong Edge-Water Drive

et al. 2023

View full text Add to dashboard Cite

show abstract

“…1, it is easy to precipitate and make the clay expanding in the process of water flooding in low permeability reservoir [13]. Due to gas is easy to flow, expand volume, reduce oil viscosity and interfacial tension, CO 2 flooding shows significant advantages in solving the development of low permeability reservoir, which could supplement formation energy and effectively control water [14][15]. Wang et al [16] indicated that CO 2 miscible flooding is advisable for lowpermeability reservoir.…”

Section: Introductionmentioning

confidence: 99%

Integrated CO2 Miscible Flooding-Storage Technologies for Complex Fault Block Reservoirs with Low Permeability

Yu¹,

Sun²,

Tang³

et al. 2023

Preprint

View full text Add to dashboard Cite

During the production process of complex fault block reservoirs with low permeability, the systematic research on the combination of oil displacement and storage is fuzzy. This work aims at oil displacement and storage to supplement formation energy and evaluate storage potential. Firstly, the optimal development scheme is designed by layer division and miscible and ability. Secondly, based on large amounts of field data, the novel FAHP evaluation system for CO2 storage site selection is established. Thirdly, since judging adaptability evaluation is suitable, the carbon storage simulation is conducted to contain mineralization, dissolved and structural mechanisms. The results indicate that after 1.2HCPV CO 2 injected cumulatively into reservoir, the cumulative oil increase reached 4001.80×10 4 m 3 and the final recovery rate was 44.46%, achieving a good effect. At the stage of injection, the CO2 capacity remaining in the reservoir was nearly 1657.53×10 4 t and the gas storage rate reached 43.84%. The novel evaluation system for CO 2 storage site selection shows that the target reservoir has more storage space, large injection capacity, high safety factor and low storage cost, which is allowed to storage. At the stage of storage, the effective storage capacity of target reservoir was 2257.48×10 4 t, of which the structural storage capacity was 73.43% and the mineral storage capacity was the least (3.46%). The average annual CO 2 storage capacity is about 225.74×10 4 t, which is equivalent to planting 2031.69×10 4 t trees or shutting down 135.69×10 4 cars for one year, achieving oil displacement/storage synergetic optimization. The findings of this study can offer engineers guidance for ensuring the long-term, stable and safe operation of CO 2 storage. For complex fault block reservoirs with low permeability "green, low-carbon, efficient" development has a certain reference.

show abstract

Microscopic Flow Characteristics of Immiscible CO2 Flooding and CO2 Foam Flooding After Water Flooding in Fractured Porous Media: A Visual Investigation

Tang

Hou

et al. 2023

Transp Porous Med

View full text Add to dashboard Cite

A novel type curve for estimating oil recovery factor of gas flooding

Cited by 6 publications

References 15 publications

Establishment of Stability Evaluation Criteria for the Oil–Gas Interface during Gas-Cap Gravity Flooding in Oil Reservoirs with Strong Edge-Water Drive

Establishment of Stability Evaluation Criteria for the Oil–Gas Interface during Gas-Cap Gravity Flooding in Oil Reservoirs with Strong Edge-Water Drive

Integrated CO2 Miscible Flooding-Storage Technologies for Complex Fault Block Reservoirs with Low Permeability

Microscopic Flow Characteristics of Immiscible CO2 Flooding and CO2 Foam Flooding After Water Flooding in Fractured Porous Media: A Visual Investigation

Contact Info

Product

Resources

About