Improving Oil Recovery Using Miscible Selective Simultaneous Water Alternating Gas (MSSWAG) Injection in One of the Iranian Reservoirs

Farahani, Zohreh Dermanaki; Movaghar, Mohammad Reza Khorsand

doi:10.1007/s13369-017-2667-z

Cited by 3 publications

(2 citation statements)

References 6 publications

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“…The first phase of the petroleum industry is to perform detailed exploration-based geological surveys at various locations. Drilling procedures and a careful analysis of the oil reserve are performed in the next phase by analysing the exploration [12][13][14][15]. The extraction of oil from the well and the preliminary phase separation processes are implemented after developing the drilling facility.…”

Section: Introductionmentioning

confidence: 99%

Process system analysis on oil processing facility and economic viability from oil well-to-tank

et al. 2021

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Hydrocarbon processing from extraction to the final product is an important aspect that needs an optimised technology for consumption-led market growth. This study investigated real data from the oil processing facility and analysed the simulation model for the entire crude oil processing unit based on the process system engineering aspect using Aspen HYSYS. The study mainly emphasises the process optimisation in processing the hydrocarbon for the maximum yield of the product with less energy consumption. The investigation also includes a thorough economic analysis of the processing facility. The datasets for oil properties are obtained from a modern petroleum refinery. The investigation comprises of varying transient conditions, such as well shutdowns using three oil reservoirs (low, intermediate, and heavy oil). The impact of various conditions, including process heating, well shutdown, oil combinations, presence of water on the production, is analysed. The results indicate that the factors involving crude oil processing are significantly affected by the process conditions, such as pressure, volume, and temperature. The vapour recovery unit is integrated with the oil processing model to recover the separator's gas. The optimisation analysis is performed to maximise the liquid recovery with Reid vapour pressure of 7 and minimum water content in oil around 0.5%. Economic analysis provided an overall capital cost of $ 9.7 × 106 and an operating cost of $2.1 × 106 for the process configuration. The model results further investigate the constraints that maximise the overall energy consumption of the process and reduce the operational cost.

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Section: Introductionmentioning

confidence: 99%

Process system analysis on oil processing facility and economic viability from oil well-to-tank

et al. 2021

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“…In this study, the aqueous solution of formate ions, referred to as a formate solution, combined with CO2 (injected as a gas from the surface) was evaluated to support the gravity control of the plume in porous media, unlike Oyenowo et al s work [29], who evaluated only a formate injection as a carbon carrier. The following three combined strategies were tested: (1) a pre-flush of the formate solution slug preceding the continuous CO2 injection; (2) injecting the formate solution slug in a continuous or alternated way with CO2; and (3) injecting formate solution simultaneously with CO2 using a dual completion well similar to that in simultaneous water alternating gas injection projects [30]. All our simulations considered the mentioned secondary trapping mechanisms in two geological models, a synthetic one and an actual aquifer in Brazil, with little evidence of effective caprock.…”

Section: Introductionmentioning

confidence: 99%

A Strategy for Enhanced Carbon Storage: A Hybrid CO2 and Aqueous Formate Solution Injection to Control Buoyancy and Reduce Risk

Barbosa Machado,

Delshad,

Carrasco Jaim

et al. 2024

Energies

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Conventional Carbon Capture and Storage (CCS) operations use the direct injection of CO2 in a gaseous phase from the surface as a carbon carrier. Due to CO2 properties under reservoir conditions with lower density and viscosity than in situ brine, CO2 flux is mainly gravity-dominated. CO2 moves toward the top and accumulates below the top seal, thus reinforcing the risk of possible leakage to the surface through unexpected hydraulic paths (e.g., reactivated faults, fractures, and abandoned wells) or in sites without an effective sealing caprock. Considering the risks, the potential benefits of the interplay between CO2 and an aqueous solution of formate ions (HCOO¯) were evaluated when combined to control CO2 gravity segregation in porous media. Three combined strategies were evaluated and compared with those where either pure CO2 or a formate solution was injected. The first strategy consisted of a pre-flush of formate solution followed by continuous CO2 injection, and it was not effective in controlling the vertical propagation of the CO2 plume. However, the injection of a formate solution slug in a continuous or alternated way, simultaneously with the CO2 continuous injection, was effective in slowing down the vertical migration of the CO2 plume and keeping it permanently stationary deeper than the surface depth.

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An experimental study of alternative hot water alternating gas injection in a fractured model

Ebadati

Akbari

Davarpanah

2018

Energy Exploration & Exploitation

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Alternative injection of gas as slugs with water slugs, or alternative water gas injection, is the conventional technique for improving the recovery factor due to its high potential for mobilizing the residual oil in place in the reservoirs and to control gas mobility. The water alternating gas methodology is a combination of two oil recovery procedures: gas injection and waterflooding. The principal parameters that must be evaluated in water alternating gas injection in laboratory scale are reservoir heterogeneity, rock type, and fluid properties. In the current investigation, a feasibility study has been performed to analyze the five various scenarios of enhanced oil recovery techniques and compare them experimentally. The laboratory experiments are done for one of the Iranian reservoirs which have been subjected to waterflooding for several years, and the amount of recovery factor for water flooding is about 42%. The results of this study illustrate that water alternating gas injection and hot water alternating gas injection exert a profound impact on the amount of recovery factor. Moreover, the primary purpose of this study is to assess the application of alternative hot water and hot carbon dioxide gas injections in the conventional and fractured reservoir model.

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Improving Oil Recovery Using Miscible Selective Simultaneous Water Alternating Gas (MSSWAG) Injection in One of the Iranian Reservoirs

Cited by 3 publications

References 6 publications

Process system analysis on oil processing facility and economic viability from oil well-to-tank

Process system analysis on oil processing facility and economic viability from oil well-to-tank

A Strategy for Enhanced Carbon Storage: A Hybrid CO2 and Aqueous Formate Solution Injection to Control Buoyancy and Reduce Risk

An experimental study of alternative hot water alternating gas injection in a fractured model

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