Pressure Measurements for Monitoring CO2 Foam Pilots

Karakas, Metin; Alcorn, Zachary Paul; Aminzadeh, Fred; Graue, A.

doi:10.3390/en15093035

Cited by 3 publications

(3 citation statements)

References 32 publications

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“…However, the base case SAG's BHP values were significantly higher than the observed BHP, especially after the fourth SAG cycle. This suggests that the foam generated during the pilot was not as strong as in laboratory studies as also observed in [25]. In addition, the simulated BHP did not match the observed pressure fall-off after the seventh cycle because the model did not capture the effect of nearby production wells on injection BHP.…”

Section: Radial Model: Baseline Wag and Base Case Sagmentioning

confidence: 83%

“…As discussed previously, fmmob is the maximum gas mobility reduction that can be achieved with foam. Previous modeling results have shown that this parameter has the most impact on the simulated BHP [25].…”

Section: Foam Model Sensitivity Studymentioning

confidence: 91%

“…In addition, the sensitivity of foam model parameters on foam generation and propagation were studied. Previous simulation studies with the radial model have also been reported elsewhere [25]. The radial model was based upon a sector scale model that was history matched to the historical water and CO 2 injection periods in East Seminole Field [26].…”

Section: Modeling Methodsmentioning

confidence: 99%

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Unsteady-State CO2 Foam Generation and Propagation: Laboratory and Field Insights

et al. 2022

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This work presents a multiscale experimental and numerical investigation of CO2 foam generation, strength, and propagation during alternating injection of surfactant solution and CO2 at reservoir conditions. Evaluations were conducted at the core-scale and with a field-scale radial simulation model representing a CO2 foam field pilot injection well. The objective of the experimental work was to evaluate foam generation, strength, and propagation during unsteady-state surfactant-alternating-gas (SAG) injection. The SAG injection rapidly generated foam based upon the increased apparent viscosity compared to an identical water-alternating-gas (WAG) injection, without surfactant. The apparent foam viscosity of the SAG continually increased with each subsequent cycle, indicating continued foam generation and propagation into the core. The maximum apparent viscosity of the SAG was 146 cP, whereas the maximum apparent viscosity of the WAG was 2.4 cP. The laboratory methodology captured transient CO2 foam flow which sheds light on field-scale CO2 foam flow. The single-injection well radial reservoir simulation model investigated foam generation, strength, and propagation during a recently completed field pilot. The objective was to tune the model to match the observed bottom hole pressure data from the foam pilot and evaluate foam propagation distance. A reasonable match was achieved by reducing the reference mobility reduction factor parameter of the foam model. This suggested that the foam generated during the pilot was not as strong as observed in the laboratory, but it has propagated approximately 400 ft from the injection well, more than halfway to the nearest producer, at the end of pilot injection.

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Section: Radial Model: Baseline Wag and Base Case Sagmentioning

confidence: 83%

Section: Foam Model Sensitivity Studymentioning

confidence: 91%

Section: Modeling Methodsmentioning

confidence: 99%

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Unsteady-State CO2 Foam Generation and Propagation: Laboratory and Field Insights

et al. 2022

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Advancing geological storage of carbon dioxide (CO2) with emerging technologies for climate change mitigation

Eyitayo,

Arbad,

Okere

et al. 2024

Int. J. Environ. Sci. Technol.

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A Hybrid Scheme for the Sustainable Production of High Water Cut Unconventional Extra-Heavy Oil Reservoirs: First Simulation Predictions for the Orinoco Oil Belt-Venezuela Shows Hope!

Belhaj,

Rodriguez,

Bello

et al. 2024

Adipec

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The production of heavy, extra-heavy and bituminous crude oils with high-water cuts is a key challenge that requires applying technologies with high economic value and less environmental impact, especially, water management and CO2 emissions. This study proposes a hybrid production scheme based on chemical enhanced oil recovery (surfactant and polymer flooding), switching wells with high-water cut to produce geothermal energy, together with CO2 injection and eventually storage in a highly viscous oil reservoir in Venezuela. A cluster of wells of the Orinoco Oil Belt with marked variation in water cut and with recovery factors of less than 5% was selected for this study, where the current production methods are cold production, CSS (Cyclic Steam Stimulation) and downhole electrical heating. Laboratory tests were matched with the simulation of surfactant and polymer flooding, and CO2 injection (compositional model), independently. The lab tests were performed using fluid and rock samples from the evaluated cluster. Additionally, some wells were adapted/converted to predict the geothermal energy scope through a smart heat exchange process that is highly recommended to support clean energy production from these deposits. Finally, different injection and production schemes were tested and evaluated, and optimization of scenarios was reached. Results of this study show that the injection of surfactants and polymers in the same mixture, under secondary conditions, allows an increase in oil production in the selected cluster by virtue of mechanisms such as mobility control and mobilization of residual oil. The effect of the injected and stored CO2 on the recovery of hydrocarbons was assessed, as well as the possible mechanisms involved in this immiscible process. The application of deep-low temperature geothermal energy (enhanced by downhole electrical heating) is an appealing option for water management and clean energy production in the evaluated field. One of the greatest challenges of the hybrid method is associated with the simultaneous management of the CEOR, CCUS, and geothermal processes in both reservoir and at surface. This coupled with surface facilities operational challenges related to the management and separation of fluids, complex emulsions, water treatment, corrosion and scales, flow assurance issues, adequate heat-transfer throughout the production system; along with issues of reservoir caprock integrity for the CO2 storage as well as economic and process safety considerations. These real challenges will determine the faith and, hence, the implementation of the proposed hybrid scheme. This study proposes an innovative scheme to produce sustainable energy with low cost and environmental impact in the Orinoco Oil Belt, where the largest reserves of highly viscous crude oil on the planet are located. This study presents a methodology for water management, CCUS and exploitation of the geothermal energy from wells of high water cut and less value, which could be extrapolated to other deposits in Venezuela and worldwide.

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Pressure Measurements for Monitoring CO2 Foam Pilots

Cited by 3 publications

References 32 publications

Unsteady-State CO2 Foam Generation and Propagation: Laboratory and Field Insights

Unsteady-State CO2 Foam Generation and Propagation: Laboratory and Field Insights

Advancing geological storage of carbon dioxide (CO2) with emerging technologies for climate change mitigation

A Hybrid Scheme for the Sustainable Production of High Water Cut Unconventional Extra-Heavy Oil Reservoirs: First Simulation Predictions for the Orinoco Oil Belt-Venezuela Shows Hope!

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