Optimizing Oil Recovery and Carbon Dioxide Storage in Heavy Oil Reservoirs

Sobers, Lorraine; LaForce, Tara; Blunt, Martin J.

doi:10.2118/132795-ms

Cited by 5 publications

(2 citation statements)

References 12 publications

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“…This work assumed that the CO 2 and oil were first-contact miscible; in this case, we propose an injection design derived from a heavy-oil sample that is immiscible with the CO 2 . The relative permeabilities used in simulations were presented in previous work (Sobers et al 2010) on the basis of history matching of sandpack-flooding experiments performed by Dyer and Farouq Ali (1994).…”

Section: Introductionmentioning

confidence: 99%

“…In previous work (Sobers et al 2010), we found that carbon storage and heavy-oil recovery can occur simultaneously using water-alternating-gas (WAG) injection but are sensitive to fluidinjection rates. A closer look at the results revealed the dependence of oil recovery and carbon storage on the extent of the mixing zone, which in turn is a function of injection rate, water/gas ratio, and slug sizes.…”

Section: Introductionmentioning

confidence: 99%

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Design of Simultaneous Enhanced Oil Recovery and Carbon Dioxide Storage With Potential Application to Offshore Trinidad

2013

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We developed an injection strategy to recover moderately heavy oil and store carbon dioxide (CO 2 ) simultaneously. Our compositional simulations are founded on pressure/volume/temperature-(PVT-) matched properties of oil found in an unconsolidated deltaic sandstone deposit in the Gulf of Paria, offshore Trinidad. In this region, oil density ranges between 940 and 1010 kg/m 3 (9 to 18 API). We use countercurrent injection of gas and water to improve reservoir sweep and trap CO 2 simultaneously; water is injected in the upper portion of the reservoir, and gas is injected in the lower portion. The two water-injection rates investigated, 100 and 200 m 3 /d, correspond to the water-gravity numbers 6.3 to 3.1 for our reservoir properties. We applied this injection strategy using vertical producers with two injection configurations: single vertical injector and a pair of horizontal parallel laterals in a simplified representation of the unconsolidated Forest sand found offshore Trinidad. Twelve simulation runs were conducted, varying injection-gas composition for miscible-and immiscible-gas drives, water-injection rate, and injection-well orientation. Our results show that water-over-gas injection can realize oil recoveries ranging from 17 to 30%. In each instance, more than 50% of injected CO 2 remained in the reservoir, with less than 15% of the retained CO 2 in the mobile phase.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Design of Simultaneous Enhanced Oil Recovery and Carbon Dioxide Storage With Potential Application to Offshore Trinidad

2013

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Synergistic Mechanism of Hydrolyzed Polyacrylamide Enhanced Branched-Preformed Particle Gel for Enhanced Oil Recovery in Mature Oilfields

Zhao

et al. 2018

Energy Fuels

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Branched-preformed particle gel (B-PPG) is a novel agent for EOR application in mature reservoirs. To improve the enhanced oil recovery (EOR) performance of B-PPG, the heterogeneous combination flooding system composed of B-PPG, hydrolyzed polyacrylamide (HPAM), and surfactant was proposed. However, the synergistic mechanism of B-PPG and HPAM still remains unclear. Here, a series of experiments were performed to study the viscosities of HPAM, B-PPG, and mixture of HPAM and B-PPG, evaluate the suspension stability of B-PPG and mixture of HPAM and B-PPG, to investigate the propagation behavior of HPAM, B-PPG, and a mixture of HPAM and B-PPG through porous media, and to study the EOR performance of HPAM, B-PPG, and a mixture of HPAM and B-PPG in heterogeneous reservoirs by performing parallel sand pack flooding experiments. Results show that the suspension stability of B-PPG can be improved by adding polymer due to the increase in viscosity. The higher the HPAM concentration is, the higher viscosity of mixture of HPAM and B-PPG suspension and the better the suspension stability is. Due to the lubrication and increased viscosity effect of the polymer, compared with the B-PPG suspension, the HPAM enhanced B-PPG suspension can be more easily injected into the porous media and can propagate through porous media. The propagation behavior of HPAM enhanced B-PPG through porous media is achieved by blocking, deforming, and passing through the pore throat. EOR performance results in a heterogeneous reservoir demonstrate that HPAM enhanced B-PPG flooding shows better sweep efficiency improvement ability and recovers more remaining oil left unswept in the low permeability zones.

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Design of Simultaneous Enhanced Oil Recovery and Carbon Dioxide Storage Applied to a Heavy Oil Field Offshore Trinidad

Sobers

Blunt

LaForce

2011

SPE Annual Technical Conference and Exhibition

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We have developed an injection strategy to recover moderately heavy oil and store carbon dioxide (CO2) simultaneously. Our compositional simulations are based on PVT-matched properties of oil found in an unconsolidated deltaic, sandstone deposit in the Gulf of Paria, offshore Trinidad. In this region oil density ranges between 940 and 1 010 kg/m3 (9-18 degrees API). We use counter-current injection of gas and water to improve reservoir sweep and trap CO2 simultaneously; water is injected in the upper portion of the reservoir and gas is injected in the lower portion. The two water injection rates investigated, 100 and 200m3/d, correspond to water gravity numbers 6.3 to 3.1 for our reservoir properties. We have applied this injection strategy using vertical producers with two injection configurations: single vertical injector and a pair of horizontal parallel laterals. Eight simulation runs were conducted varying injection gas composition for miscible and immiscible gas drives, water injection rate and injection well orientation. Our results show that water over gas injection can realize oil recoveries ranging from 17 to 30%. In each instance more than 50% of injected CO2 remained in the reservoir with less than 15% of that retained CO2 in the mobile phase.

show abstract

Optimizing Oil Recovery and Carbon Dioxide Storage in Heavy Oil Reservoirs

Cited by 5 publications

References 12 publications

Design of Simultaneous Enhanced Oil Recovery and Carbon Dioxide Storage With Potential Application to Offshore Trinidad

Design of Simultaneous Enhanced Oil Recovery and Carbon Dioxide Storage With Potential Application to Offshore Trinidad

Synergistic Mechanism of Hydrolyzed Polyacrylamide Enhanced Branched-Preformed Particle Gel for Enhanced Oil Recovery in Mature Oilfields

Design of Simultaneous Enhanced Oil Recovery and Carbon Dioxide Storage Applied to a Heavy Oil Field Offshore Trinidad

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