Comprehensive Study of Gas Cycling in the Bakken Shale

Sanaei, Alireza; Abouie, Ali; Tagavifar, Mohsen; Sepehrnoori, Kamy

doi:10.15530/urtec-2018-2902940

Cited by 16 publications

(17 citation statements)

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“…Sanaei et al compared four gases (CO 2 , N 2 , methane, and an 85% methane–15% ethane mixture) in a study of huff-n-puff in the Middle Bakken. Repressurization and oil swelling (not diffusion) were identified as the dominant mechanisms of oil recovery (Table , entry 21) . Because the injection pressure of 48 MPa was well above the MMP of all of these fluids, they yielded nearly identical oil recovery results except for CO 2 , which recovered slightly more oil.…”

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

“…For example, several reports suggest that CO 2 and other EOR fluids are more miscible with oil when confined in nanopores. ,, Insights can also be extended to the field scale using simulations. For example, many simulation studies agree that EOR should not be started until primary production is complete, ,,, closer fracture spacing can improve recovery, ,,,, and numerous short cycles can recover more oil than one long cycle. ,,,,,,, Often, conclusions from simulation studies are supported by observations in laboratory-scale experiments. For example, several simulation reports state that injection pressures at or above the MMP for a given gas can improve oil recovery, ,,,,, that a rich natural gas can improve oil recovery over methane alone, ,,,,, and that increasing the surface area of the rock exposed to EOR fluid can increase recovery. ,,, In many cases, however, simulation studies reach conflicting conclusions.…”

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

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A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

et al. 2020

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Primary oil recovery from fractured unconventional formations, such as shale or tight sands, is typically less than 10%. The development of an economically viable enhanced oil recovery (EOR) technique applicable to unconventional liquid reservoirs (ULRs) would lead to tremendous increases in domestic oil production. Although injection techniques such as waterflooding and CO2 EOR have proven profitable in conventional formations for decades, EOR in ULRs presents a far more difficult challenge. The extremely low permeability and mixed wettability of unconventional formations are the foremost obstacles to success. Because of the challenges associated with water-based EOR techniques (a.k.a., chemical EOR) in shale, several nonaqueous injection fluids have been considered, including CO2, natural gas, and (to a lesser degree) nitrogen. All these fluids have significantly lower viscosities than water, allowing them to more easily penetrate shale nanopores. Unlike water, they also each possess some degree of miscibility with oil, which enables the gas to extract oil through a combination of mechanisms. Based on laboratory-scale experimentation, CO2 and rich natural gas (methane-rich natural gas containing high concentrations of ethane, propane, and butane) are the most promising EOR fluids. The interpretation of results from field tests in the Bakken and Eagle Ford formations have been complicated by interference of frac-hits or well-bashing caused by hydraulic fracturing at nearby wells. In this review we cover mechanisms, laboratory experiments, numerical simulations, and field tests involving high-pressure CO2, natural gas, ethane, nitrogen, and water.

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Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

et al. 2020

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“…Considering the significantly higher gas injection and production rates of Case 2 compared with those of Case 3, it is quite interesting how a faster-paced production does not always result in a higher oil recovery. It can be hypothesized that there is some kind of "sweet spot" where the right optimum production conditions returns the highest recovery, 15 and not only oil recovery can be increased, but also it can be increased with less resources spent. Figure 12 indicates that most of the injected gas in a huff-npuff cycle will be recovered back during huff-n-puff production cycles.…”

Section: Resultsmentioning

confidence: 99%

Optimization of Huff-n-Puff Field Gas Enhanced Oil Recovery through a Vertical Well with Multiple Fractures in a Low-Permeability Shale–Sand–Carbonate Reservoir

et al. 2020

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This study aims at identifying some of the potential contributors to increase oil recovery through field gas huff-n-puff in a thick, heterogeneously layered, and low-permeability shale–sand–carbonate reservoir. It has been observed that the composition of the produced volume is important. At least in some cases, more oil volume can be obtained in standard conditions by optimizing the composition of the produced volume. The general trend is that the more heavy components are produced, the more oil volume will be obtained in standard conditions. Furthermore, the optimum pressure for a given reservoir composition, which may vary during the enhanced oil recovery time frame, can be determined by conducting a sensitivity study. The optimum pressure is the pressure that is able to facilitate the production of heavy components as much as possible. This optimum pressure can then be translated to controllable operation parameters. The production of the heavy components can be increased with huff-n-puff gas injection by producing more oil or gas volume in reservoir conditions relative to that in primary production since both oil and gas phases bear some heavy components even though at different degrees. Despite bearing less heavy components, the gas phase can potentially compensate for such a shortcoming by having a higher mobility than the oil phase in reservoir conditions. All of these are intended to be achieved within the scope of numerical simulation.

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“…Several experiments have been conducted to study CO 2 interaction with oil and its ability to increase oil recovery during immiscible CO 2 injection (Tran et al 2019;Hao et al 2019;Alharthy et al 2018;Mahzari. et al 2019;Sanaei et al 2018;Fakher and Imqam 2020, b, c, d; Hoffman and Rutledge 2019). Svrcek and Mehrotra (1982); Svrcek et al (1989) performed experiments on extremely high molecular weight (MW) bitumen to investigate the impact of the CO 2 altering the bitumen's viscosity and density.…”

Section: Introductionmentioning

confidence: 98%

A simplified method for experimentally quantifying crude oil swelling during immiscible carbon dioxide injection

Fakher

Imqam

2020

J Petrol Explor Prod Technol

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Immiscible carbon dioxide (CO 2) injection is one of the highly applied enhanced oil recovery (EOR) methods due to its high oil recovery potential and its ability to store CO 2 in the reservoir. The main mechanism of immiscible CO 2 injection is oil swelling. Generally, oil swelling is measured experimentally or measured using modeling methods. This research conducts oil swelling experiments using a simplified method in order to easily and accurately measure oil swelling and determines some of the most significant factors that may impact oil swelling during CO 2 injection. The impact of varying CO 2 injection pressure, temperature, oil viscosity and oil volume on oil swelling capacity was investigated. The simplified method managed to accurately determine the value of oil swelling for all the experiments. One of the factors that was found to impact the method significantly was the oil volume used. The oil volume in the experimental vessel was found to be extremely important since a large oil volume may result in a false oil swelling value. The oil swelling results were compared to other researches and showed that the method applied had an accuracy of over 90% for all the results obtained. This research introduces a simple method that can be used to measure oil swelling and applies this method to investigate some of the factors that may impact the oil swelling capacity during immiscible CO 2 injection. Keywords Oil swelling • Immiscible carbon dioxide injection • Novel technique List of symbols S o Oil swelling V so Volume of swelled oil V uo Volume of unswelled oil P Pressure of CO 2 V Volume occupied by the experimental vessel z Compressibility factor of CO 2 n Number of moles R Universal gas constant T Temperature at which the experiment is conducted 1 Initial conditions at the beginning of the experiment 2 Final conditions after the experiment was concluded IFT Interfacial tension

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Comprehensive Study of Gas Cycling in the Bakken Shale

Cited by 16 publications

References 0 publications

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

Optimization of Huff-n-Puff Field Gas Enhanced Oil Recovery through a Vertical Well with Multiple Fractures in a Low-Permeability Shale–Sand–Carbonate Reservoir

A simplified method for experimentally quantifying crude oil swelling during immiscible carbon dioxide injection

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Comprehensive Study of Gas Cycling in the Bakken Shale

Cited by 16 publications

References 0 publications

A Literature Review of CO2, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Literature Review of CO2, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

Optimization of Huff-n-Puff Field Gas Enhanced Oil Recovery through a Vertical Well with Multiple Fractures in a Low-Permeability Shale–Sand–Carbonate Reservoir

A simplified method for experimentally quantifying crude oil swelling during immiscible carbon dioxide injection

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Product

Resources

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A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs