Extraction of Oil From Bakken Shale Formations With Supercritical CO2

Jin, Lu; Hawthorne, Steven B.; Sorensen, James A.; Pekot, Lawrence J.; Kurz, Bethany A.; Smith, Steven A.; Heebink, Loreal V.; Bosshart, Nicholas W.; Torres, José Antonio Marina; Dalkhaa, Chantsalmaa; Gorecki, Charles D.; Steadman, Edward N.; Harju, John A.

doi:10.15530/urtec-2017-2671596

Cited by 27 publications

(17 citation statements)

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“…Water floods, commonly being used in conventional reservoirs as an improved oil recovery (IOR) method, has been proven to be unfeasible in tight unconventional shale formations [17,27]. In the past decade, gas injection, including huff-n-puff injection or cyclic gas injection, and gas flooding, has been demonstrated to be a promising EOR method for shale reservoirs and has been extensively studied in oil and gas research laboratories and widely modeled through numerical simulation methods by many researchers [8][9][10][11][12]14,16,17]. We review the recent research progress on gas injection in shale oil reservoirs through huff-n-puff (Section 2.1.1) and gas flooding (Section 2.1.2) methods and summarize the gas injection mechanisms in Section 2.1.3.…”

Section: Enhanced Oil Recovery Methodsmentioning

confidence: 99%

“…The experimental study of huff-n-puff gas injection or cyclic gas injection in tight rock samples have been conducted in multiple publications [9,11,28]. The schematic diagram of an experimental setup for gas flooding and huff-n-puff gas injection is shown in Figure 2.…”

Section: Huff-n-puff Gas Injection Performance Evaluationmentioning

confidence: 99%

“…The commonly used injection gases or solvents are N 2, CO 2 , CH 4 , C 2 H 6 , andCH 4 /C 2 H 6 mixture. The core plug samples were mostly selected from Eagle Ford [9,28], Bakken [10,11,29,30], and Barnett and Marcos [31]. As shown in Table 1, Middle Bakken has a relatively large permeability [10,29,30] compared to other shales.…”

Section: Huff-n-puff Gas Injection Performance Evaluationmentioning

confidence: 99%

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A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

Nojabaei

2019

Energies

112

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Shale oil and gas resources contribute significantly to the energy production in the U.S. Greenhouse gas emissions come from combustion of fossil fuels from potential sources of power plants, oil refineries, and flaring or venting of produced gas (primarily methane) in oilfields. Economic utilization of greenhouse gases in shale reservoirs not only increases oil or gas recovery, but also contributes to CO2 sequestration. In this paper, the feasibility and efficiency of gas injection approaches, including huff-n-puff injection and gas flooding in shale oil/gas/condensate reservoirs are discussed based on the results of in-situ pilots, and experimental and simulation studies. In each section, one type of shale reservoir is discussed, with the following aspects covered: (1) Experimental and simulation results for different gas injection approaches; (2) mechanisms of different gas injection approaches; and (3) field pilots for gas injection enhanced oil recovery (EOR) and enhanced gas recovery (EGR). Based on the experimental and simulation studies, as well as some successful field trials, gas injection is deemed as a potential approach for EOR and EGR in shale reservoirs. The enhanced recovery factor varies for different experiments with different rock/fluid properties or models incorporating different effects and shale complexities. Based on the simulation studies and successful field pilots, CO2 could be successfully captured in shale gas reservoirs through gas injection and huff-n-puff regimes. The status of flaring gas emissions in oilfields and the outlook of economic utilization of greenhouse gases for enhanced oil or gas recovery and CO2 storage were given in the last section. The storage capacity varies in different simulation studies and is associated with well design, gas injection scheme and operation parameters, gas adsorption, molecular diffusion, and the modelling approaches.

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Section: Enhanced Oil Recovery Methodsmentioning

confidence: 99%

Section: Huff-n-puff Gas Injection Performance Evaluationmentioning

confidence: 99%

Section: Huff-n-puff Gas Injection Performance Evaluationmentioning

confidence: 99%

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A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

Nojabaei

2019

Energies

112

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“…Therefore, the application of enhanced oil and enhanced gas recovery technologies is still required to further improve the displacement of remaining hydrocarbons (Sheng 2015). Carbon dioxide assisted recovery technologies such as supercritical extraction (Jin et al 2017), CO 2 injection either via huff and puff (Alfarge et al 2018) or CO 2 flooding (Wang et al 2010) exploit the favorable physical and chemical properties of CO 2 at reservoir conditions, where it commonly exists above its critical point (31.1 °C,7.38 MPa). Supercritical CO 2 (sc-CO 2 ) is characterized by high diffusivity, low viscosity and higher miscibility in crude oils relative to other gases (Lan et al 2019) and is consequently responsible for promoting oil phase swelling (Samara and Jaeger 2021), as well as the reduction in viscosity and interfacial tension (IFT) (Perera et al 2016), which contribute to improved displacement of residual oil that would otherwise remain unrecovered.…”

Section: Introductionmentioning

confidence: 99%

Carbon dioxide adsorption and interaction with formation fluids of Jordanian unconventional reservoirs

Samara

Ostrowski²,

Abdulkareem

et al. 2021

J Petrol Explor Prod Technol

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Shales are mostly unexploited energy resources. However, the extraction and production of their hydrocarbons require innovative methods. Applications involving carbon dioxide in shales could combine its potential use in oil recovery with its storage in view of its impact on global climate. The success of these approaches highly depends on various mechanisms taking place in the rock pores simultaneously. In this work, properties governing these mechanisms are presented at technically relevant conditions. The pendant and sessile drop methods are utilized to measure interfacial tension and wettability, respectively. The gravimetric method is used to quantify CO2 adsorption capacity of shale and gas adsorption kinetics is evaluated to determine diffusion coefficients. It is found that interfacial properties are strongly affected by the operating pressure. The oil-CO2 interfacial tension shows a decrease from approx. 21 mN/m at 0.1 MPa to around 3 mN/m at 20 MPa. A similar trend is observed in brine-CO2 systems. The diffusion coefficient is observed to slightly increase with pressure at supercritical conditions. Finally, the contact angle is found to be directly related to the gas adsorption at the rock surface: Up to 3.8 wt% of CO2 is adsorbed on the shale surface at 20 MPa and 60 °C where a maximum in contact angle is also found. To the best of the author’s knowledge, the affinity of calcite-rich surfaces toward CO2 adsorption is linked experimentally to the wetting behavior for the first time. The results are discussed in terms of CO2 storage scenarios occurring optimally at 20 MPa.

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“…The value of enhanced oil recovery (EOR) for unconventional reservoirs like the Bakken and Eagle Ford was noted early in the production of these reservoirs [7,8], and there has been significant research over the last decade on this topic (summaries in Alfarge et al [9] and Kanfar et al [10]). Much of this early work was done in the laboratory (e.g., Jin et al [11] and Tovar et al [12]) or with numerical models (e.g., Li et al [13] and Gala and Sharma [14]), where they looked at questions of overall recovery, the type of gas, soak time, vaporization, and utilization.…”

Section: Introductionmentioning

confidence: 99%

Recovery Mechanisms for Cyclic (Huff-n-Puff) Gas Injection in Unconventional Reservoirs: A Quantitative Evaluation Using Numerical Simulation

Hoffman

Reichhardt

2020

Energies

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Unconventional reservoirs produce large volumes of oil; however, recovery factors are low. While enhanced oil recovery (EOR) with cyclic gas injection can increase recovery factors in unconventional reservoirs, the mechanisms responsible for additional recovery are not well understood. We examined cyclic gas injection recovery mechanisms in unconventional reservoirs including oil swelling, viscosity reduction, vaporization, and pressure support using a numerical flow model as functions of reservoir fluid gas–oil ratio (GOR), and we conducted a sensitivity analysis of the mechanisms to reservoir properties and injection conditions. All mechanisms studied contributed to the additional recovery, but their significance varied with GOR. Pressure support provides a small response for all fluid types. Vaporization plays a role for all fluids but is most important for gas condensate reservoirs. Oil swelling impacts low-GOR oils but diminishes for higher-GOR oil. Viscosity reduction plays a minor role for low-GOR cases. As matrix permeability and fracture surface area increase, the importance of gas injection decreases because of the increased primary oil production. Changes to gas injection conditions that increase injection maturity (longer injection times, higher injection rates, and smaller fracture areas) result in more free gas and, for these cases, vaporization becomes important. Recovery mechanisms for cyclic gas injection are now better understood and can be adapted to varying conditions within unconventional plays, resulting in better EOR designs and improved recovery.

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Extraction of Oil From Bakken Shale Formations With Supercritical CO2

Cited by 27 publications

References 0 publications

A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control

Carbon dioxide adsorption and interaction with formation fluids of Jordanian unconventional reservoirs

Recovery Mechanisms for Cyclic (Huff-n-Puff) Gas Injection in Unconventional Reservoirs: A Quantitative Evaluation Using Numerical Simulation

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