Screening Criteria for Carbon Dioxide Huff ‘n’ Puff Operations

Mohammed-Singh, Lorna J.; Singhal, A.K.; Sim, S.S.K.

doi:10.2118/100044-ms

Cited by 39 publications

(20 citation statements)

References 19 publications

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“…Moreover, built upon the knowledge learned from the Mervin CO 2 -EOR pilot, the operator is planning on conducting two more projects in heavy-oil reservoirs in Tangleflags and Lashburn, Saskatchewan (CCS101 2011). Another encouraging fact is the success of a huff 'n' puff test reported by an operator in Trinidad and Tobago (Mohammed-Singh et al 2006).…”

Section: Discussion On Other Eor Methodsmentioning

confidence: 93%

“…On the other hand, the reservoir pressure at the Morgan field is quite low, which limits the amount of CO 2 that can move into solution to swell the oil and reduce its viscosity. Finally, the solvent-injection trials seem to have been performed on lighter fluids than in the Morgan field (Selby et al 1989;Mohammed-Singh et al 2006); therefore, their success cannot be extrapolated directly to such a heavier fluid.…”

Section: Discussion On Other Eor Methodsmentioning

confidence: 99%

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Oil Recovery From Thin Heavy-Oil Reservoirs: The Case of the Combined-Thermal-Drive Pilot in the Morgan Field

Gutiérrez¹,

Ursenbach

Moore

et al. 2013

Journal of Canadian Petroleum Technology

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The Morgan field in Canada produces from the Lloydminster and Sparky sands, which are thin heavy-oil reservoirs. Early development of the pool was with primary vertical wells in the late 1970s, with some enhanced-oil-recovery (EOR) projects [e.g., cyclicsteam stimulations (CSSs) and in-situ combustion (ISC)] attempted in the early 1980s. However, the area was essentially noncommercial after the 1986 oil-price collapse. In order to regain commerciality, the operators implemented progressing cavity pumps (PCPs) and horizontal drilling, which have proved to be a success. Even with these advances, though, recovery is estimated to be less than 10% of the original oil in place (OOIP).One of the EOR projects attempted was the combined-thermal-drive (CTD) pilot, which was carried out in one of the sections of the field for 10 years. After a brief primary-production period, the CTD pilot began in 1980 and consisted of three stages. In the first stage, CSSs were performed on individual wells during the first 2 years. In the next 4 years, air was added to the injection stream to perform cyclic air/steam stimulations on individual wells. In the last stage, pressure cycling in-situ combustion was performed for approximately 4 years.In this paper, historical production and injection records were gathered to perform a technical and economic analysis of the project. After approximately 20 years since the shutdown of the project, the data indicate that this pilot has outperformed all of the other operations carried out in other areas of the field. Not only has it produced the largest amount of incremental oil of all the sections of the field, but it also managed to sustain high production rates for 10 years, which is unparalleled in the area. On the economic side, the data indicate that the project was experiencing difficulty because of the 1986 oil-price collapse. However, an economic analysis under current oil prices and costs suggests that it would have been both a technical and an economic success.This air-injection case history represents a good opportunity for those operators facing the challenge to develop thin heavy-oil reservoirs.

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Section: Discussion On Other Eor Methodsmentioning

confidence: 93%

Section: Discussion On Other Eor Methodsmentioning

confidence: 99%

Oil Recovery From Thin Heavy-Oil Reservoirs: The Case of the Combined-Thermal-Drive Pilot in the Morgan Field

Gutiérrez¹,

Ursenbach

Moore

et al. 2013

Journal of Canadian Petroleum Technology

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“…CO 2 injection is among the widely applied enhanced oil recovery (EOR) methods worldwide, and it has been successfully applied in conventional reservoirs . More than 130 CO 2 injection projects are operational around the world, and they have helped identify its key mechanisms, which are (a) oil viscosity reduction; (b) oil swelling due to CO 2 solution; (c) vaporization and extraction of lighter hydrocarbon component; (d) dissolved gas drive aided by gravity drainage; (e) reduction in two‐phase interfacial tensions to achieve miscible; and (f) permeability improvement by acidification effect . Therefore, CO 2 offers better injectivity to the rock matrix than the injected water, and it is more advantageous than other gases such as nitrogen gas.…”

Section: Introductionmentioning

confidence: 99%

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Wang

et al. 2019

Energy Science & Engineering

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This paper investigates the CO2/N2 injection process in tight oil reservoirs considering the confinement effect. To study the microscopic physical mechanisms, the confinement effect is characterized by properties shift and capillarity and introduced into the flash calculation to obtain the phase equilibrium of mixture fluids (tight oil/CO2/N2) in tight porous media. The results indicate that the injected nitrogen gas could effectively maintain the reservoir pressure, while it also weakens the effects of the CO2 injection recovery mechanisms, notably diffusivity and viscosity reduction. In addition, a dual‐pore tight oil reservoir model is set up to investigate the CO2/N2 injection with ultra‐low permeability and hydraulic fracturing. The basic CO2 injection parameters are optimized by the orthogonal method. Based on CO2 injection process, three injection schemes of CO2/N2 injection, which are mixed‐gas injection, CO2‐alternating‐N2 (CAN) injection, and N2‐alternating‐CO2 (NAC) injection, were investigated and a comparative analysis was made for the pressure distribution, CO2 mole fraction distribution, and cumulative oil production. Based on this analysis, the CAN injection process proved to be the best injection scheme. A parametric analysis further suggested that the nitrogen gas injection rate was the most important factor. Besides, the effect of gravity drainage, reservoir permeability, nature fractures, and permeability heterogeneity on the oil production of CAN injection process were also investigated in detail. The results show that tight oil reservoir with better vertical connectivity, poor fracture growth, and higher heterogeneity is more favorable for the CO2/N2 injection process.

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“…CO 2 ‐based enhanced oil recovery techniques have been widely used in conventional reservoirs, and the recovery mechanisms have been revealed. The main mechanisms of CO 2 injection include oil viscosity reduction, oil swelling, vaporization and extraction of lighter hydrocarbon components, dissolved gas drive aided by gravity drainage, and reduction of two‐phase interfacial tensions to achieve misciblility; (6) permeability improvement by acidification effect . However, the recovery mechanisms of CO 2 injection would be different because of the nanoscale pores, which have a great effect on fluid properties.…”

Section: Introductionmentioning

confidence: 99%

Impact of fluid property shift and capillarity on the recovery mechanisms of CO₂injection in tight oil reservoirs

Sarma

et al. 2019

Greenhouse Gases

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The phase equilibria with the confinement effect could shift in nano‐pores, which could have a great impact on the recovery mechanisms of CO2 injection in tight oil reservoirs; this has not been systematically studied. In this paper, the confinement effect with property shift and capillarity effect is introduced into the flash calculation of confined fluids. The Soave modification of the Redlich–Kwong equation of state is extended by the molecular‐wall collision parameter to describe the shifted pressure–volume–temperature properties of confined fluid, and the Young–Laplace equation is applied to evaluate the capillary pressure. This developed model could effectively be applied for phase equilibrium calculation in tight porous media because of the verification of experimental results. A binary mixture is investigated to study the different effect of capillary pressure and property shift on phase equilibria. Subsequently, a typical hydrocarbon fluid from Middle Bakken tight oil reservoirs is studied with CO2 injection. Results illustrate that the confinement effect could play an increasingly important part in the phase equilibrium state. The CO2 solubility and mass transfer driving force in tiny pores would be greater than those in large pores under the same conditions. The gas phase saturation would be smaller with the same compositions, which could extend the single‐phase region of fluid flow in porous media. Furthermore, bubble‐point pressure, the minimum miscible pressure of CO2/hydrocarbon, and the viscosity of tight oil dissolved with CO2 both decrease with the pore size, which has a good influence on tight oil recovery. In general, the confinement effect could effectively reinforce the recovery mechanisms of CO2 injection, which is conducive to the enhancement of tight oil recovery. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Screening Criteria for Carbon Dioxide Huff ‘n’ Puff Operations

Cited by 39 publications

References 19 publications

Oil Recovery From Thin Heavy-Oil Reservoirs: The Case of the Combined-Thermal-Drive Pilot in the Morgan Field

Oil Recovery From Thin Heavy-Oil Reservoirs: The Case of the Combined-Thermal-Drive Pilot in the Morgan Field

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Impact of fluid property shift and capillarity on the recovery mechanisms of CO₂injection in tight oil reservoirs

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Screening Criteria for Carbon Dioxide Huff ‘n’ Puff Operations

Cited by 39 publications

References 19 publications

Oil Recovery From Thin Heavy-Oil Reservoirs: The Case of the Combined-Thermal-Drive Pilot in the Morgan Field

Oil Recovery From Thin Heavy-Oil Reservoirs: The Case of the Combined-Thermal-Drive Pilot in the Morgan Field

Investigation of CO2/N2 injection in tight oil reservoirs with confinement effect

Impact of fluid property shift and capillarity on the recovery mechanisms of CO2injection in tight oil reservoirs

Contact Info

Product

Resources

About

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Impact of fluid property shift and capillarity on the recovery mechanisms of CO₂injection in tight oil reservoirs