An Experimental Study on Huff-n-Puff Gas Injection to Enhance Condensate Recovery in Shale Gas Reservoirs

Meng, Xingbang; Yu, Yang; Sheng, James J.

doi:10.15530/urtec-2015-2153322

Cited by 8 publications

(8 citation statements)

References 27 publications

Supporting

Mentioning

Contrasting

Unclassified

Order By: Relevance

“…This schedule may not be applicable in operation since the operating company cannot get the investment return in a short period. Meng et al (2015) also illustrated the improvement of well production by CH 4 huff-puff in lab experiments, and concluded that the soaking period has no significant positive impact on the production increment.…”

Section: Introductionmentioning

confidence: 93%

“…Unlike the conventional reservoir, the gas flooding is not applicable in shale reservoir due to a low conductivity of tight reservoirs. Sheng et al (2015) have studies the potential of production increment by huff-n-puff gas injection in a shale condensate reservoir. The longer huff-n-puff period results in a larger production increment than the shorter period does.…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Yang

Wei²,

Chen

et al. 2016

All Days

View full text Add to dashboard Cite

With the production of a gas condensate tight reservoir, condensate in fracture can significantly decrease the productivity of gas condensate wells. Previous work shows that the negative effect of condensate bank on gas production is more seriously in tighter reservoir. The implement of hydraulic fracture and multi-stages fracturing can mitigate the negative effects on the formation of condensate bank, but the effects cannot be completely removed. A huff-n-puff methane injection has been proven to be an effective method to reduce the effect of condensate by maintaining the reservoir pressure above the dew-point pressure and revaporizing the formed condensate. However, the previous work neglects the effect of hydraulic fractures on the treatment of condensate by gas injection.Non-aqueous components are lumped into fourteen pseudo components. Dual permeability, logarithmically spaced, locally refined grids are implemented to model natural and hydraulic fractures in a simulation model. The laboratory measured relative permeability taking account of condensate bank is used to accurately represent two-phase flow in a shale reservoir. Furthermore, two different settings of cyclic schedule are implemented to test their advantages and disadvantages.The results show that the huff-n-puff dry gas injection can effectively improve gas and condensate recovery. A fracture conductivity has significant influences on well production during the injection, while during the primary recovery its impact is not that obvious. In addition, the huff-n-puff schedules also plays a crucial role in both gas and condensate recovery. Our study highlights gas injection mitigates the effect of condensate bank on gas production in a shale reservoir, and provides an extensive insight on optimal design of Huff-n-Puff gas injection.

show abstract

Section: Introductionmentioning

confidence: 93%

Section: Introductionmentioning

confidence: 99%

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Yang

Wei²,

Chen

et al. 2016

All Days

View full text Add to dashboard Cite

show abstract

“…During the soaking period, well is shut-in to allow time for mass transfer between the injected CO 2 and condensate phase. Previous studies show that the soaking times have no benefits and are actually detrimental to production for unconventional shale reservoirs (Meng et al 2015;Sheng et al 2016).…”

Section: Effect Of Storage and Transport Mechanismmentioning

confidence: 99%

Compositional Modeling of Enhanced Hydrocarbons Recovery for Fractured Shale Gas-Condensate Reservoirs with the Effects of Capillary Pressure and Multicomponent Mechanisms

Jiang

Younis

2016

All Days

View full text Add to dashboard Cite

There is considerable and timely interest in oil and condensate production from liquid-rich regions, placing emphasis on the ability to predict the behavior of gas condensate bank developments and saturation dynamics in shale gas reservoirs. As the pressure in the near-wellbore region drops below the dew-point, liquid droplets are formed and tend to be trapped in small pores. It has been suggested that the injection of CO 2 into shale gas reservoirs can be a feasible option to enhance recovery of natural gas and valuable condensate oil, while at the same time sequestering CO 2 underground. This work develops simulation capabilities to understand and predict complex transport processes and phase behavior in these reservoirs for efficient and environmentally friendly production management.Although liquid-rich shale plays are economically producible, existing simulation techniques fail to include many of the production phenomena associated with the fluid system that consists of multiple gas species or phases. In this work, we develop a multicomponent compositional simulator for the modeling of gas-condensate shale reservoirs with complex fracture systems. Related storage and transport mechanisms such as multicomponent apparent permeability (MAP), sorption and molecular diffusion are considered. In order to accurately capture the complicated phase behavior of the multiphase fluids, an equation of State (EOS) based phase package is incorporated into the simulator. Due to the large capillary pressure that exists in the nanopores of ultra-tight shale matrix, the phase package considers the effect of capillary pressure on phase equilibrium calculations. A modified negative-flash algorithm that combines Newton's method and successive substitution iteration (SSI) is used for phase stability analysis under the effect of capillary pressure between oil and gas phases.In addition, a lower-dimensional discrete fracture and matrix (DFM) model is implemented. The DFM model is based on unstructured gridding, and can accurately and efficiently handle the non-ideal geometries of hydraulic fracture in stimulated unconventional formation. Optimized local grid refinement (LGR) is employed to capture the extremely sharp potential gradient and saturation dynamics in the ultra-tight matrix around fracture.We apply the developed simulator to study the combined effects of capillary pressure and multicomponent storage and transport mechanisms that are closely associated with the phase behavior and hydrocarbon recovery in gas-condensate shale reservoirs. We present preliminary simulation studies to show the applicability of CO 2 huff-n-puff for the purpose of enhanced hydrocarbons recovery. Several design components such as the number of cycles and the length of injection period in the huff-n-puff process are also briefly investigated.

show abstract

“…At the same time, the accumulation of condensate in the bottomhole zone and at the bottom of the wells can lead to a decrease in their productivity and subsequent premature shutdown. The coefficient of final condensate recovery in the development of gas condensate fields at the depletion drive is only 13-40% [1,2].…”

Section: Introductionmentioning

confidence: 99%

“…Maintenance of the reservoir pressure in gas condensate fields can be carried out by revers injection of separated (dry) gas, use of dry gas of oil fields, non-hydrocarbon gases (nitrogen, carbon dioxide, air, flue and exhaust gases), artificial hydrocarbons which is obtained by hydrocarbon conversion by water steam, mixtures of hydrocarbon and non-hydrocarbon gases, of water and gas-water mixtures injection. [1,[3][4][5][6][7][8][9][10][11].…”

Section: Introductionmentioning

confidence: 99%

Investigation of the efficiency of gas condensate reservoirs waterflooding at different stages of development

Burachok

Kondrat

Matkivskyi³

2021

E3S Web of Conf.

View full text Add to dashboard Cite

The study of flooding gas condensate reservoirs at different stages of depletion (25, 50, 75% of the dew point pressure and at the maximum condensation pressure) with different potential hydrocarbon content of 100, 300 and 500 g/m3 and different voidage replacement by using injection (50, 100 and 150%). The results showed a positive effect of water injection on the increase of the condensate recovery factor, but a decrease in gas production compared to the basic options of development at depletion drive. Thus, for formation systems with medium and high potential yield of liquid hydrocarbons C5+, the largest incremental production is obtained in the case when water injection begins with minimum depletion of formation energy. While for a formation system with a low potential yield (100 g/m3) the maximum technological effect is obtained under the condition of maximum depletion. In the case of medium and high C5+ yield in the formation gas, with a slight decrease in the formation pressure by 25 or 50% of the dew point pressure, the maximum increase in the condensate recovery factor is achieved at high injection rates with 100 or 150% voidage replacement. The obtained results can be used for rapid screening of potential methods of impact on the gas condensate reservoir, and the final decision concerning the technological parameters of production and injection wells operation will be made due to the results of optimization of multivariate hydrodynamic calculations using geological and technological models.

show abstract

An Experimental Study on Huff-n-Puff Gas Injection to Enhance Condensate Recovery in Shale Gas Reservoirs

Cited by 8 publications

References 27 publications

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Effects of Hydraulic Fractures on the Treatment of Condensate by Huff-n-Puff Gas Injection in Eagle Ford Shale

Compositional Modeling of Enhanced Hydrocarbons Recovery for Fractured Shale Gas-Condensate Reservoirs with the Effects of Capillary Pressure and Multicomponent Mechanisms

Investigation of the efficiency of gas condensate reservoirs waterflooding at different stages of development

Contact Info

Product

Resources

About