The Impact of Condensate Blockage and Completion Fluids on Gas Productivity in Gas-Condensate Reservoirs

2005 ◽  
Author(s):  
Hamoud Ali Al-Anazi ◽  
J. Ricardo Solares ◽  
Mohammad Al-Faifi
Keyword(s):  
Gas Condensate ◽  
Gas Condensate Reservoirs ◽  
Condensate Blockage ◽  
Completion Fluids ◽  
The Impact

Effect of disjoining pressure on the onset of condensate blockage in gas condensate reservoirs

2012 ◽  
Vol 9 ◽  
pp. 160-165 ◽  
Author(s):  
Mohammad Mohammadi-Khanaposhtani ◽  
Alireza Bahramian ◽  
Peyman Pourafshary ◽  
Babak Aminshahidy ◽  
Babak Fazelabdolabadi
Keyword(s):  
Disjoining Pressure ◽  
Gas Condensate ◽  
Gas Condensate Reservoirs ◽  
Condensate Blockage

Effect of Non-Darcy Flow on Well Productivity of a Hydraulically Fractured Gas-Condensate Well

2009 ◽  
Vol 12 (04) ◽  
pp. 576-585 ◽  
Author(s):  
Jitendra Mohan ◽  
Gary A. Pope ◽  
Mukul M. Sharma
Keyword(s):  
Hydraulic Fracturing ◽  
Relative Permeability ◽  
Gas Condensate ◽  
Darcy Flow ◽  
Productivity Improvement ◽  
Well Productivity ◽  
Fracture Width ◽  
Gas Condensate Reservoirs ◽  
The Impact ◽  
Actual Fracture

Summary Hydraulic fracturing is a common way to improve productivity of gas-condensate wells. Previous simulation studies have predicted much larger increases in well productivity than have been actually observed in the field. This paper shows the large impact of non-Darcy flow and condensate accumulation on the productivity of a hydraulically fractured gas-condensate well. Two-level local-grid refinement was used so that very small gridblocks corresponding to actual fracture width could be simulated. The actual fracture width must be used to accurately model non-Darcy flow. An unrealistically large fracture width in the simulations underestimates the effect of non-Darcy flow in hydraulic fractures. Various other factors governing the productivity improvement such as fracture length, fracture conductivity, well flow rates, and reservoir parameters have been analyzed. Productivity improvements were found to be overestimated by a factor as high as three, if non-Darcy flow was neglected. Results are presented that show the impact of condensate buildup on long-term productivity of wells in both rich and lean gas-condensate reservoirs. Introduction A significant decline in productivity of gas-condensate wells has been observed, resulting from a phenomenon called condensate blocking. Pressure gradients caused by fluid flow in the reservoir are greatest near the production well. As the pressure drops below the dewpoint pressure, liquid drops out and condensate accumulates near the well. This buildup of condensate is referred to as a condensate bank. The condensate continues to accumulate until a steady-state two-phase flow of condensate and gas is achieved. This condensate buildup decreases the relative permeability to gas, thereby causing a decline in the well productivity. Afidick et al. (1994) studied the Arun field in Indonesia, which is one of the largest gas-condensate reservoirs in the world. They concluded that a significant loss in productivity of the reservoir after 10 years of production was caused by condensate blockage. They found that condensate accumulation caused well productivity to decline by approximately 50%, even for this very lean gas. Boom et al. (1996) showed that even for a lean gas (e.g., less than 1% liquid dropout) a relatively high liquid saturation can build up in the near-wellbore region. Liquid saturations near the well can reach 50 to 60% under pseudosteady-state flow of gas and condensate (Cable et al. 2000; Henderson et al. 1998). Hydraulic fracturing of wells is a common practice to improve productivity of gas-condensate reservoirs. Modeling of gas-condensate wells with a hydraulic fracture requires taking into account non-Darcy flow. Gas velocity inside the fracture is three to four orders of magnitude higher than that in the matrix. Use of Darcy's law to model this flow can overestimate the productivity improvement. Therefore, it is necessary to use Forchheimer's equation to model this flow with an appropriate non-Darcy coefficient that takes into account the gas-relative permeability and water saturation.

scholarly journals Hydraulic Fracturing Designs For Low Permeability Gas Condensate Reservoirs Having Lean and Rich Condensate Compositions

2017 ◽  
Vol 3 (3) ◽  
pp. 9
Author(s):  
Karanthakarn Mekmok ◽  
Jirawat Chewaroungroaj
Keyword(s):  
Hydraulic Fracturing ◽  
Gas Condensate ◽  
Dew Point ◽  
Well Productivity ◽  
Fracture Conductivity ◽  
Gas Condensate Reservoirs ◽  
Point Pressure ◽  
Condensate Blockage ◽  
Dew Point Pressure ◽  
Saturation Profile

Gas condensate reservoirs have been challenging many researchers in petroleum industry for decades because of their complexities in flow behavior. After dew point pressure is reached, gas condensate will drop liquid out and increase liquid saturation near wellbore vicinity called condensate banking or condensate blockage. Hydraulic fracturing in horizontal direction has been proved to be a reliable method to mitigate condensate blockage and increase productivity of gas condensate well by means of pressure redistribution in the near wellbore vicinity. In this paper the parameters of dimensionless fracture conductivity and Stimulated Reservoir Volume (SRV) designs of lean and rich condensate compositions are studied. Well productivity and saturation profile of each design had been observed. The results from this study indicate that the higher dimensionless fracture conductivity gives the higher well productivity in every studied parameter in lean condensate composition. However, in rich condensate composition shows different trend of results because it has higher heavy ends (C7+) that drop into liquid easier once pressure falls below dew point pressure. The maximum number of fracture and fracture permeability can be recognized in the study of rich condensate. In the study of SRV indicates that number of fracture is superior to fracture width in both gas and condensate productivity. Moreover, performing hydraulic fracturing can decrease pressure drawdown, production time and liquid dropout which leads to the mitigation of condensate banking near wellbore that can be recognized in the study of condensate saturation profile.

scholarly journals Gas Production from Gas Condensate Reservoirs Using Sustainable Environmentally Friendly Chemicals

2019 ◽  
Vol 11 (10) ◽  
pp. 2838 ◽  
Author(s):  
Amjed M. Hassan ◽  
Mohamed A. Mahmoud ◽  
Abdulaziz A. Al-Majed ◽  
Dhafer Al-Shehri ◽  
Ayman R. Al-Nakhli ◽  
...  
Keyword(s):  
Thermochemical Treatment ◽  
Environmentally Friendly ◽  
Gas Production ◽  
Gas Condensate ◽  
Absolute Permeability ◽  
Tight Gas ◽  
Hydrocarbon Production ◽  
Gas Condensate Reservoirs ◽  
Tight Gas Reservoir ◽  
The Impact

Unconventional reservoirs have shown tremendous potential for energy supply for long-term applications. However, great challenges are associated with hydrocarbon production from these reservoirs. Recently, injection of thermochemical fluids has been introduced as a new environmentally friendly and cost-effective chemical for improving hydrocarbon production. This research aims to improve gas production from gas condensate reservoirs using environmentally friendly chemicals. Further, the impact of thermochemical treatment on changing the pore size distribution is studied. Several experiments were conducted, including chemical injection, routine core analysis, and nuclear magnetic resonance (NMR) measurements. The impact of thermochemical treatment in sustaining gas production from a tight gas reservoir was quantified. This study demonstrates that thermochemical treatment can create different types of fractures (single or multistaged fractures) based on the injection method. Thermochemical treatment can increase absolute permeability up to 500%, reduce capillary pressure by 57%, remove the accumulated liquids, and improve gas relative permeability by a factor of 1.2. The findings of this study can help to design a better thermochemical treatment for improving gas recovery. This study showed that thermochemical treatment is an effective method for sustaining gas production from tight gas reservoirs.

scholarly journals Effect of a synthesized anionic fluorinated surfactant on wettability alteration for chemical treatment of near-wellbore zone in carbonate gas condensate reservoirs

2020 ◽  
Vol 17 (6) ◽  
pp. 1655-1668 ◽  
Author(s):  
Iman Nowrouzi ◽  
Amir H. Mohammadi ◽  
Abbas Khaksar Manshad
Keyword(s):  
Surface Tension ◽  
Contact Angle ◽  
Pressure Drop ◽  
Chemical Treatment ◽  
Gas Condensate ◽  
Reservoir Rock ◽  
Wettability Alteration ◽  
Fluorinated Surfactant ◽  
Gas Condensate Reservoirs ◽  
Condensate Blockage

AbstractThe pressure drop during production in the near-wellbore zone of gas condensate reservoirs causes condensate formation in this area. Condensate blockage in this area causes an additional pressure drop that weakens the effective parameters of production, such as permeability. Reservoir rock wettability alteration to gas-wet through chemical treatment is one of the solutions to produce these condensates and eliminate condensate blockage in the area. In this study, an anionic fluorinated surfactant was synthesized and used for chemical treatment and carbonate rock wettability alteration. The synthesized surfactant was characterized by Fourier transform infrared spectroscopy and thermogravimetric analysis. Then, using surface tension tests, its critical micelle concentration (CMC) was determined. Contact angle experiments on chemically treated sections with surfactant solutions and spontaneous imbibition were performed to investigate the wettability alteration. Surfactant adsorption on porous media was calculated using flooding. Finally, the surfactant foamability was investigated using a Ross–Miles foam generator. According to the results, the synthesized surfactant has suitable thermal stability for use in gas condensate reservoirs. A CMC of 3500 ppm was obtained for the surfactant based on the surface tension experiments. Contact angle experiments show the ability of the surfactant to chemical treatment and wettability alteration of carbonate rocks to gas-wet so that at the constant concentration of CMC and at 373 K, the contact angles at treatment times of 30, 60, 120 and 240 min were obtained 87.94°, 93.50°, 99.79° and 106.03°, respectively. However, this ability varies at different surfactant concentrations and temperatures. The foamability test also shows the suitable stability of the foam generated by the surfactant, and a foam half-life time of 13 min was obtained for the surfactant at CMC.

The impact of pertinent parameters on the design of hydraulic fracturing in gas condensate reservoirs

2005 ◽  
Author(s):  
Gustavo Adolfo Carvajal ◽  
Ali Danesh ◽  
Mahmoud Jamiolahmady ◽  
Mehran Sohrabi
Keyword(s):  
Hydraulic Fracturing ◽  
Gas Condensate ◽  
Gas Condensate Reservoirs ◽  
The Impact
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