Strategy of water-flooding enhancement for low-permeable polymictic reservoirs

Palyanitsina, Aleksandra; Tananykhin, Dmitry; Riazi, M.R.

doi:10.5937/jaes0-29693

Cited by 4 publications

(4 citation statements)

References 17 publications

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“…5,6 Moreover, up to 50% of Bazhenov's organic matter is kerogen, which is capable of in situ synthetic oil production only through the application of additional stimulation. 7,8 Although waterflooding could potentially be effective in lowand ultra-low-permeability reservoirs, 9,10 other oil recovery agents should lead to a better result, especially for tight reservoirs with mosaic hydrophobization. 11 Various enhanced oil recovery (EOR) techniques can be applied for the efficient extraction of shale oil.…”

Section: Introductionmentioning

confidence: 99%

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Enhanced Oil Recovery Method Selection for Shale Oil Based on Numerical Simulations

et al. 2021

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As unconventional reserves, oil shale deposits require additional oil recovery techniques to achieve favorable production levels. The efficiency of a shale reservoir development project is highly dependent on the application of enhanced oil recovery (EOR) techniques. There are many studies devoted to discrete investigations of each EOR method. Most of them claim that one particular method is particularly effective in increasing oil recovery. Despite the wealth of such research, it remains hard to say with certainty which technique would be the most effective when applied in the extraction of unconventional reserves. In this work, we aim to answer this question by means of a comparative study. Three EOR methods were applied and analyzed in the same environment, a single target objectan oil field in Western Siberia characterized by ultra-low permeability (0.03 mD on average) and high organic content. Methods involving huff-and-puff injection of a surfactant solution, hydrocarbon gas, and hot water were studied using numerical reservoir simulations based on preceding laboratory experiments. A single horizontal well having undergone nine-stage hydraulic fracturing was used as the field site model. The comparative calculations of cumulative oil production over an 8-year period revealed that the injection of hot (supercritical) water led to the highest oil recovery in the target shale reservoir. Each EOR method was implemented using the best operation scenario. All three cases resulted in an increase in cumulative oil production compared to the depletion mode, though the efficiency was distinctly different. Twenty-six percent more oil was obtained after hot water injection, 16% after hydrocarbon gas, and 12% after a surfactant solution. Simulation of a hot water huff-and-puff operation over a longer period (43 years) led to a level of oil production 3 times higher than depletion. The drawbacks of each EOR method on the shale site are discussed in the results. A possible solution was proposed for preventing the negative effects of heat loss and water blockage incurred from hot water injection. The comparative study concludes that hot water injection should lead to the highest volume of oil recovery. The conclusions drawn are suggested to be relevant for similar shale fields.

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Section: Introductionmentioning

confidence: 99%

“…Although waterflooding could potentially be effective in low- and ultra-low-permeability reservoirs, , other oil recovery agents should lead to a better result, especially for tight reservoirs with mosaic hydrophobization . Various enhanced oil recovery (EOR) techniques can be applied for the efficient extraction of shale oil.…”

Section: Introductionmentioning

confidence: 99%

Enhanced Oil Recovery Method Selection for Shale Oil Based on Numerical Simulations

et al. 2021

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“…The ratio of fluids in the pycnometers corresponds to the given parameters of the testi.e., during the experiment, water/"oil" 30/70, the ratio of liquids in the pycnometer was taken as such [44]; • Mass of sand that is left in the installation was not measured or evaluated; • Densities of "oil" and brine were measured once at the beginning of the test.…”

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confidence: 99%

Experimental Evaluation of the Multiphase Flow Effect on Sand Production Process: Prepack Sand Retention Testing Results

et al. 2022

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This paper considers a field with high-viscosity oil in a terrigenous weakly consolidated reservoir (sandstone) with a massive gas cap and an aquifer. The major challenge in the field operation is the migration of solid sand particles into the well, accompanied by a breakthrough of water and/or gas. The goal of the investigation was to evaluate the degree of influence on the sanding process of water and gas shares in the produced fluid and to determine the effect of pressure drop. The research methodology is based on a series of filtration experiments on small-sized bulk reservoir models. Particle size distribution of bulk models was created in accordance with that of the reservoir. The experiments were made in the form of Prepack Sand Retention Tests (SRT). Gas breakthrough allows sand production on a relatively high level for a longer amount of time, even though the concentration of solids in the produced fluid is lower than that of water breakthrough. On the other hand, water breakthrough triggers higher sand production, but it rapidly decreases as time goes on. Retained permeability of the model-screen system from the drawdown pressure (pressure gradient) and phase distribution of the flow were investigated. Moreover, a methodology has been developed for conducting filtration tests on bulk reservoir models to evaluate the efficiency of different screens (wire-wrapped screens, in particular).

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“…management [1][2][3]. Factors influencing the final ECD value include: static density; rheological parameters of the fluid; well design and profile; drilling mode; drill pipes used and bottomhole assembly; bit type (number and cross-section of each hydraulic nozzle); temperature profile of the well; chemical composition of the mud [4][5][6][7].…”

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confidence: 99%

Study on the rheological properties of barite-free drilling mud with high density

Leusheva

Alikhanov

Brovkina

2022

PMI

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Improved drilling and reservoir penetration efficiency is directly related to the quality of the drilling mud used. The right choice of mud type and its components will preserve formation productivity, stability of the well walls and reduce the probability of other complications. Oil and gas operators use barite, less often siderite or hematite weighting agent as a weighting component in the composition of drilling muds for the conditions of increased pressure. But the use of these additives for the penetration of the productive formation leads to the reduction of filtration characteristics of the reservoir, as it is almost impossible to remove them from the pore channels. Therefore, barite-free drilling mud of increased density based on formic acid salts with the addition of carbonate weighting agent as an acid-soluble bridging agent is proposed. The results of experimental investigations on rheological parameters of barite-free solutions are given and the obtained data are analyzed. Based on the comparison of results it is recommended to use high-density drilling mud on the basis of formic acid salts (sodium and potassium formate) and with the addition of partially hydrolyzed polyacrylamide with molecular mass of 27 million.

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Strategy of water-flooding enhancement for low-permeable polymictic reservoirs

Cited by 4 publications

References 17 publications

Enhanced Oil Recovery Method Selection for Shale Oil Based on Numerical Simulations

Enhanced Oil Recovery Method Selection for Shale Oil Based on Numerical Simulations

Experimental Evaluation of the Multiphase Flow Effect on Sand Production Process: Prepack Sand Retention Testing Results

Study on the rheological properties of barite-free drilling mud with high density

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