Production assessment of low production rate of well in a supergiant gas condensate reservoir: application of an integrated strategy

Azin, Reza; Sedaghati, Hassan; Fatehi, Rouhollah; Osfouri, Shahriar; Sakhaei, Zahra

doi:10.1007/s13202-018-0491-y

Cited by 13 publications

(9 citation statements)

References 45 publications

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“…For calculation we choose without pump option. We take the value of the pressure depression on the layer dP = 1 MPa [29]. This pressure difference for different geological sections corresponds to the difference in geodetic heights between the geothermal reservoir and the object of development 1500-2500 m, and the energy estimate of E water mech is:…”

Section: Research Results and Discussionmentioning

confidence: 99%

Geothermal heat use to eliminate hydrate formations in oil deposit injection wells

et al. 2021

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The article is devoted to an actual issue: the development of internal downhole heat exchangers technology to combat hydration in injection wells. Purpose: development of conceptual solutions for the use of geothermal coolant in the internal well heat exchanger of the injection well. A scheme of an internal downhole heat exchanger with a geothermal heat carrier has been developed, and includes a supply line of a geothermal carrier through the heat exchange surface of the injection well into the productive reservoir of the oil field. The scheme provides targeted utilization of thermobaric energy of a geothermal source to combat hydration in the injection well. A mathematical apparatus for describing the process of heat utilization and heat exchange in injection well is proposed. It is established that the capacity of one geothermal well discovered at the oil depths in the Dnipro-Donetsk basin is sufficient to eliminate hydration in 1-3 injection wells, and determines the feasibility of their joint work.

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Section: Research Results and Discussionmentioning

confidence: 99%

Geothermal heat use to eliminate hydrate formations in oil deposit injection wells

et al. 2021

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“…However, they demonstrate tendencies and potential to compare the functions under study [14]. In addition to the modeling experiment with the use of mathematical tools (1)(2)(3)(4)(5)(6)(7)(8)(9)(10)(11)(12)(13)(14)(15)(16), full-scale studies were carried out on the basis of Lanivske gas condensate deposit. In this context, wellhead temperatures of the produced gas fluid were measured for the period of 2006-2015.…”

Section: Figure 4 the Predicted Pressures Within The Productive Formation And A Wellhead Of Lanivske Gas Condensate Deposit For 50 Years:mentioning

confidence: 99%

“…A process of design of geothermal deposits as well as oilgas full-scales involves the use of both standard and specified techniques forecasting the basic production parameters. After bringing into operation, long-term operation, and repair, wells need determination of possible rational performance modes which stipulates the necessity of constant improvement of calculation techniques for operating parameters of a well and fluid yield [1]. The latter is determined with the help of a number of factors; first of all, it concerns hydrocarbons inflow to well bottom zone and operating mode of intra formational filtration.…”

Section: Introductionmentioning

confidence: 99%

“…Equation of gas condensate mixture inflow from the drained area of a productive formation to a well bottom is entered up with the use of such filtration coefficients as A, B, and C generally determining natural gas output per certain period [1] ; K ng = 2 (for gaseous fluid), and K ng = 1(for fluids). SI system has been used in formula (1) and henceforth.…”

Section: Introductionmentioning

confidence: 99%

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Modeling of the lifting of a heat transfer agent in a geothermal well of a gas condensate deposit

Fyk¹,

Biletsky²,

Abbood³

et al. 2020

Min. miner. depos.

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Purpose is to develop mathematical model of nonisothermal inflow and lifting of the recovered gaseous mixture (i.e. geothermal fluid) of a well taking into consideration dynamic coefficient of heat transfer and thermal diffusion coefficient; fluid expansion coefficient in terms of nonadiabatic process; effect of average integral environmental temperature on the heat transfer coefficient; changes in molar mass of the fluid during the well operation; and a process of the productive seam cooling during initial development stages (i.e. months-years). Methods of material and energy balance of fluid-heat flows within a productive formation and within a well as well as forecasting of geothermal fluid production; numerical methods of fluid thermal gas dynamics; Runge-Kutta 4 th order method; and Quazi-Newton method to solve nonlinear equations have been applied. Findings. It has been demonstrated that thermal gradient of rocks and thermal carrier-rock heat exchange vary depending upon operation modes of the formation and the well in terms of temperature effect, temperature difference in humidity, viscosity, compressibility, and other rock characteristics determining efficiency of thermal diffusion as well as coefficient of heat exchange between the fluid and rocks. Originality. The specified equations of thermal energy balance in terms of radial filtration and well product lifting have been developed. The equations are more preferable to compare with the current calculation technique, where a coefficient of fluid is expanded in a seam in the context of nonadiabatic process, and consideration of effect of average integral environment temperature of the heat transfer strength (the known methods takes into account geometric mean of the formation temperature). Actual changes in molar mass of the produced geothermal fluid during the whole period of the well operation (i.e. up to 50 years) are involved. Thermal gas dynamic model well inflow-lifting has been improved owing to the consideration of a transient process of the productive formation cooling during the initial stage of the geothermal fluid production (i.e. months-years). Practical implications. The developed mathematical model helps specify calculation of a well yield by 10-15%. To compare with the standard methods, the model makes it possible to perform 20-30% specification of heat output by a gas condensate well in terms of thermobaric intensification of the fluid production as well as in terms of binary techniques of fluidgeoheat generation.

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“…Several empirical and analytical correlations have been developed to estimate the pressure drop in multiphase flow depending on the reservoir and well conditions. The selection of an optimum correlation is essential to estimate the pressure drop along the tubing [21]. In this study, the multiphase flow simulator, PROSPER, will be used to calculate the pressure gradient along the inside of the tubing.…”

Section: Tubing Pressure Calculationsmentioning

confidence: 99%

Hybrid Model for Determining Dual String Gas Lift Split Factor in Oil Producers

et al. 2019

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Upstream oil production using dual string completion, i.e., two tubing inside a well casing, is common due to its cost advantage. High pressure gas is employed to lift the oil to the surface when there is insufficient reservoir energy to overcome the liquids static head in the tubing. However, gas lifting for this type of completion can be complicated. This is due to the operating condition where total gas is injected into the common annulus and then allowed to be distributed among the two strings without any surface control. High uncertainties often result from the methods used to determine the split factor—the ratio between the gas lift rate to one string over the total gas injected. A hybrid model which combined three platforms: the Visual Basics for Application programme, PROSPER (a nodal analysis tool) and Excel spreadsheet, is proposed for the estimation of the split factor. The model takes into consideration two important parameters, i.e., the lift gas pressure gradient along the annulus and the multiphase pressure drop inside the tubing to estimate the gas lift rate to the individual string and subsequently the split factor. The proposed model is able to predict the split factor to within 2% to 7% accuracy from the field measured data. Accurate knowledge of the amount of gas injected into each string leads to a more efficient use of lift gas, improving the energy efficiency of the oil productions facilities and contributing toward the sustainability of fossil fuel.

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Production assessment of low production rate of well in a supergiant gas condensate reservoir: application of an integrated strategy

Cited by 13 publications

References 45 publications

Geothermal heat use to eliminate hydrate formations in oil deposit injection wells

Geothermal heat use to eliminate hydrate formations in oil deposit injection wells

Modeling of the lifting of a heat transfer agent in a geothermal well of a gas condensate deposit

Hybrid Model for Determining Dual String Gas Lift Split Factor in Oil Producers

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