scholarly journals The application of nitrogen to increase gas recovery from depleten gas deposits

2018 ◽  
pp. 7-16
Author(s):  
R. М. Kondrat ◽  
L. I. Khaidarova
Keyword(s):  
Natural Gas ◽  
Gas Production ◽  
Hydrocarbon Gases ◽  
Research Results ◽  
Industrial Experience ◽  
Gas Recovery ◽  
Nitrogen Injection ◽  
Production Wells

The research results on residual natural gas displacement from depleted gas deposits by various non-hydrocarbon gases are analyzed. The use of nitrogen for this purpose is proved. The research results and industrial experience in obtaining nitrogen from air and purifying nitrogen from the products of gas production wells in case of nitrogen injection into depleted gas deposits to increase gas recovery are summarized.

scholarly journals THE EFFECT OF THE CYCLICAL NITROGEN INJECTION ON THE FINAL COEFFICIENT OF GAS RECOVERY AT DIFFERENT RATES IN THE DEPLETED GAS RESERVOIR

2018 ◽  
pp. 15-22
Author(s):  
R. M. Kondrat ◽  
L. I. Khaidarova
Keyword(s):  
Gas Production ◽  
Reservoir Pressure ◽  
Hydrocarbon Gases ◽  
Gas Reservoir ◽  
Recovery Coefficient ◽  
Research Results ◽  
Gas Recovery ◽  
Nitrogen Injection ◽  
Residual Gas ◽  
Depleted Gas Reservoir

The application of non-hydrocarbon gases with the aim of displacing residual gas from depleted fields is substantiated. Mathematical modeling is carried out of the process of residual gas displacing with nitrogen in the GEM compositional simulating module under the conditions of a hypothetical gas reservoir of circular shape. The said module is a part of the licensed CMG computer program. The effect of the cyclical nature of the aquifer injection nitrogen into depleted gas reservoir at different rates till the final gas recovery coefficient for residual gas is developed. The study concerns different durations of nitrogen injection cycles into the reservoir (6, 12, 18, 24, 30, and 36 months) and various correlations of the rates of nitrogen injection and gas production in reservoir conditions of 1:1; 1.5:1; 2:1. During the nitrogen injection into the reservoir, the output wells stopped; whereas after surcease of the nitrogen injection, they were again exploited until the reservoir pressure reached to 0.1 Pprimary. Then the process of cyclic nitrogen injection into the layer continued, until nitrogen break through into the producing wells and its content in the produced products reached 5% vol. The research results were processed in the form of graphical dependencies of reservoir pressure, gas flow rate and gas recovery coefficient for residual gas at the end of the cycle of nitrogen injection into the reservoir as a function of the number of such cycles. The research results indicate a significant effect on the gas recovery coefficient for the residual gas of the duration of the cycle of nitrogen injection into the reservoir and the ratio of rates of nitrogen injection and gas production, with an increase in which the coefficient of gas output gradually decreases. According to the research results, the optimal parameters of the process of nitrogen injection into the reservoir should be chosen on the basis of technological results, as well as technical and economic calculations.

scholarly journals Effects of the rate of natural gas production on the recovery factor during carbon dioxide injection at the initial gas-water contact

2021 ◽  
Vol 1 (3(57)) ◽  
pp. 6-11
Author(s):  
Serhii Matkivskyi
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Gas Production ◽  
Gas Condensate ◽  
Recovery Factor ◽  
Formation Water ◽  
Hydrocarbon Gases ◽  
Water Contact ◽  
Natural Gas Production ◽  
Gas Recovery

The object of research is gas condensate reservoirs, which is being developed under the conditions of the manifestation of the water drive of development and the negative effect of formation water on the process of natural gas production. The results of the performed theoretical and experimental studies show that a promising direction for increasing hydrocarbon recovery from fields at the final stage of development is the displacement of natural gas to producing wells by injection non-hydrocarbon gases into productive reservoirs. The final gas recovery factor according to the results of laboratory studies in the case of injection of non-hydrocarbon gases into productive reservoirs depends on the type of displacing agent and the level heterogeneity of reservoir. With the purpose update the existing technologies for the development of fields in conditions of the showing of water drive, the technology of injection carbon dioxide into productive reservoirs at the boundary of the gas-water contact was studied using a digital three-dimensional model of a gas condensate deposit. The study was carried out for various values of the rate of natural gas production. The production well rate for calculations is taken at the level of 30, 40, 50, 60, 70, 80 thousand m3/day. Based on the data obtained, it has been established that an increase in the rate of natural gas production has a positive effect on the development of a productive reservoir and leads to an increase in the gas recovery factor. Based on the results of statistical processing of the calculated data, the optimal value of the rate of natural gas production was determined when carbon dioxide is injected into the productive reservoir at the boundary of the gas-water contact is 55.93 thousand m3/day. The final gas recovery factor for the optimal natural gas production rate is 64.99 %. The results of the studies carried out indicate the technological efficiency of injecting carbon dioxide into productive reservoirs at the boundary of the gas-water contact in order to slow down the movement of formation water into productive reservoirs and increase the final gas recovery factor.

Modeling Condensate Banking Mitigation by Enhanced Gas Recovery Methods

2021 ◽  
Author(s):  
Adel Mohsin ◽  
Abdul Salam Abd ◽  
Ahmad Abushaikha
Keyword(s):  
Natural Gas ◽  
Finite Difference ◽  
Positive Impact ◽  
Enhanced Recovery ◽  
Gas Production ◽  
Dew Point ◽  
Productivity Index ◽  
Base Case ◽  
Enhanced Gas Recovery ◽  
Gas Recovery

Abstract Condensate banking in natural gas reservoirs can hinder the productivity of production wells dramatically due to the multiphase flow behaviour around the wellbore. This phenomenon takes place when the reservoir pressure drops below the dew point pressure. In this work, we model this occurrence and investigate how the injection of CO2 can enhance the well productivity using novel discretization and linearization schemes such as mimetic finite difference and operator-based linearization from an in-house built compositional reservoir simulator. The injection of CO2 as an enhanced recovery technique is chosen to assess its value as a potential remedy to reduce carbon emissions associated with natural gas production. First, we model a base case with a single producer where we show the deposition of condensate banking around the well and the decline of pressure and production with time. In another case, we inject CO2 into the reservoir as an enhanced gas recovery mechanism. In both cases, we use fully tensor permeability and unstructured tetrahedral grids using mimetic finite difference (MFD) method. The results of the simulation show that the gas and condensate production rates drop after a certain production plateau, specifically the drop in the condensate rate by up to 46%. The introduction of a CO2 injector yields a positive impact on the productivity and pressure decline of the well, delaying the plateau by up to 1.5 years. It also improves the productivity index by above 35% on both the gas and condensate performance, thus reducing production rate loss on both gas and condensate by over 8% and the pressure, while in terms of pressure and drawdown, an improvement of 2.9 to 19.6% is observed per year.

Well Completion for Effective Deliquification of Natural Gas Wells

2011 ◽  
Vol 134 (1) ◽  
Author(s):  
John Yilin Wang
Keyword(s):  
Natural Gas ◽  
Operating Cost ◽  
Gas Production ◽  
Gas Wells ◽  
Liquid Loading ◽  
Gas Recovery ◽  
Well Completion ◽  
Reservoir Permeability ◽  
Gas Fields ◽  
Gas Lift

Liquid loading has been a problem in natural gas wells for several decades. With gas fields becoming mature and gas production rates dropping below the critical rate, deliquification becomes more and more critical for continuous productivity and profitability of gas wells. Current methods for solving liquid loading in the wellbore include plunger lift, velocity string, surfactant, foam, well cycling, pumps, compression, swabbing, and gas lift. All these methods are to optimize the lifting of liquid up to surface, which increases the operating cost, onshore, and offshore. However, the near-wellbore liquid loading is critical but not well understood. Through numerical reservoir simulation studies, effect of liquid loading on gas productivity and recovery has been quantified in two aspects: backup pressure and near-wellbore liquid blocking by considering variable reservoir permeability, reservoir pressure, formation thickness, liquid production rate, and geology. Based on the new knowledge, we have developed well completion methods for effective deliquifications. These lead to better field operations and increased ultimate gas recovery.

scholarly journals ESTIMATION OF TECHNOLOGICAL EFFICIENCY OF WORK AND SHUTDOWN OF PRODUCTION WELLS WITH NITROGEN INJECTION INTO THE DEPLETED GAS RESERVOIR

2018 ◽  
pp. 7-11
Author(s):  
R. M. Kondrat ◽  
L. I. Khaidarova
Keyword(s):  
Group Program ◽  
Gas Reservoir ◽  
Gas Recovery ◽  
Nitrogen Injection ◽  
Technological Efficiency ◽  
Modeling Group ◽  
Production Wells ◽  
Residual Gas ◽  
Composite Modeling ◽  
Depleted Gas Reservoir

The main directions of increasing hydrocarbon output from depleted gas deposits and possible options of injecting nitrogen into the reservoir are described. For the conditions of a depleted hypothetical gas reservoir, a mathematical modeling of the process of displacement of the residual gas by nitrogen using the composite modeling module GEM, which is part of the CMG (Computer Modeling Group) program, was performed. Based on the results of the research, the effect on the gas recovery factor for the residual gas and other technical indicators was established on the development of the work and production wells shut-down zone when nitrogen was injected into the deposit with different time periods.

scholarly journals Dual hydrocarbon–geothermal energy exploitation: potential synergy between the production of natural gas and warm water from the subsurface

2019 ◽  
Vol 98 ◽  
Author(s):  
Jeroen van der Molen ◽  
Elisabeth Peters ◽  
Farid Jedari-Eyvazi ◽  
Serge F. van Gessel
Keyword(s):  
Natural Gas ◽  
Financial Risk ◽  
Net Present Value ◽  
Gas Production ◽  
Added Value ◽  
Reservoir Properties ◽  
Gas Field ◽  
Gas Recovery ◽  
Water Breakthrough ◽  
High Standards

Abstract The decline of domestic natural gas production, increasing dependency on gas imports and lagging development of renewable energy production may pose serious challenges to the current high standards of secure energy supply in the Netherlands. This paper examines synergy between hydrocarbon- and geothermal exploitation as a means to reinforce energy security. The Roden gas field is used as an example to demonstrate potential delay of water breakthrough in the gas well and a resulting increase of recovered gas (up to 19%), by positioning of a geothermal doublet in the water leg of the gas field. The reservoir simulations show that the total increase of gas production primarily depends on the amount of aquifer support. An optimal configuration of gas- and geothermal wells is key to maximise gas recovery and strongly depends on the distribution of reservoir properties. The study also reveals that this option can still be beneficial for gas fields in a late stage of production. Net Present Value calculations show that the added value from the geothermal doublet on total gas production could lead to an early repayment of initial investments in the geothermal project, thereby reducing the overall financial risk. If no subsidies are taken into account, the additional profits can also be used to finance the geothermal project up to break-even level within 15 years. However, this comes with a cost as the additional profits from improved gas recovery are significantly reduced.

An investigation of methods for calculating the volume of methane dissolved in reservoir water

2021 ◽  
pp. 103-111
Author(s):  
O. V. Fominykh ◽  
S. A. Leontiev
Keyword(s):  
Saline Water ◽  
Gas Production ◽  
Reliable Estimate ◽  
Dissolved Gas ◽  
Hydrocarbon Gases ◽  
Reservoir Water ◽  
Gas Recovery ◽  
Production Technologies ◽  
Residual Gas ◽  
Gas Fields

Existing gas production technologies limit gas recovery at the level of 85 %. Therefore, it is important to introduce technologies that make it possible to maximize the volume of production and intensify the inflow; for their selection it is important to have a reliable estimate of the residual gas reserves, since with a significant volume of the aquifer of gas fields, the volume of dissolved gas can be up to 10 % of the total reserves of the reservoir, which should be taken into account when designing the application of technologies to increase gas recovery.The main hydrocarbon dissolving in reservoir water is methane. In this regard, it is of interest to study methods that make it possible to determine the volume of hydrocarbon gases dissolved in saline water, which will make it possible to determine the total reserves of such gas. We investigated the existing methods for calculating the amount of methane dissolved in reservoir water, and gave a quantitative assessment of the volume of gas dissolved in water.

scholarly journals Enhanced gas recovery by nitrogen injection: The effects of injection velocity during natural gas displacement in consolidated rocks

2020 ◽  
Vol 83 ◽  
pp. 103513
Author(s):  
Nuhu Mohammed ◽  
Abubakar J. Abbas ◽  
Godpower C. Enyi ◽  
Donatus E. Edem ◽  
Salihu M. Suleiman
Keyword(s):  
Natural Gas ◽  
Injection Velocity ◽  
Enhanced Gas Recovery ◽  
Gas Recovery ◽  
Nitrogen Injection

scholarly journals EXTRACTION OF THE RESIDUAL GAS DEPLETED GAS RESERVOIRS NITROGEN INJECTION

2019 ◽  
pp. 20-29
Author(s):  
R. M. Kondrat ◽  
O. R. Kondrat ◽  
L. I. Khaidarova
Keyword(s):  
Porous Medium ◽  
Nitrogen Content ◽  
Physical Nature ◽  
Hydrocarbon Gases ◽  
Recovery Coefficient ◽  
Gas Recovery ◽  
Nitrogen Injection ◽  
Start Of Injection ◽  
Depleted Gas Reservoirs ◽  
Residual Gas

The relevance and feasibility of extracting residual gas from depleted gas deposits is shown. The possible directions of the extraction of residual gas from depleted gas deposits by its displacement from a porous medium of non-hydrocarbon gases are characterized. The use of nitrogen to displace natural gas from a porous medium has been substantiated. Using the GEM compositional modeling module, which is included in the licensed computer program CMG (Computer Modeling Group), studies were made of the effect of the pressure of the start of injection of nitrogen into the reservoir and the duration of its injection period on the gas recovery coefficient for residual gau. The study was conducted for deposits of square and round shape. The research results are presented in the form of graphical dependencies of the current reservoir pressure, nitrogen content in borehole products and gas recovery coefficient for residual gas from the pressure of the start of injection of nitrogen into the reservoir and the duration of the period of its injection. Using the results of the research, the optimal values ​​of the parameters of the process of injecting nitrogen into the exhausted gas deposits of square and round forms and the corresponding values ​​of the gas recovery coefficient were established. For the considered deposits of square and rounded forms, they are 0.29 Рin and 14.8 months, 0.31 Рin and 12.9 months, respectively. At the time of reaching the volumetric nitrogen content in the producing gas of 5 %, the gas recovery coefficient for residual gas for a square-shaped deposit is 83.91 %, for a round-shaped deposit – 77.49 %. The physical nature of the process of displacing residual gas with nitrogen from depleted gas deposits of square and round forms is characterized.

scholarly journals Approbation of the technology for displacing residual gas with nitrogen for the conditions of a depleted gas reservoir in the VS-9 horizon of the Lyubeshivske gas field

2020 ◽  
pp. 16-23
Author(s):  
R. M. Kondrat ◽  
L. I. Khaidarova
Keyword(s):  
Natural Gas ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Recovery Coefficient ◽  
Gas Recovery ◽  
Production Wells ◽  
Depleted Gas Reservoirs ◽  
Reser Voirs ◽  
Residual Gas ◽  
Natural Gas Reservoirs

Most natural gas reservoirs of Ukraine are depleted to some extent; still they contain significant tail gas reserves. A promising direction for increasing gas recovery from depleted gas reservoirs is the displacement of tail gas from the porous medium with nitrogen which is easily accessible and does not cause corrosion of the down-hole equipment. This article characterizes the technologies for increasing gas recovery from depleted gas reser-voirs by injecting nitrogen into them. The technology of replacing tail gas with nitrogen is tested on the example of the depleted reservoir of ND-9 horizon of Lyubeshivskyy gas field, the productive deposits of which are composed mainly of sandstones with interlayers of limestone and clay. The authors consider fifteen options of injecting ni-trogen into the reservoir, including options of treating the bottom-hole of low-production wells at the beginning of the process of further reservoir development and at the beginning of the injection of nitrogen into the reservoir. In all cases, the reservoir is first redeveloped in the depletion mode until the reservoir pressure decreases to 0,1 from the initial value. After that, nitrogen is injected into one of the producing wells which is transferred to the injection well. The injection of nitrogen into the reservoir continues until the nitrogen content in the last produc-ing well is less than 5 % vol. All options are characterized by high values of the gas recovery coefficient and close values of the dura-tion of the reservoir further development. The positions of the front of the displacement of natural gas by nitrogen at various time points are given. According to the research results, the gas recovery coefficient for tail gas for var-ious options varies from 14,12 to 34,58 %. With the introduction of the technology of injecting nitrogen into the reservoir, the overall gas recovery coefficient increases from 72,25 % (at present development system) to 80,28 % when the residual gas is displaced by nitrogen.

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