Development of a training simulator for the gas production and gathering system of an offshore gas condensate field

The authors created a geodynamical polygon on the Komsomolsk oil and gas condensate field to ensure the industrial safety of oil and gas production facilities. The aim of its creation is mul-tiple repeated observations of recent deformation processes. Analysis and interpretation of the results of geodynamical monitoring which includes class II leveling, satellite observations, radar interferometry, exploitation parameters of field development provided an opportunity to identify that the conditions for the formation of recent deformations of the earth’s surface is an anthropogenic factor. The authors identified the relationship between the formation of subsidence trough of the earth’s surface in the eastern part of the field with the dynamics of accumulated gas sampling and the fall of reservoir pressures along the main reservoir PK1 (Cenomanian stage).

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Case Study of Condensate Dropout Effect in Unconventional Gas/Condensate Reservoirs with Hydraulically Fractured Wells

10.2118/205252-ms ◽

2022 ◽

Author(s):

Ali H. Alsultan ◽

Josef R. Shaoul ◽

Jason Park ◽

Pacelli L. J. Zitha

Keyword(s):

Gas Production ◽

Gas Condensate ◽

Dew Point ◽

Productivity Index ◽

Large Reservoir ◽

Unconventional Gas ◽

Gas Condensate Reservoirs ◽

Liquid Saturation ◽

Reservoir Volume ◽

Fracture Performance

Abstract Condensate banking is a major issue in the production operations of gas condensate reservoirs. Increase in liquid saturation in the near-wellbore zone due to pressure decline below dew point, decreases well deliverability and the produced condensate-gas ratio (CGR). This paper investigates the effects of condensate banking on the deliverability of hydraulically fractured wells producing from ultralow permeability (0.001 to 0.1 mD) gas condensate reservoirs. Cases where condensate dropout occurs over a large volume of the reservoir, not only near the fracture face, were examined by a detailed numerical reservoir simulation. A commercial compositional simulator with local grid refinement (LGR) around the fracture was used to quantify condensate dropout as a result of reservoir pressure decline and its impact on well productivity index (PI). The effects of gas production rate and reservoir permeability were investigated. Numerical simulation results showed a significant change in fluid compositions and relative permeability to gas over a large reservoir volume due to pressure decline during reservoir depletion. Results further illustrated the complications in understanding the PI evolution of hydraulically fractured wells in "unconventional" gas condensate reservoirs and illustrate how to correctly evaluate fracture performance in such a situation. The findings of our study and novel approach help to more accurately predict post-fracture performance. They provide a better understanding of the hydrocarbon phase change not only near the wellbore and fracture, but also deep in the reservoir, which is critical in unconventional gas condensate reservoirs. The optimization of both fracture spacing in horizontal wells and well spacing for vertical well developments can be achieved by improving the ability of production engineers to generate more realistic predictions of gas and condensate production over time.

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

Technology audit and production reserves ◽

10.15587/2706-5448.2021.225603 ◽

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.

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Simulation of a gas-condensate mixture passing through a porous medium in depletion mode

Russian Family Doctor ◽

10.17816/rfd10663 ◽

2019 ◽

Vol 27 (3) ◽

pp. 205-216

Author(s):

Alina V. Volokhova ◽

Elena V. Zemlyanaya ◽

Vladimir V. Kachalov ◽

Victor S. Rikhvitsky ◽

Vadim N. Sokotushchenko

Keyword(s):

Experimental Data ◽

Porous Medium ◽

Nonlinear Partial Differential Equations ◽

Gas Production ◽

Gas Condensate ◽

Darcy Law ◽

Gas Condensation ◽

Combined Use ◽

Multicomponent Gas ◽

Production Regime

One of important tasks in a development of gas-condensate fields is to minimize hydrocarbons loss arising from the gas condensation in pores of the gas-bearing layer. The search for the optimal gas production regime is carried out both on the basis of laboratory experiments and on the base of computer simulation. In this regard, the relevant is the verification of the constructed mathematical models by means of comparison of numerical results with experimental data obtained on the laboratory models of a hydrocarbon reservoirs. Within the classical approach on the basis of the Darcy law and the law continuity for flows, the model is formulated that describes the passing a multicomponent gas-condensate mixture through a porous medium in the depletion mode. The numerical solution of the corresponding system of nonlinear partial differential equations is implemented on the basis of the combined use of the C++ programming language and the Maple software. Shown that the approach used provides an agreement of results of numerical simulations with experimental data on the dynamics of hydrocarbon recoverability depending on the pressure obtained at VNIIGAZ, Ukhta.

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Aspects of protection against carbon dioxide corrosion of gas production facilities

E3S Web of Conferences ◽

10.1051/e3sconf/201912102013 ◽

2019 ◽

Vol 121 ◽

pp. 02013 ◽

Cited By ~ 3

Author(s):

Dmitry Zapevalov ◽

Ruslan Vagapov

Keyword(s):

Carbon Dioxide ◽

Gas Production ◽

Gas Condensate ◽

Safe Operation ◽

Hydrocarbon Production ◽

Stage Of Development ◽

The Media ◽

Technical Solutions ◽

Intensive Development ◽

Production Facilities

The modern stage of development of many onshore and offshore gas and gas condensate fields is associated with objects in which carbon dioxide (CO2) gas is present in the production. The presence of CO2 in the produced gas in combination with other factors stimulates the intensive development of corrosion processes, which requires careful and reasonable attitude both to assess the degree of aggressiveness of the media and to choose technical solutions to ensure reliable and safe operation of hydrocarbon production facilities. The authors analyzed the existing approaches to the assessment of the danger of corrosion produced media, selection and implementation of protection against corrosion in the presence in them of aggressive CO2.

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Specifics of Implemented Development System of Shtormove Field Black Sea Offshore

10.2118/208534-ms ◽

2021 ◽

Author(s):

Mykhailo Mykytovych Bahniuk ◽

Vitaliy Mykolaiovych Vladyka ◽

Oleh Stepanovych Hotsynets ◽

Oleksandra Olehivna Dmyshko ◽

Maksym Volodymyrovych Dorokhov ◽

...

Keyword(s):

Estimation Method ◽

Gas Production ◽

Gas Condensate ◽

Reservoir Rock ◽

Rock Properties ◽

Well Testing ◽

Reservoir Properties ◽

Water Contact ◽

Thin Sections ◽

Development System

Abstract The development system of the main hydrocarbon deposit of the Shtormove field was designed taking into account the change in reservoir rock properties in horizontal and vertical sections of the gas-saturated interval. Based on the results of core analyses and interpretation of logging data from exploration and appraisal wells, maximum porosity values were assigned to the top part of the deposit, with lower porosity values assigned closer to the gas-water contact area. The analyzed thin sections demonstrated vertical and subvertical fractures, as well as multiple pores and dissolution vugs. Most of the fractures occur in the top part of the gas-condensate deposit. Natural fractures in the rocks of the productive interval were confirmed by well testing using a steady flow analysis. Taking into account the determined reservoir properties’ distribution pattern in the gas-condensate deposit II, the wells were drilled in the top part of the deposit from a fixed offshore platform during the pilot development period. During this period, the estimated recoverable gas reserves’ values matched the values obtained using the volumetric estimation method. In the following years, in order to increase the gas recovery rate, the infilling production wells were drilled in the top part of the deposit. Based on the analysis of the development, it was determined that the addition of new wells had little effect on the performance of existing ones. As a result, attributable to infill drilling in the top part of the deposit, the annual gas production increased. Given the similarity of the geological model and distribution of reservoir properties, the implemented development system of the Shtormove field should be recommended for new development targets.

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