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Copyright of Natural Gas Geoscience is the property of Natural Gas Geoscience and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Iran is the second largest oil and gas producer among the Persian Gulf states, with 13.26 billion m3 gas flaring in 2020, approximately 9.34% of the global gas flaring. To reduce pollutants emissions and energy loss, an accurate feasibility study of flare gas recovery technologies is needed as the first step. Multi-objective optimization of process structure for the development of a comprehensive flare gas recovery system based on process simulation has not attracted much attention in the literature. In this study, a process structure for a flare gas recovery system was proposed using a multi-objective optimization approach to decrease associated gas flaring in southern Iran with a current flaring capacity of 279.7 MMSCFD. In the proposed structure, associated gas goes through sweetening and Natural Gas Liquids (NGL) units. After separating the liquid and vapor products, the NGL outlet gas is allocated to different units, including reinjection of gas to oil wells, gas pipelines, Liquefied Natural Gas, Compressed Natural Gas, Gas to Liquid, Gas to Power, and Desalination units. These units were simulated in Aspen HYSYS, providing an accurate economic and environmental analysis. Afterward, the shares of NGL outlet gas allocated to downstream units were considered optimization variables. The process structure was optimized by maximizing the economic (net present value) and environmental (greenhouse gas emission) objective functions. Results show that in the optimized process structure, 93.4% of the NGL outlet gas is allocated to gas injection and 6.6% to the power generation unit, resulting in a reduction of 6.22 million tons of CO2 emissions per year in this oilfield. The net present value of the flare gas recovery system is approximately 1.504 billion dollars, with a payback period of 1.60 years, suggesting the feasibility of the process.

An engine modelling study was conducted to investigate the relative change in performance and emissions of a 4-stroke, spark-ignition engine using Iraqi Associated Petroleum Gas as fuel. The research was done using a well-verified simulation software Diesel-RK. The data available for Ricardo E6/T variable compression ratio spark-ignition engine was used to conduct this study. The performance of the engine using associated petroleum gas was compared with those for gasoline, natural gas, and the average properties of the natural gas in Europe. The performance parameters studied were engine power, thermal efficiency, oxides of nitrogen, unburned hydrocarbon, and carbon monoxide levels. The study showed that the Iraqi associated petroleum gas could not be used "as is" if the aim is to cut down pollution. The main advantage is the absence of sulfur in the gas, which is present in the gasoline used in Iraq. There is a significant rise in NOx levels, a reduction in UHC, and also a rise in CO levels when using APG fuel. Further, there is an average reduction in engine power of about 10% with the associated gas compared with gasoline. At the same time, the only gain is the reduction in SFC and improvement in thermal efficiency with the new fuel. [ABSTRACT FROM AUTHOR]

Liquefied petroleum gas (LPG) is a C3/C4's hydrocarbon mixture used as fuel gas, obtained through natural gas processing or crude oil refining. The Ecuadorian LPG production (~1.88 MMbbl/year) comes from the Shushufindi gas plant and the Esmeraldas refinery. However, LPG production cannot meet the Ecuadorian market demand, and over 90% of this commodity is imported. At the same time, the natural gas produced in the Amazon region is not fully valued. A significant quantity of the associated gas is flared (~100 MMscfd), representing wasted energy with a significant environmental impact. Therefore, this study aimed to develop a technical and economic assessment of the potential natural gas valuation in the Amazon region to increase LPG production. The study started with a detailed review of the associated gas produced in the Amazon region. The data were analyzed considering the geographic location of the hydrocarbon fields, molar composition, flowrates, and operational conditions. Then, a natural gas value chain visualization was proposed and technically analyzed. Finally, an economic feasibility (class V) study was conducted, considering a preliminary analysis of capital expenditure (CAPEX) and an economic balance. The outcome of this study showed that by processing 21.50 MMscfd of associated gas from the Sacha field, domestic LPG production could increase by 30.9%. The required infrastructure consists of conventional processes for natural gas processing, with an estimated CAPEX of 36.6 MMUSD. Furthermore, despite the domestic subsidies of commodities, the potential savings for the country would be 32.13 MMUSD/year, an alternative more economically viable than the current LPG imports. Thus, the investment cost will be justified. [ABSTRACT FROM AUTHOR]

Copyright of Revista Fuentes, El Reventón Energético is the property of Universidad Industrial de Santander and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Generally the oil between SAGD oil production station and the joint station is transmitted by pumping, with high energy consumption, significant loss and safety hazards. At the stage of steam chamber expansion in SAGD development, there is a great amount of associated gas stably generated, which make it possible to realize self-pressurized oil transmission. Therefore, a study was conducted on the self-pressurized oil transmission tech- nology for SAGD production station. The original gathering and transmission technology was optimized on the basis of high and stable gas cap pressure of the buffer tank in SAGD production station, and self-pressurized oil transmission was enabled without any external force. The technology can bring about such economic and social benefits as low cost, high profit, staff reduction and improved efficiency. This technology has been stably applied in three stages of SAGD development: steam chamber expansion, stable oil drainage and initial steam chamber decline, providing technical support for the promotion and application of SAGD development technology. [ABSTRACT FROM AUTHOR]

This paper evaluates Nigeria’s commitment to ending gas flaring within the context of the global quest for zero routine flaring by 2030. The combination of strategies deployed by Nigeria has been generally ineffective in inducing compliance from IOCs. The ineffectiveness is linked to both Nigeria’s weak institutional framework and the unattractiveness of economic payoffs associated with investing in gas-gathering infrastructure by IOCs. Using data from secondary sources, the paper locates the non-realization of flare-out dates in the disconnect between legal enactments and economic permutations, especially in view of the huge capital outlay required to develop gas-gathering infrastructure and the uncertainty surrounding the gas market. The paper contends that achieving zero gas flaring in 2020 as planned by Nigeria or 2030 as projected by the international community will entail going beyond present operational arrangements by adopting a holistic implementation strategy that is capable of extracting unconditional compliance from IOCs.

The Jurassic Yan'an Formation (J1y) crude oil-associated gas in the Pengyang area of the Ordos Basin contains a certain amount of H2S. The study of its genesis is important for us to predict the distribution of H2S in Mesozoic in the basin. The Chang7 source rock of the Yanchang Formation (T3y) is the principal source of crude oil in the Jurassic Yan'an Formation area. However, H2S is not detected in the crude oil-associated gas of Chang10 to Chang3 members of the Yanchang Formation. As a result, the formation of H2S in the crude oil-associated gas of Yan'an Formation may be related to reservoir and accumulation factors. The study shows that Jurassic formation water has a high salinity and is rich in divalent sulfur, which inhibits the development of sulfate-reducing bacteria (SRB). It is less likely to biologically reduce sulfate to produce H2S. The δ34S values of H2S in crude oil-associated gas of Yan'an Formation are greater than 25‰, which are obviously different from those of volcanic hydrothermal fluid, organic matter, and microbial reduction products, but similar to divalent sulfur isotope values in formation water and about 10‰ negative to sulfate ion in formation water. TSR has generated sulfur isotope distribution and fractionation characteristics in H2S. The temperature measurement of reservoir inclusions in the Jurassic Yan'an Formation shows that the initial filling temperature of oil and gas is higher than 100 °C, and the maximum accumulation forming temperature is 150 °C. The formation water of Yan'an Formation contains a large number of sulfate ions from anhydrite or buried stage. Those rich sulfate ions meet the conditions for a sulfate thermochemical reduction reaction. At the same time, the rich magnesium ions in formation water catalyzed the reaction. Therefore, H2S in Jurassic crude oil-associated gas in the Pengyang area of the Ordos Basin has thermochemical sulfate reduction (TSR) genesis.

A key feature of small-scale associated gas utilization schemes is the possibility for increasing carbon efficiency by various means. The paper reviews the methods of preparation of syngas and its components as well as organization of Compact technological schemes for conversion of natural and associated gas into premium synthetic liquid fuels (GTL), use of which will significantly reduce carbon footprint. Production of eco-friendly aviation fuels based on kerosene obtained by Fischer-Tropsch (SAF FT-SPK - Sustainable Aviation Fuel Fischer-Tropsch Paraffinic Kerosene) single-stage carbon dioxide hydrogenation process is promising. [ABSTRACT FROM AUTHOR]

The paper reviews the catalysts and the main methods used for implementation of natural and associated petroleum gas dehydroaromatization process and methods for separating gaseous products mixture, and describes membrane reactors, reactors with fluidized, moving, and fixed catalyst beds used for implementation of natural and associated petroleum gas dehydroaromatization process. [ABSTRACT FROM AUTHOR]

Copyright of Natural Gas & Oil is the property of Editorial Department of Natural Gas & Oil and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Due to the existence of the associated gas, the spiral weld of a pipeline in Tahe Oilfield was cracked.In order to clarify the failure reason of spiral weld of the pipeline and provide effective guidance for future pipeline corrosion control, the macro morphology of the cracked part of the spiral weld of the associated gas pipeline, the part far away from the weld and the material surface at both ends of the defect were observed, respectively.The composition of material was analyzed by fluorescence spectrometer.The micro morphology and element components of the cracked part were observed and analyzed by scanning electron microscope and X-ray energy dispersive spectrum, and the cracking reason of the spiral weld of the associated gas pipeline were analyzed.Results showed that the fracture of the associated gas pipeline was the result of hydrogen induced cracking(HIC)and sulfide stress corrosion cracking(SSCC)caused by high content of H2S in the associated gas in the pipeline.The middle of the fissure(i.e.the widest part)was the starting point of the crack.

Liquefied petroleum gas (LPG) is a C3/C4’s hydrocarbon mixture used as fuel gas, obtained through natural gas processing or crude oil refining. The Ecuadorian LPG production (~1.88 MMbbl/year) comes from the Shushufindi gas plant and the Esmeraldas refinery. However, LPG production cannot meet the Ecuadorian market demand, and over 90% of this commodity is imported. At the same time, the natural gas produced in the Amazon region is not fully valued. A significant quantity of the associated gas is flared (~100 MMscfd), representing wasted energy with a significant environmental impact. Therefore, this study aimed to develop a technical and economic assessment of the potential natural gas valuation in the Amazon region to increase LPG production. The study started with a detailed review of the associated gas produced in the Amazon region. The data were analyzed considering the geographic location of the hydrocarbon fields, molar composition, flowrates, and operational conditions. Then, a natural gas value chain visualization was proposed and technically analyzed. Finally, an economic feasibility (class V) study was conducted, considering a preliminary analysis of capital expenditure (CAPEX) and an economic balance. The outcome of this study showed that by processing 21.50 MMscfd of associated gas from the Sacha field, domestic LPG production could increase by 30.9%. The required infrastructure consists of conventional processes for natural gas processing, with an estimated CAPEX of 36.6 MMUSD. Furthermore, despite the domestic subsidies of commodities, the potential savings for the country would be 32.13 MMUSD/year, an alternative more economically viable than the current LPG imports. Thus, the investment cost will be justified.

Flare volume measurement has been the sole yardstick for tracking flare gas reduction progress and provides a single view of monitoring in the context of its use. In this study, an alternative method was introduced to broaden the perspective of flare gas monitoring. Flaring intensity is a simple and effective measure for tracking flare gas reduction. Flaring Intensity index was applied in different levels of flare volume estimation, namely Oilfield, Oil Company, Petroleum Upstream Contract and Country. Nigerian Petroleum Production data were sourced from regulatory reports and satellite data from 2012 to 2015 and 2018 annual reports. The results revealed that Nigeria’s flaring intensity is on the decline due to exogenous factors and it illustrates flaring intensity as a comparative and benchmarking tool for gas flare performance at various hydrocarbon production levels. The study also inferred that improved flare gas measurement, transparency in reporting, robust regulation and increased gas handling infrastructure were necessary in order to mitigate flaring in Nigeria to achieve the 2030 Zero Routine Flaring target.

Copyright of Petroleum Geology & Recovery Efficiency is the property of Petroleum Geology & Recovery Efficiency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Objectives Solve the problems such as liquid blocking of tower caused by amine solution foam and the excessive H2S content in purification gas during the desulfurization process of high sulfur-containing associated gas produced by Sinopec Northwest Oilfield Branch. Methods Industrial application test study of purification of amine solution used in associated gas desulfurizing with inorganic membrane process was carried out after analyzing the problems existing in the production process and their causes. Results The analysis results showed that accumulation of solid particles and oily sludge in amine solution and emulsified oil droplets formed by condensation of heavy hydrocarbons in associated gas during absorption were the main causes of foaming and low absorption efficiency of amine solution. The industrial test result of amine solution purification with inorganic membrane cross-flow filtration process showed that the mass concentrations of oil and solid in the purified amine solution were both reduced by more than 95%, and the polluted inorganic membrane could recover flux by cleaning. The desulfurization process conditions were optimized after amine solution purification. The mass fraction of amine solution increased from 32% to 40%, the H2S mass concentration in purified natural gas reduced to less than 10 mg/m³, and the energy consumption of the system reduced more than 25%. Conclusions After the application of amine solution purification with inorganic membrane process in associated gas desulfurizing process, the foaming performance of amine solution was significantly reduced, the liquid blocking phenomenon was eliminated, and the problem of excessive H2S content in liquid blocking tower and purification gas caused by amine solution foaming was solved, and the desulfurization efficiency was improved. The successful application of this process in the desulfurization process of complex associated gas with high sulfur content can provide reference for similar devices. [ABSTRACT FROM AUTHOR]

The NW Greater Caucasus and surrounding areas have a long history of petroleum production dating back to the mid‐19th century. However the origin of the oil and gas is still a matter of debate. This paper focusses on a study area to the north of the western Greater Caucasus covering the West and East Kuban Basins and neighbouring structural highs where oil and natural gas occur in reservoir units of Neogene, Paleogene, Cretaceous and Jurassic ages. The study is based on the results of organic geochemical and stable carbon isotope analyses of 21 samples of associated gases from 16 oil fields. The gas samples' compositions were investigated together with the δ13C values of C1 to C5 alkanes. Twenty of the gas samples were of thermogenic origin and one was mixed (thermogenic and secondary microbial). δ13C values for CH4 for all the gas samples varied over a wide range from ‐62.3 to ‐30.0 ‰, indicating major variations in the thermal maturity of the respective source rocks. In a previous study, three genetic types of oil were identified in the study area and are referred to here as Types 1, 2 and 3. Gaseous hydrocarbons associated with Type 1 oils were generated by source rocks in the Middle Eocene Kuma Formation and the Oligocene (lower) part of the Maikop Group which are inferred to have been deposited in anoxic, deep‐marine conditions. C2–C5 alkanes in gases associated with Type 1 oils have the lowest (most negative) δ13C values of the samples studied, and the lowest iso‐butane: n‐butane and iso‐pentane: n‐pentane ratios. These gas samples were recovered from wells in oilfields located in the south and SE of the West Kuban Basin, in the Akhtyrskaya fault zone which extends along the northern flank of the Greater Caucasus foldbelt. Higher δ13C values of C2–C5 alkanes were found in gas samples associated with Type 2 oils which were recovered from wells in the central West Kuban Basin. The associated source rocks are interpreted to have been deposited in weakly oxidizing subaqueous conditions and to contain mainly marine organic matter but with an input of higher land plant material. The precise age and stratigraphic identity of the source rocks is unresolved but they may comprise the Upper Oligocene – Lower Miocene (middle and upper) part of the Maikop Group. In gases associated with Type 3 oils, δ13C values of ethane to pentane are similar to those of gases associated with Type 2 oils. These gases were recovered from wells in oilfields located on the Adygeya Swell which divides the southern East and West Kuban Basins and from the Armavir‐Nevinnomyssk Swell to the north. The precise source of these gases and oils is not known but the oils are probably older than Late Cretaceous on account of the absence of oleanane. [ABSTRACT FROM AUTHOR]

The Jurassic Yan'an Formation (J1y) crude oil-associated gas in the Pengyang area of the Ordos Basin contains a certain amount of H2S. The study of its genesis is important for us to predict the distribution of H2S in Mesozoic in the basin. The Chang7 source rock of the Yanchang Formation (T3y) is the principal source of crude oil in the Jurassic Yan'an Formation area. However, H2S is not detected in the crude oil-associated gas of Chang10 to Chang3 members of the Yanchang Formation. As a result, the formation of H2S in the crude oil-associated gas of Yan'an Formation may be related to reservoir and accumulation factors. The study shows that Jurassic formation water has a high salinity and is rich in divalent sulfur, which inhibits the development of sulfate-reducing bacteria (SRB). It is less likely to biologically reduce sulfate to produce H2S. The δ34S values of H2S in crude oil-associated gas of Yan'an Formation are greater than 25‰, which are obviously different from those of volcanic hydrothermal fluid, organic matter, and microbial reduction products, but similar to divalent sulfur isotope values in formation water and about 10‰ negative to sulfate ion in formation water. TSR has generated sulfur isotope distribution and fractionation characteristics in H2S. The temperature measurement of reservoir inclusions in the Jurassic Yan'an Formation shows that the initial filling temperature of oil and gas is higher than 100 ◦C, and the maximum accumulation forming temperature is 150 ◦C. The formation water of Yan'an Formation contains a large number of sulfate ions from anhydrite or buried stage. Those rich sulfate ions meet the conditions for a sulfate thermochemical reduction reaction. At the same time, the rich magnesium ions in formation water catalyzed the reaction. Therefore, H2S in Jurassic crude oil-associated gas in the Pengyang area of the Ordos Basin has thermochemical sulfate reduction (TSR) genesis. [ABSTRACT FROM AUTHOR]

Copyright of Special Oil & Gas Reservoirs is the property of Special Oil & Gas Reservoirs Editorial Office and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Machine learning (ML) approaches have risen in popularity for use in many oil and gas (O&G) applications. Time series-based predictive forecasting of hydrocarbon production using deep learning ML strategies that can generalize temporal or sequence-based information within data is fast gaining traction. The recent emphasis on hydrocarbon production provides opportunities to explore the use of deep learning ML to other facets of O&G development where dynamic, temporal dependencies exist and that also hold implications to production forecasting. This study proposes a combination of supervised and unsupervised ML approaches as part of a framework for the joint prediction of produced water and natural gas volumes associated with oil production from unconventional reservoirs in a time series fashion. The study focuses on the pay zones within the Spraberry and Wolfcamp Formations of the Midland Basin in the U.S. The joint prediction model is based on a deep neural network architecture leveraging long short-term memory (LSTM) layers. Our model has the capability to both reproduce and forecast produced water and natural gas volumes for wells at monthly resolution and has demonstrated 91 percent joint prediction accuracy to held out testing data with little disparity noted in prediction performance between the training and test datasets. Additionally, model predictions replicate water and gas production profiles to wells in the test dataset, even for circumstances that include irregularities in production trends. We apply the model in tandem with an Arps decline model to generate cumulative first and five-year estimates for oil, gas, and water production outlooks at the well and basin-levels. Production outlook totals are influenced by well completion, decline curve, and spatial and reservoir attributes. These types of model-derived outlooks can aid operators in formulating management or remedial solutions for the volumes of fluids expected from unconventional O&G development. [ABSTRACT FROM AUTHOR]

Copyright of Natural Gas Geoscience is the property of Natural Gas Geoscience and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Globally, 150–170 billion cubic metres of gas are being flared annually from petroleum refineries, petrochemical industries and from landfills. In this paper, we critically review the flaring technology, the impact of flare gas on the environment, and recovery options. We also discuss flare gas challenges such as technical, structural, economic, and regulatory challenges. We found that ground flaring is preferred whenever the facility is situated in a highly populated area or close to an aviation zone. Gas flaring produces major pollutants including benzene, benzopyrene and toluene. The recovery of this gas should be intensified to minimise impacts. [ABSTRACT FROM AUTHOR]

In the crude oil recovery industries, explosion accidents involving associated gases can often result in fatal damage. The main purpose of this study is to provide theoretical support and engineering background for the SAGD operations in the extra-heavy oil reservoirs. To investigate the explosive behavior of CH4/C2H6/C3H8 gases and the inhibition mechanism of CO2 gas, the authors have experimentally studied the factors influencing the explosion behavior of the associated gas in a standard-designed 20 L spherical explosion vessel at ambient temperature and pressure. Based on experimental data, they analyzed the explosive parameters of the combustible gas mixtures, including the explosive peak pressure, time to reach the maximum pressure, the velocity of flame propagation, upper explosive limit (UEL), and lower explosive limit (LEL). The results show that a small amount of C2H6/C3H8 could promote the explosive characteristics of CH4. The addition of CO2 gas has a different inhibitory effect on the explosive behavior of CH4/C2H6/C3H8. The explosive overpressure strength of the CH4/C2H6/C3H8 gas mixture decreases with increase in the CO2 concentration. When the CO2 gas is added to the extra-heavy-oil associated gas, the flame propagation velocity of the CH4/C2H6/C3H8 mixture explosion decreases accordingly. Due to the inert effect of the CO2 gas, with the continuous addition of CO2 to the mixture, the UEL parameter of CH4/C2H6/C3H8 decreases linearly and the LEL parameter increases exponentially. The results of the study are important for eliminating potential risks and providing safety management of the SAGD operations at the extra-heavy oil reservoirs. [ABSTRACT FROM AUTHOR]

In this paper, we consider the issue of thermo-chemical heat recovery of waste heat from gas turbine engines for the steam conversion of associated gas for offshore vessels. Current trends in the development of offshore infrastructure are identified, and the composition of power plants for mobile offshore drilling units and FPSO vessels is analyzed. We present the results of a comparison of power-to-volume ratio, power-to-weight ratio and efficiency for diesel and gas turbine power modules of various capacities. Mathematical modeling methods are used to analyze the parameters of an alternative gas turbine unit based on steam conversion of the associated gas, and the estimated efficiency of the energy module is shown to be 50%. In the modeling of the burning processes, the UGT 25000 serial low emission combustor is considered, and a detailed analysis of the processes in the combustor is presented, based on the application of a 35-reaction chemical mechanism. We confirm the possibility of efficient combustion of associated gas steam conversion products with different compositions, and establish that stable operation of the gas turbine combustor is possible when using fuels with low calorific values in the range 7–8 MJ/kg. It is found that the emissions of NOx and CO during operation of a gas turbine engine on the associated gas conversion products are within acceptable limits.

Improved designs of vertical adsorbers for the separation of butane mixtures are presented. The utilization of these designs at chemical and oil and gas enterprises will improve efficiency of implementation of technological processes for the separation of gas mixtures by increasing the adsorption capacity of the adsorbent. [ABSTRACT FROM AUTHOR]

The theory of branched-chain processes, created by the founder of the Russian school of chemical physics, Nikolai Nikolaevich Semenov, has become the foundation of modern ideas about the mechanism of gas-phase hydrocarbon conversion processes and the base for a deep understanding of the phenomena occurring in many related fields. However, throughout the 20th century, the chemical processing of hydrocarbon gases remained a secondary area of petroleum chemistry, since liquid petroleum hydrocarbons were the main hydrocarbon feedstock. A radical change in the situation after the start of industrial development of huge unconventional natural gas resources made it necessary to create cost-effective technologies for processing cheaper and more accessible gaseous hydrocarbons into basic petrochemical products. This article discusses new non-catalytic methods for processing hydrocarbon gases, developed at the Institute of Problems of Chemical Physics, Russian Academy of Sciences (IPCP RAS) and the Federal Research Center for Chemical Physics, Russian Academy of Sciences, and promising areas of their application. [ABSTRACT FROM AUTHOR]

The paper considers the issue of thermo-chemical recovery of engine’s waste heat and its further use for steam conversion of the associated gas for oil and gas floating units. The characteristics of the associated gas are presented, and problems of its application in dual-fuel medium-speed internal combustion engines are discussed. Various variants of combined diesel-gas turbine power plant with thermo-chemical heat recovery are analyzed. The heat of the gas turbine engine exhaust gas is utilized in a thermo-chemical reactor and a steam generator. The engines operate on synthesis gas, which is obtained as a result of steam conversion of the associated gas. Criteria for evaluating the effectiveness of the developed schemes are proposed. The results of mathematical modeling of processes in a 14.1 MW diesel-gas turbine power plant with waste heat recovery are presented. The effect of the steam/associated gas ratio on the efficiency criteria is analyzed. The obtained results indicate relatively high effectiveness of the scheme with separate high and low pressure thermo-chemical reactors for producing fuel gas for both gas turbine and internal combustion engines. The calculated efficiency of such a power plant for considered input parameters is 45.6%.

Flaring of gases often having a high heating value results in considerable economic and energy losses in addition to significant environmental impacts. Power generation through combined gas and steam turbine cycles may be considered as a suitable flare gas recovery process. Thermal desalination of seawater is a process that requires a considerable amount of heat; hence, it may be used in the downstream section of power generation cycles. Energy is the largest part of the cost of the water generation of all desalination processes. The energy cost of the thermal distillation of seawater is close to 50%-60% of the water generation costs. In the current study, the generation of power and desalinated water through the gas turbine cycle, steam cycle, and multistage flash (MSF) method using the flare gases of Cheshmeh Khosh is investigated. The economic parameters related to the different scenarios considered for the production of power and water are evaluated in this work. According to the economic evaluation carried out, the most economically profitable scenarios for the investigated cogeneration plant is generating as much as possible power in the steam turbine and using the remaining heat in the low-pressure outlet steam for the MSF desalination process. The results show that by increasing the steam turbine outlet pressure from 3 to 78 bar, the power generation and the water generation change from 697 to 581 MW and from 1557 to 2109 m3/h respectively. Also, by increasing the outlet pressure of the steam turbine from 3 to 78 bar, the total capital cost increases from 1177 to $1192 million, and the operating cost changes from 117.85 to $117 million per year. Finally, the operating profit decreases from 300 to $50 million per year, and the payback period extends from 3.92 to 4.75 years. [ABSTRACT FROM AUTHOR]

An engine modelling study was conducted to investigate the relative change in performance and emissions of a 4-stroke, spark-ignition engine using Iraqi Associated Petroleum Gas as fuel. The research was done using a well-verified simulation software Diesel-RK. The data available for Ricardo E6/T variable compression ratio spark-ignition engine was used to conduct this study. The performance of the engine using associated petroleum gas was compared with those for gasoline, natural gas, and the average properties of the natural gas in Europe. The performance parameters studied were engine power, thermal efficiency, oxides of nitrogen, unburned hydrocarbon, and carbon monoxide levels. The study showed that the Iraqi associated petroleum gas could not be used "as is" if the aim is to cut down pollution. The main advantage is the absence of sulfur in the gas, which is present in the gasoline used in Iraq. There is a significant rise in NOx levels, a reduction in UHC, and also a rise in CO levels when using APG fuel. Further, there is an average reduction in engine power of about 10% with the associated gas compared with gasoline. At the same time, the only gain is the reduction in SFC and improvement in thermal efficiency with the new fuel. [ABSTRACT FROM AUTHOR]

Some information is provided on industrial use of butane. Methods of its separation from gas mixtures are discussed. A new design of a device for adsorptive separation of gases is proposed. A notable difference of the design of the proposed adsorber from the existing designs is inclusion of a device for generating vibrations in the bulk of the loaded adsorbent, which reduces the loading density in the lower section of the adsorber. This technical solution helps improve the quality of butane separation from butane fraction and separate effectively other gas mixtures as well. [ABSTRACT FROM AUTHOR]

In the Northwest oilfield, there were some problems for high sulfur-containing associated gas during the desulfurization and purification of dimethylethanolamine ( MDEA) solution, such as frequent liquid blocking and flushing tower and the hydrogen sulfide concentration in the purified gas over-standard, etc. The analysis results showed that the high heavy hydrocarbon content in the associated gas system was one of the causes which led to the amine solution foaming and lo>v tray efficiency. A new- counter current low back mixing spray state tray structure ( SDST) based on the principle of spray state was proposed and designed. The hydraulic test results showed that compared to the Fl float valve tray, the SDST pressure drop could be reduced by 10 %, the flux could be increased by 30 %, and the operation flexibility was basically unchanged. The industrial application results of SDST trays in associated gas desulfurization process showed that SDST tray has a good foaming suppression performance, which can effectively solve the problem of liquid blocking and flushing tower in associated gas desulfurization process, and at the same time increase the plate efficiency by more than 1 Cl%, and also effectively solve the problem of hydrogen sulfide concentration over-standard in the purified gas caused by the low tray efficiency during the associated gas desulfurization process. [ABSTRACT FROM AUTHOR]

Copyright of Roa Iktissadia Review is the property of Roa Iktissadia Review and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

The application of degassed oil instead of recombined oil model for a slim tube technique was investigated. It is found that the use of degassed oil is not recommended for modeling and studying of gas and oil miscibility under typical conditions of Western Siberia deposits. The previously estimated miscibility of light oil and associated gas was confirmed in case of application of recombined oil model or degassed oil at displacement from a slim tube. This occurs because of a gradual transition from the mode of immiscible displacement to the mode of limited-mixing displacement of oil and further to the mode of complete mixing as a result of the mass exchange of light oil and associated gas. [ABSTRACT FROM AUTHOR]

Naphthides are widely distributed on the Earth and are found in separate locations in the gas, liquid, semi-solid and solid states or in as a mixture of these phases. We adhere to the abiogenic theory of the formation of naphthides by deep mantle fluids. The mantle fluids along deep faults move and penetrate into the Earth crust, where they form naphthide systems. Based on the idea of the mantle origin of oil, it was shown that nitrogen found in gaseous mantle liquids participates in the formation of naphthides. Using the geoecological evolving organised index, the role of nitrogen in the stabilisation of naphthides is estimated. It has been established that in the series of natural gases → gas condensate fields → synthesis gas → associated gas → oil, the index of geoecological evolution and organisation increases. It is shown that the presence of nitrogen in natural gas condensate, in associated petroleum gases and in synthesis gas leads to stabilisation of the system in the direction of order. For oil, the Geo-ecological evolving organised index tends to unity, which indicates that when oil is formed in the trap mainly from the mantle high-energy fluid, the structural organisation of the oil reservoir is in equilibrium. Along with other geo-information methods and technologies, it is recommended to use an index of geo-ecological evolution and organisation to assess the maturity of oil fields. [ABSTRACT FROM AUTHOR]

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Nigeria has recently issued the Flare Gas (Prevention of Waste & Pollution) Regulations 2018. Its objective is to completely phase out gas flaring which has persisted notwithstanding several efforts to encourage associated gas utilisation and discourage the process. This work assesses the Regulations in light of enabling legislation, particularly the Petroleum Act 1969 and the Associated Gas (Reinjection) Act 1979 to address questions that arise regarding some of its innovative aspects such as the taking of all flare gas by the Federal Government of Nigeria and a new permits regime to enable third-party investors access to petroleum lease areas to effect the taking of the flare gas. It argues that public interest is at the heart of the Regulations and considering enabling legislation and previous case law, justifies its provisions given the pollution and economic waste ill-effects of gas flaring. [ABSTRACT FROM AUTHOR]

The prospects for creating low-volume-production technologies for reforming of natural and associated gases to liquid carbon-containing products based on the use of cheap nitrogen-rich synthesis gas have been analyzed. Processes for obtaining cheap nitrogen-rich synthesis gas and sustainable high-performance synthesis of liquid products based on it have been considered. Data on the conversion of nitrogen-rich synthesis gas to methanol, dimethyl ether, and higher hydrocarbons are presented. The main advantages of using nitrogen-rich synthesis gas have been pointed out, which are the capability of reformers to operate on-site, no need for expensive cryogenic devices for air separation, and reduction of the explosion risks during production. [ABSTRACT FROM AUTHOR]